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Home My WebLink About20241341.tiffMountain Peak Power, LLC I Mountain Peak Power Project Attachment 2 11041 Submittal Application Attachment 2 Application From Mountain Peak Power Weld County 1041 Application Stanley Consultants USE BY SPECIAL REVIEW (USR) APPLICATION FOR PLANNING DEPARTMENT USE: AMOUNT $ APPLICATION RECEIVED BY DATE RECEIVED: CASE # ASSIGNED: PLANNER ASSIGNED: PROPERTY INFORMATION (Attach additional sheets if necessary.) Proposed use: Natural Gas Peaking Facility Is the property currently in violation? No / ■ Yes Violation Case Number: CI S ite Address: 10001 County Road Parcel Number: 1305 - 09 - 0 - 00 - 005 Legal Description: SE 1/4 Section: 9 Township 02 N, Range 64 W Zoning District: A Acreage: 20 Within subdivision? x No / Yes Townsite? _ No / ■ Yes ■ x If yes, subdivision or townsite name: Floodplain No / Yes Geological Hazard _ No / Yes Airport Overlay _ No / ■ Yes x ■ x ■ PROPERTY OWNER(S) (Attach additional sheets if necessary.) N ame: United Power, Inc (c/o Greg Howes) x Company: United Power, Inc Phone #: Email: ghowes@UnitedPower.com Street Address: 500 Cooperative Way City/State/Zip Code: Brighton, Colorado 80603 N ame: Company: Phone #: Email: Street Address: City/State/Zip Code: APPLICANT/AUTHORIZED AGENT (Authorization must be included if there is an Authorized Agent) N ame: Mountain Peak Power, LLC (c/o Jon Baylor) Company: Mountain Peak Power, LLC (c/o Kindle Energy LLC) Phone #: :5:-' i:- 151 mai :Jon. • ay or • in. e-energy.com Street Address: 500 Alexander Park Drive, Suite 300 City/State/Zip Code: Princeton, NJ 08540 I (We) hereby depose and state under penalties of perjury that all statements, proposals, and/or plans submitted with or contained within the application are true and correct to the best of my (our) knowledge. All fee owners of the property must sign this application. If an Authorized Agent signs, an Authorization Form signed by all fee owners must be included with the application. If the fee owner is a corporation, evidence must be included indicating the signatory has the legal authority to sign for the corporation. �i � 01/12/24 Signature Date Jon Baylor, SVP Development Signature Date Print Print Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 4 11041 Submittal Application Attachment 4 Authorization Form Mountain Peak Power Weld County 1041 Application Stanley Consultants (We), AUTHORIZATION FORM United Power, Inc. (Owner — please print) DEPARTMENTS OF PLANNING BUILDING, DEVELOPMENT REVIEW AND ENVIRONMENTAL HEALTH 1402 NORTH 17TH AVENUE PO BOX 758 GREELEY CO 80632 give permission to Mountain Peak Power, LLC (Authorized Agent/Applicant—please print) to apply for any Planning, Building, Access, Grading or OWTS permits on our behalf, for the property located at (address or parcel number) below: 10001 County Road 55, WELD COUNTY Legal Description: 8370A PT SE4 9 2 64 EEG AT SE 09 64 p of Section , Township Nt Range Subdivision Name: Property Owners Information: Address: 500 Cooperative Way, Brighton, Co 80603 Lot Block s Phone: 303-637-1234 E=mail: sbarwick@unitedpcwer corn Authorized Agent/Applicant Contact Information: Address: 500 Alexander Park Drive, Princeton, NJ 08540 Phone: 609-250-7227 E -Mail: Thomas.Flexon@kindle-energy.com Correspondence to be sent to: Owner EL Authorized Agent/Applicant � by: Mail Email, n Additional Info: • I (We) hereby certify, under penalty of perjury and after carefully reading the entire contents of this document, that the information stated above is true and correct to the best of my (our) knowledge. Date 12d1gin Owner Signature Owner Signature Subscribed and sworn to before me this day of gyctE 'B�1¢.+euic�L � L� MOD S€cto 4L 1 19Z‘49 My commission expires 07122 Date Notary Public POUACK NOTARY PUBLIC STATE OF COLORADO NOTARY ID 20224013362 My COMMISSION EXPIRES APRIL 4, 2026 20 11:3 by 11 STATEMENT OF AUTHORITY CRS 38-30-172 1. Name of the entity: United Power, Inc. 2. Mailing address of entity: 500 Cooperative Way, Brighton CO 80603 3. Type of entity: Colorado cooperative association --- i _ Corporation Registered Limited Liability Limited Partnership Limited Partnership X Nonprofit Corporation Limited Partnership Association Government or Governmental Subdivision or Agency i _ I I Limited Liability Company General Partners Trust 4. Name of person authorized to execute instruments conveying, encumbering, or otherwise affecting title to real property on behalf of the entity: Mark A. Gabriel, united Power, Inc. President & Chief Executive Officer Executed this 20 day of February - --- ` CHERI LYNNE SIMMONS Notary Public State of Colorado Notary ID # 20174030886 LPLAy Commission Expires 0744-2025 State of 6i01 county of MUMS} The foregoing instrument was acknowledged before me this A2_6460briAN 2024 , Signatory for Entity: } }ss. Witness my hand and official seal. My commission expires: (s) z twp ins z 0 vabee Signature of Authorized Agent &ay of q021I4.ar1, Notary Public 2024. by 8/7/2014 STATEMENT OF AUTHORITY CRS 38-30-172 1. Name of the entity: United Power, Inc. 2. Mailing address of entity: 500 Cooperative Way, Brighton CO 80603 s 3. Type of entity: Colorado cooperative association I 1 Corporation Registered tirn iced Liability Limited Partnership Limited Partnership x Nonprofit Corporation Limited Partnership Association Government or Governmental Subdivision or Agency • i Limited Liability Company General Partners Trust 4. Name of person authorized to execute instruments conveying, encumbering, or otherwise affecting title to real property on behalf of the entity: Steve Barwick, Land Director, United Power Inc. Executed this day of re ss. Signatory for Entity: Signature of Authorized Agent ofA ipstru ent was acknowledged before me this Witness my hand and office= I se I. co missio ex• r s: Mark A. Gabriel, United Power, Inc. President & Che Executive Officer day of 20 ANA POLLACK NOTARY PUBLIC 8/7/2014 STATE of COLORADO NOTARY ID 20224013362 MY COMMISSION EXPIRES APRIL 4, 202 Kindle Energy 500 Alexander Park — Ste 300 Princeton, NJ 08540 February 15, 2024 Via email only Maxwell Nader Kim Ogle Weld County Department of Planning Services 1402 N 17th Avenue Greeley, CO 80631 mnader@weld.gov kogald.qov Re: PRE23-0285 Completeness Review — 1041 Permit Application of Mountain Peak Power, LLC Mr. Nader and Mr. Ogle: Please accept this letter as verification of employment for Thomas Flexon who is currently an active employee with Kindle Energy Management Company LLC ("Kindle Energy"); his job title is Vice President - Development and Mr. Flexon reports to Jonathan R. Baylor, Sr. Vice President of Kindle Energy and Vice President of Mountain Peak Power, LLC. Kindle Energy LLC, an affiliate of Kindle Energy Management Company LLC, owns Mountain Peak Power, LLC ("Mountain Peak"). Mountain Peak has filed a 1041 permit application that is currently pending before Weld County. This letter confirms that Mr. Flexon is authorized to serve as the designated contact for Mountain Peak for questions or communications concerning the pending 1041 application. If you have any questions or require additional information, please contact me at 713-208-8420 or at lori.dunn@kindle-energy.com. Sincerely, Lori L. Dunn Kindle Energy Management Company LLC Vice President Human Resources Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 5 11041 Submittal Application Attachment 5 Incorporation Documents Mountain Peak Power Weld County 1041 Application Stanley Consultants Delaware The First State I, JEFFREY W. BULLOCK, SECRETARY OF STATE OF THE STATE OF DELAWARE, DO HEREBY CERTIFY THE ATTACHED IS A TRUE AND CORRECT COPY OF THE CERTIFICATE OF FORMATION OF "MOUNTAIN PEAK POWER, LLC", FILED IN THIS OFFICE ON THE SIXTH DAY OF APRIL, A.D. 2023, AT 3 : 51 O' CLOCK P . M. 7394493 8100 SR# 20231335312 You may verify this certificate online at corp.delaware.gov/authver.shtml Page 1 Authentication: 203096345 Date: 04-06-23 State of Delaware Secretary of State Division of Corporations Delivered 03:51 PM 04/06/2023 FILED 03:51 PM 04/06/2023 SR 20231335312. - File Number 7394493 CERTIFICATE ORMATION OF MOUNTAIN PEAK POWER, LLC This Certificate of Formation is being executed as of April 6, 2023, for the purpose of forming a limited liability company pursuant to the Delaware Limited Liability Company Act, 6 Del. C. § 18-101, et sect, The undersigned, being duly authorized to execute and file this Certificate of Formation, does hereby certify as follows: 1. Name. The name of the limited liability company is Mountain Peak Power, LL (the "Company"). , Registered Office and Registered Agent. The Company's registered office in the State of Delaware is located at 251 Little Falls Drive, in the City of Wilmington, New Castle County, Delaware 19808. The registered agent of the Company for service of process is Corporation Service Company located at 251 Little Falls Drive, in the City of Wilmington, New Castle County, Delaware 19808. IN WITNESS WHEREOF, the undersigned has duly executed this Certificate of Formation as of the day and year first above written. By: Al Kellie Keeling Name: Kellie Keeling Title: Authorized Person MOUNTAIN PEAK POWER, LLC INCUMBENCY CERTIFICATE The undersigned certifies that she is the Vice President and Secretary of Mountain Peak Power, LLC, a Delaware limited liability company (the "Company"), and as such she is authorized to execute this Certificate and further certifies that the following persons have been elected or appointed, are qualified, and are acting as officers of Mountain Peak Power, LLC in the capacity or capacities indicated below, and that the signatures set forth opposite their respective names are their true and genuine signatures: Name William Lee Davis Lee McFalls Brant Meleski Jonathan R. Baylor Julie Friedberg Lisa Carty Office/Title Signature President and Chief Executive Officer Chief Operating Officer Chief Financial Officer Vice President Vice President Vice President BY( osoe IN WITNESS WHEREOF, I have signed this certificate as of this 15th day of February, 2024. By: Name: Gradd Kurdian Title: Vice President and Secretary Mountain Peak fr _ lower January 18, 2024 Mr. Maxwell Nader Planning Manager Dept. of Planning Services 1402 N 17th Ave Greeley, CO 80631 Subject: 1041 Application Submittal - Mountain Peak Power Project 10001 County Road, Keenesburg, CO Dear Mr. Nader, Mountain Peak Power, LLC c/o kindle Energy I_LC 500 Alexander Park Drive Suite 300 Princeton, NJ 08540 Office: (609) 250-7702 Fax: (609) 250-7231 info@kindle-energy.com kindle-energy.com kindle-energy.corn This letter is being submitted as part of the 1041 application submittal for Mountain Peak Power, LI_C ("Mountain Peak") in relation to the Mountain Peak Power Project. The 1041 application has been prepared by Mountain Peak with specific portions provided by Holland & Hart I_I_P and Stanley Consultants, Inc, under the direction of Mountain Peak. The application package has been prepared in accordance with Weld County requirements, as described in the 1041 Use by Special Review (USR) Procedural Guide, Major Facility of a Public Utility received from Weld County Department of Planning Services. Mountain Peak is preparing to install a natural gas simple -cycle combustion turbine power generation facility (the "Project"), comprised of six General Electric ("GE") LIVI2500 Xpress power generation units with a cumulative generating capacity of 165 MW (gross). The Project will be located on property owned by United Power, Inc. ("United Power") and leased to Mountain Peak and will exclusively serve United Power's members. The Project will be interconnected to United Power's existing 69 kV transmission lines located at the existing Tesla substation located on the property. The Project will support United's transition away from previous power providers to more renewable based power sources for their cooperative members. This Letter includes the following information: 1. Applicant and preparer, including addresses and telephone numbers 2. Scope of Project 3. Site location, size, and zoning 4. Request and justification 5. Existing and proposed facilities, structures, and roads. 1041 Application Submittal - Mountain Peak Power Project Page 2 January 18, 2024 The Site Plan Drawing, is shown in Attachment 3 of this application, has been prepared in accordance with the Weld County Development Services Department Procedures Manual. Additionally, other applicable documents, analysis, plans, studies, and surveys are also provided in the attachments to this application. 1. Owner/Applicant and Preparer Owner/Applicant and Preparer Mountain Peak Power, I_I_C is the Applicant. Holland & Hart LLP and Stanley Consultants, Inc. assisted Mountain Power Peak in preparing this application. The primary contact for the Project is Mr. Thomas Flexon. He can be contacted as follows: Mr. Thomas Flexon c/o Kindle Energy I_I_C 500 Alexander Park Drive Suite 300 Telephone: (609) 250-7227 The Holland & Hart LLP contact is Ms. Jordan Bunch. She can be contacted as follows: Ms. Jordan Bunch 1800 Broadway Suite 300 Boulder, CO 80302 Telephone: (303) 473-4828 The Stanley Consultants, Inc. contact is Mr. Michael Reed. He can be contacted as follows: Mr. Michael Reed Stanley Consultants, Inc. 8000 South Chester Street, Suite 400 Centennial, CO 80112 Telephone: (303) 925-8346 2. Scope of Project Mountain Peak is proposing to construct a simple cycle natural gas fired combustion turbine (CT) power generation facility in Weld County, Colorado. The facility would be located on existing property currently owned by United Power. The property is located at the crossroads of County Road 22 and County Road 55 in Weld County, Colorado. The current access point to the property is from County Road 55, on the southeast corner of the site. * Mountain Peak Power 1041 Application Submittal - Mountain Peak Power Project Page 3 January 18, 2024 The Project originated with United Power's desire for reliable, natural gas based, power generation. United Power is currently transitioning to more renewable based power generation for their source of electrical power. Renewable based power generation is an intermittent resource, subject to both weather conditions and power demands placed on the grid. Intermittent resources are complemented by alternative resources that provide reliability and stability to the grid, such as peaking power plants, which are flexible and reliable. A peaking power plant, known for having fast start capabilities, only runs when demand is required by the grid. The proposed combustion turbines can provide power very quickly as each can be online within 10 minutes or less. Although the design is for a gross output of 165 MW, the plant can operate at lower loads based on how many units are dispatched at any given time. It is expected that the entire plant will operate less than 25% annually. The role of the Mountain Peak units will be to allow United Power to source more renewable based power while utilizing state of the art, fast -response combustion turbines to support the reliability of their power grid. This Project, combined with United Power's transition to more renewable energy resources, will help reduce the environmental profile of United's current supply portfolio, support the energy demand growth of United Power, and help provide stable pricing for cooperative members. The Project will produce power utilizing combustion turbine generators (GE LM2500 Xpress) ("CTG"). Each CTG uses a dry low NOx emission oxidation combustion system to reduce nitrogen oxide ("NOx") emissions production during natural gas combustion. In addition to the dry low NOx combustion technology, each CTG unit will be equipped with a Selective Catalytic Reduction (SCR) system that will further reduce NOx emissions from the flue gas prior to exiting the CTG stack. The SCR utilizes 19% aqueous ammonia as the reagent in the catalytic conversion of NOx emissions to nitrogen and oxygen. The 19% aqueous ammonia is supplied by an on -site 20,000 -gallon ammonia storage and forwarding system with containment and truck unloading pad. The LM2500 Xpress is GE's state of the art aeroderivative-based combustion turbine generator for both efficiency and emissions. Additionally, the LM2500 Xpress also provides fast -start capabilities and the ability for multiple daily starts and stops. GE has developed this CTG package to complement power grids that are experiencing increased renewable energy penetration. Each LM2500 Xpress CTG package is considered a unit. Each unit will consist of three main modules: (i) The Turbine Module, (ii) the Generator Module, and (iii) the Control House Module. The LM2500 Xpress CTG is a two -shaft aeroderivative design with the combustion turbine separate from the power turbine. This mechanically decoupled design allows the power turbine to operate at a continuous speed allowing for startup to full load in less than 10 minutes. The main deck of the generator module contains the generator, generator ventilation, generator lube oil system and switchgear. The turbines will utilize pipeline quality natural gas. /� Mountain Peak Power 1041 Application Submittal - Mountain Peak Power Project Page 4 January 18, 2024 Each unit is equipped with an 80 -foot exhaust stack. Each exhaust stack includes a Selective Catalytic Reduction (SCR) to control NOx and a Catalytic -Oxidation (CatOx) to control Carbon Monoxide (CO) and Volatile Organic Compound (VOC) emissions. The SCR utilizes 19% aqueous ammonia injection to reduce NOx emissions. An Ammonia Storage and Forwarding system will store and supply ammonia to the SCRs at each CTG exhaust stack. Each exhaust stack will be equipped with a 40 CFR Part 60 / 75 continuous emissions monitoring system (CEMS) providing monitoring of CO emissions, NOx emissions, and fuel flow. The extractive sampling system will also include an O2 analyzer for diluent and reporting purposes. Each CEMS will be in a prefabricated climate -controlled enclosure with a sample handling system, analyzers, calibration gases and a data acquisition and handling system. The Project will connect to United's existing 69 kV transmission system on the site with no additional infrastructure required outside of the site boundaries. Each CTG produces power at 13.8 kV which is fed to a Generator Step -Up (GSU) transformer that converts the power to 69 kV. This 69 kV power is then connected to United Power's transmission system. The connection to 69 kV transmission system will occur on the north side of the existing Tesla Substation with new high voltage disconnects and circuit breakers. Each CTG will have a separate GSU and separate connection to the 69 kV service. This will allow the facility to serve a range of loading to United Power's electrical grid based on the power demand at any particular time. The Project will be fueled by natural gas connected by an [8"] natural gas lateral pipeline that will connect the Project to the Colorado Interstate Gas ("CIG") pipeline that runs parallel to the property line along County Road 55. No other infrastructure or utilities from adjacent properties or the surrounding areas will be required for operation of the facility. A gas meter yard is planned for the northeast corner of the site. This is where CIG will supply natural gas to the facility. Natural gas received from the yard will go through a knockout drum to remove any moisture and will be preheated prior to supplying each combustion turbine. See Attachment 33 of the 1041 application for copy of Applicant's Synthetic Minor Source Air Permit application submitted to the Colorado Department of Public Health and Environment ("CDPHE"). This submission request with the CDPHE is for a permit to construct the six (6) new natural gas fired turbines and the accompanying Air Pollution Emission Notice (APEN) and APCD Form 102 in accordance with the 5 Code of Colorado Regulations (CCR) 1001-5, Regulation No. 8 (Colo. Reg. 3), Part B, Section II. The permit is seeking to obtain a minor source air permit via establishment of enforceable limits to permit emissions of NOx and VOC. The Project will require certain Balance of Plant ("BOP") equipment to support both the plant operations and emergencies. A skidded compressed air system is consisting primarily of an * Mountain Peak Power 1041 Application Submittal - Mountain Peak Power Project Page 5 January 18, 2024 air compressor skid with dryer and storage tank will be implemented to support plant operations. For fire protection, a 125,000 gallon fire water storage tank will be connected to a fire pump skid that provides pressurized fire water to an underground fire water loop. The fire water loop will encircle the plant and have fire hydrants spaced according to National Fire Protection Association (NFPA) requirements. The fire pump skid will contain an electric fire pump, a jockey pump to maintain fire loop pressure, and a backup diesel fire pump. The Fire Pump Skid also contain a small diesel fuel tank for the backup diesel fire pump, sized to National Fire Protection Association (NFPA) requirements. The Fire Water Storage Tank will include a connection to provide service water for the site, such as dust suppression needs. This service water connection will be located above the 120,000 gallon level of the Fire Water Storage tank so this volume is preserved for fire water supply. Finally, the Project will feature installation of six (6), oil -filled power transformers, each with a rating of 28.8/38.4/48 MVA, primary winding of 69 kV and secondary winding at 13.8 kV, at 60 Hz. The purpose of the transformers is to supply power from the CTGs to United Power's existing 69 kV transmission system. 3. Site Location, Size, and Zoning Site Location This site address is 10001 County Road in Weld County, approximately 20 acres inside property boundaries (the "Site"). The location of the Site and the Site features are presented in Attachments 3 (Site Plan) and 29 (USR Map - Vicinity and Area Maps). Size Construction activities at the Site will disturb approximately 13 acres, generally on the central and north side of the Site. Approximately 3 acres will be used as a temporary laydown area for equipment storage, construction employee parking, and construction trailers. The footprint of the new equipment is approximately 10 acres. Temporary equipment, such as cranes, and materials needed for construction activities (i.e., fuels, sealants, lubricating oils, paints) will also be located in the temporary laydown and fabrication areas. The location of all these areas is presented on the Site Plan provided in Attachment 3. Zoning No zoning changes are required for this Project. All construction associated with the scope of work included in this application will occur in Weld County. According to the property records, the site is zoned A (Agricultural), with use, Utility Service Facility, for the Mountain Peak Power Project. The Project will be constructed on property (Parcel # 1305-09-0-00- 005) owned by United Power. The parcel is identified in the legal description provided in * Mountain Peak Power 1041 Application Submittal - Mountain Peak Power Project Page 6 January 18, 2024 Attachment 2. There will be no changes to zoning required for the scope of work described in this application. 4. Request and justification Project Schedule The Project will be constructed per the general schedule milestones provided below: • Site mobilization and ground preparation - Late July or early August 2024 • Earthwork - August/September 2024 • Foundation work - September/October 2024 • Installation completed - April 2025 • Performance testing - May 2025 justification Mountain Peak's Project will be compatible with the allowable land uses in the areas impacted by construction. All proposed construction activities and resulting operating facilities will be located on United Power -owned land. Site selection was driven by the following considerations: • Optimization of available utility land. Ability to install a facility at property currently owned by United Power. As noted in Applicant's response to USR question 7 below, co -location with existing electric utility infrastructure was also analyzed. • Maximum utilization of existing infrastructure. The ability to use United Power's existing electrical transmission infrastructure located at the site enhances project efficiency. • Access to natural gas. Adjacent, existing natural gas pipeline can provide natural gas at required pressure and flow for CTGs. Site location minimizes the amount of pipeline installation and disruption of neighboring real property. Conformance to Weld County Comprehensive Plan The Project is in conformance with the Weld County Comprehensive Plan, which guides land use in Weld County. The Project aligns with the principles, goals, and objectives as set forth in the Weld County Comprehensive Plan, Plan Section 22-2-10, particularly the following: • Respecting Private Property Rights. One of the basic principles upon which the United States was founded is the right of citizens to own and utilize property so long as that use complies with local regulations and does not interfere with or infringe upon the rights of others. * Mountain Peak Power 1041 Application Submittal - Mountain Peak Power Project Page 7 January 18, 2024 o The Project will be located on existing property owned by United Power and does not infringe on adjacent properties. The Project will follow the principles as set forth in the Weld County Comprehensive Plan and requirements of the Weld County Code. o The Project will comply with the Weld County Code and local regulations. • Promoting Economic Growth and Stability. Land use policies have a significant impact on economic conditions in the County and should be structured to encourage economic prosperity. To ensure the continued strength of Weld County's economy, land use processes and decisions based on this plan shall be consistent and promote fiscally responsible growth. o The Project will support United Power's goal of providing new renewable energy and reliability to their grid. This includes ensuring resiliency and capacity for future growth to their members. This will ensure the power infrastructure within Weld County supports continued economic growth. • Protecting Health, Safety, and General Welfare. Land use regulations and policies will protect and enhance the health, safety, and general welfare of the citizens of Weld County. o The Project is utilizing GE's technological advanced power production turbines to provide safe, efficient, and reliable power to support United Power's grid. o The Project is working with the State (CDPHE) to ensure the plant's air permit conforms to the State's goals for future energy and power development. o The Project is currently or in the near future will be working with local agencies, local authorities having jurisdiction, and the Town of Keenesburg to ensure compliance with all health, safety, and the welfare of Weld County residents. 5. Existing and Proposed Facilities and Structures Existing Facilities and Structures Existing facilities include the United Power owned Tesla Substation and (future) Battery Energy Storage System (BESS). The Tesla Substation is connected to United Power's electrical transmission system, specifically a 69 kV transmission line. The Mountain Peak Power Project will connect directly to the 69 kV transmission lines located within the Tesla Substation fence line. The only modifications to the substation that are required are adding disconnects and circuit breakers to allow the six CTG's to connect to the 69 kV transmission system. The BESS system is expected to be finished with construction and operational prior to any site activities associated with the Mountain Peak Power Project. Mountain Peak has * Mountain Peak Power 1041 Application Submittal - Mountain Peak Power Project Page 8 January 18, 2024 coordinated with United Power and the BESS system developer to ensure neither project or facility interferes with operations across the site. This includes coordinating site layout and consolidated point of access for emergency responders. Currently, three (3) barn structures and an uninhabited trailer home are located on the Site. These structures will be removed by United Power prior to construction. Proposed Facilities and Structures The proposed facilities and structures for construction will be temporary in nature and generally consist of construction trailers, storage for construction materials, equipment, supplies and construction employee parking. Upon completion, the new structures will be the following: • Plant Control Trailer which will include a dedicated plant control room, server/computer controls hardware, and operator offices. • A small storage shed will be installed to hold approximately ten (10) 55 -gallon drums for CTG lubricating oils. The shed will include internal secondary containment for fluids and appropriate insulation/roofing/side for weather. Existing and Proposed Roads The site plan contained in Attachment 3 shows the existing road access from County Road 55 and proposed site roads for the new facility. Expected haul routes for construction are addressed in the Traffic Study in Attachment 17. Most traffic will utilize the 1-76 interchange in Keenesburg, head north to County Road 18, turn left onto County Road 18, turn right on County Road 55, then north to intersection of County Road 55 and 22. There are no new roads being proposed with this Project for either construction deliveries or other deliveries associated with facility operations. Once equipment operation commences, traffic will be generally limited to plant operators and deliveries. We look forward to your review of this 1041 Application which is critical as we look to develop this important Project to serve United Power and provide reliable power in Colorado. If you have any questions during this review process, please contact Tom Flexon at Thomas.Flexon@kindle-energy.com or Michael Reed of Stanley Consultants at (303) 925- 8346 or reedmichael®stanleygroup.com. Thank you for your consideration. Respectfully submitted, Mountain Peak Power, LI_C J. Baylor Vice President /� Mountain Peak Power Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 6 11041 Submittal Application Attachment 6 Completed Questionnaire with Responses Mountain Peak Power Weld County 1041 Application Stanley Consultants USE BY SPECIAL REVIEW (USR) QUESTIONNAIRE ANSWERS Answer the following questions on a separate sheet. If a question does not pertain to your use, please respond with "not applicable". S upplemental questions for 1041 Major Facilities of Public Utilities: 1. Describe the type of facility. Specify where applicable: Mountain Peak Power, LLC ("Mountain Peak" or "Applicant") proposes to construct a simple -cycle combustion turbine power generation facility (the "Project"), comprised of six (6) General Electric ("GE") LM2500 Xpress Combustion Turbine Generators (CTG) with a cumulative gross generating capacity of 165 MW. The Project exclusively will serve U nited Power, Inc. ("United Power") members and will be interconnected to United Power's existing 69 kV transmission system at its Tesla Substation located on the property. a. The voltages and lengths of transmission lines. • Not applicable. b. Power source and generating capacity. The Project will be fueled by natural gas. A natural gas lateral pipeline will connect the Project to the Colorado Interstate Gas ("CIG") pipeline (CIG Line 266-A) that runs parallel to the property line along County Road 55. Mountain Peak submitted an application to interconnect the Project to the CIG system on October 10, 2023. The Project's cumulative gross generating capacity is 165 MW. c. The functions and sizes of substations. The Project will interconnect to United Power's existing 69 kV transmission system at its Tesla Substation located on the property. d. The capacities of storage tanks and types of petroleum derivative to be stored. One (1) 150 -gallon ultra -low sulfur diesel fuel tank for the emergency Fire Pump Skid diesel fire pump operation. • One (1) 20,000 -gallon 19% aqueous ammonia storage tank with containment and truck unloading pad • Approximately 550 gallons of lubricating oils to be stored in an area that will have secondary containment. e. Corridor locations. WCR22&WCR55. f. Service area. • United Power service territory. g. Resource area (e.g., source of power being generated or transmitted). The Project is a simple -cycle combustion turbine power generation facility with a cumulative gross generating capacity of 165 MW fueled by natural gas sourced from the CIG 24" pipeline located northeast of the property. h. Applicable support facilities (e.g., pollution control, parking areas, landscaping, etc.) to be provided. • Combustion Turbine Generator (GE LM2500 Xpress) ("CTG") - Each CTG uses a dry low NOx emission oxidation combustion system to reduce nitrogen oxide ("NOx") production during natural gas combustion. • Air — Each CTG is equipped with an 80 -foot exhaust stack. Each exhaust stack includes a Selective Catalytic Reduction (SCR) to control NOx and a Catalytic -Oxidation (CatOx) to control Carbon Monoxide (CO) and Volatile Organic Compound (VOC) emissions. See Attachment 33 of 1041 application for copy of Applicant's Synthetic Minor Source Air Permit application submitted to the Colorado Department of Public Health and Environment ("CDPHE"). • Balance of Plant — The facility will include a 20,000 gallon 19% aqueous ammonia storage and forwarding system to supply ammonia to SCR's for additional NOx reduction. A compressed air skid will provide compressed air to support equipment and plant operations across the site. • Fire Water — A 125,000 gallon fire water storage tank will be connected to a fire pump skid that provides pressurized fire water to underground fire water loop. The fire water loop will encircle the plant and have fire hydrants spaced according to NFPA requirements. The fire pump skid will contain and electric fire pump, a jockey pump to maintain fire loop pressure, and a backup diesel fire pump. The fire pump skid will also contain a small diesel fire tank for the backup diesel fire pump, sized to NFPA requirements. The fire water storage tank will include a connection to provide service water for the site, such as dust suppression needs. This service water connection will be located above the 120,000 gallon level of the fire water storage tank so this volume is preserved for fire water supply onl Y • Control Trailer — A permanent double -wide trailer will house two (2) operators per shift, where they will be stationed to monitor plant operations. The Control Trailer will have areas dedicate for the following: control room, operator offices, and a servers/control system hardware area. The Control Trailer will be Americans with Disabilities Act (ADA) accessible. • Parking areas — There will be parking area in front of the Control Trailer, containing eight (8) parking spots with 2 dedicated ADA parking spots. • Storage Shed — A small storage shed will be installed to hold approximately ten (ten) 55 -gallon drums for CTG lubricating oils. The shed will include internal secondary containment for fluids and appropriate insulation/roofing/side for weather. • Landscaping — Gravel is expected to be used for access roads around site and parking areas. The areas around equipment will utilize rock mulch, similar to the existing Telsa Substation. Areas where gravel or rock is not used will be returned to pre -construction state to reduce erosion and dust generation. See Attachment 20 of 1041 application for further details on landscaping plans. When necessary, dust abatement (water truck) will be utilized during normal operations for parking and roads. • Noise — Applicant has contracted a noise study (See Attachment 23) to identify compliance with Weld County noise levels measured 25' off of the property lines. The Noise Study includes an overlay of estimated sound levels into adjacent properties on Page 13. 2. Describe the projected development schedule. Specify where applicable: • Construction is projected to start in late July or August 2024 with expected Project operation commencing in May 2025. a. Estimated maximum number of employees, number of shifts and employees per shift during the construction, operation and maintenance phases of the project. Construction — Estimated 25 staff/contractor staff working between the hours of 8:00 am and 5:00 pm. Estimated completion within 8 months (weather permitting). • Operation — Two (2) operators per shift, with two (2) shifts of twelve (12) hours each. Maintenance — Activities to be conducted by the operators as necessary during operation shifts. b. Any future phases or extensions of the facility and relationship of the facility (if currently foreseen) to larger programs and plans. Not applicable. c. Timetable for planning (e.g., federal permits, other state permits, local zoning, etc.). Please see Attachment 35 for Permitting Matrix, which identifies State and Local permits and timelines the Project. d. Estimated beginning and completion of construction and beginning of operation of facility. • Construction is projected to start in July 2024 with completion expected in March 2025 (weather dependent). Commissioning and startup of the Project is expected to require two (2) months to complete with commercial operation to begin in May 2025. 3. Describe hazards and emergency procedures. Specify where applicable: See Attachment 22 of 1041 application for Emergency Response Plan. a. Hazards, if any, of fire, explosion and other dangers to the health, safety and welfare of employees and the general public. • See Attachment 22 of 1041 application for Emergency Response Plan. b. Hazards, if any, of environmental damage and contamination due to materials used at or activities taking place at the proposed facility. See Attachment 22 of 1041 application for Emergency Response Plan. c. Emergency procedures to be used in the event of fire, explosion or other event which may endanger the public health, safety and welfare. See Attachment 22 of 1041 application for Emergency Response Plan. d. Any prevalent natural hazards that will affect or be affected by development and describe mitigating measures to be taken to reduce danger due to such natural hazards. See Attachment 22 of 1041 application for Emergency Response Plan. 4. Summarize major natural and socioeconomic environmental constraints as they affect the site selection and construction of the facility as proposed. w No major natural or socioeconomic environmental constraints affect the site selection or construction of the Project as proposed. 5. Summarize the effects of the proposed site selection and construction upon the natural and socioeconomic environment of the impact area as applicable to submission requirements. Included should be an analysis of impacts upon agricultural productivity and agricultural resources and upon vested water rights. The proposed site is located within an existing utility corridor with an existing electric substation, supporting electric distribution lines on site. Oil and gas development facilities are prevalent in the immediate area. There is no anticipated impact to agricultural productivity or agricultural resources, and the Project is an allowed use. Adequate water to support agriculture does not current appear to exist and geological location is not within the local water aquifer. There is no proposed impact to vested water rights. 6. Include analysis of the long-term effects of the proposed site selection and construction upon the physical and socioeconomic development of the impact area. There are no long-term effects anticipated as a result of the proposed site selection or subsequent construction activities. The site is co -located with United Power's existing transmission and distribution infrastructure. As United Power transitions to more renewable energy resources, the Project will provide reliability to the local, electric grid enabling continued economic growth in the surrounding area. The Project will have minimal impact on United Power's existing substation and transmission infrastructure. Further, co -locating the Project with existing electrical infrastructure helps reduce additional needs required for a new substation and/or transmission infrastructure in surrounding areas. 7. Include a description of a program to minimize and mitigate adverse impacts and to maximize the positive impacts of the proposed site selection and construction. The proposed site was selected due to its location within an existing utility corridor with and co - location with an existing electric substation and supporting electric distribution lines on site. Once operational, the Project would not have adverse effects on traffic, noise, light, and odors to the surrounding areas. The site location would also not require any additional infrastructure that pose a hinderance on surrounding property and owners as no new easements or right of ways are required. The Project also does not affect existing easement or right of way holders on the property. • The Project will provide enormous positive benefits on the deployment of renewable sources of power for United Power and the surrounding areas. This will eliminate coal -burning power production that United Power previously received power from. At 10% operating capacity, the Project will also not be operational full time throughout the year. 8. Include analysis of nonstructural alternatives to the project such as conservation of energy use, no development or management (different scheduling, conservation programs, facility design, land trades, etc.), if applicable. • Based on the growth of demand within United Power's service territory, as well as its separation from the Tri-State cooperative system, United Power cannot satisfy its supply needs with conservation of energy use only. Moreover, as stated above, due to the increase in the amount of renewable generation within United Power's portfolio, the Project is necessary to provide flexible, reliable generation necessary for the support of such intermittent resources. 9. Include analysis of reasonable structural alternatives to the project such as alternate locations and routes, alternative types of facilities, use of existing rights -of -way, joint use of rights -of -way with other utilities, and upgrading of existing facilities. Site selection was driven by the following: i. Optimization of available utility land. Ability to install facility at property currently owned by United Power. As noted in Applicant's response to USR question 7. above, co -location with existing, electric utility infrastructure was also analyzed. ii. Maximum utilization of existing infrastructure. Ability to use United Power's existing electrical distribution infrastructure located at the site enhances project efficiency. iii. Access to natural gas. Adjacent, existing natural gas pipeline can provide natural gas at required pressure and flow for CTGs. Site location and co -location using United Power's existing infrastructure minimizes the amount of pipeline installation that is required for this Project. Include analysis of air and water pollution impacts and control alternatives. 3 There are no anticipated water pollution impacts as a result of the proposed facilities. Applicant's proposed Project will not discharge any process or sanitary wastewaters to waters of the State and no waters of the United States or wetlands are located within the property. As detailed in Applicant's response to USR question 1.h. above, the Project will incorporate state of the art pollution control technologies to reduce air emissions. The Project will allow United Power to decrease reliance on coal-fired power generation, thereby resulting in lower emissions and an overall net benefit to air. The Projects will also support United Power's increased reliance on renewable sources of power. 11. Include analysis of design alternatives concerning access, landscaping, architectural controls, and so forth. Access — Reuse of existing access point from WCR 55 is proposed. Access point is same as that of existing Tesla Substation. • Landscaping — Use of trees or shrubs (or other water intensive vegetation) is not viable due to the natural terrain/topography; it would be inefficient to divert the limited amount of water at the site for such uses. The planned landscaping for the project aims to preserve as much existing native grasses area as reasonably possible, this includes minimizing impacts during construction. Alternate landscaping, other than rock gravel, around equipment is not ideal as the rock gravel helps with overall site drainage and the performance of planned ground grid. The ground grid provides a safe environment for working around equipment of this nature as it provides protection from possible sources of electrical hazards. • Architectural — Proposed Project is consistent with the existing facilities on the subject parcel (i.e. electrical substation). 12. Include analysis of hydrologic, atmospheric, geologic, pedologic, biotic, visual and noise impacts. Mountain Peak will avoid or minimize adverse impacts to the maximum extent possible during development of the proposed Project. While construction of the Project may result in some dust, noise, and odor impacts associated with the construction machinery, as well as trucks transporting materials, personnel, and equipment to site, operation of the facility will result in minimal nuisance impacts. Mountain Peak will implement best management practices ("BMPs") to minimize construction phase nuisances, including waste management, regular inspections and maintenance of vehicles and equipment, use of low -sulfur diesel fuel, and avoidance of idling. The site -specific Stormwater Management Plan will also outline BMPs designed to maintain compliance with the Project's Construction Stormwater Discharge General Permit. • Hydrologic — Preliminary Drainage Report completed, please see Attachment 16 in 1041 application. • Atmospheric — Application for Synthetic Minor Construction Permit was submitted to CDPH E, please see Attachment 33 in 1041 application. • Geotechnical — Soils Study was conducted, please see Attachment 24 in 1041 application. • Biotic — Environmental Review of site completed, please see Attachments 30 & 31 in 1041 application. • Visual — Being addressed with the County landscaping requirement, please see Attachment 20 in 1041 application. Noise — Noise Study conducted, please see Attachment 23 in 1041 application. 13. Include surface and subsurface drainage analysis. Preliminary Drainage Report completed, please see Attachment 16 in 1041 application. Geotechnical - Soils Study conducted, please see Attachment 24 in 1041 application. 14. Applicants seeking a permit for the site selection and construction of transmission lines or substations shall submit the following additional documents and information: Not applicable. 15. Specific submittal requirements. The following information may also be required: a. Detailed description of the need for the proposed development or activity, including but not limited to: • The present population of the area to be served and the total population to be served when the project is operating at full capacity. United Power's service territory is over 900 square miles with members representing approximately 107,000 meters. • Weld County has an estimated population of 322,424 as of 2021 (information provided by Data USA https://datausa.io/profile/geo/weld-county-co ). • The predominant type of users or communities to be served by the proposal. Residential, agricultural, and commercial. • The percentage of the design capacity at which the current system is now operating. In 2022, United Power's average system demand was approximately 342 MW per hour, and its peak demand was approximately 612 MW. Using 2022 as the basis, the Project represents an ability to supply approximately 26% of United Power's peak demand. • The relationship of the proposal to the applicant's long-range planning and capital improvements programs. Residential, agricultural, and commercial. • A description of why public convenience and necessity require a facility of the size and nature proposed. Based on United Power's average and peak demand, the Project's cumulative net generating capacity of 162 MW is capable of satisfying approximately half of United Power's average demand and less than one-third of its peak demand. As stated above, due to the increase in the amount of renewable generation within United Power's portfolio, the Project is necessary in order to provide flexible, reliable generation necessary to support such intermittent resources. • A description of the user needs and user patterns to be fulfilled by the proposed project. Peaker power plants, like the Project, are a necessary component of an increased reliance on renewable sources of power. CTGs, such as those comprising the Project, provide fast -start capability and minimize risks of outage -related disruptions. • A description of the relationship of the project to other existing and planned utility facilities of a similar nature, other communication or energy generation and transmission facilities, local government capital improvement programs and special district expansion programs. The Project generates electrical power similar to other power plant facilities located within Weld County through the use of combustion turbine generators. This Project will be utilizing state of the art aeroderivative-based combustion turbines, designed and manufactured to support renewable power based electrical supply grids. The Project will also be utilizing the best available emissions control technologies. The Project also provides a local entity, United Power, the ability to move forward with a strategy they believe best serves their cooperative members. b. Environmental impact analysis — land use. i. Describe the relationship of the project to local land use, policies and comprehensive plans and to policies and plans adopted or under preparation by federal, state, regional or other affected local governmental agencies. • Applicant has been engaging State and Local authorities to ensure project is consistent with establish policies, plans, and guidance. Applicant initially engaged CDPHE prior to preparing and submitting air permit to ensure new facility is in line with established goals and objectives. This included the type of facility planned, the technology used, and how the facility will operate and support United Power's operational needs. • Applicant has worked to ensure facility, as currently planned, is compliant with Weld County Comprehensive Plan for both land use and supporting future growth. Specifically, this includes expanding the renewable energy supply for United Power and their members living in Weld County. Applicant will also design the facility in accordance with Weld County Code and all related national codes, standards, and practices. This includes necessary measures and design features to protect Weld County land, environment, wildlife, and local residents. The Project will also protect the rights and equipment of entities that share easements and right of ways with the planned Project site. • Applicant has met with local authorities (Keenesburg and Southeast Weld County Fire District) to ensure that the facility, as planned, is compliant with the government and emergency services requirements. ii. Detail the agricultural productivity capability of the land affected by the proposal (SCS classification). The Project site does not currently support agricultural productivity as it is occupied in pad by the Tesla Substation. Mountain Peak has been investigating the site for water resources and has learned that there is limited water available at the site due to site location and its lack of accessible water aquifer or pipeline water. Mountain Peak believes this lack of water would make agricultural activities difficult. The Project's facility will not require water for operations other than potable water needs for operator staff. • Mountain Peak's facility can utilize the existing land without requiring additional infrastructure to or from the site that would require new routing of transmission lines and natural gas pipelines. The site includes accessibility to existing 69 kV transmission system. And the natural gas supply is on adjacent property to the east. Additional easements or right of ways to install this type of infrastructure is not required and would not be asked of residents or property owners near or adjacent to the site. • Please reference soils report in Attachment 24, Environmental Survey in Attachment 30 and Environmental Site Evaluation in Attachment 31. iii. Specify how the proposed development will utilize existing easements or rights -of -way for any associated distribution or collector networks. The Project will interconnect to United Power's existing 69 kV transmission system at its Tesla Substation located on the property, and power generated by the Project will transfer to United Power at the point of interconnection. To the extent that United Power's transmission system relies on existing easements or rights -of way to distribute power from the Tesla Substation, then United Power will rely on these rights to distribute the power to its members. c. Environmental impact analysis — water resources. See Attachments 30 & 31 of 1041 Application for Environmental Review i. Documentation of the historical flooding activity should be included. Detail potential, adverse impacts related to the associated floodplain. Not applicable, the property is not located in a designated floodplain_ Describe the potential adverse effects of the proposal upon plant and animal life dependent upon the water resources in question. No potential adverse effects are anticipated to plant or animal species. d. Environmental impact analysis — significant environmentally sensitive factors. Detail the potential impact of the proposal upon each feature: See Attachments 30 & 31 of 1041 Application for Environmental Review i. Marshlands and wetlands. Not applicable. No WOTUS or wetlands were identified on the property during field delineations completed in August of 2023. ii. Groundwater recharge areas, if applicable. Not applicable. iii. Potential natural hazards. • See Attachment 22 of 1041 application for Emergency Response Plan. iv. Forests and woodlands. Not applicable. The subject property is not located in a forest or woodland. v. Critical wildlife habitat. Not applicable. No state or federal species were found during environmental field delineations completed in August of 2023. vi. Public outdoor recreation areas. Not applicable. No outdoor recreation areas are located on the subject property. vii. Unique areas of geologic, historic or archeological importance. • Not applicable. No significant or historical structures were identified on the property, and it is not listed as a local landmark or listed on the National or State Register. e Environmental impact analysis — Visual aesthetics and nuisance factors. i. Identify key locations where the facility can be viewed from and its proximity to residences, simulate the appearance of the facility, and identify noise pollution or obnoxious odors which may stem from the proposal. Per the Weld County Property Portal there are no residences within approximately 1,500 feet of the subject site. • There is no significant noise pollution or obnoxious odors anticipated. Please see Noise Study in Attachment 23 of 1041 application. ii. Where significant, map or describe areas within view of project. Not applicable. iii. Describe proposed mitigation strategy. Not applicable based on response to (i). Going forward, Mountain Peak will work with the County to determine the need for visual and/or noise abatement in the future if the currently proposed development to north and west of the property is actually developed. f. Environmental impact analysis — Transportation impacts. i. Describe what impacts the proposal will have upon transportation patterns in the area intended to be served or affected by the proposal. See Traffic Narrative in Attachment 17 of 1041 application. ii. Describe the potential impact on roads within the County. Applicant working with Weld County to address potential road impacts and improvements. iii. Identify improvements required to any roads within the County in order to serve the project adequately. Due to projected small increase in vehicle traffic to support plant operations, roads improvements do not seem necessary at this time. Planning Questions: Planner on Call (970) 400-6100 1. Explain, in detail, the proposed use of the property. Include, at a minimum, the following: Current or previous use of the land, if any. The land is currently used by United Power for an electric substation. Describe the uses surrounding the site and explain how the proposed use is compatible with them. The uses surrounding the site are primarily zoned as Agricultural and Exempt parcels, comprised by a mix of state, metro district, corporate, and privately -owned properties. There are abundant oil and gas facilities and utility corridors in the immediate area. The proposed use is consistent with the existing electric substation on the property and the associated electric/gas distribution and transmission corridors in the area. Describe the proximity of the proposed use to residential structures. The closest residence is over 1,500' away (data from Weld County Online Mapping. Describe the hours and days of operation (e.g. Monday thru Friday 8:00 a.m. to 5:00 p.m.). The current substation and proposed peaking facility provide 24/7 service to United Power's transmission and distribution system. List the types, number, and uses of the proposed structures to be erected. • The proposed improvements include: six (6) GE LM2500 Xpress power generation units; six (6) selective catalytic reduction units and oxidation catalysts to control NOx emissions; a Control Trailer; small storage shed, fencing surrounding the units; a stormwater detention pond in the southwest corner of the property; drive aisles to allow for 360 -degree access around the property; and, once operational, parking on the north side of the property next to the Control Trailer. Describe the size of stockpile, storage or waste areas to be utilized, if any. Not applicable. Describe the method and time schedule of removal or disposal of debris, junk and other wastes associated with the proposed use. There are several old, dilapidated, and abandoned barn structures that will be removed prior to the commencement of Project construction. As noted in the Environmental Review provided under Attachment 30 of the 1041 Application, a review of the Weld County historic property records indicated that these structures have not been designated as "significant" nor have the buildings been designated as a local landmark or listed on the National or State Register. Include a timetable showing the periods of time required for the construction of the operation. • August 2024 — September 2024 - Site Grading, Earthwork, Underground Utilities • September 2024 — November 2024 — Foundation and Concrete Work • December 2024 — February 2025 — Mechanical and Electrical Installation • March 2025 — May 2025 — Commissioning & Startup • June 2025 — Commercial Operation Describe the type of lot surface proposed and the square footage of each type (e.g. asphalt, gravel, landscaping, dirt, grass, buildings). Planned project area on existing site is roughly 428,230 square feet overall. Please see Site Plan in Attachment 3 for proposed surfaces. • Proposed lot surfaces include: i. Gravel — site roads and parking area at Control Trailer — estimated coverage = 63,307 sq ft ii. Rock Gravel - equipment areas — estimated coverage = 232, 987 sq ft iii. Grass — Areas not disturbed during construction and all other areas not planned for gravel — estimated coverage = 64,225 sq ft iv. Concrete — Equipment will sit on concrete foundations surrounded by gravel to allow for maintenance access and site drainage. How many parking spaces are proposed? How many handicapped (ADA) parking spaces are proposed? • Eight (8) parking spaces for Control Trailer with two (2) spaces designated ADA compliant. Describe the proposed screening for all parking and outdoor storage areas. • Screening for parking and storage areas is not proposed for any part of the site. Describe the existing and proposed landscaping for the site. Please see Site Plan in Attachment 3 and Landscape Plan in Attachment 20 of 1041 application. • Existing landscaping consists of natural grasses and a few trees of varying size and age. • New landscaping will consist of reseeding of natural grasses in areas disturbed by construction related activities and where equipment or gravel is not located. Describe the type of fence or other screening proposed for the site. See Landscape Plan in Attachment 20 of 1041 application. • The Project will be surrounded by a fence. Use of trees or shrubs for screening of the property boundary is not feasible due lack of water availability for irrigation purposes. Going forward, Applicant will work with the County to determine the need for visual abatement in the future based on proposed development to north and west of the property. Describe reclamation procedures to be employed as stages of the operation are phased out or upon cessation of the activity. • Please see Decommissioning Plan in Attachment 21 of 1041 application for more details should facility cease operations and require decommissioning. Describe the proposed fire protection measures. The Project has been discussed with Chief Tom Beach of the Southeast Weld Fire District. Fire protection will include installation of a 125,000 -gallon fire water tank connected to 1,000 gpm fire pump skid that will provide pressure to underground fire water loop and hydrants. The fire water loop and hydrants will encircle the site and equipment. The fire pump skid will include an electric -driven fire water pump, a backup emergency diesel fire water pump, and a jockey pump to keep the fire water loop constantly pressurized. • The Project will be designed with a fire protection system in accordance with NFPA 850 and other NFPA standards including: o The plant perimeter road will be designed and built with proper turning radius to accommodate fire trucks. o Proper equipment spacing or use of fire walls where necessary. o Each gas turbine unit will be equipped with fire detection and a CO2 fire extinguishing system equipped with visual and audible alarms required by NFPA. o The plant will be equipped with a main gas shut-off interlocked to the fire detection/protection systems. o A clean agent fire protection system for the server/control system room in the Control Trailer is planned. 2. Explain how this proposal is consistent with the Weld County Comprehensive Plan. • The Project follows the principles, goals, and objectives as set forth in the Weld County Comprehensive Plan, particularly the following: o Respecting Private Property Rights. One of the basic principles upon which the United States was founded is the right of citizens to own and utilize property so long as that use complies with local regulations and does not interfere with or infringe upon the rights of others. ■ The Project will be located on existing property owned by United Power and does not infringe on adjacent properties. The Project will follow the principles as set forth in the Weld County Comprehensive Plan and requirements of the Weld County Code. ■ The Project will comply with the Weld County Code and local regulations. o Promoting Economic Growth and Stability. Land use policies have a significant impact on economic conditions in the County and should be structured to encourage economic prosperity. To ensure the continued strength of Weld County's economy, land use processes and decisions based on this plan shall be consistent and promote fiscally responsible growth. ■ The project will support United Power's goal of providing new renewable energy and consistency to their grid. This includes ensuring resiliency and capacity for future growth to their members. This will ensure the power infrastructure within Weld County support continued economic growth. o Protecting Health, Safety, and General Welfare. Land use regulations and policies will protect and enhance the health, safety, and general welfare of the citizens of Weld County. ■ The Project is utilizing GE's technological advanced power production turbines to provide safe, efficient, and reliable power to support United Power's grid . ■ The Project is working with the State (CDPHE) to ensure the plant's air permit conforms to the State's goals for future energy and power development. ■ The Project is or will be working local agencies, local authorities having jurisdiction, and the City of Keenesburg to ensure compliance with all health, safety, and the welfare of Weld County residents. 3. Explain how this proposal is consistent with the intent of the zone district in which it is located. (Intent statements can be found at the beginning of each zone district section in Article III of Chapter 23.) The project site is currently zoned as Agricultural and is considered a Utility Service Facility. The Project's proposed use is listed as one of the acceptable Uses from Article III, Section 23-3-20 — Uses allowed by right outside of subdivisions and historic townsites. 4. Explain how this proposal will be compatible with future development of the surrounding area or adopted master plans of affected municipalities. • The Project will allow United Power to continue to provide power to members and the local community. This will allow continued development in the surrounding areas. The Project will also help improve United Power's grid stability and resiliency as they transition to new renewable power sources. 5. Explain how this proposal complies with Article V and Article XI of Chapter 23 if the proposal is located within any Overlay Zoning District (Airport, Geologic Hazard, or Historic Townsites Overlay Districts) or a Special Flood Hazard Area identified by maps officially adopted by the County. The Project is not located within an Overlay Zoning District or Flood Plain. 6. If the proposed use is to be located in the A (Agricultural) Zone District, explain your efforts to conserve prime agricultural land in the locational decision for the proposed use. Due to lack of existing water resources and current substation use, both utility services (pipeline) and geological formation (aquifer), the site appears limited in use for agricultural purposes. The proposed Project will not require such resources to operate and will provide benefits to United Power and the local community in improving the electrical grid. 7. Explain whether this proposal interferes with the protection of the health, safety and welfare of the inhabitants of the neighborhood and the County. • Although the Project will be producing electrical power via the combustion of natural gas, the equipment used to produce power employs technology to reduce emissions to the environment. The Project will also not be storing large amounts of combustible materials or hazardous materials that could a risk to the local environment and public. • All equipment will be located on foundations that will provide containment for any accidental spills of grease or oil during maintenance or operational activities. Also, for the 19% aqueous ammonia storage system, the system will be designed with low points for unloading and delivery for containing any accidental release. • The Project will also employ instruments and monitoring systems to alarm and notify operators for any accidental release of materials used on site, this includes natural gas and 19% aqueous ammonia. Monitoring includes local visual and audio alarm systems and operator notification in the Control Room. Environmental Health Questions: (970) 400-2702 1. What is the drinking water source on the property? If utilizing a drinking water well include either the well permit or well permit application that was submitted to the State Division of Water Resources. If utilizing a public water tap include a letter from the Water District, a tap or meter number, or a copy of the water bill. With only two (2) operators per shift, the Applicant plans to provide bottle water for drinking water as potable water supply, located in in the Control Trailer. 2. What type of sewage disposal system is on the property? If utilizing an existing septic system provide the septic permit number. If there is no septic permit due to the age of the existing septic system, apply for a septic permit through the Department of Public Health and Environment prior to submitting this application. If a new septic system will be installed please state "a new septic system is proposed." Only propose portable toilets if the use is consistent with the Department of Public Health and Environment's portable toilet policy. • The project will employee two (2) Operators per shifts with two (2) — 12 hour shifts each day. There are currently no plans to install a dedicated septic system on the site. Portable/temporary bathroom and washroom facilities will be separate from and external to the trailer and will include tanks to contain generated sanitary wastewater. The temporary sanitary wastewater holding tanks will be emptied by vacuum septic truck on a regular basis and disposed off site. There are currently no plans to install a dedicated septic system on the site. 3. If storage or warehousing is proposed, what type of items will be stored? • A small storage shed is required to store any lubricating oil consumables. Miscellaneous parts such as filters, will be brought onsite when needed. 4. Describe where and how storage and/or stockpile of wastes, chemicals, and/or petroleum will occur on this site. The Project will use a small storage shed for storage of lubricants. No large storage facility or stockpile of wastes is planned for the site. Any wastes generated will be removed from the site and disposed of in accordance with State or Local guidelines. 5. If there will be fuel storage on site, indicate the gallons and the secondary containment. State the number of tanks and gallons per tank. • The Fire Pump Skid will include a storage tank with ultra -low sulfur diesel fuel to support operation of the backup diesel fuel pump that is part of skid. The volume of this storage tank is expected to be 572 gallons or less. The Fire Pump Skid will have secondary containment. 6. If there will be washing of vehicles or equipment on site, indicate how the wash water will be contained. No washing of vehicles will occur on the site. 7. If there will be floor drains, indicate how the fluids will be contained. • Equipment that contains fluids will include containment designed into their foundations to collect fluids or will incorporate a drain system where any fluids will be collected by an oil/water separator. 8. Indicate if there will be any air emissions (e.g. painting, oil storage, etc.). The plant will have emissions that are regulated by CDPHE, no other fugitive air emissions are anticipated from plant equipment and operations. The plant will not be storing potential sources of emissions such as waste oil storage, painting supplies, or portable engines such as portable personal generators. 9. Provide a design and operations plan if applicable (e.g. composting, landfills, etc.). • See Site Plan in Attachment 3 of 1041 application. • The plant will be designed in accordance with all applicable national codes and standards of practice for a thermal power plant, at a minimum, this includes ASME, IBC, IPC, IMC, IFGC, IECC, NEC, NFPA, and national safety standards including OSHA. • The plant will operate on an on -demand basis and has limited operator inputs. The plant will have dedicated control system that will automate and monitor the operation of the combustion -turbine generators and all supporting balance of plant equipment. The plant is designed to achieve maximum electric power output within 10 minutes of start command. Each Original Equipment Manufacturer (OEM) will include safety and protective control measures such that, in case of operation issues or damage to equipment is possible, will shut down the equipment and facility. 10. Provide a nuisance management plan if applicable. See Nuisance Plan in Attachment 19 of 1041 application. 11. Additional information may be requested depending on type of land use requested. Engineering Questions: (970) 400-6100 1. Include a traffic narrative with the information below. A traffic impact study may be required. Improvements to adjacent streets/roads may be necessary to provide adequate safe and efficient transportation to and from the site. An Improvements Agreement may be required. • Please see Traffic Study Report in Attachment 17 of 1041 application for answers to questions below. • Applicant is working with Weld County to address any potential road impacts and improvements. a The projected number of vehicle trips (average per day, maximum per day, peak hour data) to and from the site and the type of vehicles (passenger, semi -truck, etc.). • During normal operations, operators traveling to and from the plant will be the only daily vehicles trips expected. On occasion, vehicles required for equipment maintenance or deliveries will travel to and from the site Two (2) operators per shift, at 12 -hour shifts = 4 vehicle roundtrips per day b. Describe how many roundtrips/day are expected for each vehicle type: Passenger Cars/Pickups, Tandem Trucks, Semi-Truck/Trailer/RV (Roundtrip = 1 trip in and 1 trip out of site) • During normal operations, expected vehicles daily roundtrips: i. Passenger Car/Pickups = 4 ii. Tandem Trucks = 0 iii. Semi-Truck/Trailer/Rv = 0 c. Describe the expected travel routes for site traffic. To access the Mountain Peak site, most traffic will utilize the 1-76 interchange in Keenesburg, head north to County Road 18, turn left onto County Road 18 then turn right onto County Road 55. This route is anticipated to serve traffic accessing the site during and post construction. d. Describe the travel distribution along the routes (e.g. 50% of traffic will come from the north, 20% from the south, 30% from the east, etc.) Operator traffic is expected to come from the south and west of the site, all other traffic is expected from the south. Describe the time of day that you expect the highest traffic volumes to and from the site. • The plant will be operated by two (2) operators per shift, each shift will be twelve (12) hours each. Shift changeover will see the highest volume of traffic entering or exiting the plant. The next shift operator will arrive to the plant prior to operators ending their shifts depart the plant. At the most, this would be 2 vehicles entering the plant before shift change over, then 2 vehicles exiting the plant after shift change over Describe where the access to the site is planned. ® Site access will not be changed. Access to the site will remain off of County Road 55. 3. Drainage Design: Design and construction of a detention pond as described in an approved Drainage Report is required unless the project falls under an exception to stormwater detention requirements per code. (See below.) Does your site qualify for an exception to stormwater detention? If so, describe in a drainage narrative the following: Please see Preliminary Drainage Report in Attachment 16 of 1041 application for answers to questions below. a. Which exception is being applied for? Include supporting documentation. - None b. Does the water flow onto the property from an offsite source? If so, from where? - None c. Describe where the water flows to as it leaves the property. — flows to southwest d. Describe the direction of flow across the property. — Northeast to Southeast e. Describe the location of any irrigation facilities adjacent to or near the property. - None f. Describe any previous drainage problems with the property.- None 4. If your site does not qualify for an exception, the following applies: Please see Preliminary Drainage Report in Attachment 16 of 1041 application for answers to questions below a. A Drainage Report summarizing the detention pond design with construction drawings and maintenance plan shall be completed by a Colorado Licensed Professional Engineer and adhere to the drainage related sections of the Weld County Code. b. The Drainage Report must include a certification of compliance, which can be found on the Public Works website, stamped and signed by the PE. c. See the attached Drainage Report Review Checklist. Exceptions to stormwater detention requirements: 1. Towers including, but not limited to, wind and telecommunication towers. 2. Pipelines or transmission lines, excluding laydown yards, metering sites, substations, and any other above ground appurtenances. 3. Gravel pits if the stormwater drains into the gravel pit. Releases from the site shall comply with the Weld County Storm Drainage Criteria, including dewatering. Topographical information shall be provided. 4. Development of sites where the change of use does not increase the imperviousness of the site. 5. Non -Urbanizing areas where the total pre-existing and post development impervious area produces stormwater runoff of less than, or equal to, 5 cfs for the 1 -hour, 100 -year, storm event. This exception shall be supported by calculations signed and stamped by a Colorado Licensed Professional Engineer. 6. Parcels with total area less than, or equal to, 1.0 gross acre. 7. An individual parcel with an unobstructed flow path and no other parcel(s) between the Federal Emergency Management Administration (FEMA) regulatory floodplain channel and the project. 8. A parcel greater than 1 gross acre and less than, or equal to, 5 gross acres in size is allowed a one-time exception for a new 2,000 sq. ft. building or equivalent imperviousness. 9. A parcel greater than 5 gross acres in size is allowed a one-time exception for a new 4,500 sq. ft. building or equivalent imperviousness. Building Questions: (970) 400-6100 Please see Environmental Review in Attachment 30 and 1041 USR Map of Attachment 29 of 1041 application. 1. List the type, size (square footage), and number of existing and proposed structures. Show and label all existing and proposed structures on the USR drawing. Label the use of the building and the square footage. • Existing - There current exists barn structures and a trailer home on the site. There also exists the Tesla Substation, owned and operated by United Power. The Tesla Substation is connected to United Power's 69 kV transmission system. • Proposed — The Project is planning to install the following: i. The Control Trailer will be a double -wide trailer that is roughly 24 -ft x 60 -ft. ii. A small storage shed that is roughly 6 -ft x 8 -ft 2. Explain how the existing structures will be used for this USR. The Tesla Substation will provide means for the new facility to connect to existing 69 kV transmission system. The existing barn and trailer structures at the site will not be reused by the Project and will therefore be removed by Untied Power prior to construction. Note that it has been concluded by environmental survey in Attachment 30 that there is no historical significance to the barn/shed structures. 3. List the proposed use(s) of each structure. New structures will be: i. Plant Control Trailer which will include a dedicate plant control room, server/computer controls hardware, and operator offices. ii. A small storage shed will be installed to hold approximately ten (10) 55 -gallon drums for CTG lubricating oils. The shed will include internal secondary containment for fluids and appropriate insulation/roofing/side for weather. iii. All other items on the site are equipment associated with plant operations. Mountain Peak Power, LLC Mountain Peak Power Project Attachment 35 11041 Submittal Application Attachment 35 Permitting Matrix — Mountain Peak Power Project Mountain Peak Power Weld County 1041 Application Stanley Consultants Permit Name Issuer Status Approval Timeline (Target) Filing Date Expected Approval Milestone Minor Source Air Permit Colorado Department of Public Health & Environment (CDPHE) In Process 12 months 7/14/2023 Jul -24 Pre -Construction 1041 Permit Weld County In Process 6-7 months 1/18/2024 Jul -24 Pre -Construction Grading Permit Weld County To Be Filed 30-60 days (6/1/2024) Jul -24 Pre -Construction Building Permits Weld County To Be Filed 30-60 days (6/1/2024) Jul -24 Pre -Construction Construction Stormwater General Permit (CSGP) CDPHE (State) To Be Filed 10 days (5/15/2024) May -24 Pre -Construction Hydrostatic Testing Permit CDPHE (State) To Be Filed 30 days (7/1/2024) Aug -24 Pre -Construction Dewatering Permit CDPHE (State) To Be Filed 30 days (7/1/2024) Aug -24 Pre -Construction Industrial Stormwater General Permit CDPHE (State) To Be Filed 90 days (3/1/2025) Jun -25 Pre -Operations Underground Storage Tanks (USTs)/Aboveground Storage Tanks (ASTs) Colorado Division of Oil & Public Safety (OPS) To Be Filed 20 days (5/1/2025) Jun -25 Pre -Operations 4942712 02/02/2024 04:13 PM Total Pages: 7 Rec Fee: $43.00 Carly Koppes - Clerk and Recorder, Weld County , CO WHEN RECORDED RETURN TO: Mountain Peak Power, LLC c/o Kindle Energy LLC 500 Alexander Park Drive, Suite 300 Princeton, NJ 08540 MEMORANDUM OF LEASE AGREEMENT This MEMORANDUM OF LEASE AGREEMENT (the "Memorandum") is made and entered into as of January 19, 2024 by and between UNITED POWER, INC., a Colorado cooperative association ("Landlord"), and MOUNTAIN PEAK POWER, LLC, a Delaware limited liability company ("Tenant"). RECTITAL S A. Landlord is the owner that certain property commonly containing approximate 18.46 acres located in Weld County, Colorado, more particularly described on Exhibit A (the "Property"). B. Landlord and Tenant have entered into a Lease Agreement dated January 19, 2024 (as the same may be amended from time to time, the "Lease") to provide Tenant access to the Property to install natural gas -powered electric generating equipment ("Generation Facility") and interconnection facilities (the "Tenant's Interconnection Facilities ") to supply electric capacity and associated energy to Landlord. C. The Parties now desire to provide record evidence of the Lease by executing and recording this Memorandum as required under and pursuant to the Lease. AGREEMENT NOW, THEREFORE, the parties hereto do hereby certify and agree as follows: 1. Grant. Owner hereby leases, to Tenant and Tenant hereby leases from Landlord, the right to the possession, use, and control of the pad site depicted in the Exhibit B attached (the "Generation Site"). Tenant may install a security fence around the Generation Site and limit access to Tenant's authorized representatives. Security of the equipment on the Generation Site is the sole responsibility of Tenant. Landlord further grants to Tenant the nonexclusive right to use, in common with Landlord, the driveways, parking areas and open spaces on the Property ("Common Areas") for ingress to and egress from the Generation Site, for parking and for the installation of the Gas Line. The Generation Site and the Common Areas are referred to herein as the "Premise". 2. Term. The Lease shall commence upon the Effective Date and shall continue for a period of time (the "Construction Term") ending on the Delivery Commencement Date (as defined in the Lease). The Term of the Lease shall automatically extend and continue for a period of time (the "Primary Term") ending on the date that is thirty (30) years after the expiration of the Construction Term, subject to extensions as set forth in the Lease. 3. Permitted Use. Tenant may use the Generation Site for the installation, construction, operation, maintenance, repair, replacement, and reconstruction of the Generation Facility and the Tenant's 4942712 02/02/2024 04:13 PM Paget of7 Interconnection Facilities, including the right to fence off the Generation Site and other uses incident to such operations. Tenant may use the Common Areas for access, short term parking, and similar purposes and for the installation, construction, operation, maintenance, repair, and replacement of the Gas Line. Tenant shall cause a third -party provider to construct a natural gas distribution line to supply fuel to the Generation Facility. Tenant shall select the location for an underground natural gas supply line from the main gas line to the Generation Facility (the "Gas Line"), subject to Landlord's approval prior to construction, which shall not be unreasonably withheld. At Tenant's sole cost and expense, Tenant shall be entitled to make improvements, repairs, or alterations, including without limitation security fencing, to the Generation Site, the Generation Facility, and the Tenant's Interconnection Facilities from time to time, as Tenant considers necessary or appropriate, subject to the requirements of the Lease. Tenant shall retain title to the Generation Facility, the Tenant's Interconnection Facilities, and all other personal property, trade fixtures, and other fixtures and equipment installed by Tenant in the Generation Site or elsewhere on the Premises at all times during and after the Term, and Tenant shall be entitled to remove all such items from the Premises at any time, on the condition that Tenant repairs any damage caused by the removal. Landlord may, in accordance with the terms of the Lease, install the interconnection facilities ("Landlord's Interconnection Facilities "to be owned, controlled, and operated by Landlord on the Generation Site. 4. A sig r b L�tndl rd. Any sale or other transfer of the Property by Landlord shall be subject to the Lease. The Lease shall burden and run with the Property. Landlord may encumber the Property after the Effective Date with a mortgage or deed of trust; provided, however, that any such encumbrance shall be subject and subordinate to the Lease and Tenant's rights hereunder and Landlord shall obtain for the benefit of Tenant any subordination, attornment, and non -disturbance agreement in a form reasonably acceptable to Tenant. 5. A i °i�� er by Teat. Except for a Permitted Transfer, Tenant may not assign or sublet its interest in the Lease, or sublet the Generation Site, without the prior written consent of Landlord, which consent shall not be unreasonably withheld or delayed. Tenant shall have the right, without the need for Landlord's consent, to assign its interest in the Lease or sublet the Generation Site to: (a) any affiliate of Tenant, (b) any successor entity created by merger, reorganization, or operation of law, or (c) any entity which purchases substantially all of the Tenant's assets (each a "Permitted Transfer"). Any change in control of Tenant shall not be deemed an assignment hereunder. Tenant shall further have the right, without Landlord's consent, to finance, securitize, utilize as credit support, mortgage, or otherwise encumber the Premises, the Generation Facility, or the Tenant's Interconnection Facilities and Landlord shall execute all commercially reasonable documents requested by Tenant in connection therewith. Any assumption of the Lease by a lender pursuant to the foregoing financing shall not be deemed an assignment hereunder. 6. ClatinSs. This Memorandum may be executed in two or more counterparts and by different parties on separate counterparts, all of which shall be considered one and the same agreement and each of which shall be deemed an original. 7. Notice. The purpose of this instrument is to give notice of said Lease and all of its terms, covenants, and conditions to the same extent as if said Lease were set forth herein. This Memorandum is not a complete recitation of all the terms and conditions of the Lease and is not to be construed as restricting, enlarging, modifying, or amending the Lease. Lessor and Tenant possess executed counterparts of the Lease to which reference is made for a complete recitation of all terms and conditions set forth therein. 8. Conflict Between Lease and Memorandum. In the event of any conflict between the terms and conditions of this instrument and the terms and conditions of the Lease, the terms and conditions of the Lease shall control. [signatures on next pages] 2 4942712 02/02/2024 04:13 PM Page 3of7 IN WITNESS WHEREOF, the undersigned has caused this instrument to be executed as of the Effective Date. LANDLORD UNITED POWER, INC., a Colorado coocertiPe association COUNTY OF STATE OF (COI b i'�G.CAO ) ss. S ) By: Name: Title: NIA The foregoing instalment was acknowledged owledged before me this ay of January, 2024 by as United Power, I c., a Colorado cooperative association. Witness my hand and official seal. My commission expires: CHERI LYNNE SIMMONS Notary Public State of Colorado Notary ID # 2017403086fi My Commission Expires 07-24_._,20425... .. 4 4942712 02/02/2024 04:13 PM Page 4of7 IN WITNESS WHEREOF, the undersigned has caused this instrument to be executed as of the Effective Date, TENANT MOUNTAIN PEAK POWER, LLC, a Delaware limited liability compa Afjet By: Name: W ` \\I ca-te-Nr-N Lt.& Title: C_--\\ ° - tCa— I STATE OF c_" -erse ) ) ss. COUNTY OF \INfTh t (te ) Day \. ,, The foregoing instrument was acknowledged before me this "S day of January, 2024 by 1. %.\\i tPptcNteciartti as is -t a,eO'' f Mountain Peak Power, LLC, a Delaware limited liability company. Witness my hand and official seal. My commission expires: r e '\ Oc e) -N Nal Notary Public Sb MAN E EVAN NotetY PubNe, Std of New Jersey Comm. p 50197550 My Commission Expires 6113/2027 t 3 4942712 02/02/2024 04:13 PM Page 5of7 EXHIBIT A All that part of the Southeast 1/4 of Section 9, Township 2 North, Range 64 West of the 6th P.M., County of Weld, State of Colorado, described as follows: Commencing at the Southeast corner of said Section 9; thence West along the South line of said Section 9, a distance of 1005 feet; thence at right angles North a distance of 825 feet; thence as right angles East a distance of 1005 feet to the East line of said Section 9; thence South along the East line of said Section 9 a distance of 825 feet to the point of beginning, except the East 30 feet thereof. 5 4942712 02/02/2024 04:13 PM Page 6of7 EXHIBIT B See attached. 31273818 v2 G E D B L PROPERTY LINE LEASE BOUNDARY -Y • JI•JITED POWER'S EXISTING SUBSTATION (69 KV• 13,2 <V) • PRELIMINARY ISSUE n FOR LEASE AGREEMENT NOT FOR CONSTRUCTION C Q JANUARY 13.2024 CCLNTY ROAD 22 COUNTY ROACI 55 NORTH i AT F JLL SIZE 0 I 3 IN I I I I I I` I I I f 6 1 2 3 4 5 6 7 6 cm GENERAL NOTES I THIS DRAWING IS CONCEPTUAL AND S FOR PLANNING PURPOSES ONLY ALL INFORMATION SHOWN IS SUBJECT TO CHAN'3E DURING DETAILEJ DESIGN 2 UNLESS DIrv1ENS ONE° FEATJRES SHOWN ARE APPROXIMATE 3 FEATJRES SHOWN ARE BASED ON SURVEY DOCJVIENTED ON DRAWING "L23 -110-7O STANLEY CONSULTANTS_ 231327' PROVIDED By LAMBERT LAND CONSULTIN3 QN 10-27-23. STANLEY CONSULTANTS HAS NOT VER FIED TI -E ACCURAC" OF THIS SJRVEY A SSJE =OR LEASE AGREEMENT JOT 01/19(_4 NO REVISIONS DSGN CHKA APVD JATE Stanley Consultants INC. 8000 South Chester Street, Suite 500, Center a,'oloraflo ^00112-3516 uncc.stardeyconsultarts coin MOUNTAIN PEAK POWER. LLC MOUNTAIN PEAK ROWER STATION WELD COUNTY, COLORADO GENERAL SITE PLAN GENERATION FACILITY BOUNDARIES DESIGNED J C THORNAM DRAM J C THORNAM CHECKED APPROVED APPROVED DATE SCALE 1' = 56' NO 31324 GG101 D REV A 1 I 2 3 I 4 5 I 6 7 I a 10to.IuLtie cxcmnurs 11 RESOLUTION RE: APPROVE AGREEMENT FOR LOCAL GOVERNMENT LAND USE APPLICATIONS TIMELINE EXTENSION FOR USE BY SPECIAL REVIEW PERMIT, USR24-0009, FOR A 1041 MAJOR FACILITY OF A PUBLIC UTILITY OR PUBLIC AGENCY FOR 165 MW PEAKER POWER PLANT WITH SIX (6) COMBUSTION TURBINE GENERATORS, 69 KV SWITCHYARD, AND ANCILLARY EQUIPMENT ASSOCIATED WITH FACILITY OPERATIONS UTILIZED FOR ENERGY GENERATION OUTSIDE OF SUBDIVISIONS AND HISTORIC TOWNSITES IN THE A (AGRICULTURAL) ZONE DISTRICT, AND AUTHORIZE CHAIR TO SIGN - UNITED POWER, INC., C/O MOUNTAIN PEAK POWER, LLC WHEREAS, the Board of County Commissioners of Weld County, Colorado, pursuant to Colorado statute and the Weld County Home Rule Charter, is vested with the authority of administering the affairs of Weld County, Colorado, and WHEREAS, the Board has been presented with an Agreement for Local Government Land Use Applications Timeline Extension for Use by Special Review Permit, USR24-0009, for a 1041 Major Facility of a Public Utility or Public Agency for 165 MW Peaker Power Plant with six (6) combustion turbine generators, 69 KV switchyard, and ancillary equipment associated with facility operations utilized for energy generation outside of subdivisions and historic townsites in the A (Agricultural) Zone District, between the County of Weld, State of Colorado, by and through the Board of County Commissioners of Weld County, on behalf of the Department of Planning Services, and United Power, Inc., do Mountain Peak Power, LLC, with terms and conditions being as stated in said agreement, and WHEREAS, after review, the Board deems it advisable to approve said agreement, a copy of which is attached hereto and incorporated herein by reference. NOW, THEREFORE, BE IT RESOLVED by the Board of County Commissioners of Weld County, Colorado, that the Agreement for Local Government Land Use Applications Timeline Extension for Use by Special Review Permit, USR24-0009, for a 1041 Major Facility of a Public Utility or Public Agency for 165 MW Peaker Power Plant with six (6) combustion turbine generators, 69 KV switchyard, and ancillary equipment associated with facility operations utilized for energy generation outside of subdivisions and historic townsites in the A (Agricultural) Zone District, between the County of Weld, State of Colorado, by and through the Board of County Commissioners of Weld County, on behalf of the Department of Planning Services, and United Power, inc., c/o Mountain Peak Power, LLC, be, and hereby is, approved. BE IT FURTHER RESOLVED by the Board that the Chair be, and hereby is, authorized to sign said agreement. CC:PL. (ER/MFA eta ('EG/3R) oS 116(2N 2024-1141 PL2917 APPROVE AGREEMENT FOR LOCAL GOVERNMENT LAND USE APPLICATIONS TIMELINE EXTENSION FOR USR24-0009 FOR A 1041 MAJOR FACILITY OF A PUBLIC UTILITY OR PUBLIC AGENCY -- UNITED POWER, INC., 0/0 MOUNTAIN PEAK POWER, LLC PAGE 2 The above and foregoing Resolution was, on motion duly made and seconded, adopted by the following vote on the 8th day of May, A.D., 2024. BOARD OF COUNTY COMMISSIONERS ATTEST: cdJ � set/744;a Weld County Clerk to the Board Deputy Clerk to the Board APP ,.VED AS 'flRM: I, County Attorney 6 Date of signature: WELD COUN (247/4 Perry L. BPro-Tern Inslat• Mike Freeman James Sai ne 2024-1141 PL2917 MEMORANDUM TO: Board of County Commissioners DATE: May 7, 2024 FROM: Maxwell Nader, Planning Manager SUBJECT: USR24-0009 Timeline Extension Mountain Peak Power, LLC, working on behalf of United Power, Inc and is seeking approval of a 1041 Major Facility of a Public Utility or Public Agency for a 165 MW Peaker Power Plant. As part of the procedure outlined in Chapter 21, Article 11, Section 21-2-260 and Section 21-3-320 of the Weld County Code there are impractical timelines identified that neither the applicant nor the planning staff can effectively meet. Therefore, the applicant has submitted a timeline extension agreement for the Board of County Commissioners to accept and sign showing that the applicant and the County are willing to waive the timelines established in Section 21-2-260 and Section 21-3-3202.1 of the Weld County Code. Planning staff supports this timeline extension request. 5/S1 2024-1141 PL2911 LOCAL GOVERNMENT LAND USE APPLICATIONS TIMELINE EXTENSION AGREEMENT BETWEEN THE COUNTY OF WELD, COLORADO AND MOUNTAIN PEAK POWER, LLC MAJOR FACILITIES OF A PUBLIC UTILITY 1041 PERMIT February 14, 2024 INTRODUCTION The County of Weld, Colorado (the "County") and Mountain Peak Power, LLC, a Delaware limited liability company ("MPP") (each individually a "Party," or collectively the "Parties") hereby enter into this Timeline Extension Agreement (the "Agreement") effective as of February 14, 2024, to define the applicable deadlines for review and final action by the County on MPP's Major Facilities of a Public Utility 1041 Permit application (the "Application"). ARTICLE I. BACKGROUND Section 1.01 MPP is proposing to construct a peaking power generation facility comprised of natural gas simple -cycle combustion turbines (the "Project") within the County's jurisdiction in unincorporated Weld County. Section 1.02 The Project Pathway is subject to approval by the County pursuant to the: Weld County, Colorado, County Code (the "Code"), specifically Code Chapter 21, Article III, Division 3, Permit Program for Site Selection and Construction of Major facility of a Public Utility (the "1041 Regulations"). Section 1.03 The Application and the County's review of the same are subject to various state statutes, including C.R.S. § 24-65.1-501(2)(a). Section 1.04 C.R.S. § 24-65.1-501(2) requires local government to publish a hearing notice for a 1041 application within 30 days after receipt of an application. The initial public hearing, in turn, must take place between 30 and 60 days after publication of notice. Section 1.05 Code Section 21-2-260 also includes deadlines associated with 1041 applications. Specifically, upon the Department of Planning Services' determination that the application is complete, it must (1) set a Planning Commission public hearing date that cannot be more than thirty (30) days after the complete application is submitted; (2) provide certain notices and post signs about the application and the public hearing at least ten (10) days prior to the public hearing; (3) refer the application to referral agencies for comment with a deadline to respond of twenty-eight (28) days; and (4) prepare staff comments for the Planning Commission. After the Planning Commission public hearing and recommendation on the 1041 application, the Board of County Commissioners must hold a public hearing on 1 DE8252186.1 the application within 45 days. That public hearing also requires certain notices at least 10 days prior. Code Section 21-2-310. Section 1.06 As required by the Code, MPP held a pre -application meeting with the County on November 30, 2023. Section 1.07 MPP submitted the Application for the Project on January 18, 2024. Section 1.08 Pursuant to Code Section 21-3-320, MPP was required to submit the Application within ten (10) days after the pre -application meeting. Section 1.09 Each of the County and MPP desires to waive certain of the deadlines set forth above to allow MPP to comply a complete Application and allow the County a full and fair opportunity to review and consider the Application. Section 1.10 Accordingly, the Parties have come to an agreement to waive the deadlines with respect to the Application. Section 1.11 The County and MPP mutually acknowledge that this Agreement is supported by appropriate and adequate consideration. ARTICLE II. TERMS OF AGREEMENT The Parties stipulate and agree to an alternative review and final local government action timeline as described below. Section 2.01 MPP hereby waives the deadlines set forth in C.R.S. § 24-65.1- 501(2)(a) and Code Section 21-2-260 requiring that the County to notify the public the Application within thirty (30) days and requiring that the County schedule a hearing on the Application in front of the Planning Commission within thirty (30) days after the Application is deemed complete. Section 2.02 The County hereby waives the deadline set forth in Code Section 21-3- 320 requiring that MPP submit the Application within ten (10) days after the pre -application meeting. ARTICLE III. MISCELLANEOUS Section 3.01 Other than the waiver of the Deadlines, by entering into this Agreement neither party waives any rights or obligations contained within the Code applicable to the Project. Section 3.02 This Agreement shall not be binding on any future applications for projects, by MPP or otherwise, within the County. 2 DE8252186.1 Section 3.03 The undersigned is authorized to enter into this Agreement on behalf of MPP, MPP has full corporate power and authority to carry out its obligations hereunder and consummate the transactions contemplated hereby. This Agreement has been duly executed and delivered by MMO, and constitutes a legal, valid, and binding obligation of MPP enforceable against MPP in accordance with its terms. [Signatures on the following page.] 3 a DE8252186,1 IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed and delivered as of the date set forth below, Date: May 1, 2024 Date: Attest: Weld B MAY 0 8 2024 tat Cd," Deputy Clef of t e Bo APPRO D AS TO F By: Name: arin McDougal Title: Deputy County Attorney 31938025_v1 4 Mountain Peak Power, LLC, A Delaware limited liability compan 1 sea — By: Nam- : Jon Baylor Title: Vice President BOARD OF COUNTY COMMISSIONERS COUNTY OF WELD, COLORADO By: ne: Kevin D. Ross BOCC Chair MAY 0 8 2024 Date: MAY 0 8 2024 DE8252186.1 07.,40a�- i/sal AGREEMENT FOR LOCAL GOVERNMENT LAND USE APPLICATIONS TIMELINE EXTENSION FOR USE BY SPECIAL REVIEW PERMIT, USR24-0009 APPROVED AS TO SUBSTANCE: n `f Depaent Head, or ected Official APPROVED AS TO FUNDING: post Chief Financial Officer, or Controller LOCAL GOVERNMENT LAND USE APPLICATIONS TIMELINE EXTENSION AGREEMENT BETWEEN THE COUNTY OF WELD, COLORADO AND MOUNTAIN PEAK POWER, LLC MAJOR FACILITIES OF A PUBLIC UTILITY 1041 PERMIT February 14, 2024 INTRODUCTION The County of Weld, Colorado (the "County") and Mountain Peak Power, LLC, a Delaware limited liability company ("MPP") (each individually a "Party," or collectively the "Parties") hereby enter into this Timeline Extension Agreement (the "Agreement") effective as of February 14, 2024, to define the applicable deadlines for review and final action by the County on MPP's Major Facilities of a Public Utility 1041 Permit application (the "Application"). ARTICLE I. BACKGROUND Section 1.01 MPP is proposing to construct a peaking power generation facility comprised of natural gas simple -cycle combustion turbines (the "Project") within the County's jurisdiction in unincorporated Weld County. Section 1.02 The Project Pathway is subject to approval by the County pursuant to the: Weld County, Colorado, County Code (the "Code"). Section 1.03 As required by the Code, MPP held a pre -application meeting with the County on November 30, 2023. Section 1.04 MPP submitted the Application for the Project on January 18, 2024. Section 1.05 Pursuant to the Code, (i) MPP was required to submit the Application within ten (10) days after the pre -application meeting, and (ii) the County is required to schedule hearing in front of the Planning Commission within thirty (30) days after the Application is deemed complete (the "Deadlines"). Section 1.06 Each of the County and MPP desires to waive Deadlines to allow MPP to comply a complete Application and allow the County a full and fair opportunity to review and consider the Application. Section 1.07 Accordingly, the Parties have come to an agreement to waive the Deadlines with respect to the Application. Section 1.08 The County and MPP mutually acknowledge that this Agreement is 1 DE8252186.1 supported by appropriate and adequate consideration. ARTICLE H. TERMS OF AGREEMENT The Parties stipulate and agree to an alternative review and final local government action timeline as described below. I Section 2.01 MPP hereby waives the Deadline requiring that the County schedule a hearing on the Application in front of the Planning Commission within thirty (30) days after the Application is deemed complete. Section 2.02 The County hereby waives the Deadline requiring that MPP submit the Application within ten (10) days after the pre -application meeting. ARTICLE III. MISCELLANEOUS Section 3.01 Other than the waiver of the Deadlines, by entering into this Agreement neither party waives any rights or obligations contained within the Code applicable to the Project. Section 3.02 This Agreement shall not be binding on any future applications for projects, by MPP or otherwise, within the County. Section 3.03 The undersigned is authorized to enter into this Agreement on behalf of MPP. MPP has full corporate power and authority to carry out its obligations hereunder and consummate the transactions contemplated hereby. This Agreement has been duly executed and delivered by MMO, and constitutes a legal, valid, and binding obligation of MPP enforceable against MPP in accordance with its terms. [Signatures on the following page.] 2 DE8252186.1 IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed and delivered as of the date set forth below. Date: March 1, 2024 Date: Attest: Weld County Clerk of the Board Mountain Peak Power, LLC, A Delaware limited liability company By: ei-4---r—Stis I Cr Name. Jon Baylor Title: Sr. Vice President COUNTY OF WELD, COLORADO By: Name: Title: By: Date: Deputy Clerk of the Board APPROVED AS TO FORM: By: Name: Title: 3 Date: DE8252186.1 Mountain Peak Power, LLC Mountain Peak Power Project Attachment 3311041 Submittal Application Attachment 33 CDPHE Application for Synthetic Minor Construction Permit Mountain Peak Power Weld County 1041 Application Stanley Consultants Colorado Department of Public Health and Environment Air Pollution Control Division Stationary Sources Program APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246 APPLICATION FOR SYNTHETIC MINOR CONSTRUCTION PERMIT MOUNTAIN PEAK POWER WELD COUNTY, COLORADO To Whom It May Concern: Mountain Peak Power is proposing to construct a simple cycle combustion turbine power generation facility in Weld County, Colorado. This submission seeks to authorize the construction of six new natural gas fired turbines. Mountain Peak Power is seeking to obtain a minor source air permit via establishment of enforceable limits to permit emissions of NOX and VOC to less than the major source thresholds of 25 tons per year (tpy) each, to avoid nonattainment New Source Review (NNSR). The APEN fee has been paid online through the CDPHE payment portal. This submission contains the request for a permit to construct the six new natural gas fired turbines and the accompanying Air Pollution Emission Notice (APEN) and APCD Form 102 in accordance with the 5 Code of Colorado Regulations (CCR) 1001-5, Regulation No. 3 (Colo. Reg. 3), Part B/ Section II. Please contact Eric Hodek at (303) 382-5465 or contact ehodek@ramboll.com if you have any questions related to this application. Sincerely, 714 Eric S. Hodek Principal D +1 (303) 382-5467 ehodek@rarnboll.com 1/1 ENVIRONMENT & HEALTH July 14, 2023 Ramboll 1999 Broadway Suite 2225 Denver, CO 80202 USA T +1 303.382.5460 www.ramboll.com Prepared for: Mountain Peak Power, LLC Submitted to: Colorado Department of Public Health and Environment (CDPHE) Air Pollution Control Division (APCD) Prepared by: Ramboll US Consulting, Inc. Date: July 2023 Project Number: 1690030136 APPLICATION FOR AN AIR PERMIT TO CONSTRUCT MOUNTAIN PEAK POWER WELD COUNTY, COLORADO Ramboll 1999 Broadway Suite 2225 Denver, CO 80202 USA T +1 303 382 5460 F +1 303 382 5459 www.ramboll.com Permit to Construction Application Mountain Peak Power, LLC CONTENTS ACRONYMS AND ABBREVIATIONS 1. INTRODUCTION 2. PROJECT DESCRIPTION 2.1 Six (6) LM25OO Combustion Turbines 2.2 Emergency Firewater Pump 2.3 Ultra -Low Sulfur Diesel Storage Tank 3. EMISSIONS SUMMARY 3.1 Six Simple Cycle Combustion Turbines (FINs CT -1 through CT -6) 3.2 Emergency Firewater Pump 3.3 Diesel Storage Tank 4. 4.1 4.1.1 4.1.2 4.1.3 4.1.4 4.1.5 4.1.6 4.1.7 4.1.8 4.1.9 4.1.10 4.1.11 4.1.12 4.1.13 4.2 4.2.1 4.2.2 4.2.3 4.2.4 4.2.5 4.2.6 3 4 7 7 7 8 9 9 9 9 FEDERAL AND STATE REGULATORY APPLICABILITY 12 State Regulatory Requirements 12 5 CCR 1001-3: Regulation 1 - Emission Control for Particulate Matter, Smoke, Carbon Monoxide, and Sulfur Oxides 12 5 CCR 1001-4: Regulation 2 - Odor Emission 12 5 CCR 1001-5: Regulation 3 - Stationary Source Permitting and Air Pollutant Emission Notice Requirements 12 5 CCR 1001-6: Regulation 4 - Sale and Installation of Wood -Burning Appliances and the Use of Certain Wood -Burning Appliances during High Pollution Days 12 5 CCR 1001-8: Regulation 6 - Standards of Performance for New Stationary Sources 12 5 CCR 1001-9: Regulation 7 - Control of Ozone via Ozone Precursors and Control of Hydrocarbons via Oil and Gas Emissions 5CCR 1001-10: 5 CCR 1001-11: 5 CCR 1001-19: 5 CCR 1001-22: 5 CCR 1001-23: 5 CCR 1001-25: Regulation 8 - Control of Hazardous Air Pollutants Regulation 9 - Open Burning, Prescribed Fire, and Permitting Regulation 15 - Control of Emissions of Ozone -Depleting Compounds Regulation 18 - Control of Emissions of Acid Deposition Precursors Regulation 19 - The Control of Lead Hazards Regulation 21 - Control of Volatile Organic Compounds from Consumer Products and Architectural and Industrial Maintenance Coatings 5 CCR 1001-30: Regulation 26 - Control of Emissions From Engines and Major Stationary Sources Federal Regulatory Applicability New Source Review (NSR) Applicability New Source Performance Standards (NSPS) National Emission Standards for Hazardous Air Pollutants (NESHAP) Chemical Accident Prevention (CAM) - 40 CFR 68 Acid Rain Program - 40 CFR 72 - 78 Stratospheric Ozone Protection - 40 CFR 82 FIGURES Figure 1-1 Site Location Map Figure 1-2 Site Plot Plan APPENDICES Appendix A - Emission Calculations Appendix B - APCD Forms 13 13 13 13 13 13 13 13 13 13 14 15 15 15 15 Permit to Construction Application Mountain Peak Power, LLC TAB iES Table 2-1 - GE LM2500 Performance and Emissions Table 3-1 - Project Air Pollutant Emission Rates Table 3-2 - HAP Emissions Summary ACRONYMS AND ABBREVIATIONS AP -42 APCD APEN CDPHE CO DMNFR HAP lb/hr lb/yr MMscf/yr NAAQS N OX N NSR N SPS PM PM io PM2.5 PSD SO2 tpy U SEPA VOC 40 CFR CFR EPA's AP -42, Compilation of Air Pollutant Emission Factors, Fifth Edition Air Pollution Control Division Air Pollution Emission Notice Colorado Department of Public Health and Environment Carbon Monoxide Denver Metro North Front Range Hazardous Air Pollutants Pound per Hour Pound per Year Million standard cubic feet per year N ational Ambient Air Quality Standards N itrogen Oxides N onattainment New Source Review N ew Source Performance Standards Particulate matter Inhalable particulate matter with diameters of 10 microns or less Fine particulate matter with diameters of 2.5 microns or less Prevention of Significant Deterioration S ulfur Dioxide Tons per Year U .S. Environmental Protection Agency Volatile Organic Compounds Title 40 of the United States Code of Federal Regulations Code of Federal Regulations Permit to Construction Application Mountain Peak Power, LLC 1. INTRODUCTION Mountain Peak Power, LLC (Mountain Peak) is proposing to construct a simple cycle combustion turbine power generation facility in Weld County, Colorado. By means of this application, Mountain Peak seeks an air permit for construction of the emissions equipment and processes at the proposed facility. The facility is a greenfield site located northeast of Denver near town of Keenesburg in Weld County. A site location map for the proposed plant is presented in Figure 1-1. This facility is located in the Denver Metro North Front Range (DMNFR) area which is designated as attainment/maintenance for particulate matter less than 10 microns in diameter (PMio) and carbon monoxide (CO). Under that designation, all SIP -approved requirements for PMio and CO will continue to apply until the end of the maintenance period. The DMNFR is classified as severe nonattainment for the 2008 8 -hr ozone standard and is part of the 8 -hr Ozone Control Area as defined in Regulation No. 7, Section II.A.1. As such, oxides of nitrogen (NOX) and volatile organic compounds (VOCs) are regulated as nonattainment pollutants. The area is designated as attainment/unclassified for all other criteria air pollutants. With this permit application, Mountain Peak is seeking to obtain a minor source air permit via establishment of enforceable limits to permit emissions of NOX and VOC to less than the major source thresholds of 25 tons per year (tpy) each, to avoid nonattainment New Source Review (NNSR). There are no affected states within 50 miles of the proposed project. Rocky Mountain National Park, a Federal Class I designated area, is within 100 kilometers of the plant. Enclosed are the required application materials consisting of the following: project and process descriptions, emission calculations, and APCD forms. Air quality modeling determinations and corresponding files have been submitted to the Permit Modeling Unit under separate cover. Permit to Construction Application Mountain Peak Power, LLC Figure 1-1 Site Location Map tc Mountain Peak Power Station 4994 ft L5 peod /caunoj 0 £5 peoj Munop County Road 20 County Road 18 Interstate 76- Frontage Rd M to 5038 ft County Road 57 2 4 Kilometers County Road 59 6 • Keenesburg N Esri, NASA, NGA, USGS, FEMA, Esri, HERE, Garmin, SafeGraph, GeoTechnologies, [nc, METI/NASA; USGS, EPA, NPS, USDA DRAFTED I DATE: BY: ET 06/30/2023 Site Location Map Mountain Peak Power, LLC Mountain Peak Power Keenesburg, CO Permit to Construction Application Mountain Peak Power, LLC Figure 1-2 Site Plot Plan NORTH cc O O r I_) / f I r -1:F, f yL Es- / I • X • ♦ • • A / der / / • • \ \ • \ .4/ r tt� _ M. _ / CONTROL ROOM/MAINTENANCEAREAMIAREHOUSE/LOCKER ROOMS i / jet / — J - / HVAC EQUIPMENT BUILDING dr TRANSFORMER i / r \ \ i I GAS CONDITIONING EQUIPMENT -< ] \ SECONDARY UNIT ccirrcKETE I•, SUBSTATION (5' X 26') wrrn SR=) Il PRIMARY UNIT SUBSTATION (5' X 26') \� G�1 GAS METER YARD / \ \, { `- HAZARDOUS AREA (TYP) 1, I • • \ • > >/\ < \ • • ♦ PkEL N I AMY PROPERTY L I E (Tyr C 1 I RETENTION POND /\ /\ / I • • \ • • • • 1 ) • • 1 \ • ♦ • \ • • / 275.00 N. GRAI ITEE ORAJ, LLC RECEPT till1t ;i52T "2 • • • • \\SC - A 5- e • \ " \ • r \ • • • • • \ \ • • \ • 00B) x 1 POWER DISTRIBUTION CENTER (TYP) 22 i IGRAVFJL ROA1) • ELECTRICAL EQUIPMENT (TYP) DIESEL GENERATOR SECONDARY UNIT SUBSTATION (5' X 26') POLE BARI I VV STEEL S" /it, < - -1-` \ \ \ CEI ITER PORT CPI I BE I IG AI I F / / /� y ,'GARAGE -]-• " ,. \ \ 275.00 %,'l, N / \ `� J . I 1 I 1 �I 1 r max-,\ _ Iv. __ L.- I I it ` -♦, X11 �/ _ / / // / PWMP t1OU_` L - - \ COLT ITy-RaA6 z2 (GRAVEL R6AQ) S GSU TRANSFORMER (TYP) - HIGH -VOLTAGE EQUIPMENT AND TAKEOFF STRUCTURE (TYP) a) I I I I tor r • r r I ♦ • I i gEJI II POWER, I C EASENEI RE EP" 'Ji I O 2817765 (200' ) \ AMMONIA UNLOADING, STORAGE AND FORWARDING SECONDARY UNIT SUBSTATION (5' X 26') FUEL OIL UNLOADING, STORAGE AND FORWARDING FIRE WATER PUMPS FIRE WATER STORAGE TANK \ 355.00 \ TRNAR \ I 1 1 PROPANE TANK -- � Orem FIT WYTH DTO`CO kniuTrcz METER k, I CATTLE GUAR!' DOH AR2 ANId IGEY PAio 7- AWAGENT ACCESS POINTS GAS LINE MAR XER5 OFCN Pri wi-rn EXPo9Em VrrLrTt£5 SOUTHEAST CORI ER SECT OI 4 325 I ARIA/ I UN CAP LS 13155 (1808) AT FULL SIZE 1 2 3 IN I I r 1 7 1 I I I 1 I 1 2 3 4 5 6 7 8cm PRELIMINARY PROOF OF CONCEPT MAY XX, 2023 A PRELIMINARY ISSUE NO REVISIONS DSGN CHKD APVD 05 /XX123 DATE Stanley Consultants INC. 8000 South Chester Street, Suite 500, Centennial, Colorado 80112-3516 www.stanleyco nsultants.com KINDLE ENERGY KINDLE ENERGY - PRELIMINARY ENGINEERING BROOMFIELD, COLORADO TESLA SITE PLAN PROOF OF CONCEPT DESIGNED J.C. THORNAM DRAWN J.C. THORNAM SCALE, 1"= 50' CHECKED 1 NO 31324 APPROVED APPROVED DATE REV Q; GG101 A 2 1 7 1 9 10 © STANLEY cUA sLl- ANTS 11 Permit to Construction Application Mountain Peak Power, LLC PROJECT DESCRIPTION The project primarily consists of the installation of installation of six (6) General Electric (GE) LM2500 Xpress simple cycle combustion turbines at a greenfield location identified by Mountain Peak as the "Testa Site". Each GE LM2500 Xpress gas turbine generator package is approximately a 27 MW unit equipped with a LM2500+G4 engine, a dry low NOx emissions (DLE) combustion system with a selective catalytic reduction (SCR) system, and a catalytic oxidation (CatOx) emission control system. These units will operate solely on natural gas. The auxiliary equipment consists of a 355 -hp emergency firewater pump engine and its associated 572 -gallon diesel storage tank. 2.1 Six (6) LM2500 Combustion Turbines Each LM2500 Gas Turbine Generator package is considered a unit. Each unit will consist of three main modules: (i) The Turbine Module, (ii) the Generator Module, and (iii) the Control House Module. The LM2500 combustion turbine engine is a two -shaft aeroderivative design with a gas generator separate from the power turbine. This mechanically decoupled design allows the power turbine to operate at a continuous speed allowing for startup to full load in less than 10 minutes. The main deck of the generator module contains the generator, generator ventilation, generator lube oil system and switchgear. The control house module includes a lighted and insulated control house. Each unit is equipped with an 80 -foot stack to release the combustion exhaust gases into the atmosphere. The turbines will fire pipeline quality natural gas. Additionally, each unit will be equipped with a 40 CFR Part 60 / 75 continuous emissions monitoring system providing monitoring of CO emissions, NOx emissions, and fuel flow. The extractive sampling system will also include an O2 analyzer for diluent and reporting purposes. Each CEMS will be in a prefabricated climate -controlled enclosure with a sample handling system, analyzers, calibration gases and a data acquisition and handling system. Emission controls for the turbines include: • Dry Low Emission (DLE) system and SCR for NOx control • CatOx for CO and VOC control • Use of pipeline -quality natural gas to minimize SO2 emissions Performance data from the manufacturer are summarized in Table 2-1 below. Table 2-1 GE LM2500 Performance and Emissions (At Maximum Heat Input) Parameter Value Load (%) 100% Fuel Consumption, MMBtu/hr (HHV) 295.43 MMBtu/hr NOx, ppmvd at 15% O2 2.5 ppmvd CO, ppmvd at 15% O2 4.0 ppmvd VOC, ppmvd at 15% O2 2.5 ppmvd SO2, lb/hr 1.16 lb/hr PMfiit, lb/hr 0.37 lb/hr PMlo, lb/hr 3.94 lb/hr PM2.s, lb/hr 3.94 lb/hr 2.2 Emergency Firewater Pump The project includes the addition of a 355 -horsepower, diesel -fired emergency firewater pump. The firewater pump engine will use ultra -low sulfur diesel fuel and will be United States Environmental Permit to Construction Application Mountain Peak Power, LLC Protection Agency (USEPA)-certified to meet the New Source Performance Standards (NSPS) in 40 CFR 60, Subpart IIII and will meet the National Emissions Standards for Hazardous Air Pollutants (NESHAP), Subpart ZZZZ. 2.3 Ultra -Low Sulfur Diesel Storage Tank A horizontal above ground storage tank will be installed to store ultra -low sulfur diesel fuel to be used in the emergency firewater pump. The tank will have a working volume of 572 gallons. Permit to Construction Application Mountain Peak Power, LLC 3. EMISSIONS SUMMARY This section summarizes emissions information for the six combustion turbines, the emergency firewater pump and the small diesel tank proposed at Mountain Peak Power. Detailed emissions calculations are shown in Appendix A. 3.1 Six Simple Cycle Combustion Turbines (FINs TBD) Mountain Peak is proposing to install six (6) General Electric (GE) LM2500 Xpress simple cycle combustion turbines at the Mountain Peak Power facility. Emissions of criteria air pollutants and formaldehyde from the combustion turbines are estimated based on the performance data from the manufacturer. Other Hazardous Air Pollutant (HAP) emissions are estimated using factors from AP -42 Fifth Edition Chapter 3.1. Greenhouse Gas (GHG) emissions are calculated in accordance with 40 CFR Part 98, Subpart C §98.33. Emissions of GHGs are based on the emission factors presented in 40 CFR 98, Table C-1 and C-2 and the emissions of GHGs as carbon dioxide equivalents (CO2e) in 40 CFR 98, Table A-1. 3.2 Emergency Firewater Pump A new diesel -fired 355 horsepower (HP) firewater pump will be constructed to provide the fire protection needs of the proposed Station. The annual emissions from the 355 HP firewater pump are based on 100 hours per year per the annual operating limit for emergency engines under 40 CFR 60, Subpart IIII. Emissions of NOR, CO, VOC, PM, PMio and PM2.5 are based on United States Environmental Protection Agency's Tier III emission standards for engines of model year 2014 or later, as the proposed firewater pump will be a Tier III certified engine. Emissions for hazardous air pollutants and other air toxics are based on AP - 42 Chapter 3, Table 3.3-2. Emissions of sulfur dioxide (S02) are based on an emission factor developed from the low sulfur content of the diesel (15 ppmw). Emissions of GHGs are based on the emission factors presented in 40 CFR 98, Table C-1 and C-2 and the emissions of GHGs as CO2e were developed based on the GHG species' global warming potentials presented in 40 CFR 98, Table A-1. 3.3 Diesel Storage Tank A new horizontal, fixed roof, 572 -gallon diesel storage tank will be constructed to store the diesel used in the firewater pump. Emissions for the tank were estimated using the methodologies presented in AP -42, Chapter 7. The diesel storage tank is categorically exempt from filing an Air Pollutant Emissions Notice requirements as stated in 5 CCR 1001-5 Regulation No. 3 Part B.II.D.1.fff.(ii)(A) and the storage of petroleum liquid requirements as stated in 5 CCR 1001-9 Regulation No. 7 Part B.IV.B.1.a.(i). Table 3-1 summarizes annual emissions from all emission sources proposed at the Station. 1 https://nepis.epa.gov/Exe/ZyPDF.cgi?Docket'=P100OA05.pdf Permit to Construction Application Mountain Peak Power, LLC Table 3-1 Projected Air Pollutant Emission Rates EPN/Emission Source VOC NO CO SO2 TSP MID PM2S Benzene Formaldehyde HAP lb/hr tpy lb/hr tpy Ib/hr tpy Ib/hr tpy Ib/hr tpy lb/hi tpy lb/hr tpy lb/hr tpy Ib/hr tpy lb/hi tpy 1.05 132 2.85 4.13 3.37 4.89 0,19 0.28 0,61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0,17 0.24 0.26 0.38 CT -1 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4.89 0,19 0.28 0,61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -2 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4,89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -3 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4,89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -4 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4,89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -5 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4.89 0,19 0.28 0,61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0,17 0.24 0.26 0.38 CT -6 / LM2500 G4 DLE Gas Turbine FWP / Firewater Pump 0.08 0.12 0.08 0.12 0.07 0,10 1.30E-04 1.89E-04 4.03E-03 0.01 4.03E-03 0.01 4.03E-03 0,01 7.99E-05 1.16E-04 1.01E-04 1.47E-04 1.01E-04 1.47E-04 Diesel Tank 7.06E-05 1.02E-04 -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- Total 6.37 9.24 17.18 24.91 20.31 29.46 1.16 1.68 39.37 57.09 39.37 57.09 42.79 62.04 1.01 1.47 1.59 2.3D Major Source Threshold i NSR) 25.00 25.00 250.00 250.00 250,00 250.00 10.00 10.00 25,00 Major Source Threshold (Title V) 25.00 25.00 100.00 100,00 100.00 100.00 10.00 10.00 25,00 Permit to Construction Application Mountain Peak Power, LLC Table 3-2 HAP Emissions Summary (tpy) HAP Emissions (tpy) 6 CTs FWP 6 CTs + FWP 1,3 -Butadiene 1.11E-03 4.86E-06 1.12E-03 Acetaldehyde 1.03E-01 9.53E-05 1.03E-01 Acrolein 1.65E-02 1.15E-05 1.66E-02 Benzene 3.10E-02 1.16E-04 3.11E-02 Ethylbenzene 8.27E-02 0.00E+00 8.27E-02 Formaldehyde 1.47E+00 1.47E-04 1.47E+00 Propylene Oxide 7.50E-02 0.00E+00 7.50E-02 Toluene 3.36E-01 5.08E-05 3.36E-01 Xylenes (m,p,o) 1.65E-01 3.53E-05 1.65E-01 Polycyclic Matter (Total Organic PO M) 9.48E-04 2.09E-05 9.69E-04 Metals Arsenic 5.07E-04 0 5.07E-04 Beryllium 3.04E-05 0 3.04E-05 Cadmium 2.79E-03 0 2.79E-03 Chromium 3.55E-03 0 3.55E-03 Chromium VI 3.55E-03 0 3.55E-03 Cobalt 2.13E-04 0 2.13E-04 Lead 1.27E-03 0 1.27E-03 Manganese 9.63E-04 0 9.63E-04 Mercury 6.59E-04 0 6.59E-04 Nickel 5.32E-03 0 5.32E-03 Selenium 6.08E-05 0 6.08E-05 Total HAPs 2.30 4.81E-04 2.30 Permit to Construction Application Mountain Peak Power, LLC FEDERAL AND STATF REGULATORY APPLICABILITY This section summarizes the applicable federal and state regulations2 to the proposed Mountain Peak Power facility located in Weld County, Colorado. Federal and state applicability is evaluated for the proposed sources at the facility. 4.1 State Regulatory Requirements 4.1.1 5 CCR 1001-3: Regulation 1 - Emission Control for Particulate Matter, Smoke, Carbon Monoxide, and Sulfur Oxides The proposed facility will be subject to the requirements stipulated in Regulation 1 of 5 CCR 1001-3 and will comply with the requirements provided in Section II.A.1 and 2. 4.1.2 5 CCR 1001-4: Regulation 2 - Odor Emission The facility is subject to the requirements stipulated in Regulation 2 of 5 CCR 1001-4. According to Section I.B of the regulation, for facilities located in areas not used predominantly for residential or commercial purposes, it is a violation if odors are detected after the odorous air has been diluted with fifteen (15) or more volumes of odor free air. Consistent with Section I.C.1 of the regulation, as a manufacturing source, the facility is required to have an affirmative defense to violations of Section I.B. of the regulation. 4.1.3 5 CCR 1001-5: Regulation 3 - Stationary Source Permitting and Air Pollutant Emission Notice Requirements The State of Colorado has been granted authority to implement and enforce the permitting requirements specified by the federal Clean Air Act. The general requirements for permits and permit revisions are codified under the state air quality control commission regulations, Regulation Number 3, Stationary Source Permitting and Air Pollutant Emission Notice Requirements. Weld County is located in the DMNFR area designated as nonattainment for ozone under the 8 -Hour 2008 and 2015 N ational Ambient Air Quality Standard (NAAQS). The DMNFR nonattainment area is designated as "severe" nonattainment for the 2015 standard, and the proposed facility has PTE less than 25 tpy for each of the ozone precursors, NOx and of VOC. As such, the facility will be a minor source under N onattainment New Source Review (NNSR). Table 4-1 presents an applicability analysis of the various sub -sections of Regulation 3. The facility is a minor source of criteria air pollutants for which the area is designated as attainment or unclassifiable as defined in 40 CFR 52.21(b)(4) incorporated in Reg. 3. Review under Prevention of Significant Deterioration (PSD) regulations is not required. As promulgated in 40 CFR 70.3, the facility will be a minor source of a regulated pollutant and therefore, it is not subject to the Title V Operating Permits program as implemented in 5 CCR 1001-5, Colo. Reg. 3, Part C and Part D. A summary of the facility uncontrolled and controlled emissions of all criteria pollutants are provided in Table 3-1. Detailed calculations are provided in Appendix A. Air quality modeling determinations and corresponding files have been submitted directly to the APCD Modeling Group under separate cover. 4.1.4 5 CCR 1001-6: Regulation 4 - Sale and Installation of Wood -Burning Appliances and the Use of Certain Wood -Burning Appliances during High Pollution Days N ot applicable; the facility does not sell, install, or utilize wood -burning appliances. 4.1.5 5 CCR 1001-8: Regulation 6 - Standards of Performance for New Stationary Sources See the discussion presented in Section 4.2. 2 5 CCR Regulations 5, 13, 14 and 17 have been repealed and are no longer effective. Permit to Construction Application Mountain Peak Power, LLC 4.1.6 5 CCR 1001-9: Regulation 7 - Control of Ozone via Ozone Precursors and Control of Hydrocarbons via Oil and Gas Emissions The facility is located in the Denver Metro North Front Range nonattainment area and will be a minor source of VOC and NOx; therefore, Regulation 7 is applicable to the facility. The proposed emergency firewater pump will be diesel fuel -fired, and thus will not be subject to Part E, Section I. 4.1.7 5 CCR 1001-10: Regulation 8 - Control of Hazardous Air Pollutants See the discussion presented in Section 4.2. 4.1.8 5 CCR 1001-11: Regulation 9 - Open Burning, Prescribed Fire, and Permitting N ot applicable; the facility does not propose to engage in any open burning or prescribed fire. 4.1.9 5 CCR 1001-19: Regulation 15 - Control of Emissions of Ozone -Depleting Compounds The facility will comply, as applicable, with the requirements stipulated in Regulation 15, including the standards, criteria, and requirements set forth in 40 CFR Part 82, Subpart F. 4.1.10 5 CCR 1001-22: Regulation 18 - Control of Emissions of Acid Deposition Precursors See the discussion presented in Section 4.2. 4.1.11 5 CCR 1001-23: Regulation 19 - The Control of Lead Hazards N ot applicable; the facility will not generate emissions containing lead compounds. 4.1.12 5 CCR 1001-25: Regulation 21 - Control of Volatile Organic Compounds from Consumer Products and Architectural and Industrial Maintenance Coatings N ot applicable; the facility will not generate emissions containing volatile organic compounds from consumer products and architectural and industrial maintenance coatings. 4.1.13 5 CCR 1001-30: Regulation 26 - Control of Emissions From Engines and Major Stationary Sources The facility is located in the Denver Metro North Front Range nonattainment area and is a synthetic minor source of NOx. However, the Part B Section II.A and II.A.6 requirements for major sources of NOx are not applicable because the new turbines did not exist as of the dates in Sections II.A.1 or II.A.6.a. 4.2 Federal Regulatory Applicability 4.2.1 New Source Review (NSR) Applicability See discussion presented in Section 4.1.3 above. Permit to Construction Application Mountain Peak Power, LLC 4.2.2 New Source Performance Standards (NSPS) The following subparts of the NSPS, codified at 40 CFR 60, are evaluated for potential applicability to the proposed power station. 4.2.2.1 NSPS Subpart A - General Provisions Sources subject to source specific NSPS are also subject to the general provisions of NSPS Subpart A that contain the initial notification requirements, initial startup notifications, performance tests, general monitoring, recordkeeping, and reporting requirements. 4.2.2.2 NSPS Subpart Kb - Volatile Organic Liquid Storage Vessels N SPS Subpart Kb is applicable to storage vessels for which construction, modification or reconstruction commenced after July 23, 1984, with storage capacities greater than or equal to 75 m3 (19,812 gallons) and that store volatile organic liquids (VOL). This subpart does not apply to storage vessels with a capacity greater than or equal to 151 m3 storing liquid with a maximum true vapor pressure less than 3.5 kPa or with a capacity greater than 75 m3 but less than 151 m3 storing a liquid with a maximum true vapor pressure less than 15.0 kPa. The proposed ultra -low sulfur diesel storage tank at the station has a storage capacity less than 75 m3 with a true vapor pressure less than 15.0 kPa, and is therefore, not subject to NSPS Subpart Kb. 4.2.2.3 NSPS Subpart KKKK - NSPS for Stationary Combustion Turbines 40 CFR 60, Subpart KKKK applies to stationary combustion turbines that commence construction after February 18, 2005, and that have a heat input at peak load that is equal to or greater than 10 MMBtu per hour, based on the higher heating value of the fuel. Each combustion turbine will have a peak load heat input of greater than 50 MMBtu/hr and less than 850 MMBtu/hr. For natural gas - fired turbines, NOx emission limit of 25 ppm at 15 percent oxygen (O2) or 1.2 pound per megawatt - hour (lb/MWh) would apply. Mountain Peak Power will use continuous emissions monitoring system (CEMS) to monitor compliance with the NOx limit. 40 CFR Part 60, Subpart KKKK specifies that the proposed combustion turbines can either comply with an SO2 emission limit of 0.9 lb/MWh gross output or must not burn in any fuel which contains total potential sulfur emissions in excess of 0.060 lb SO2/MMBtu heat input. Natural gas is the only fuel proposed for these combustion turbines and as such compliance with the SO2 limit should not be an issue. N ote that NSPS Subpart GG is not applicable to combustion turbines that are subject to NSPS S ubpart KKKK. 4.2.2.4 NSPS Subpart TTTT - NSPS for Greenhouse Gas Emissions for Electric Generating Units 40 CFR Part 60, Subpart TITI- applies to stationary combustion turbines that commence construction after January 8, 2014, have a base heat input rating greater than 250 MMBtu/hr and serve a generator capable of selling 25 MW of electricity to a utility power distribution system. The proposed GE LM2500 simple cycle combustion turbines are affected sources under this rule. These simple cycle combustion turbines would not be capable of complying with the 1,000 lb CO2/MWh standard that is designed for combined cycle combustion turbine installations. Instead, these units would need to supply their design efficiency or 50 percent, whichever is less, times their potential electric output or less as net -electric sales on either a 12 -operating month or a 3 -year rolling average basis and would comply with the heat input -based standards (see Table 2 of 40 CFR Part 60, Subpart I I I I ). In addition, the heat input -based standards will apply. If a unit combusts more than 90 percent natural gas on a heat input basis on a 12 operating month rolling basis, then the 120 lb/CO2 MMBtu (HHV) limit would apply. Permit to Construction Application Mountain Peak Power, LLC 4.2.2.5 NSPS Subpart IIII - NSPS for Stationary Compression Ignition Internal Combustion Engines 40 CFR Part 60, Subpart IIII applies to stationary compression -ignition internal combustion engines manufactured in 2007 or later. The proposed emergency firewater pump engine, model year 2009 or later, will be subject to 40 CFR Part 60, Subpart IIII. Per 40 CFR Part 60, Subpart IIII, Mountain Peak must operate the engine in compliance with the emergency engine emission standards set forth in 40 CFR 60.4204 for non -methane hydrocarbons plus NON, CO and PM. Mountain Peak Power will comply with 40 CFR Part 60, Subpart IIII by purchasing a USEPA Tier III engine certified by the manufacturer and equipped with a non-resettable hour meter, by installing and configuring the engine per the manufacturer's specifications, and by operating and maintaining the engine consistent with the manufacturer's instructions. 4.2.3 National Emission Standards for Hazardous Air Pollutants (NESHAP) 4.2.3.1 NESHAP Subpart A - General Provisions Sources subject to source specific NESHAP are also subject to the general provisions of NESHAP S ubpart A that contain the initial notification requirements, initial startup notifications, performance tests, general monitoring, recordkeeping, and reporting requirements. 4.2.3.2 NESHAP Subpart YYYY - Stationary Combustion Turbines S ubpart YYYY provides HAP emission limitations, operating limitations, and compliance requirements for stationary combustion turbines located at major sources of HAPs. The proposed facility is not a major source of HAPs and therefore, is not subject to Subpart YYYY. 4.2.3.3 NESHAP Subpart ZZZZ - Stationary Reciprocating Internal Combustion Engines (RICE) S ubpart ZZZZ provides HAP emission limitations and operational limitations for stationary RICE including emergency engines located at major or area sources of HAP. The diesel -fired emergency firewater pump is subject to Subpart ZZZZ and will comply with the NESHAP via compliance with N SPS Subpart IIII. 4.2.4 Chemical Accident Prevention (CAM) - 40 CFR 68 The Clean Air Act (CAA) requires affected sources to develop a Risk Management Plan (RMP). The RMP rule is applicable to stationary sources that have processes that processes, stores, or uses a chemical listed under 112(r) of the CAA in excess of its threshold quantity, then that process is subject to the applicable provisions of the RMP rule. The proposed facility will use an aqueous ammonia (<=19% by weight) storage tank that is not subject to RMP requirements. 4.2.5 Acid Rain Program - 40 CFR 72 - 78 Clean Air Act (CAA) Title IV authorizes the EPA under the Acid Rain Program (40 CFR 72 through 78) to achieve reductions of SO2 and NOx emissions (acid rain). The proposed facility will be subject to the requirements listed under this rule and will comply as required. 4.2.6 Stratospheric Ozone Protection - 40 CFR 82 Title VI of the CAA requires phase out of ozone depleting substances (ODS). The proposed facility will not manufacture any ODS and will not own or operate equipment containing ODS. As such, requirements of 40 CFR 82, Subpart F will not apply. Permit to Construction Application Mountain Peak Power, LLC APPENDIX A EMISSION CALCULATIONS Mountain Peak Power LLC Mountain Peak Power Weld County, Colorado PTE Summary EPN/Emission Source VOC NO, CO SO2 TSP PMlo PM25 Benzene Formaldehyde HAP lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy 1.05 1.52 2.85 4.13 3.37 4.89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -1 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4.89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -2 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4.89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -3 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4.89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -4 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4.89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -5 / LM2500 G4 DLE Gas Turbine 1.05 1.52 2.85 4.13 3.37 4.89 0.19 0.28 0.61 0.88 6.56 9.51 6.56 9.51 7.13 10.34 0.17 0.24 0.26 0.38 CT -6 / LM2500 G4 DLE Gas Turbine FWP / Firewater Pump 0.08 0.12 0.08 0.12 0.07 0.10 1.30E-04 1.89E-04 4.03E-03 0.01 4.03E-03 0.01 4.03E-03 0.01 7.99E-05 1.16E-04 1.01E-04 1.47E-04 1.01E-04 1.47E-04 Diesel Tank 7.06E-05 1.02E-04 -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- -- Total 6.37 9.24 17.18 24.91 20.31 29.46 1.16 1.68 39.37 57.09 39.37 57.09 42.79 62.04 1.01 1.47 1.59 2.30 Major Source Threshold (NSR) 25.00 25.00 250.00 250.00 250.00 250.00 10.00 10.00 25.00 Major Source Threshold (Title V) 25.00 25.00 100.00 100.00 100.00 100.00 10.00 10.00 25.00 Mountain Peak Power LLC Mountain Peak Power Weld County, Colorado Six Combustion Turbines with SCR and Oxidation Catalyst Natural Gas Heat Input (100% Load) Natural Gas Heat Input (50% Load) 295.43 MMBtu/hr 188.43 MMBtu/hr Per turbine Number of Combustion Turbines (CTs) Annual Operating Hours per CT (Normal Ops) Number of Startups/Shutdowns per year Duration of Startups/Shutdown Total SU/SD hours per year Total SU/SD hours + normal ops hours per year per CT Total for 6 turbines Total Annual Operating Hours for all CTs 6 2,900 hr/year/CT 100 events/year/CT (50 SU and 50 SD) 0.167 hr/event (10 mins per event) 16.67 hr/year/CT 2,917 hr/year/CT 17,500 hr/year (normal ops + SU/SD) EMISSION FACTORS 100% Load 50% Load Parameter/Pollutant Nat. Gas. NOX Emissions, lb/MMBtu 0.00913 0.00912 CO Emissions, lb/MMBtu 0.00889 0.00888 PMf;it Emissions, lb/MMBtu 0.00190 0.00190 PM10 Emissions, lb/MMBtu 0.01479 0.02205 PM2.5 Emissions, lb/MMBtu 0.01479 0.02205 SO2 Emissions, lb/MMBtu 0.00065 0.00065 VOC Emissions, lb/MMBtu 0.00343 0.00337 EMISSION FACTORS Startup Shutdown NOX Emissions, lb/event 6.73217 2.17073 CO Emissions, lb/event 20.18549 23.17507 PMfilt Emissions, lb/event 2.15915 0.62197 PM10 Emissions, lb/event 2.15915 0.62197 PM2.5 Emissions, lb/event 2.15915 0.62197 SO2 Emissions, lb/event _ 0.07296 0.05915 VOC Emissions, lb/event 1.34802 0.65529 GE Data - with SCR GE Data - with Ox Cat AP -42 GE Data GE Data GE Data GE Data (Filt PM) (Filt + Cond PM) (Filt + Cond PM) SCR Controlled emission rate Ox. Cat Controlled emission rate assumed to be = PM10 (i.e., includes CPM) PM10 (Front and Back + SCR contribution) PM2.5 (Front and Back + SCR contribution) SO2 lb/event for SCR controlled scenario Ox. Cat Controlled emission rate Parameter/Pollutant Normal Ops SU/SD NANSR Major Source Threshold PSD Major Source Threshold NANSR Triggered? . PSD Review Triggered? NOX Emissions, tpy 23.46 1.34 25 250 No : CO Emissions, tpy 22.85 6.50 : 250 No PMf;it Emissions, tpy 4.88 0.42 : : 250 : No PM10 Emissions, tpy 56.67 0.42 = - : 250 = - No PM2.5 Emissions, tpy 56.67 0.42 - : 250 No SO2 Emissions, tpy 1.66 0.020 : : 250 No VOC Emissions, tpy 8.82 0.30 25 No Mountain Peak Power LLC Mountain Peak Power Weld County, Colorado Six Combustion Turbines with SCR and Oxidation Catalyst Natural Gas Heat Input (100% Load) Natural Gas Heat Input (50% Load) 295.43 MMBtu/hr 188.43 MMBtu/hr I Per turbine Number of Combustion Turbines (CTs) Annual Operating Hours per CT (Normal Ops) Number of Startups/Shutdowns per year Duration of Startups/Shutdown Total SU/SD hours per year Total SU/SD hours + normal ops hours per year per CT Total for 6 turbines Total Annual Operating Hours for all CTs 6 2,900 hr/year/CT 100 events/year/CT (50 SU and 50 SD) 0.167 hr/event (10 mins per event) 16.67 hr/year/CT 2,917 hr/year/CT 17,500 hr/year (normal ops + SU/SD) EMISSION FACTORS 1' 2 I Value Units CO2 53.06000 kg/MM Btu CH4 a 1.00E-03 kg/MMBtu Btu N2O 1.00E-04 kg/MM Btu CO2e 53.11480 kg/MM Btu EMISSIONS Value Units CO2 302,388.9 tons/year CH4 5.7 I tons/year N2O 0.6 tons/year CO2e 302,701.2 tons/year 50450.20037 (1) Emission factors for CO2, CH4 and N2O are taken from 40 CFR 98, Table C-1 and Table C-2. Values are converted from kg/MMBtu to Ib/MMBtu. (2) Global Warming Potentials taken from 40 CFR 98, Table A-1. CO2 1 CH4 25 N2O 298 Mountain Peak Power LLC Mountain Peak Power Weld County, Colorado Emergency Diesel -Fired Firewater Pump Description Value Units Engine Rating Annual Operating Hours Fuel Type Diesel S Content 1 Density of Diesel Heating Value of Diesel 2 Conversion Factor 3 355 HP 100 hr/year Diesel 15 ppmw 7 lb/gal 138000 Btu/gal 7000 Btu/hp-hr FWP Annual Fuel Use - Diesel 249 MMBtu/year Pollutant Emission Factor Emission Factor Units of Measure Reference Emissions (tons/year) PM10 3.29E-04 lb/hp-hr (4) 0.0058 PM, 5 3.29E-04 lb/hp-hr (5) 0.0058 SO2 1.06522E-05 lb/hp-hr (6) 0.0002 NOx 6.58E-03 lb/hp-hr (4) 0.1168 CO 5.76E-03 lb/hp-hr (4) 0.1022 VOC Total 6.58E-03 lb/hp-hr (7) 0.1168 CO, 163.05 lb/MMBtu (8) 20.259 CH4 0.0066 lb/MMBtu (8) 0.001 N20 0.0013 lb/MMBtu (8) 0.000 CO2e 163.612 lb/MMBtu (9) 20.329 (1) Per 40 CFR 60.4207(b), maximum sulfur content of ultra low Sulfur diesel nonroad diesel as specified in 40 CFR 80.510(b)(1)(i). (2) Higher Heating Value (HHV) of diesel obtained from 40 CFR 98. (3) Average brake -specific fuel consumption (BSFC) is based on AP -42 Section 3.3, Table 3.3-1. (4) Emission factors for Nox, PM, VOC and CO obtained from Tier III emission standards for engine within size range 225 kW to 450 kW. Factors converted from g/kW-hr to lb/hp-hr (5) PM2.5 assumed to be equal to PM10. (6) SO2 emission factor = BSFC (7,000 Btu/hp-hr) / HHV (138,000 Btu/gal) x density of diesel (7 lb/gal) x concentration of Sulfur (15 ppmw) / 1,000,000 x 64 lb SO2 / 32 lb S (7) Nox and VOC emissions are each depicted at a rate of 4.0 g/kW-hr (EPA Tier Ill) for conservative permitting purposes. However, being a Tier III unit, the firewater pump's emissions of Nox+NMHC will not exceed 4.0 g/kW-hr, as specified in 40 CFR 60, Subpart 1111. (8) Emission factors for CO2, CH4 and N2O are taken from 40 CFR 98, Table C-1 and Table C-2. Values are converted from kg/MMBtu to lb/MMBtu. (9) Global Warming Potentials taken from 40 CFR 98, Table A-1. CO, 1 CH4 25 N2O 298 Detailed Emissions Calculations Diesel Belly Tanks Mountain Peak Power LLC Mountain Peak Power Weld County, Colorado Diesel Fire Water Pump Fuel Tank Emissions Calculations Parameter Description(a) Equation Value Tank Contents Diesel Fuel Tank Height (H) (ft) 6.00 Tank Diameter (D; (ft) 4.10 Tank Effective Diameter (DE) (ft) For horizontal tanks DE = V[LD/(rr/4)] 5.60 Tank Dome Roof Radius (RR), ft Dome Roofs: Assumed RR = D Flat Roofs: N/A N/A Tank Shell Height (Hs), ft [Use height of horizontal tank] 6.0 Effective Height (HE), ft For horizontal Tanks: HE = (rr/4)DE 4.4 Nominal Capacity, ft3 76.5 Nominal Capacity (gal; 572 Liquid Height (HD, ft Assumed = 0.9H5 5.4 Tank Cone Roof Slope (SR), ft/ft 0.0625 - Unknown Slope 0.0625 Tank Roof Height (HR), ft HR = SRRs 0.375 Roof Outage (Hu)), ft Dome Roofs: HRo = HR Cone [(1/2)±(116)(HR/RS)2] Roofs: HRo = 1/3HR Flat Roofs: HRo = 0 0.1250 Vapor Space Outage (Hvo), ft Vertical tanks (used for rectangular tank): Hvo=Hs -HL+HRo Horizontal tanks: Hvo = HE/2 2.2 Vapor Space Volume (Vv), ft3 For horizontal tank: Hvo x (7/4 DE2) 54.1 Ideal Gas Constant (R), psia ft3/lb-mole R Constant 10.731 Daily Maximum Ambient Temperature (TAX), R (b) AP -42, Table 7.1-7 523.2 Daily Minimum Ambient Temperature (TAN), R (b) AP -42, Table 7.1-7 497.6 Daily Average Ambient Temperature (TAA), R TAA = (TAX + TAN)/2 510.4 Paint Solar Absorptance (a), dimensionless (c) AP -42, Table 7.1-6 0.89 Liquid Bulk Temperature (TB), R TB = TAA + 6a - 1 514.7 Daily Total Solar Insolation Factor (I;, Btu/ft2 d (b) AP -42, Table 7.1-7 1,491.0 Daily Average Liquid Surface Temperature (T,A), R T,A = 0.4TAA + 0.6TB + 0.005 aI 519.6 Vapor Molecular Weight (Mv), lb/lb-mole Vapor Molecular weight of diesel fuel 130 Vapor Pressure at T,A (PVA), Asia Raoult's Law or Antoine Equation 0.0047 Vapor Density (Wv), lb/ft3 Wv = MvPvA/RT,A 0.00011 Daily Ambient Temperature Range (TA), R TA = TAX - TAN 25.6 Daily Vapor Temperature Range (Tv), R Tv = 0.7TA + 0.02 aI 44.5 Vapor Pressure at TAN (PVN), Asia Raoult's Law or Antoine Equation 0.0030 Vapor Pressure at TAX (Pvx), Asia Raoult's Law or Antoine Equation 0.0073 Daily Vapor Pressure Range (Pv), psia Pv = Pvx - PVN 0.0042 Breather Vent Pressure Setting Range (PB), psia PB = PBp - Pgv (Assumed = 0.06) 0.06 Atmospheric Pressure (PA), psia Constant 14.7 Vapor Space Expansion Factor (KE), dimensionless KE = Tv/T,A + (Pv - PB)/(PA - PvA) 0.08 Vented Vapor Saturation Factor (Ks), dimensionless Ks = 1/(1 + 0.053PvAHvo) 1.0 Number of Days/Year in Operation Constant 365 Standing Storage Losses (Ls), lb/year Ls = 365 WvVvKEKs 0.18 Liquid Density (lb/gal; Density of diesel fuel 7.10 Potential Throughput (Q), gal 100 hours of operation at 100% load 1,801 Potential Throughput (Q), bbl Throughput is in bbls (42 gal/bbl; 42.9 Maximum Liquid Height (H0(), ft Assumed = 0.9H5 5.4 Tank Maximum Liquid Volume (V0<), ft3 Assumed = 0.9*Nominal Capacity 68.8 Turnovers (N), dimensionless N = 5.614Q/VLX 3.5 Turnover Factor (KN), dimensionless For N ≤ 36 KN = 1, 1.0 For N > 36 KN = (180 + N)/6N Working Loss Factor (Kr), dimensionless For Organic Liquids, KP = 1 1.0 Working Losses (Lw), lb/year LW = 0.001MvPvAQKNKP 0.03 Total Uncontrolled Losses (LT), lb/year/tank TL = Ls + LW 0.20 Total Uncontrolled Losses (LT), ton/year/tank 2,000 lb/ton 1.02E-04 Total Uncontrolled Losses (LT), lb/hr/tank 8,760 hr/yr 2.34E-05 Notes: (a) Emissions calculated according to the methodology presented in AP -42, Section 7.1 with adjustments made to account for vapor space volume of the proposed horizontal diesel tank. (b) Meteorological data from AP -42, Table 7.1-7 for Denver, CO was used. (c) Paint solar absorptance from AP -42, Table 7.1-6 for green tanks in new condition. Page 6 of 13 Mountain Peak Power LLC Mountain Peak Power Weld County, Colorado Hazardous Air Pollutant Emissions Per combustion turbine Natural Gas (100% Load) Natural Gas (50% Load) 295.43 MMBtu/hr 188.43 MMBtu/hr Annual Fuel Use - Natural Gas Annual Limit 861,683 MMBtu/year/ct Btu/yea r/ct 2,917 hr/year/CT Description Value Units Engine Rating Annual Operating Hours Fuel Type Diesel S Content Density of Diesel Heating Value of Diesel Conversion Factor 355 HP 100 hr/year Diesel 15 ppmw 7 lb/gal 138000 Btu/gal 7000 Btu/hp-hr FWP Annual Fuel Use - Diesel 249 MMBtu/year HAP Emission Factors for Natural Gas -Fired Stationary Turbines (AP -42 Section 3.1) lb/MMBtu Emission Diesel (AP Factors for Fired Engines -42 Section 3.3) lb/MMBtu Emissions (tons/year) Source Threshold 6 CTs FWP I 6 CTs + FWPCombustion Major (tons/year) 1,3 -Butadiene 4.30E-07 3.91E-05 1.11E-03 4.86E-06 1.12E-03 10 10 10 10 10 10 10 10 10 Acetaldehyde 4.00E-05 7.67E-04 1.03E-01 9.53E-05 1.03E-01 Acrolein 6.40E-06 9.25E-05 1.65E-02 1.15E-05 1.66E-02 Benzene 1.20E-05 9.33E-04 3.10E-02 1.16E-04 3.11E-02 Ethylbenzene 3.20E-05 0 8.27E-02 0.00E+00 8.27E-02 Formaldehyde 5.68E-04 1.18E-03 1.47E+00 1.47E-04 1.47E+00 Propylene Oxide 2.90E-05 0 7.50E-02 0.00E+00 7.50E-02 Toluene 1.30E-04 4.09E-04 3.36E-01 5.08E-05 3.36E-01 Xylenes (m,p,o) 6.40E-05 2.84E-04 1.65E-01 3.53E-05 1.65E-01 Polycyclic Organic Matter (Total POM) 2.20E-06 1.68E-04 9.48E-04 2.09E-05 9.69E-04 10 Metals - 10 10 10 10 10 10 10 10 10 10 10 25 Arsenic 1.96E-07 -- 5.07E-04 0 5.07E-04 Beryllium 1.18E-08 -- 3.04E-05 0 3.04E-05 Cadmium 1.08E-06 -- 2.79E-03 0 2.79E-03 Chromium 1.37E-06 -- 3.55E-03 0 3.55E-03 Chromium VI 1.37E-06 -- 3.55E-03 0 3.55E-03 Cobalt 8.24E-08 -- 2.13E-04 0 2.13E-04 Lead 4.90E-07 -- 1.27E-03 0 1.27E-03 Manganese 3.73E-07 -- 9.63E-04 0 9.63E-04 Mercury 2.55E-07 -- 6.59E-04 0 6.59E-04 Nickel 2.06E-06 -- 5.32E-03 0 5.32E-03 Selenium 2.35E-08 -- 6.08E-05 0 6.08E-05 Total HAPs 2.30 4.81E-04 I 2.30 Note: ULSD for the FWP will need a storage tank whose HAP emissions are assumed to be small, total VOC from storage tanks was added to the total HAP emissions to compare against Major Source Threshold of 25 tons per year total HAPs. GTP REPORT Date: 03/14/2023 Version: GTP 5.0.6 Performed By: Project: Cherine Wojcik Colorado - Uncontrolled emissions cases Estimated Engine Performance NOT FOR GUARANTEE: USE FOR STUDY ONLY Engine Model Generator Frequency Vo ltage PF Case Ambient Conditions Dry Bulb Temperature Wet Bulb Temperature Relative Humidity Elevation a.s.l. Barometric Pressure Engine Inlet Conditioning Compressor Inlet Temperature Compressor Inlet RH Chilling/Heat Capacity EVAP Water Flow Pressure Losses Inlet Pressure Loss Exh. Pressure Loss Performance GTG Load Generator Output, Gross Estimated Heat Rate, Gross STD Aux Load OPT Aux Load BOP Aux Load Gen. Output, Unit Net Estimated Heat Rate, Net Heat Consumption Fuel Fuel LHV Heat Input - LHV Heat Input - HHV Fuel Flow Vol. Fuel Flow Fuel Temperature Fuel HHV Fuel GCV Fuel NO/ NOx Control Diluent Flow Emissions (ESTIMATED) NOx, Ref % 02 CO, Ref % 02 UHC, Ref % 02 VOC, Ref % 02 HCOH NOx as NO2 NOx as NO2 CO CO UHC (CH4) VOC VOC PM -10 PM10 / PM2.5 SOx as 502 (0.25 grains / 100 SCF) SOx as SO2 ( 0.25 grains / 100 SCF) HCOH HCOH Benzene (AP -42) Acrolein (AP -42) Hz kV "F ft psia 'F kBtu/h lb/s LM2500 LM2500 LM2500 LM2500 LM2500 LM2500 LM2500 +G4 DLE Gas +G4 DLE Gas +G4 DLE Gas +G4 DLE Gas +G4 DLE Gas +G4 DLE Gas +G4 DLE Gas ANDRITZ A03 c1B ANDRITZ A03 cIB ANDRITZ A03 cIB ANDRITZ A03 cIB ANDRITZ A03 clB ANDRITZ A03 c1B ANDRITZ A03 dB 60 60 60 60 60 60 60 13.8 13.8 13.8 13.8 13.8 13.8 13.8 0.85 0.85 0.85 0.85 0.85 0.85 0.85 Case 1 Low -Low Day Full load 0.0 -0.7 80.0 4861.0 12.3 None 0.0 80.0 0.0 0.0 in H2O 5.8 in H2O 6.2 kW Btu/kWh kW kW kW kW Btu/kWh MMBtu/h Btu/lb MMBtu/h MMBtu/h lb/s scfm OF Btu/lb Btu/scf Btu/scf 100.0 30502.7 8627.7 193.0 0.0 0.0 30309.7 8682.7 263.2 Gas - Fuel Comp. 20512.2 263.2 291.9 3.6 4740.1 77.0 22753.1 1026.4 925.3 DLE lb/s 0.0 ppm ppm ppm ppm ppb lb/h Ib/MMBtu lb/h Ib/MMBtu lb/h lb/h I b/MMBtu lb/h Ib/MMBtu lb/h Ib/MMBtu lb/h Ib/MMBtu lb/h lb/h Case 15 Low -Low Day +heating Full load 0.0 -0.7 80.0 4861.0 12.3 Heating 10.0 47.9 1570.7 0.0 Case 3 Cold Day Full load 30.0 26.9 70.0 4861.0 12.3 None 30.0 70.0 0.0 0.0 6.8 5.8 6.2 6.2 100.0 30604.0 8667.5 193.0 0.0 0.0 30411.0 8722.5 265.3 Gas - Fuel Comp. 20512.2 265.3 294.2 3.6 4777.8 77.0 22753.1 1026.4 925.3 DLE 0.0 100.0 30545.3 8721.3 193.0 0.0 0.0 30352.3 8776.7 266.4 Gas - Fuel Comp. 20512.2 266.4 2955 3.6 4798.2 77.0 22753.1 1026.4 925.3 DLE 0.0 Case 17 Cold Day + heating Full load 30.0 26.9 70.0 4861.0 12.3 Heating 40.0 46.5 1525.7 0.0 Case 23 ISO Full load 59.0 50.9 60.0 4861.0 12.3 Case 7 not aay + Evap Full load 90.0 63.6 25.0 4861.0 12.3 None Evap. Cooling 59.0 66.2 60.0 87.5 0.0 0.0 0.0 0.9 6.8 5.8 6.2 6.2 100.0 29568.3 8757.8 193.0 0.0 0.0 29375.3 8815.3 259.0 Gas - Fuel Comp. 20512.2 259.0 287.2 3.5 4664.2 77.0 22753.1 1026.4 925.3 DLE 0.0 100.0 27677.9 8874.3 193.0 0.0 0.0 27484.9 8936.6 245.6 Gas - Fuel Comp. 20512.2 245.6 272.5 3.3 4424.1 77.0 22753.1 1026.4 925.3 OLE 0.0 Case 5 not aay Full load 90.0 63.6 25.0 4861.0 12.3 None 90.0 25.0 0.0 0.0 5.8 5.8 6.2 6.2 100.0 27030.6 8932.5 197.0 0.0 0.0 26833.6 8998.1 241.5 Gas - Fuel Comp. 20512.2 241.5 267.8 3.3 4349.0 77.0 22753.1 1026.4 925.3 DLE 0.0 100.0 24036.5 9153.9 193.0 0.0 0.0 23843.5 9228.0 220.0 Gas - Fuel Comp. 20512.2 220.0 244.1 3.0 3963.1 77.0 22753.1 1026.4 925.3 LM2500 +G4 DLE Gas ANDRITZ A03 cIB 60 13.8 0.85 Case 2 Low -Low Day MECL 0.0 -0.7 80.0 4861.0 12.3 None 0.0 80.0 0.0 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 16 Low -Low Day +heating MECL 0.0 -0.7 80.0 4861.0 12.3 Heating 10.0 47.9 1195.4 0.0 5.8 6.8 6.2 6.2 50.0 15251.4 11554.7 193.0 0.0 0.0 15058.4 11702.8 167.8 Gas- Fuel Comp. 20512.2 167.8 186.2 2.3 3023.0 77.0 22753.1 1026.4 925.3 50.0 15302.0 11605.2 193.0 0.0 0.0 15109.0 11753.5 169.1 Gas - Fuel Comp. 20512.2 169.1 187.6 2.3 3046.3 77.0 22753.1 1026.4 925.3 LM2500 +G4 DLE Gas ANDRITZ A03 dB 60 13.8 0.85 Case 4 Cold Day MECL 30.0 26.9 70.0 4861.0 12.3 None 30.0 70.0 0.0 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 cIB 60 13.8 0.85 Case 18 Cold Day + heating MECL 30.0 26.9 70.0 4861.0 12.3 Heating 40.0 46.5 1140.6 0.0 5.8 6.8 6.2 6.2 50.0 15272.7 11436.6 193.0 0.0 0.0 15079.7 11583.0 166.4 Gas - Fuel Comp. 20512.2 166.4 184.5 2.3 2996.3 77.0 22753.1 1026.4 925.3 DLE DLE DLE DLE 0.0 0.0 0.0 0.0 Estimated Estimated Estimated Estimated Estimated Estimated Estimated 25.0 25.0 25.0 25.0 25.0 25.0 25.0 40.0 25.0 25.0 25.0 25.0 25.0 25.0 24.0 15.0 15.0 15.0 15.0 15.0 15.0 4.8 3.0 3.0 3.0 3.0 3.0 3.0 640.0 400.0 400.0 400.0 400.0 400.0 400.0 26.5 26.7 26.8 26.1 24.8 24.3 22.1 0.091 0.091 0.091 0.091 0.091 0.091 0.091 25.8 16.2 16.3 15.9 15.1 14.8 13.5 0.088 0.055 0.055 0.055 0.056 0.055 0.055 15.5 9.7 9.8 9.5 5.2 8.9 8.1 1.9 1.2 1.2 1.2 1.1 1.1 1.0 0.0065 0.0041 0.0041 0.0041 0.0041 0.0042 0.0041 3.0 3.0 3.0 3.0 3.0 3.0 3.0 0.01028 0.01020 0.01015 0.01044 0.01101 0.01120 0.01229 0.19 0.19 0.19 0.19 0.18 0.17 0.16 0.00065 0.00065 0.00065 0.00065 0.00065 0.00065 0.00065 0.4661 0.2629 0.2567 0.2510 0.2398 0.2353 0.2186 0.00160 0.00089 0.00087 0.00087 0.00088 0.00088 0.00090 0.0031 0.0031 0.0031 0.0031 0.0029 0.0028 0.0026 0.0017 0.0017 0.0017 0.0016 0.0016 0.0015 0.0014 50.0 14784.1 11428.7 193.0 0.0 0.0 14591.1 11579.9 160.9 Gas - Fuel Comp. 20512.2 160.9 178.5 2.2 2898.4 77.0 22753.1 1026.4 925.3 OLE 0.0 LM2500 +G4 OLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 24 ISO MECL 59.0 50.9 60.0 4861.0 12.3 None 59.0 60.0 0.0 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 dB 60 13.8 0.85 Case 6 not aay MECL 90.0 63.6 25.0 4861.0 12.3 None 90.0 25.0 0.0 0.0 5.8 5.8 6.2 6.2 50.0 13838.9 11505.8 193.0 0.0 0.0 13645.9 11668.5 151.6 Gas- Fuel Comp. 20512.2 151.6 168.2 2.1 2731.4 77.0 22753.1 1026.4 925.3 DLE 0.0 50.0 12018.2 12838.4 193.0 0.0 0.0 11825.2 13047.9 146.9 Gas - Fuel Comp. 20512.2 146.9 163.0 2.0 2646.8 77.0 22753.1 1026.4 925.3 DLE 0.0 Estimated Estimated Estimated Estimated Estimated Estimated 25.0 25.0 25.0 25.0 25.0 25.0 60.0 25.0 25.0 25.0 25.0 25.0 36.0 15.0 15.0 15.0 15.0 15.0 7.2 3.0 3.0 3.0 3.0 3.0 960.0 400.0 400.0 400.0 400.0 400.0 16.9 17.0 16.7 16.2 15.3 14.8 0.091 0.091 0.091 0.091 0.091 0.091 24.6 10.3 10.2 9.8 9.3 9.0 0.132 0.055 0.055 0.055 0.055 0.055 14.8 6.2 6.1 5.9 3.3 5.4 1.8 0.8 0.7 0.7 0.7 0.7 0.0096 0.0040 0.0040 0.0040 0.0040 0.0041 3.0 3.0 3.0 3.0 3.0 3.0 0.01611 0.01599 0.01626 0.01681 0.01783 0.01840 0.12 0.12 0.12 0.12 0.11 0.11 0.00065 0.00065 0.00065 0.00065 0.00065 0.00065 0.3034 0.2993 0.2897 0.2807 0.1764 0.1649 0.00163 0.00160 0.00157 0.00157 0.00105 0.00101 0.0173 0.0174 0.0171 0.0166 0.0156 0.0151 0.0014 0.0014 0.0014 0.0013 0.0013 0.0012 Exhaust Parameter Exhaust Temperature Exhaust Flow Exhaust Volume Flow Exhaust Volume Flow Exhaust Pressure Exhaust Energy (Ref OR) Exhaust Energy (Ref T2) Exhaust Cp Exhaust Molecular Weight Fuel Composition Methane Ethane Propane i-Butane i-Pentane n -Hexane Oxygen Water Nitrogen Carbon Dioxide Carbon Monoxide Hydrogen Ammonia Exhaust Wght 96 Wet Argon AR Nitrogen N2 Oxygen O2 Carbon Dioxide CO2 Water Vapor H2O Sulfur Dioxide 5O2 Exhaust Mole % Wet Argon AR Nitrogen N2 Oxygen O2 Carbon Dioxide CO2 Water Vapor H2O Sulfur Dioxide 5O2 Stack Exhaust (Estimated) Tempering Air Flow Catalyst Operating Temp Total Mass flow Exhaust Flow NOx @ 15% O2 CO @ 15% O2 VOC @ 15%O2 HCOH @ 15% O2 NOx as NO2 CO VOC HCOH Benzene (AP -42) Acrolein (AP -42) Generator Information Generator Name Generator Coolant Generator Capacity Generator Efficiency Gen. Capacity Curve Gen. Efficiency Curve Gen. Coolant Temperature Gearbox Losses 'F lb/s acfm scfm psia MMBtu/h MMBtu/h Btu/lbF lb/lb-mol % vat % vol % vol % vol % vol % vol % vol % vol % vol vol % vol % vol % vol % mass % mass % mass % mass % mass % mass % vol % vol % vol % vat % vol % vol lb/h 'F lb/h acfm ppmvd pp mvd ppmvd ppbvd lb/h lb/h lb/h lb/h Ib/h lb/h kW % 'F 909.4 185.0 456374.5 147527.8 12.5156 231.0 155.7 0.272 28.547 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2642 74.0400 15.3584 5.1793 4.1506 0.0000 0.9034 75.4504 13.7017 3.3596 6.5770 0.0000 ANDRITZ A03 clB Air 44085.7 98.5 18136.0 18134.0 0.0 0.0 938.4 182.5 460062.9 145634.2 12.5 233.3 159.0 0.273 28.538 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2637 74.0093 15.1920 5.2913 4.2377 0.0000 0.9028 75.3971 13.5492 3.4312 6.7131 0.0000 ANDRITZ A03 cIB Air 44085.7 98.5 18136.0 18134.0 0.0 0.0 981.5 178.3 463887.8 142458.7 12.5156 236.1 158.6 0.276 28.492 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2602 73.8079 14.9184 5.4398 4.5674 0.0000 0.8988 75.0665 13.2831 3.5217 7.2233 0.0000 ANDRITZ A03 cIB Air 44263.5 98.5 18136.0 18134.0 30.0 0.0 987.2 174.3 455401.0 139298.3 12.5 231.8 156.0 0.276 28.495 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2604 73.8162 14.9671 5.4075 4.5426 0.0000 0.8990 75.0811 13.3275 3.5010 7.1847 0.0000 ANDRITZ A03 dB Air 44263.5 98.5 18136.0 18134.0 30.0 0.0 1001.1 166.5 440390.8 133421.7 12.5 224.6 147.6 0.277 28.421 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2545 73.4716 14.9158 5.3692 4.9828 0.0000 0.8924 74.5287 13.2459 3.4668 7.8596 0.0000 ANDRITZ A03 cIB Air 42501.6 98.5 18136.0 18134.0 59.0 0.0 1007.4 163.4 435694.0 131435.6 12.5156 222.6 142.2 0.279 28.309 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2456 72.9528 14.7432 5.3785 5.6737 0.0000 0.8824 73.7002 13.0392 3.4587 8.9129 0.0000 ANDRITZ A03 clB Air 37615.7 98.4 18136.0 18134.0 90.0 0.0 1028.2 151.8 409148.2 121698.0 12.5156 208.9 134.5 0.278 28.405 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2532 73.3942 15.0240 5.2766 5.0461 0.0000 0.8909 74.4081 13.3345 3.4051 7.9549 0.0000 ANDRITZ A03 cIB Air 37615.7 98.3 18136.0 18134.0 90.0 0.0 879.7 140.5 338704.4 111917.8 12.5156 170.4 113.5 0.271 28.611 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2682 74.2695 16.6018 4.3577 3.4977 0.0000 0.9083 75.8542 14.8442 2.8330 5.5550 0.0000 ANDRITZ A03 cIB Air 44085.7 97.8 18136.0 18134.0 0.0 0.0 907.6 138.6 341172.6 110435.3 12.5 172.0 115.8 0.272 28.569 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2677 74.2434 16.4629 4.4473 3.5705 0.0000 0.9077 75.8078 14.7161 2.8905 5.6690 0.0000 ANDRITZ A03 clB Air 44085.7 97.8 18136.0 18134.0 0.0 0.0 930.8 134.1 336172.6 107002.8 12.5156 169.8 111.8 0.273 28.536 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2646 74.0628 16.3053 4.5190 3.8400 0.0000 0.9042 75.5123 14.5538 2.9328 6.0879 0.0000 ANDRITZ A03 dB Air 44263.5 97.8 18136.0 18134.0 30.0 0.0 937.5 129.9 327232.2 103652.8 12.5 165.4 109.2 0.273 28.543 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2647 74.0641 16.3160 4.5118 3.8351 0.0000 0.9042 75.5148 14.5636 2.9281 6.0803 0.0000 ANDRITZ A03 dB Air 44263.5 97.7 18136.0 18134.0 30.0 0.0 952.4 122.5 312547.8 97955.8 12.5 158.3 102.0 0.274 28.472 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2586 73.7083 16.2078 4.5133 4.3068 0.0000 0.8973 74.9408 14.4264 2.9209 6.8090 0.0000 ANDRITZ A03 cIB Air 42501.6 97.6 18136.0 18134.0 59.0 0.0 1049.9 114.5 312933.5 91742.5 12.5156 159.4 103.5 0.280 28.416 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2560 73.5596 15.9282 4.6775 4.5732 0.0000 0.8944 74.6957 14.1598 3.0234 7.2211 0.0000 ANDRITZ A03 cIB Air 37615.7 97.3 18136.0 18134.0 90.0 0.0 GTP REPORT Date: 03/14/2023 Version: GTP 5.0.6 Performed By: Cherine Wojcik Project: Colorado - SCR/CO Controlled cases Estimated Engine Performance NOT FOR GUARANTEE: USE FOR STUDY ONLY Engine Model Generator Frequency Voltage PF Case Ambient Conditions Dry Bulb Temperature Wet Bulb Temperature Relative Humidity Elevation a.s.l. Barometric Pressure Engine Inlet Conditioning Compressor Inlet Temperature Compressor Inlet RH Chilling/Heat Capacity EVAP Water Flow Pressure Losses Inlet Pressure Loss Exh. Pressure Loss Performance GTG Load Generator Output, Gross Estimated Heat Rate, Gross STD Aux Load SCR Aux Load BOP Aux Load Gen. Output, Unit Net Estimated Heat Rate, Net Heat Consumption Fuel Fuel LHV Heat Input Heat Input - HHV Fuel Flow Vol. Fuel Flow Fuel Temperature Fuel HHV Fuel GCV Fuel NCV NOx Control Diluent Flow Emissions (ESTIMATED) NOx, Ref % 02 CO, Ref °% 02 UHC, Ref %02 VOC, Ref % 02 HCOH NOx as NO2 CO UHC (CH4) VOC PM -10 SOx as 502 (0.25 grains / 100 SCF) HCOH Benzene (AP -42) Acrolein (AP -42) Exhaust Parameter Exhaust Temperature Exhaust Flow Exhaust Volume Flow Exhaust Volume Flow Exhaust Pressure Exhaust Energy (Ref OR) Exhaust Energy (Ref 12) Exhaust Cp Exhaust Molecular Weight Hz kV °F °F ft psia °F ketu/h lb/s LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0,85 Case 8 Low -Low Day Full load 0.0 -0.7 80.0 4861.0 12.3 None 0.0 80.0 0.0 0.0 In H2O 5.8 in H2O 12.0 kW Btu/kWh kW kW kW kW Btu/kWh MMBtu/h Btu/lb MMBtu/h MMBtu/h lb/s sdm aF Btu/lb Btu/scf Btu/scf lb/s ppm ppm ppm ppm ppb lb/h lb/h lb/h Ib/h lb/h lb/h lb/h lb/h lb/h <F lb/s acfm scfm psia MMBtu/h MMBtu/h Btu/IbF Ib/Ib-mol 100.0 30293.7 8693.8 193.0 500.0 0.0 29600.7 8897.3 263.4 Gas - Fuel Comp. 20512.2 263.4 292.1 3.6 4743.7 77.0 22753.1 1026.4 925.3 DLE 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 19 Low -Low Day +heating Full load 0.0 -0.7 80.0 4861.0 12.3 Heating 10.0 47.9 1570.7 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 10 Cold Day Full load 30.0 26.9 70.0 4861.0 12.3 None 30.0 70.0 0.0 0.0 6.8 5.8 12.0 12.0 100.0 30403.4 8730.9 193.0 500.0 0.0 29710.4 8934.5 265.4 Gas - Fuel Comp. 20512.2 265.4 294.4 3.6 4781.2 77.0 22753.1 1026.4 925.3 DLE 0.0 100.0 30319.0 8784.5 193.0 500.0 0.0 29626.0 8990.0 266.3 Gas - Fuel Comp. 20512.2 266.3 295.4 3.6 4797.2 77.0 22753.1 1026.4 925.3 DLE 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 21 Cold Day + heating Full load 30.0 26.9 70.0 4861.0 12.3 Heating 40.0 46.5 1525.0 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 cIB 60 13.8 0.85 Case 26 ISO Full load 59.0 50.9 60.0 4861.0 12.3 LM2500 +G4 DLE Gas ANDRITZ A03 cIB 60 13.8 0.85 Case 14 nui. uay + Eva p Full load 90.0 63.6 25.0 4861.0 12.3 None Evap. Cooling 59.0 66.2 60.0 87.5 0.0 0,0 0.0 0.9 6.8 5.8 12.0 12.0 100.0 29305.0 8832.6 193.0 500.0 0.0 28612.0 9046.6 258.8 Gas - Fuel Comp. 20512.2 258.8 287.1 3.5 4662.2 77.0 22753.1 1026.4 925.3 DIE 0.0 100.0 27408.2 8953.9 193.0 500.0 0.0 26715.2 9186.2 245.4 Gas - Fuel Comp. 20512.2 245.4 272.2 3.3 4420.3 77.0 22753.1 1026.4 925.3 DLE 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 cIB 60 13.8 0.85 Case 12 nut aay Full load 90.0 63.6 25.0 4861.0 12.3 None 90.0 25.0 0.0 0.0 5.8 5.8 12.0 12.0 100.0 26764.8 9013.5 197.0 500.0 0.0 26067.8 9254.5 241.2 Gas - Fuel Comp. 20512.2 241.2 267.6 3.3 4345.2 77.0 22753.1 1026.4 925.3 DLE 0.0 100.0 23729.5 9245.7 193.0 500.0 0.0 23036.5 9523.9 219.4 Gas - Fuel Comp. 20512.2 219.4 243.4 3.0 3951.7 77.0 22753.1 1026.4 925.3 DLE 0.0 Estimated Estimated Estimated Estimated Estimated Estimated Estimated 25.0 25.0 25.0 25.0 25.0 25.0 25.0 40.0 25.0 25.0 25.0 25.0 25.0 25.0 24.0 15.0 15.0 15.0 15.0 15.0 15.0 4.8 3.0 3.0 3.0 3.0 3.0 3.0 640.0 400.0 400.0 400.0 400.0 400.0 400.0 26.5 26.7 26.8 26.1 24.8 24.3 211 25.8 16.2 16.3 15.9 15.1 14.8 13.5 15.5 9.7 9.8 9.5 5.2 8.9 8.1 1.9 1.2 1.2 1.2 1.1 1.1 1.0 3.0 3.0 3.0 3.0 3.0 3.0 3.0 0.19 0.19 0.19 0.19 0.18 0.17 0.16 0.4661 0.2629 0.2567 0.2509 0.2396 0.2353 0.2186 0.0031 0.0031 0.0031 0.0031 0.0029 0.0028 0.0026 0.0017 0.0017 0.0017 0.0016 0.0016 0.0015 0.0014 914.4 185.0 450514.6 147529.9 12.7252 231.9 156.6 0.272 28.547 943.3 182.5 454067.4 145636.4 12.7 234.2 159.9 0.274 28.538 985.7 178.2 457506.7 142428.8 12.7252 236.8 159.3 0.276 28.492 992.2 174.3 449252.9 139239.6 12.7 232.6 156.8 0.276 28.495 1006.2 166.4 434275.4 133307.3 12.7 225.2 148.3 0.278 28.421 1012.5 163.3 429633.8 131323.3 12.7252 223.3 142.9 0.279 28.309 1033.6 151.4 402709.4 121351.3 12.7252 209.2 135.0 0.279 28.405 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 9 Low -Low Day MECL 0.0 -0.7 80.0 4861.0 12.3 None 0.0 80.0 0.0 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 20 Low -Low Day +heating MECL 0.0 -0.7 80.0 4861.0 12.3 Heating 10.0 47.9 1196.3 0.0 5.8 6.8 12.0 12.0 50.0 15146.8 11682.9 193.0 500.0 0.0 14453.8 12243.1 168.5 Gas - Fuel Comp. 20512.2 168.5 186.9 2.3 3035.6 77.0 22753.1 1026.4 925.3 DLE 0.0 50.0 15201.7 11733.1 193.0 500.0 0.0 14508.7 12293.5 169.9 Gas - Fuel Comp. 20512.2 169.9 188.4 2.3 3059.6 77.0 22753.1 1026.4 925.3 DLE 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0,85 Case 11 Cold Day MECL 30.0 26.9 70.0 4861.0 12.3 None 30.0 70.0 0.0 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 22 Cold Day + heating MECL 30.0 26.9 70.0 4861.0 12.3 Heating 40.0 46.5 1139.9 0.0 5.8 6.8 12.0 12.0 50.0 15159.5 11537.7 193.0 500.0 0.0 14466.5 12090.4 166.6 Gas - Fuel Comp. 20512.2 166.6 184.8 2.3 3000.3 77.0 22753.1 1026.4 925,3 DLE 0.0 50.0 14652.5 11542.3 193.0 500.0 0.0 13959.5 12115.3 161.1 Gas - Fuel Comp. 20512.2 161.1 178.7 2.2 2901.2 77.0 22753.1 1026.4 925.3 DLE 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 25 ISO MECL 59.0 50.9 60.0 4861.0 12.3 None 59.0 60.0 0.0 0.0 LM2500 +G4 DLE Gas ANDRITZ A03 clB 60 13.8 0.85 Case 13 nog uay MECL 90.0 63.6 25.0 4861.0 12.3 None 90.0 25.0 0.0 0.0 5.8 5.8 12.0 12.0 50.0 13704.1 11626.8 193.0 500.0 0.0 13011.1 12246.1 151.7 Gas - Fuel Comp. 20512.2 151.7 168.3 2.1 2733.2 77.0 22753.1 1026.4 925.3 DLE 0.0 50.0 11864.8 13027.5 193.0 500.0 0.0 11171.8 13835.6 147.2 Gas - Fuel Comp. 20512.2 147.2 163.3 2.0 2651.5 77.0 22753.1 1026.4 925.3 DIE 0.0 Estimated Estimated Estimated Estimated Estimated Estimated 25.0 25.0 25.0 25.0 25.0 25.0 60.0 25.0 25.0 25.0 25.0 25.0 36.0 15.0 15.0 15.0 15.0 15.0 7.2 3.0 3.0 3.0 3.0 3.0 960.0 400.0 400.0 400.0 400.0 400.0 16.9 17.0 16.7 16.2 15.3 14.8 24.6 10.3 10.2 9.8 9.3 9.0 14.8 6.2 6.1 5.9 3.3 5.4 1.8 0.8 0.7 0.7 0.7 0.7 3.0 3.0 3.0 3.0 3.0 3.0 0.12 0.12 0.12 0.12 0.11 0.11 0.3034 0.1997 0.2897 0.1870 0.1762 0.1649 0.0174 0.0175 0.0172 0.0166 0.0156 0.0152 0.0014 0.0014 0.0014 0.0013 0.0013 0.0012 886.8 140.6 335134.1 112001.5 12.7252 171.5 114.5 0.271 28.610 914.8 138.7 337619.9 110531.5 12.7 173.1 116.9 0.272 28.567 935.5 134.1 331711.8 106985.2 12.7252 170.4 112.4 0.273 28.537 942.8 129.9 322840.4 103586.2 12.7 166.0 109.8 0.273 28.543 957.9 122.4 308281.6 97858.0 12.7 158.8 102.5 0.275 28.472 1058.0 114.3 308994.3 91614.9 12.7252 160.1 104.2 0.280 28.414 Fuel Composition Methane Ethane Propane i-Butane i-Pentane n -Hexane Oxygen Water Nitrogen Carbon Dioxide Carbon Monoxide Hydrogen Ammonia Exhaust Wght % Wet Argon AR Nitrogen N2 Oxygen O2 Carbon Dioxide CO2 Water Vapor H2O Sulfur Dioxide 5O2 Exhaust Mole % Wet Argon AR Nitrogen N2 Oxygen O2 Carbon Dioxide CO2 Water Vapor H2O Sulfur Dioxide 5O2 %vol %vol %vol %vol %vol %vol %vol %vol %vol % vol % vol %vol %vol % mass % mass % mass % mass % mass % mass %vol %vol %vol %vol % vol %vol 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2642 74.0389 15.3518 5.1854 4.1536 0.0000 0.9034 75.4491 13.6957 3.3636 6.5818 0.0000 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2636 74.0083 15.1864 5.2950 4.2406 0.0000 0.9027 75.3953 13.5441 3.4336 6.7177 0.0000 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2602 73.8079 14.9185 5.4398 4.5674 0.0000 0.8988 75.0665 13.2831 3.5217 7.2233 0.0000 Stack Exhaust (Estimated) Tempering Air Flow lb/h 57823.8 82695.0 122118 2 Catalyst Operating Temp °F 849.8 850.0 849.8 Total Mass flow lb/h 723690.3 739838.6 763764.9 Exhaust Flow acfm 466596.6 477222.0 493395.4 NOx @ 15% O2 ppmvd 2.5 2.5 2.5 CO @ 15%O2 ppmvd 4.0 4.0 4.0 VOC @ 15%O2 ppmvd 2.5 2.5 2.5 HCOH @ 15% O2 ppbvd 128.0 91.0 91.0 NOx as NO2 lb/h 2.7 2.7 2.7 NOx as NO2 lb/MMBtu 0.0091 0.0091 0.0091 CO lb/h 2.6 2.6 2.6 CO lb/MMBtu 0.0089 0.0089 0.0089 VOC lb/h 1.0 1.0 1.0 VOC lb/MMBtu 0.0034 0.0034 0.0034 HCOH lb/h 0.07 0.07 0.08 FICOH lb/MMBtu 0.0002 0.0003 0.0003 Benzene (AP -42) lb/h 0.0 0.0 0.0 Benzene (AP -42) lb/MMBtu 2.94E-06 2.94E-06 2.94E-06 Acrolein (AP -42) lb/h 0.0 0.0 0.0 Acrolein (AP -42) lb/MMBtu 3.26E-06 3.26E-06 3.26E-06 PM10 (Front and Back + SCR contribution)* lb/h <3.6 <3.6 <3.6 PM10 (Front and Back + SCR contribution)* lb/h 3.6 3.6 3.6 PM10 (Front and Back + SCR contribution)* lb/MMBtu 0.0123 0.0122 0.0122 * estimated contributions from ammonia slip and SO2. Values to be evaluated and provided equipment vendor at a later date Generator information Generator Name ANDRITZA03 cIB ANDRITZ A03 cIB ANDRITZ A03 clB Generator Coolant Air Air Air Generator Capacity kW 44085.7 44085.7 44263.5 Generator Efficiency % 98.5 98.5 98.5 Gen. Capacity Curve 18136.0 18136.0 18136.0 Gen. Efficiency Curve 18134.0 18134.0 18134.0 Gen. Coolant Temperature °F 0.0 0.0 30.0 Gearbox Losses 0.0 0.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2604 73.8162 14.9671 5.4075 4.5426 0.0000 0.8990 75.0811 13.3275 3.5010 7.1847 0.0000 125268.5 850.0 752614.5 486186.0 2.5 4.0 2.5 91.0 2.6 0.0091 2.5 0.0089 1.0 0.0034 0.08 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0125 ANDRITZ A03 cIB Air 44263.5 98.5 18136.0 18134.0 30.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2545 73.4716 14.9158 5.3692 4.9828 0.0000 0.8924 74.5287 13.2459 3.4668 7.8596 0.0000 135814.9 850.0 734857.4 475963.4 2.5 4.0 2.5 91.0 2.5 0.0091 2.4 0.0089 0.9 0.0034 0.07 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0132 ANDRITZ A03 clB Air 42501.6 98.4 18136.0 18134.0 59.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2456 72.9528 14.7432 5.3785 5.6737 0.0000 0.8824 73.7002 13.0392 3.4587 8.9129 0.0000 144884.9 850.0 732700.8 476432.1 2.5 4.0 2.5 91.0 2.4 0.0091 2.4 0.0089 0.9 0.0034 0.07 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0135 ANDRITZ A03 cIB Air 37615.7 98.4 18136.0 18134.0 90.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2532 73.3942 15.0241 5.2765 5.0460 0.0000 0.8909 74.4082 13.3346 3.4050 7.9548 0.0000 151342.4 849.8 696366.9 451206.2 2.5 4.0 2.5 91.0 2.2 0.0091 2.2 0.0089 0.8 0.0034 0.07 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0148 ANDRITZ A03 cIB Air 37615.7 98.3 18136.0 18134.0 90.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2681 74.2654 16.5792 4.3727 3.5096 0.0000 0.9082 75.8468 14.8234 2.8426 5.5736 0.0000 24997.8 849.7 531026.0 341597.2 2.5 4.0 2.5 192.0 1.7 0.0091 1.7 0.0088 0.6 0.0033 0.11 0.0006 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0193 ANDRITZ A03 cIB Air 44085.7 97.8 18136.0 18134.0 0.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2677 74.2390 16.4391 4.4630 3.5829 0.0000 0.9076 75.8001 14.6943 2.9006 5.6885 0.0000 43355.9 850.0 542617.6 349645.6 2.5 4.0 2.5 91.0 1.7 0.0091 1.7 0.0088 0.6 0.0033 0.05 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0191 ANDRITZ A03 cIB Air 44085.7 97.8 18136.0 18134.0 0.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2646 74.0609 16.2950 4.5258 3.8453 0.0000 0.9041 75.5090 14.5444 2.9371 6.0963 0.0000 57332.5 849.8 540059.8 348322.0 2.5 4.0 2.5 91.0 1.7 0.0091 1.6 0.0088 0.6 0.0033 0.05 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0195 ANDRITZ A03 cIB Air 44263.5 97.8 18136.0 18134.0 30.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2646 74.0622 16.3053 4.5189 3.8407 0.0000 0.9042 75.5113 14.5538 2.9327 6.0891 0.0000 60287.5 850.0 527777.8 340374.2 2.5 4.0 2.5 91.0 1.6 0.0091 1.6 0.0088 0.6 0.0033 0.05 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0201 ANDRITZ A03 cIB Air 44263.5 97.7 18136.0 18134.0 30.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2585 73.7062 16.1965 4.5208 4.3127 0.0000 0.8973 74.9372 14.4160 2.9257 6.8182 0.0000 68495.4 850.0 509037.1 329104.9 2.5 4.0 2.5 91.0 1.5 0.0091 1.5 0.0089 0.6 0.0034 0.05 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0214 ANDRITZ A03 cIB Air 42501.6 97.6 18136.0 18134.0 59.0 0.0 95.0000 2.0000 1.0000 0.0500 0.0400 0.0100 0.0000 0.0000 0.7000 1.2000 0.0000 0.0000 0.0000 1.2560 73.5555 15.9057 4.6924 4.5850 0.0000 0.8943 74.6885 14.1392 3.0329 7.2394 0.0000 128846.9 850.0 540445.7 350130.6 2.5 4.0 2.5 91.0 1.5 0.0091 1.5 0.0089 0.6 0.0034 0.05 0.0003 0.0 2.94E-06 0.0 3.26E-06 <3.6 3.6 0.0220 ANDRITZ A03 cIB Air 37615.7 97.3 18136.0 18134.0 90.0 0.0 GE Power LM2500-G4 Startup & Shutdown Estimated Emissions - Gas Fuel Operation No Emissions Control Equipment Installed Event Duration (min) Heat Input (MMBTU - HHV) NOx (Ib) CO (Ib) VOC (Ib) PM10/PM2.5 (Ib) SOX as SO2 (Ib) HCOH (Ib) Benzene (AP -42) Acrolein (AP -42) Start: 10min GT Exhaust 10.0 16.7 2.9 18.9 0.754 0.5 0.1 0.0204 0.0022 0.0002 Shutdown: GT Exhaust 9.0 20.7 3.4 21.1 0.845 0.6 0.1 0.0252 0.0027 0.0002 *Must Meet GE Gas Fuel Spec (MID -TD -0000-1 LATEST REVISION) * Fast Start per GE Procedures. Normal shutdown per GE procedures. NOTE 1: VOC's are defined as non -methane, non -ethane, 50% saturated. Mass rate reported as methane. NOTE 2: Calculations executed using the gas below with margined heat input NOTE 3: Fuel composition contains <5% C3+ NOTE 4: Scope includes GT Exhuast without SCR/COR and Stack with SCR/COR NOTE 5: Intentonally blank NOTE 6: Shutdown is defined to end when fuel is shut off. Excludes cooldown crank time. NOTE 7: SOX is reported as SO2. For stack calculations, SOX is converted to sulfates and sulfate salts. These are counted as PM and not included in SOX numbers here. Gas Fuel Composition Hydrogen Methane Ethane Ethylene Propane Propylene Butane Butylene Butadiene Pentane Cyclopentane Hexane Heptane Carbon Monoxide Carbon Dioxide Nitrogen Water Vapor Oxygen Hydrogen Sulfide Ammonia LHV, BTU/lb HHV, BTU/lb NOx Scalar Specific Gravity MWI, (Btu/SCF)/SQRT(R) LHV, BTU/scf HHV, BTU/scf Fc, SCF/MMBtu HHV Fd, SCF/MMBtu HHV Volume % 0.0000 95.0000 2.0000 0.0000 1.0000 0.0000 0.0500 0.0000 0.0000 0.0400 0.0000 0.0100 0.0000 0.0000 1.2000 0.7000 0.0000 0.0000 0.0000 0.0000 20512 22753 0.990 0.5895 52.07 930.1 1026.4 1028.8 8653.3 Weight % 0.0000 89.2636 3.5223 0.0000 2.5827 0.0000 0.1702 0.0000 0.0000 0.1690 0.0000 0.0505 0.0000 0.0000 3.0932 1.1485 0.0000 0.0000 0.0000 0.0000 GE Power LM2500-G4 Startup & Shutdown Estimated Emissions - Gas Fuel Operation Emmissions Equipment Installed Event Duration (min) Heat Input (MMBTU - HHV) NOx (Ib) CO (Ib) VOC (Ib) PM10/PM2.5 (Ib) SOX (Ib) as SO2 HCOH (Ib) Benzene (AP -42) Acrolein (AP -42) Start: 10min GT Exhaust 10.0 17.1 3.2 20.2 0.8071 0.5 0.07 0.0208 0.0022 0.0002 Shutdown: GT Exhaust 9.0 20.8 3.8 23.2 0.9266 0.6 0.06 0.0254 0.0027 0.0002 Start: Stack w/ SCR+COR 25.0 88.5 6.7 16.4 1.3 2.2 0.04 0.2231 0.0070 0.0007 Shutdown Stack w/ SCR+COR 9.0 20.8 2.2 11.3 0.7 0.6 0.01 0.0094 0.0001 0.0001 *Must Meet GE Gas Fuel Spec (MID -TD -0000-1 LATEST REVISION) * Fast Start per GE Procedures. Normal shutdown per GE procedures. Stack compliance for emissions is assumed to be 25 minutes with ammonia injection starting after full load is reached (10 minutes) and catalysts operating at designed temperatures. NOTE 1: VOC's are defined as non -methane, non -ethane, 50% saturated. Mass rate reported as methane. NOTE 2: Calculations executed using the gas below with margined heat input NOTE 3: Fuel composition contains <5% C3+ NOTE 4: Scope includes GT Exhuast without SCR/COR and Stack with SCR/COR NOTE 5: Intentonally blank NOTE 6: Shutdown is defined to end when fuel is shut off. Excludes cooldown crank time. NOTE 7: SOX is reported as SO2. For stack calculations, SOX is converted to sulfates and sulfate salts. These are counted as PM and not included in SOX numbers here. Gas Fuel Composition Hydrogen Methane Ethane Ethylene Propane Propylene Butane Butylene Butadiene Pentane Cyclopentane Hexane Heptane Carbon Monoxide Carbon Dioxide Nitrogen Water Vapor Oxygen Hydrogen Sulfide Ammonia LHV, BTU/Ib HHV, BTU/Ib NOx Scalar Specific Gravity MWI, (Btu/SCF)/SQRT(R) LHV, BTU/scf HHV, BTU/scf Fc, SCF/MMBtu HHV Fd, SCF/MMBtu HHV Volume % 0.0000 95.0000 2.0000 0.0000 1.0000 0.0000 0.0500 0.0000 0.0000 0.0400 0.0000 0.0100 0.0000 0.0000 1.2000 0.7000 0.0000 0.0000 0.0000 0.0000 20512 22753 0.990 0.5895 52.07 930.1 1026.4 1028.8 8653.3 Weight % 0.0000 89.2636 3.5223 0.0000 2.5827 0.0000 0.1702 0.0000 0.0000 0.1690 0.0000 0.0505 0.0000 0.0000 3.0932 1.1485 0.0000 0.0000 0.0000 0.0000 Permit to Construction Application Mountain Peak Power, LLC APPENDIX B APEN FORMS Company Name: Source Name: Date: Non -Oil & Gas Industry Construction Permit Application Completeness Checklist Form APCD-100a Air Pollution Control Division Mountain Peak Power, LLC Mountain Peak Power July 14th, 2023 Are you requesting a facility wide permit for multiple emissions points? In order to have a complete application, the following attachments must be provided, unless stated otherwise. If application is incomplete, it will be returned to sender and filing fees will not be refunded. Attachment Application Element Attached? A APEN Filing Fee(s) ✓ B Air Pollutant Emission Notice(s) (APENs) - APCD Form Series 200 ✓ C Emissions Calculations and Supporting Documentation ✓ D Company Contact Information - Form APCD-101 ✓ Check here if there will only be one point of contact (Attachment D not required) E Ambient (One of the Air following Impact Analysis MUST be selected in order for the application to be considered complete) Check here if source is exempt from modeling determination requirements "Interim Colorado Modeling Guideline for Air Permits" "Permitting Section Addendum per to the Modeling Guideline". Quality and/or Check here if operator submitted a request for modeling determination (Form APCD-114) to the Division's Permit Modeling Unit (PMU) prior to application submittal, and the Division determined that modeling was ✓ not required. (Include the version of form APCD-114 that was approved and returned by the PMU.) Check prior to here if application operator submittal. submitted a modeling (Include form analysis APCD-114, to the operator's Division which approved was approved modeling analysis, by the Division and the PMU Modeling Review Report provided by the Division which documents compliance with the NAAQS and conditions of approval for proposed source.) Check here if operator is submitting a modeling analysis to the Division concurrently with the application ✓ submittal, or if the already -submitted modeling analysis has not been approved by the Division. yet F Facility Emissions Inventory - Form APCD-102a ✓ Check here if single emissions point source (Attachment F not required) G Process description, flow diagram, plot plan of emissions unit and/or facility ✓ Check here if single emissions point source (Attachment G not required) H Regulatory Analysis ✓ Check here to request APCD to complete regulatory analysis (Attachment H not required) Additional attachments Certain sources may require additional forms. Refer to https://www.colorado. ov/pacific/cdphe/air/air-permit to check if any APEN supplement forms are required for your source. Send Complete Application to: Colorado Department of Public Health at Environment APCD-SS-B1 4300 Denver, Cherry Colorado Creek 80246-1530 Drive South Check box if facility is an existing Title V source: ❑ Send an additional application copy Check box if refined modeling analysis included: ❑ Send an additional application copy Check box if application is for major NANSR or PSD permit: NANSR = Nonattainment Area New Source Review ❑ Send eight (8) total application copies PSD = Prevention of Significant Deterioration Form APCD-100a Non -Oil at Gas Industry Construction Permit Application Completeness Checklist - Revision 2/2023 COLORADO Department of Public Health & Environment Colorado Department of Public Health and Environment Air Quality Impact Analysis Checklist for New Minor Sources and Minor Modifications March 8, 2002 (revised 04/25/11) Air Pollution Control Division / Technical Services Program This checklist is intended to help determine what type of "impact analysis" is warranted, based on procedures in the Colorado Modeling Guideline (guideline). It applies to permits subject to Regulation No. 3 Part. B, §III.B.5.d (100103agccstationarysourcepermitting.pdf) and to general permits that have an "impact analysis" requirement. It applies to sources emitting particulate matter, carbon monoxide, lead, sulfur dioxide, or nitrogen oxides. Sources emitting only volatile organic compounds (VOCs) should disregard this form. 1. la Submit a complete Air Pollutant Emission Notice (APEN) form and all other required forms. APEN forms are available at: http://www.cdphe.state.co.us/ap/stationary.html 2. 181 Submit Form (http://colorado.gov/airquality/permits/AQlmpactForml.pdf). the information in section 7.4 of the guideline or submit a complete Use this Air Quality Modeling information in Step 6. 3. M Submit a facility plot plan drawn to scale and labeled with the following: north arrow, property lines, fences', emission source points/areas, buildings, structures (e.g., equipment housing). Include a geo-reference point (e.g., coordinate and datum) plus source IDs that match APEN/inventory IDs. 4. a Submit a map showing the location of the facility. [Note: U.S. Geological Survey (USGS) 7.5 minute topographic maps (e.g., DRGs) are preferred since they show the topography of the area.) 5. Ca Determine if there are sources within 5 kilometers that emit the same pollutant. 6. la Determine if modeling is warranted using the information from steps 1-5 and additional information as necessary. Review section 2 and Table 1 (page 12) of the guideline (http :1/colorado. gov/airquality/permits/guide .pdf) Explain the decision process. ig If the requested emission usually warranted. If it rate(s) is equal to or greater than is less, modeling is not usually warranted the thresholds in Table 1, modeling is unless a circumstance exists (see Table 1 footnotes) violation of ambient that makes it reasonable air quality standards. If to there believe the source could cause or contribute is doubt, consult with the Division. to a Determine if there is a localized nearby area of "poor existing air quality" that may trigger modeling at levels below the thresholds in Table 1. For example, a key indicator of poor air quality is the presence of one or more sources within 5 km that emit the same pollutant and cause a significant concentration gradient (individually or collectively). 1 Fences and/or physical barriers may be used to exclude property owned or controlled by the source operator from "ambient air." Ambient air quality standards only apply in "ambient air." For example, receptors (geographic locations at which the model calculates the source's impact) may be omitted from the property of the facility under review, provided it is inaccessible to the general public. Refer to the definition of ambient air in the glossary of the guideline. If there is not a physical barrier (e.g., fence, wall), receptors should be located on the property of the applicant. Division approval is necessary if the applicant wants to use a physical barrier such as a canyon, river, tailings pile, or other physical features as the ambient air boundary. 2 Air Quality Impact Analysis Checklist for New Minor Sources and Minor Modifications (March 8, 2002; updated 04/25/11) 7. U If modeling is warranted, applicants for "general permits" should submit a modeling analysis with the permit application. Applicants for conventional "construction permits" should consider the pros and cons of submitting modeling along with the permit application.2 If modeling is performed: 8. LJ the guideline (guide.pdf) modeling recommendations. Follow 9. If there are downwash buildings or structures (e.g., equipment housing) nearby, account for in the modeling. Include terrain processing. building ❑ 10. ❑ Determine not "significant" significant, exceed if the the modeling and a full impact is "significant." significance additional air quality impact analysis is If levels in analysis warranted. the impact not to 3 step warranted. from on page 11. the new 15 of Go the to source or modification guideline, step 14. If the the impact impact is does is not Table is Go 11. If with impact" the impact is significant, perform ambient air quality standards + "background concentration a full impact on page 12)" analysis 20 + to determine of the guideline): "nearby source if the action impact" (see step comply U will "source "full impact (Table 5 (see step = 13)" 12. iJ If accounts at the impact nancy.chicki&,state.co.us. for is significant, other sources not Add a "background modeled. more, obtain concentration" a background 4.1 on page to the concentration, 18 of the modeled guideline. impacts contact Nancy that Chick To see section For 13. If for s.html#datareq) the impact is significant, sources within 5km or otherwise are from of "nearby" that nearby obtain the are significant determine stationary a "standard impact if there sources not accounted sources with modeling for a model are that radius any nearby cause by the "background and/or emission inventory" from (http://www.cdphe.state.co.us/ap/i-n- the Division iJ significant contact sources. Use the inventory concentration gradients concentration." If the Division for additional so, to (i.e., determine if there "nearby source impact") estimate the impacts guidance. 14. J Provide output the model input and output files on diskette, files are necessary for screening -level models. CD, or by other electronic means. Only 15. ❑ Provide Items 1 through a concise report 4 and 8 that explains assumptions through 14 above. and results. At a minimum, the report addresses 2 Minor sources and minor modifications are not required by regulation to submit modeling with the permit application. However, a general permit may require that the applicant submit an "impact analysis" with the application. Unless an impact analysis is required by a general permit, applicants may elect to submit modeling with the application to prevent unnecessary delays. If modeling is not submitted with the application, the Division will decide if it is warranted. If it is, the Division will perform a screening -level analysis if it is technically feasible to perform one. If there is a problem, the Division will contact the applicant to discuss options. If refined -level modeling is necessary, the Division will typically request that it be done by the applicant. Colorado Department of Public Health & Environment/APCD/Technical Services Program Form APCD-101 COLORADO Department of Public Health & Environment Company Contact Information Form Ver. September 10, 2008 Company Name: Mountain Peak Power, LLC Source Name: Mountain Peak Power Permit Contacts: Sim Deshpande Address: 3 Carlisle Road Suite 210 Street Westford MA 01886 City State Zip Phone Number: 978.449.0304 n/a Fax Number: seshpande@ramboll.com E-mail: Billing Contact: (Permit Fees)3 Shawn Environmental Donovan, Director - c/o Kindle LLC, 500 Suite 300 Address: Energy Alexander Park Drive, Street Princeton NJ 08540 City State Zip Phone Number: 609.436.9020 n/a Fax Number: shawn.donovan@kindle-energy.com E-mail: Compliance Contact2: Lisa Carty, VP — Environmental Address: c/o Kindle Energy LLC, 500 Alexander Park Drive, Suite 300 Street Princeton NJ 08540 City State Zip Phone Number: 303.842.2115 n/a Fax Number: E-mail: lisa.carty@kindle-energy.com Billing Contact: (Annual Fees)4 Dinah Anderson Evans, Office Manager Address: c/o Kindle Energy LLC, 500 Alexander Park Drive, Suite 300 Street Princeton NJ 08540 City State Zip Phone Number: 609.250.7212 n/a Fax Number: dinah.anderson@kindle-energy.com E-mail: Check how would you like to receive your permit fee invoice? Mail: E-mail: Fax: Footnotes: 1 The permit contact should be the point of contact for technical information contained in the permit application. This may be a company representative or a consultant. 2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted facility. 3 The billing contact (Permit fees) should be the point of contact that should receive the invoice for fees associated with processing the permit application & issuing the permit. (Reg. 3, Part A, Section VI.B) 4 The billing contact (Annual fees) should be the point of contact that should receive the invoices issued on an annual basis for fees associated with actual emissions reported on APENs for the facility. (Reg. 3, Part A, Section VI.C) Page 1 of 1 AP_Form-APCD- 10 1 -Company -Contact -Information (2).doc Form APCD-102a Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. September, 2019 Company Name: Mountain Peak Power, LLC Source Name: Mountain Peak Power Source AIRS ID: TBD Uncontrolled Potential to Emit (PTE) Controlled Potential to Emit (PTE) Criteria (TRY) I HAPs ( bs/yr) Criteria (TP\ ) I IfAPs (lbs/yr) AIRS ID Permit No. Description TSP PM70 PM2 FUG. TSP FUG. PVI70 FUG P112 s 5O2 NOx VOC CO I Benzene Toluene EB Xylene n -Hex HCHO TSP PMI 0 PM2.5 FUG. TSP FUG. PNI70 FUG P1I2 5O2 NOx VOC CO I Benzene Toluene EB Xylene n -Hex HCHO TBD TBD LM2500 G4 DLE Gas Turbine 0.84 7.91 7.91 - - -- 0.28 39.24 4.16 57.68 I 10.34 112.02 27.57 55.15 0.00 1404.31 0.88 9.51 9.51 - -- -- 0.28 4.13 1.52 4.59 I 10.34 112.02 27.57 55.15 0.00 489.53 TBD TBD LM2500 G4 DLE Gas Turbine 0.84 7.91 7.91 -- -- -- 0.28 39.24 4.16 57.68 I 10.34 112.02 27.57 55.15 0.00 1404.31 0.88 9.51 9.51 -- -- -- 0.28 4.13 1.52 4.89 I 10.34 112.02 27.57 55.15 0.00 489.53 TBD TBD LM2500 (14 DLE Gas Turbine 0.84 7.91 7.91 -- -- -- 0.28 39.24 4.16 57.68 I 10.34 112.02 27.57 55.15 0.00 1404.31 0.88 9.51 9.51 0.28 4.13 1.52 4.89 I 10.34 112.02 27.57 55.15 0.00 489.53 TBD TBD LM2500 G4 DLE Gas Turbine 0.84 7.91 7.91 -- -- -- 0.28 39.24 4.16 57.68 I 10.34 112.02 27.57 55.15 0.00 1404.31 0.88 9.51 9.51 -- -- -- 0.28 4.13 1.52 4.89 I 10.34 112.02 27.57 55.15 0.00 489.53 TBD TBD LM2500 G4 DLE Gas Turbine 0.84 7.91 7.91 - - -- 0.28 39.24 4.16 57.68 10.34 112.02 27.57 55.15 0.00 1404.31 0.88 9.51 9.51 - -- - 0.28 4.13 1.52 4.89 10.34 112.02 27.57 55.15 0.00 489.53 TBD TBD LM2500 G4 DLE Gas Turbine 0.84 7.91 7.91 - - -- 0.28 39.24 4.16 57.68 , 10.34 112.02 27.57 55.15 0.00 1404.31 0.88 9.51 9.51 - -- -- 0.28 4.13 1.52 4.89 , 10.34 112.02 27.57 55.15 0.00 489.53 _ Permitted Sources Subtotal = 5.06 47.49 47.49 11.00 0.00 0.00 1.68 235.41 24.93 346.10 I I 62M4 672.11 165.44 330.89 0.00 8425.84 5.30 57.1)8 57.08 0.01) 0.011 11.110 1.68 24.80 9.12 29.35 I I 62.04 672.11 165.44 330.89 0.00 2937.19 APEN Only - Permit Exempt Sources I I I I I I I I I I I I APEN Only Subtotal = 0.0 0.0 0.0 0.0 0.0 0.11 0.0 0.0 0.0 0.0 I 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 I 0 0 0 0 0 0 APEN Exempt / Insignificant Sources N/A N/A Firewater Pump 0.01 0.01 0.01 - - -- 0.00 0.12 0.12 0.10 1 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.01 0.01 - -- -- 0.0002 0.12 0.12 0.10 1 0.00 0.00 0.00 0.00 0.00 0.00 N/A N/A Diesel Tank 0.00 0.00 0.00 - - -- 0.00 0.00 0.00 0.00 I 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 - -- 0.00 0.00 0.00 0.00 I 0.00 0.00 0.00 0.00 0.00 0.00 I I I I I I I I I I Insignificant Subtotal = 0.0 0.0 0.0 0.0 0.0 0.11 0.0 0.1 0.1 0.1 I 11 1 I) 0 11 0 0 0.11 0.0 0.0 0.0 0.0 0.11 0.0 0.1 0.1 0.1 I 0 1 11 0 0 0 0 Total. All Sources = 5.1 47.5 47.5 0.0 0.0 0.0 1.7 235.5 25.0 346.2 I 62 672 165 331 0 8.426 5.3 57.1 57.1 0.0 0.1) 0.1) 1.68 24.9 9.24 29.5 I 62 672 165 331 0 2,937 Uncontrolled HAPs Summary (TPY) = 0.0 0.3 0.1 0.2 0.0 4.2 Controlled HAPs Summary (TRY) = 0.0 0.3 0.1 0.2 0.0 1.5 Uncontrolled Total, All HAPs (TPY) =I 4.8 I Controlled Total, All HAPs (TPY) =I 2.1 I Footnotes: i . This Ibrm should be completed to include both existing sources and all proposed new or modifications to existing emissions sources 2. lithe emissions source is new then enter "proposed" under the Permit No. and AIRS ID data columns 3. Add and/or replace I LAPS and other Non -Criteria Reportable Pollutants as necessary. I iAP abbreviations include: EB = Ethylbenzenc Acro = Acrolcin HCHO = Formaldehyde n -Hex = n-i lexanc 224-TMP = 2,2,4-Trimethylpentane Meth = Methanol Acetal = Acetaldehyde 4. APEN Exempt/Insignificant Sources should be included when warranted. Company Name 7/14/2023 Page 1 of 13 General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. There may be a more specific APEN for your source (e.g. boiler, mining operations, engines, etc.). A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Namel: Site Name: Mountain Peak Power, LLC Mountain Peak Power Site Location: Keenesburg, Colorado Mailing Address: 500 Alexander Park Drive, Suite 300 (include Zip Code) Portable Source Home Base: Princeton, NJ 08540 Site Location County: Weld County NAICS or SIC Code: 221100 Contact Person: Sim Deshpande Phone Number: (978)449-0304 E -Mail Address2: sdeshpande@ramboll.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-2OO - General APEN - Revision 10/2022 1 COLORADO Department of Public Health El Environment Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ■ ■ ■ ■ NEW permit OR newly -reported emission source (check one below) O STATIONARY source ■ PORTABLE source - OR - MODIFICATION to existing permit (check each box below that applies) ■ ■ Change fuel or equipment ■ Change company name3 ■ Add point to existing permit Change permit limit ■ Transfer of ownership4 ■ Other (describe below) - OR- APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: New peaking power plant: Electricity generation using natural gas -fired combustion turbines. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Six (6) identical GE LM2500 G4 DLE natural gas fired turbines for power generation. Manufacturer: General Electric Model No.: LM2500 Serial No.: TBD Company equipment Identification No. (optional): For existing sources, operation began on: CT -1, CT -2, CT -3, CT -4, CT -5, CT -6 Not applicable For new or reconstructed sources, the projected start-up date is: ■ 9/1/2024 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25% Mar -May: 25% Jun -Aug: 25% Sep -Nov: 25% Form APCD-200 - General APEN - Revision 10/2022 2I COLORADO Department of Public Health El Environment Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information & Material Use Check box if this information is not applicable to source or process From what year is the actual annual amount? Material Consumption: Description Design (Specify Process Rate Units) Actual Amount (Specify Annual Units) Requested Permit (Specify Annual Limits Units) Finished Product(s): 5 Requested values wilt become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. Section 5 - Geographical/Stack Information ■ Geographical Coordinates (Latitude/Longitude or UTM) 40.14675, -104.548703 Coordinates are for center of the facility. Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (° F) Flow Rate (ACFM) CT -1 through CT -6 80 850 493,390 Velocity (f t/sec) -160 Indicate the direction of the stack outlet: (check one) ■ Upward Horizontal ■ ■ Downward Other (describe): Indicate the stack opening and size: (check one) ■ ■ Circular Square/rectangle Interior stack width (inches): Other (describe): Interior stack diameter (inches): ■ Upward with obstructing raincap 96 Interior stack depth (inches): Form APCD-200 - General APEN - Revision 10/2022 COLORADO Department of Public Health El Environment Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ■ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate Actual Annual Fuel Use Requested Annual Permit Limits (MMBTU/hr) (Specify Units) (Specify Units) 295 5037 MMscf/yr MMscf/yr 5037 From what year is the actual annual fuel use data? Projected Indicate the type of fuel used6: • ■ ■ ■ ■ ■ Pipeline Natural Gas Field Natural Gas Ultra Low Sulfur Diesel Propane Coal Other (describe): (assumed fuel heating value of 1,020 BTU/SCF) Heating value: BTU/SCF (assumed fuel heating value of 138,000 BTU/gallon) (assumed fuel heating value of 2,300 BTU/SCF) Heating value: BTU/lb Ash content: Sulfur content: Heating value (give units): 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? p Yes ■ No If yes, describe the control equipment AND state the collection and control efficiencies: Pollutant Control Description Equipment Collection (% of total control Efficiency emissions equipment) captured by Control (% reduction emissions) Efficiency of captured TSP (PM) PM1 0 PM2.5 SOX NOX SCR 100% >90% Co Oxidation Catalyst 100% >90% voC Oxidation Catalyst 100% >50% Other: Form APCD-200 - General APEN - Revision 10/2022 41 COLORADO Department of Public Health El Environment Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] From what year is the following reported actual annual emissions data? Projected Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled (Specify Emission Factor Units) (AP Emission Factor Source -42, Mfg., etc.) Actual Annual Emissions Requested Emission Annual Limit(s)5 Permit Uncontrolled (tons/year) Controlled' (tons/year) Uncontrolled (tons/year) Controlled (tons/year) TSP (PM) 1.90E-31b/MMBtu Mfg. 5.30 5.30 5.30 5.30 PM1() 0.015 lb/MMBtu Mfg. 57.08 57.08 57.08 57.08 PM2.5 0.015 lb/MMBtu Mfg. 57.08 57.08 57.08 57.08 SOX 6.5E-41b/MMbtu Mfg. 1.68 1.68 1.68 1.68 NO), 25 ppm Mfg. 235.41 24.80 235.41 24.80 co 60 ppm Mfg. 346.10 29.35 346.10 29.35 voc 7.2 ppm Mfg. 24.93 9.12 24.93 9.12 Other: 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable, and should consider future process growth. Requested values are required on all APENs, including APEN updates. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Yes ■ No CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg., etc.) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 50-00-0 108-88-3 1330-20-7 Formaldehyde Toluene Xylene Not Available Not Available Not Available 640.0 ppb 1.30E-04 Ib/MMBtu 6.40e-05 Ib/MMbtu Mfg. AP -42 AP -42 8,425.84 672.11 330.89 2937.19 672.11 330.89 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Form APCD-200 - General APEN - Revision 10/2022 5 COLORADO Department of Public Health El Environment Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. CA4v,,a 7/14/2023 Signature of Legally Authorized Person (not a vendor or consultant) Date Lisa Carty Vice President - Environmental Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $242.00 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For more information or assistance, contact: Small Business Assistance Program cdphe_apcd_sbap@state.co.us APCD Main Phone Number (303) 692-3100 Make check payable to: Colorado Department of Public Health and Environment Alternatively, payment can be provided online, by credit card or electronic check, via the APCD Payment Portal.. Form APCD-200 - General APEN - Revision 10/2022 6I tate COLORADO Department of Public Health El Environment Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 21 11041 Submittal Application Attachment 21 Decommissioning Plan Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Decommissioning Plan 11041 Submittal Application Decommissioning Plan Background Mountain Peak Power, LLC is proposing construction of a supplemental, natural gas fired power plant in Weld County off County Road 55 northwest of the Town of Keenesburg. The site will be co -located with the existing United Power Tesla Substation. Decommissioning Plan Decommissioning activities will be completed to remove all above -ground structures, equipment, tanks, ancillary structures, and any other associated equipment to restore the site to a condition suitable for industrial use, with consideration first given for safety procedures and in accordance with all environmental permits and regulations. Before decommissioning activities commence, safety and environmental walkdowns will be completed to identify and mitigate personnel and safety risks as well as all remaining environmental hazards. Site security will be increased to prevent property theft and to mitigate risk of trespasser(s) injury. Hard barriers will be erected, and additional warning signage will be posted, around areas of the property that present increased safety risks. Additionally, environmental permits will be reviewed for any ongoing environmental compliance activities, such as stormwater sampling, and those activities will be completed and tracked for the remainder of the permit life. The site will be surveyed for any materials posing an environmental risk. All fluid -containing equipment, including but not limited to that containing fuel, oil, glycol, and refrigerant, will be inventoried and all fluid removal will be tracked to ensure proper handling and disposal. All fluids will be removed by specialty contractors in accordance with appropriate safety procedures, all equipment will be properly cleaned, and all waste will be properly disposed. Site walkdowns will also be completed to collect any radioactive waste, such as non -powered Exit signs, for proper disposal. A qualified contractor will remove all above -ground equipment, structural steel, combustion turbines, generators, inlet filters, exhaust stacks, transformers, electrical equipment, pump skids, cabling, wiring, piping, and equipment closures from the site. All other demolished materials will be properly disposed. Foundations and underground piping and conduit duct bank runs will remain in place. All underground piping will have fluids removed and will be capped just above grade. e Stanley Consultants Mountain Peak Power, LLC Mountain Peak Power Project Attachment 16 — Rev 1 11041 Submittal Application Attachment 16 Drainage Report - Preliminary - Rev 1 Mountain Peak Power Weld County 1041 Application Stanley Consultants PRELIMINARY DRAINAGE REPORT MOUNTAIN PEAK POWER STATION WELD COUNTY, COLORADO Project Location Section 9, Township 2 North, Range 64 West of the 6th Principal Meridian Submittal: February 16, 2024 Prepared by: Stanley Consultants ��... 8000 S Chester Street, Suite 400 Centennial, CO 80112 Phone (303) 799-6806 Contact: Michael Reed Developer/Owner: Client Name: MOUNTAIN PEAK POWER, LLC Project: MOUNTAIN PEAK POWER STATION Location: WELD COUNTY, COLORADO Page 1 Stanley Consultants Preliminary Drainage Report MOUNTAIN PEAK POWER STATION Weld County, Colorado Table of Contents Preliminary Drainage Report 1. General Location and Description 2. Drainage Basins and Sub -Basins 3. Drainage Design Criteria 4. Conclusions Appendix Drainage Report Checklist NRCS Soils Maps FIRM Site Plan Hydrology and Hydraulic Analysis NOAA Storm Intensities NOAA Storm Depths Peak Runoff Calculation - 2% Impervious area Detention Calculation — Modified FAA Method Construction Drawings Site Plan & 1041 USR Map Engineering scale & north arrow Property lines, right-of-way, and easement Grading Plan 1' Contours & elevations (existing & proposed) Pre- and post -development drainage basin Arrows depicting flow direction c Stanley Consultants mc Page 2 1. GENERAL LOCATION AND DESCRIPTION 1.1 Location Mountain Peak Power, LLC (Mountain Peak) proposes construction of a supplemental, natural gas fired power plant in Weld County, Colorado, northwest of the Town of Keenesburg. The project is located on the west side of RD 55 approximately 1 mile north of RD 20. The site is currently used as a Power Plant for United Power referred to as the Tesla Substation. The Mountain Peak development would utilize existing vacant portions of the existing property located north and west of the existing Tesla substation site. The overall site is 18.50 acres with the new development including 12.53 acres. See Figure 1 below and the Site Plan included in the Appendix. Construction of the Mountain Peak plant is scheduled to begin July 2024 and end in June 2025. 1.2 Description This report presents the hydrologic and hydraulic analysis for development of the Mountain Peak site. Design would be in accordance with Weld County requirements per the Weld County Engineering and Construction Criteria, dated March 17, 2021. The project is located in Section 9, Township 2 North, Range 64 West of the 6th Principal Meridian. See Figure 1 Vicinity Map for project location. Figure 1 — Vicinity Map Page 3 Stanley Consultants N. 1.3 Description of Property 1.3.1 General This project includes development of a portion of the existing site for a new power plant for Mountain Peak Power and expansion of the existing Tesla substation (See Appendix for Site Plan). The portion of the site being developed for this project is located on vacant land with overall drainage patterns flowing from the northeast to the southwest across the site. The development would maintain the existing drainage patterns and a detention pond would be provided at the southwest corner of the site to attenuate flow. Access to the site would use an existing driveway from County Road 50 shared with the existing Tesla Substation. 1.3.2 Development includes several turbines and ancillary facilities. The site would be covered in gravel with the perimeter open to provide a perimeter access road and parking. Drainage would be provided using an open drainage system using overland flow and ditches flowing to a proposed detention pond. General Topography The project site is vacant with limited vegetation on site. Existing slopes are generally flat with existing grades less than 3 percent. The adjacent Tesla Substation site is enclosed by a security fence and also slopes toward the southwest. Runoff from the existing Tesla site would not be tributary to the detention pond. 1.3.3 General Soil Conditions The project location is made up of two soil types, (44) Olney loamy sand and (49) Osgood sand. The existing slopes are less than 3 percent. These soil types are Hydrologic Soil Group of A. Appendix includes the NRCS Soil Map and Soil Survey for the project location. 1.3.4 Major Drainageways The project site is not located near a major waterway. The site is not located within a Special Flood Hazard Area (SFHA) as shown on the Federal Emergency Management Agency (FEMA) Flood Insurance Rate Map (FIRM), otherwise denoted as "Zone X." The project is shown on FIRM PaneI1975 of 2250, Weld County, number 080266 (see appendix), revised December 7, 2018. 1.3.5 1.3.6 Irrigation Facilities There are no existing irrigation canals or ditches on site. Utilities and Other Encumbrances There are no significant geologic features or other encumbrances on site. Nor are there any utilities within the project limits that would be impacted by the improvement. 2. DRAINAGE BASINS AND SUB -BASINS 2.1 Drainage Areas Existing Drainage Areas The existing site slopes from the northeast to the southwest. The 18.50 -acre site is split into two drainage areas, one for the new improvements by Mountain Peak Power that Page 4 Stanley Consultants includes some expansion of the Tesla Site, and the existing Tesla Substation maintained by United Power. The existing Tesla Substation site is outside the scope of this Drainage Report. Proposed Basins The proposed drainage areas are the same as existing. The proposed design includes the new Mountain Peak development on the north and west sides of the site that are vacant, and new development by United Power on the north and west sides of the existing Tesla site. All the new development, 12.53 acres, is included in the drainage design and used to calculate the required detention volume. Development includes covering the site with gravel and construction of concrete pads to support the proposed equipment. Stormwater runoff would be using overland low with drainage ditches to guide flow to the proposed detention pond. 3. DRAINAGE DESIGN CRITERIA 3.1 Development Criteria Reference Design is based on the Weld Count Engineering and Construction Criteria, dated March 17, 2021 (Weld County Manual). 3.2 Hydrologic and Hydraulic Criteria Preliminary detention calculations used the Modified FAA method tab from the Urban Drainage and Flood District workbook (ud-detention_v2.35), based on a 100 -year, 1 hour storm event. The workbook is included in the Appendix and shown in the Major Detention Volume portion of the workbook. The preliminary volume of the detention pond is 0.76 acre-feet and would be approximately 110 feet by 100 feet pond that is 3.0 deep. A 1 ft freeboard would be included, side slopes would be graded at a 4:1 maximum slope, and the pond bottom would be graded flat with a trickle channel graded at 0.005 ft/ft. The design of the pond, the overflow structure, and the release structure would be developed further as design is advanced. The Peak Runoff Prediction by the Rational Method workbook (ud-rational-vi .02a) was used to estimate historic flow using 2% impervious cover. Note that historic flow from the site using Soil Group A is calculated as 0.00 cfs. This calculation is included in the Appendix. 4. CONCLUSIONS This project complies will the standards and requirements of Weld County. The basic drainage concept is to collect all flows from the site, and outfall to the stormwater detention pond located on site. The detention pond would be sized to contain the 100 -year 1 -hour storm. The site runoff would not adversely affect the downstream and surrounding land. This drainage report is in conformance with the Weld County Engineering and Construction Criteria dated March 17,2021. The Preliminary Grading Plan and Site Plan are included in the Appendix. An Erosion Control Plan and Storm Water Pollution Prevention Plan (SWPPP) would be developed as part of the construction documents. devium Stanley Consultants Page 5 Appendix • Drainage Report Checklist • NRCS Soils Maps • FIRM • Site Plan Hydrology and Hydraulic Analysis • NOAA Storm Intensities • NOAA Storm Depths • Peak Runoff Calculation - 2% Impervious • Detention Calculation — Modified FAA Method Construction Drawings • General Site Plan • 1041 USR Map • Grading Plan Drainage Report Checklist Project Name: The purpose of this checklist is to assist the applicant's Engineer with developing a drainage report that supports the intent of the Weld County Code using commonly accepted engineering practices and methodologies. Is the project in the MS4? Yes No If yes, the following requirements in blue apply. See Chapter 8, Article IX of the Weld County Code. Report Content Weld County Case Number Certificate of Compliance signed and stamped by a Colorado Licensed PE X Description/Scope of Work X Location (County Roads, S -T -R) X Nearby water features and ownership ❑ Total acres vs. developed acres CI Hydrological soil types/maps FEMA Flood Zones Urbanizing or non -urbanizing IX Methodologies used for report & analysis (full spectrum is not accepted) Base Design Standard used for permanent control measure design in the MS4 Discussion of offsite drainage routing Conclusion statement indicating that the design will adequately protect public health, safety, and general welfare and have no adverse impacts on public rights -of -way or offsite properties Hydrology and Hydraulic Analysis fX Design Storm / Rainfall Information (NOAA Atlas or Local Data) Release Rate calculations Post construction site imperviousness Hydrologic calculations (historic & developed basins) Hydraulic calculations for proposed drainage improvements (swales, culverts, riprap, pond, outlet, spillway, WQCV outlet, etc.) ICI Detention/WQCV calculations Comments: Construction Drawings Stamped by PE X Engineering scale & north arrow Xf Property lines, rights -of -way, and easements f� 1' Contours & elevations (existing & proposed) X] Pre- and post -development drainage basins Ix Arrows depicting flow direction Time of concentration critical path Drainage design points Improvements labeled Permanent control measure and associated drainage features labeled 'No Build/No Storage', include design volume Cross sections for open channels, profiles for pipes Elevations for inverts, flow lines, top of grates, orifice(s), etc. Pipe specs (size, material, length, slope) Outlet and spillway details Maintenance Plan Frequency of onsite inspections Repairs, if needed Cleaning of sediment and debris Vegetation maintenance Manufacturer maintenance specifications, if applicable Other Required Documents (If Applicable) Variance Request and documentation— explain hardship, applicable code section, and proposed mitigation. Variances will not be granted for the Base Design Standard requirement in the MS4. Department of Public Works I Development Review 1111 H Street, Greeley, CO 80631 I Ph: 970-304-6496 I www.weldgov.com/departments/public_works/development_review 8/14/2019 Meters 0 30 60 120 180 Feet 0 100 200 400 600 Map projection: Web Mercator Corner coordinates: WGS84 Edge tics: UTM Zone 13N WGS84 Soil Map —Weld County, Colorado, Southern Part MAP LEGEND Area of Interest (AO!) Area of Interest (AO1) ) Soils 0 U Soil Map Unit Polygons Soil Map Unit Lines Soil Map Unit Points Special Point Features Blowout Borrow Pit Clay Spot Closed Depression Gravel Pit Gravelly Spot Landfill Lava Flow Marsh or swamp Mine or Quarry Miscellaneous Water Perennial Water Rock Outcrop Saline Spot Sandy Spot Severely Eroded Spot Sinkhole Slide or Slip Sodic Spot a U vi? Spoil Area Stony Spot Very Stony Spot Wet Spot Other Special Line Features Water Features Streams and Canals Transportation Rails Interstate Highways US Routes Major Roads Local Roads Background ,; Aerial Photography MAP INFORMATION The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: Coordinate System: Web Mercator (EPSG:3857) Maps from the Web Soil Survey are based on the Web Mercator projection, which preserves direction and shape but distorts distance and area. A projection that preserves area, such as the Albers equal-area conic projection, should be used if more accurate calculations of distance or area are required. This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Weld County, Colorado, Southern Part Survey Area Data: Version 22, Aug 24, 2023 Soil map units are labeled (as space allows) for map scales 1:50,000 or larger. Date(s) aerial images were photographed: Jun 8, 2021 Jun 12, 2021 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. ,b Natural Resources lain Conservation Service Web Soil Survey National Cooperative Soil Survey 12/5/2023 Page 2of3 Soil Map —Weld County, Colorado, Southern Part Map Unit Legend Map Unit Symbol Map Unit Name Acres in AOI Percent of AOI 44 Olney loamy percent slopes sand, 1 to 3 13.1 61.7% 49 Osgood slopes sand, 0 to 3 percent 8.2 38.3% Totals for Area of Interest 21.3 100.0% e Natural Resources Web Soil Survey Conservation Service National Cooperative Soil Survey 12/5/2023 Page 3of3 NOTES TO USERS This map is for use in administering the National Flood Insurance Program tt does not necessarily Identify ail areas subject to (booing. particularly from local drainage sources d small size. The community r OaltO should be consulted for map repository' possible updated or additional flood hazard information. To obtain more detailed information in areas where Base Flood Elevations (BFEs) and/or floodways have been determined, users are encouraged to consult the Flood Profiles and Floodway Data and/or Summary of Stillwater Elevations tables contained within the Flood Insurance Study (FIS) Report that accompanies this FIRM. Users should be aware that BFEs shown on the FIRM represent rounded whoa -foot elevations. These BFEs are intended for flood insurance rating purposes only and should not be used as the sole source of flood elevation information Accordingly, flood elevation data presented in the EIS Report should be utilized in conjunction with the FIRM for purposes of construction and/or floodplain management- Coastal Base Flood Elevations shown on this map apply only landward of D,0" North American Vertical Datum of 1988 (NAVD 88). Users of this FIRM should be aware that coastal flood elevations ere also provided In the Summery of Stillwater Elevations table in the Flood Insurance Study Report for this jurisdiction. Elevations shown in the Summary of Stillwater Elevations table should be used for construction and/or floodplain management purposes when they are higher than the elevations shown on this FIRM. Boundaries of the floodways were computed at cross sections and interpolate° between cross sections. The floodways were based on hydraulic considerations with regard to requirements of the National Flood Insurance Program. Floodway widths and other pedinent Foodway data are provided in the Flood Insurance Study Report for this jurisdiction. Certain areas not in Special Flood Hazard Areas may be protected by flood control structures. Refer to Section 2.4 "Flood Protection Measures" of the Flood ns.iran e' Study Report for information on flood control structures for this jurisdiction. The projection used in the preparation of this map was Universal Transverse Mercator (UTM) zone 13 The horizontal datum was NAD 83, GRS 1980 spheroid. DiNerent�v in datum, spheroid, projection or 11TM zones used in the production of FIRMS for adjacent jurisdictions may result in slight positional differences in map features across jurisdiction boundaries- These differences do not affect the accuracy of this FIRM. Flood elevations on this map are referenced to the North American Vertical Datum of 1988. These flood elevations must be compared to structure and ground elevations referenced to the same vertical datum. For information regarding conversion between the National Geodetic Vertical Datum of 1929 and the North American Vertical Datum of 1988, visit the National Geodetic Survey website at htfolLanim n°s-noea.gov or contact the National Geodetic Survey at the following _- r 45"' - 3 E d E `39 ""E -r — `41'"-'°E C : 7' JO" - i ratdS?!.N 1,.5 '4Z E 104° 30' 00" LEGEND SPECIAL ROOD I IAZARD AREAS (SFHAs) SUBJECT TO Ill OD INUNDATION BYr� THE also 'mo1% wnasthe ham rood, isUAL CHANCE Gthe flood that hr. The 1% annual chance flood aT"schalcedtang equates exceeded ,n any g year. The Special Rood hoard are a the area Subioct to tIoxbng by the 1% annual coerce flood. Areas d Special Flood Hazard rciude iuresA, AE, NI, A0, AA, A99, V, and VE The Ease Flood Elevation Is the vrdter-xxtare elevation of the 3% aerial chance nand. i , i .,. i .7 • _ ,� - 5 •' ,?im dRf 4 3 c 1 1 ' _ 40°15' 00" — 1335000 FT O -- nr #' I ; I -A fF� ss ,t 1 3s - _ ZONE A No Base Flood Beiatiors determined. ZONE AE use Flooc eminent. drummed ZONF AH 'Toed depths d 100 3 feet (uSilafyaheacd posing); ease Flood Eleanore determa-od. ZONE AC Food depths d i Go 3 hat (usually Shit now m 5ldpilg terrain): average tenths detem fled. For arm d alluvial fan Hooding, velocities also determined. ZONE AR Spunk Flood (Hazard Areas Nutley protected Iran the 1% annual theme flood by a hood control system that was subsequentt datelined. Zone AaindeatesNetthe (sonartbpdControl sysemisben9resprcdtoprtwde n cation from the 1% annual chance a Vraate flood. ZONE A99 Ar®m be protected urn room 1n annual chin florid by a Federal Hoot protection system urger construction; no Base food Glevaoons rletermirred ZONE v • rfJood zone with veodty Itaurd (waveaClm); s Bain Flood Elevations ed. ZONE VE Coastal flood tone with vekdty hazard (Wave action); Base Flood Elevation: deternred. I re. j I =� v Cr =: sa • if-- y ' • 1 0 1 1 - ' 1 2 1 jv 1-117,-1 , ,,••} 12 i" 8° 9 atit N — r- ,� ^ \Veld County Unincorporated thefts 08(l. Gb • • • • • • .• ••• ••• •• ••• •• • 1330000 FT - 1,- 3d - - IC - k `;t ti • + `-_• ` ' •1 �� ZONE A /� f� 00DWAY AREAS TN ZONE AE me no9hm is the dwnnei d a stream sus my accacent cartedf•xdplain meal that must t e knit free of itocrdahment so mat the 1% annual chant flood can tie carried without sulynnaal Increases In leas heights vii • • L 13 ` - ;,• = ' 1 ,1 ` ' 16 15 14 1 • '' '''' ' ' OTHER FLOOD AREAS r y ¢ it ui 1 -r t a7 'o — '� rSl a :x . _ - e, •.' n ��. o z . ' , -� 1 ' ` • t`` _-,4 j v ' 6 1 I `i' - V `" -• _ - 1325000 FT ZONE X• Areas d 0 2%amual chance none; auras of I% annual cnance hood wrtn average deDlhs orl�than • (cot M.YNGarage areas kn5 than 1scuare mile; and areas protected by levees from 1"o annual chance hood. OTHER AREAS um x ZONED rimes determined le be *aside the 0.2% annual chance roodpion. Areas m which heed hazards are unde4emined' butpo6sble. • r i :: •`' '_' :+- 32 I - •., e� • .. - - I • �v --_ .__ - '. A r k\\1 COASTAL BARRIER RESOURCES SYSTEM (0311S) AREAS re r -�_ S - 31 - - - 20 21 22 ' 23 :t• : 24 kN` �NN' OTHERWISE PROtLC, tt D AREAS (°Pits) CBRS a sits and OPAs are rwlnSly located within or adjacent to Spectre Flood Hazard Areas. 1% Annual CliarKe Floodplain Boundary address: NGS Information Services NOAA, N/NGS12 National Geodetic Survey SSMC -3, #9202 1315 East-West Highway Silver Spring, Maryland 20910-3282 (301)713-3242 To obtain current elevation, description, and/or location information for bench marks shown on this map, please contact the Information Services Branch of the National Geodetic Survey at (301) 713- 3242, or visit its website at hUPdiwww,ncts,noaa.gov 0.2% Annuli Chance Floodplain Boundary :51"'.. NJ 73 24 19 ._ p I 1 _.20 CI 0 0 -T Floodway boundary Zone D traunddry C8RS and OPA boundary Boundary diwdin So Ha Flood Hazard A -ea Zones and bounded dh+dlrp $Jrddl Flood Havant A-ea5 of cdferrrl Base Flrrxl Eie•.ataxn. flood, or nand vcJwdies 70 - ""^ .513'`^^ Base Flood Elevator line and value; elevation in feels Rt. 987) Base Flood Elevation value where uniform widen dune; elevation in free referenced to the North American Vertical Datum of 149E OV Cna section line "S0 r' -'T4 '4 . N 26 r e Q 25 rX:':::::4 i� z �� ` -: ••:•:: : > !. ZONE A ;}- , .:., L-:"': ' • :•• -:- I , , ' • 29 28 27 �VelIl �'(j 3ll lttt ( nin&in'p ii.itttl Areas 080266 - r - ' • 1315000 FT 8 J Base map information shown on this FIRM was derived fromNAIPOAhophotography produced with a one meter ground resolution from photography dated 2013. The profile baselines depicted on this map represent the hydraulic modeling baselines that rnatchthe flood prnxlesinthe FIS report Asa result of Unproved topographic data the profile baseline, in some cases, may deviate significantly from the channel centerline or appear outside the SFHA. This map reflects more detailed and up to -date stream channel configurations than those shown on the previous FIRM for this jurisdiction. The Iloodplalns and floodways that were transferred from the previous FIRM may have been adjusted to conform to these new stream channel configurations. As a result, the Flood Profiles and Floodway Data tables for multiple streams in the Flood Insurance Study Report (which contains authoritative hydraulic data) may retied stream chhannel distances that differ from what is shown on this map. Corporate limits shown on this map are based on the best date available at the time of publication. Because changes due to annexations or de -annexations may have after this map was ublished map users should contact appropriate P apD p community officials to verity current corporate limit locations. Please refer to the separately pnnted Map Index for an overview map of the county showing the layout of map panels; community map repository addresses: and a Listing of Communities table containing National Flood Insurance Program dates for each community as well as a listing of the panels on which each community is located. For Information on available products associated with this FIRM visit the Map Service Center (MSC) website at htto://mscfema.cov Available products may ZS 23 Trangect nne 46.32 or 93.0217 Geocraphc coordinates referent --rd to the North Amerlcarn DdLini of Ica3 (+MO 83) Wegem Hemisphere 31013000 FT S000•fral t;ks: Colorado Slate Plane Central Zone (FIPS Zone 0502), Lnmhert Conformal Conicpmyctlon «e4°0°^' N 1000 -Meter Universal Tracst a Mercator grid values, zone 13 t]XiEtc X Berdn mark (see explanation n nktes to users section of r� 5 RPM •Mt s aver r Mac MAP REPOSITORIES list os Refer to Map Repositories list on Mao Indite EFFECTIVE DATE OF COVNTYW DE RATE MAP FLOOD January Jenuey 20, 2018 EFFECTIVE DATE(S)OF REVISIONS) TO THIS PANEL For community map revision history prior to COuntywida mopping, refer to the Cpmrtwnly Map Hatory table located in the Flood Insurance Study report tor tMs puteerrainn or call me Imposmine r t Insurance ce is lineable nim 3' • eommtt0 woginsunna agars liair :4s N 3 i' ,- I,`' 35 - - `-` - - - r i o ,t 36 :� :::�:.: :••n•: •''::•: •' •occurred •31 32' 33 I 34 '' a i ri1 ; ( x -j . '. - T ;N ZGenre a H Z O' 1310000 FT a NJ = :::;:; a:: - •.•:•:•:•:•:•:•:.•'1 = : ::t - 5 4 2 include previously issued Letters of Map Change, a Flood Insurance Study Report. and/or digital versions of this map. Many of these products can be ordered or obtained directly from the MSC website If you have questions about this map, hem to order products, or the National Flood Insurance Program in general, please call the FEMA Map Information eXchange (FMIX) at 1-877-FEMA-MAP (1-877-336-2527) or visit the FEMA website at http://www.fema,40v/business/nfip. MAP SCALE 1- = 2000' 2000 1000 04000 2 1 •:''• .-:•:•:•:•:;:•:•:•:•. `:- "' 6 1305000 FT /--• �-• �— • FEET >—• . (METERS WO 600 1200 d 1111 IIMIII, i N� ;moil Ir11r111 i.i ,fl. nor) mei I I PANEL 1975E • • w „ 1111111 a CO II4r or,taN ZONE A •:,,: 12 : Yad'', `� "'ck{,' I ir,` A� ! 7 %Vold County 8 9 I0 11 - .. 1''.' 1300000FT .,a FIRM a al FLOOD INSURANCE RATE MAP i to _,I o '' WELD COUNTY, COLORADO AND INCORPORATED AREAS A II III II PANEL 1975 OF 2250 Inincnrpnrated 1r•t'ac 0802GG = rf , .i.�,,r (SEE MAP INDEX FOR FIRM PANEL LAYOUT) r44°0C'1•J y r — CONTAINS - lli„ a h 1 pail II .. COMMUNITY v HUMBER PANEL St.' FIX wale caartiv 0302,93 tore E 1�3 eat S ZONE A,:` c- —• 'i 1 ( a 1 , e 1295000 FT t '14 y 18 17 1 (j` - = 15 - tic • . _ .... _ -i •f a...............................- _moo : .-- — •s ��1�� assn NoticetoUser The Map Number shown below should be used when placing map orders: the Number shown above should be a !,cations for the ' �'-•Community i_ 23 24' 20 3i I 24 i. ; Ha t used or Issuance subtd ommur•:y Pp subject u42,N sh�.�k23 C �= .. %IIIi ,ti t ',r+ •� P_'; r 40 07' 30' ctvaaryF Sr9. MAP NUMBER 08123C1975E 40 G7 30' d. 104- 37' 30'• JOINS PANEL 2155 JOINS' PANEL 2160 JOINS PANEL 2157 104' 30' 00" 3250000 FT 3255000 FT 3260000 F T 3265000 FT 3270000 FT 32751JC0 FT I�I� Jlr � o f 4t4MnSFt'' a' EFFECTIVE DATE JANUARY 20. 2016 �. 111111 l , Federal Emergency Management Agency , 12998.250 1298159 1298050 1297950 1297850 1297750 1297650 1297550 1297450 1297250 1297350 0 n 0 h t0 h 0 N M t0 D N 1 0 n N 0 tri M CO M 0 0 N M Si aa� -----------oc�e-ar� -caca �a=ea �r zi+-ar,,iccs, . n' O 0 0) eD 0 r 8 M ( LI N NS 1298250 LU 1296150 1298050 1297950 1297850 1297750 1297650 '1297560 1', p I , I ' I I ,: 129#450 I i I I I I ? I I 1297350 0 co 1297250 M Hydrology and Hydraulic Analysis • Design Storm / Rainfall Information (NOAA Atlas or Local Data) o NOAA Storm Intensities o NOAA Storm Depths • Peak Runoff Calculation - 2% Impervious area • Detention Calculation — Modified FAA Method NOAA's National Weather Service Hydrometeorological Design Studies :. Precipitation Frequency Data Server (PFD General Information Homepage Progress Reports FAQ Glossary Precipitation Frequency Data Server GIS Grids Maps Time Series Temporals Documents Probable Maximum Precipitation Documents Miscellaneous Publications Storm Analysis Record Precipitation Contact Us Inquiries 111:51‘19,9vlam Home Site Map Organization Search ® NWS O All NOAA NOAA ATLAS 14 POINT PRECIPITATION FREQUENCY ESTIMATES: CO www.nws.noaa.gov %tip Data description Data type: Precipitation depth V Units: English v Time series type: Partial duration Se Select location 1) Manually: a) By location (decimal degrees, use "-" for S and W): Latitude: 40.14 b) By station (list of CO stations): Select station c) By address 2) Use map: V Search Q Longitude: -104.55) Submit a) Select location Move crosshair or double click b) Click on station icon �j Show stations on map Location information: Name: Keenesburg, Colorado, US/ Latitude: 40.1400° Longitude: -104.5500° Elevation: 4948 ft ** * Source: ESRI Maps ** Source: USGS PF tabular POINT PRECIPITATION FREQUENCY (PF) ESTIMATES WITH 90% CONFIDENCE INTERVALS AND SUPPLEMENTARY INFORMATION NOAA Atlas 14, Volume 8, Version 2 PF graphical Supplementary information a Print page PDS-based precipitation frequency estimates with 90% confidence intervals (in inches)1 Average recurrence interval (years) Duration 1 2 5 10 25 50 100 200 500 1000 5 -min 0.242 (0.194-0.305) 0.294 (0.235-0.371) 0.392 (0.312-0.496) 0.486 (0.384-0.617) 0.633 (0.491-0.854) 0.761 (0.571-1.03) 0.901 (0.652-1.25) 1.06 (0.730-1.50) 1.28 (0.849-1.87) 1.47 (0.939-2.15) 10 -min 0.355 (0.283-0.447) 0.431 (0.344-0.543) 0.574 (0.457-0.726) 0.711 (0.562-0.903) 0.927 (0.718-1.25) 1.11 (0.837-1.51) 1.32 (0.954-1.83) 1.55 (1.07-2.20) 1.88 (1.24-2.74) 2.15 (1.38-3.15) 15 -min 0.433 (0.346-0.545) 0.525 (0.419-0.662) 0.700 (0.557-0.885) 0.867 (0.685-1.10) 1.13 (0.876-1.52) 1.36 (1.02-1.84) 1.61 (1.16-2.24) 1.89 (1.30-2.69) 2.29 (1.52-3.34) 2.62 (1.68-3.84) 30 -min 0.581 (0.464-0.732) 0.702 (0.561-0.886) 0.934 (0.743-1.18) 1.16 (0.914-1.47) 1.51 (1.17-2.04) 1.82 (1.36-2.47) 2.16 (1.56-3.00) 2.53 (1.75-3.61) 3.08 (2.04-4.50) 3.53 (2.26-5.17) 60 -min 0.714 (0.571-0.900) 0.856 (0.683-1.08) 1.13 (0.900-1.43) 1.40 (1.11-1.78) 1.84 (1.43-2.50) 2.23 (1.68-3.04) 2.66 (1.93-3.71) 3.14 (2.18-4.49) 3.85 (2.55-5.63) 4.44 (2.84-6.50) 2 -hr 0.848 (0.683-1.06) 1.01 (0.811-1.26) 1.33 (1.07-1.67) 1.65 (1.32-2.08) 2.18 (1.71-2.93) 2.64 (2.01-3.58) 3.17 (2.32-4.38) 3.76 (2.63-5.32) 4.62 (3.10-6.70) 5.34 (3.45-7.75) 3 -hr 0.924 (0.748-1.15) 1.09 (0.881-1.36) 1.43 (1.15-1.78) 1.77 (1.42-2.22) 2.34 (1.85-3.14) 2.85 (2.18-3.83) 3.42 (2.52-4.70) 4.06 (2.86-5.72) 5.02 (3.38-7.23) 5.82 (3.78-8.38) 6 -hr 1.09 (0.886-1.34) 1 1.27 (1.03-1.56) 1.64 (1.33-2.02) 2.01 (1.62-2.49) 2.63 (2.10-3.49) 3.18 (2.46-4.24) 3.81 (2.83-5.19) 4.52 (3.21-6.30) 5.56 (3.78-7.93) 6.44 (4.22-9.17) 12 -hr 1.29 (1.06-1.57) 1.51 (1.24-1.84) 1.94 (1.59-2.37) 2.35 (1.91-2.89) i 3.00 (2.39-3.90) 3.56 (2.76-4.66) 4.18 (3.12-5.60) 4.87 (3.48-6.68) j 5.86 (4.02-8.24) 6.68 (4.43-9.42) 24 -hr 1.52 (1.26-1.84) 1.80 (1.48-2.17) i 2.29 (1.89-2.77) 2.74 (2.24-3.33) 3.42 (2.74-4.37) 4.00 (3.11-5.15) 4.62 (3.47-6.09) 5.30 (3.81-7.16) 6.26 (4.32-8.67) 7.04 (4.71-9.81) 2 -day 1.73 (1.45-2.07) 2.08 (1.74-2.50) 2.68 (2.22-3.22) 3.19 (2.64-3.85) 3.93 (3.15-4.92) 4.52 (3.53-5.72) 5.14 (3.87-6.65) 5.78 (4.18-7.68) 6.67 (4.63-9.08) 7.36 (4.97-10.1) 3 -day 1.89 (1.59-2.26) 2.25 (1.89-2.68) 2.85 (2.38-3.41) 3.37 (2.80-4.05) 4.12 (3.32-5.12) 4.72 (3.71-5.94) 5.34 (4.05-6.87) 5.99 (4.35-7.90) 6.88 (4.81-9.31) 7.58 (5.15-10.4) 4 -day 2.02 (1.70-2.40) 2.38 (2.00-2.82) 2.98 (2.50-3.55) 3.51 (2.92-4.19) 4.26 (3.44-5.27) 4.86 (3.83-6.08) 5.48 (4.17-7.02) 6.14 (4.48-8.06) 7.04 (4.94-9.48) 7.74 (5.28-10.6) 7 -day 2.32 (1.96-2.72) 2.70 (2.29-3.18) 3.35 (2.82-3.95) 3.90 (3.27-4.62) 4.67 (3.79-5.71) 5.28 (4.19-6.54) 5.91 (4.53-7.49) 6.56 (4.82-8.52) 7.44 (5.26-9.91) 8.12 (5.58-11.0) 10 -day 2.56 (2.18-3.00) 2.98 (2.54-3.50) 3.67 (3.11-4.31) 4.25 (3.58-5.01) 5.05 (4.11-6.13) 5.68 (4.52-6.98) 6.30 (4.85-7.93) 6.95 (5.13-8.96) 7.81 (5.54-10.3) 8.47 (5.86-11.4) 20 -day 3.29 (2.82-3.82) 3.78 (3.24-4.39) 4.58 (3.91-5.32) 5.23 (4.44-6.11) 6.12 (5.01-7.32) 6.79 (5.44-8.24) 7.45 (5.78-9.25) 8.12 (6.04-10.3) 8.99 (6.44-11.7) 9.64 (6.74-12.8) 30 -day 3.87 (3.34-4.46) 4.43 (3.82-5.12) 5.33 (4.58-6.17) 6.06 (5.17-7.04) 7.03 (5.79-8.35) 7.76 (6.26-9.35) 8.48 (6.61-10.4) 9.18 (6.87-11.6) 10.1 (7.26-13.1) 10.7 (7.56-14.2) 45 -day 4.58 (3.97-5.25) 5.24 (4.54-6.02) 6.30 (5.44-7.24) 7.14 (6.13-8.25) 8.26 (6.82-9.72) 9.07 (7.34-10.8) 9.86 (7.72-12.0) 10.6 (7.98-13.3) 11.6 (8.38-14.9) 12.3 (8.68-16.1) 60 -day 5.15 (4.48-5.88) 5.92 (5.15-6.77) 7.13 (6.18-8.17) 8.09 (6.97-9.30) 9.34 (7.74-10.9) 10.2 (8.32-12.2) 11.1 (8.72-13.5) 11.9 (8.99-14.8) 12.9 (9.39-16.5) 13.6 (9.69-17.8) 1 Precipitation frequency (PF) estimates in this table are based on frequency analysis of partial duration series (PDS). Numbers in parenthesis are PF estimates at lower and upper bounds of the 90% confidence interval. The probability that precipitation frequency estimates (for a given duration and average recurrence interval) will be greater than the upper bound (or less than the lower bound) is 5%. Estimates at upper bounds are not checked against probable maximum precipitation (PMP) estimates and may be higher than currently valid PMP values. Please refer to NOAA Atlas 14 document for more information. 1 Estimates from the table in CSV format: Precipitation frequency estimates v Submit Main Link Categories: Home I OWP US Department of Commerce National Oceanic and Atmospheric Administration National Weather Service Office of Water Prediction (OWP) 1325 East West Highway Silver Spring, MD 20910 Page Author: HDSC webmaster Page last modified: April 21, 2017 Map Disclaimer Disclaimer Credits Glossary Privacy P Abot. Career Opportur NOAA's National Weather Service Hydrometeorological Design Studies :. Precipitation Frequency Data Server (PFD General Information Homepage Progress Reports FAQ Glossary Precipitation Frequency Data Server GIS Grids Maps Time Series Temporals Documents Probable Maximum Precipitation Documents Miscellaneous Publications Storm Analysis Record Precipitation Contact Us Inquiries 111:51‘19,9vlam Home Site Map Organization Search ® NWS O All NOAA NOAA ATLAS 14 POINT PRECIPITATION FREQUENCY ESTIMATES: CO www.nws.noaa.gov %tip Data description Data type: Precipitation intensity v Units: English v Time series type: Partial duration Se Select location 1) Manually: a) By location (decimal degrees, use "-" for S and W): Latitude: 40.14 b) By station (list of CO stations): Select station c) By address 2) Use map: V Search Q Longitude: -104.55) Submit a) Select location Move crosshair or double click b) Click on station icon �j Show stations on map Location information: Name: Keenesburg, Colorado, US/ Latitude: 40.1400° Longitude: -104.5500° Elevation: 4948 ft ** * Source: ESRI Maps ** Source: USGS PF tabular POINT PRECIPITATION FREQUENCY (PF) ESTIMATES WITH 90% CONFIDENCE INTERVALS AND SUPPLEMENTARY INFORMATION NOAA Atlas 14, Volume 8, Version 2 PF graphical Supplementary information a Print page PDS-based precipitation frequency estimates with 90% confidence intervals (in inches/hour) Average recurrence interval (years) Duration 1 2 5 10 25 50 100 200 500 1000 5 -min 2.90 (2.33-3.66) 3.53 (2.82-4.45) 4.70 (3.74-5.95) 5.83 (4.61-7.40) 7.60 (5.89-10.2) 9.13 (6.85-12.4) 10.8 (7.82-15.0) 12.7 (8.76-18.1) 15.4 (10.2-22.5) 17.6 (11.3-25.8) 10 -min 2.13 (1.70-2.68) 2.59 (2.06-3.26) 3.44 (2.74-4.36) 4.27 (3.37-5.42) 5.56 (4.31-7.50) 6.68 (5.02-9.08) 7.92 (5.72-11.0) 9.29 (6.41-13.2) 11.3 (7.46-16.5) 12.9 (8.25-18.9) 15 -min 1.73 (1.38-2.18) 2.10 (1.68-2.65) 2.80 (2.23-3.54) 3.47 (2.74-4.40) 4.52 (3.50-6.10) 5.44 (4.08-7.38) 6.44 (4.66-8.94) 7.55 (5.22-10.8) 9.16 (6.06-13.4) 10.5 (6.71-15.4) 30 -min 1.16 (0.928-1.46) 1.40 (1.12-1.77) 1.87 (1.49-2.36) 2.31 (1.83-2.94) 3.02 (2.34-4.07) 3.63 (2.73-4.94) 4.31 (3.12-5.99) 5.06 (3.50-7.21) 6.16 (4.08-8.99) 7.06 (4.51-10.3) 60 -min 0.714 (0.571-0.900) 0.856 (0.683-1.08) 1.13 (0.900-1.43) 1.40 (1.11-1.78) 1.84 (1.43-2.50) 2.23 (1.68-3.04) 2.66 (1.93-3.71) 3.14 (2.18-4.49) 3.85 (2.55-5.63) 4.44 (2.84-6.50) 2 -hr 0.424 (0.341-0.529) 0.504 (0.405-0.630) 0.665 (0.533-0.833) 0.826 (0.658-1.04) 1.09 (0.855-1.46) 1.32 (1.00-1.79) 1.58 (1.16-2.19) 1.88 (1.31-2.66) 2.31 (1.55-3.35) 2.67 (1.73-3.87) 3 -hr 0.307 (0.249-0.382) 0.363 (0.293-0.451) 0.475 (0.382-0.593) 0.590 (0.472-0.738) 0.778 (0.615-1.04) 0.947 (0.724-1.28) 1.14 (0.837-1.56) 1.35 (0.951-1.91) 1.67 (1.12-2.41) 1.94 (1.26-2.79) 6 -hr 0.181 (0.147-0.223) 1 0.211 (0.172-0.260) 0.273 (0.221-0.337) 0.335 (0.270-0.416) 0.438 (0.350-0.582) 0.531 (0.409-0.708) 0.636 (0.472-0.866) 0.754 (0.535-1.05) 0.929 (0.632-1.32) 1.08 (0.704-1.53) 12 -hr 0.106 (0.087-0.130) 0.125 i (0.103-0.153) 0.160 (0.131-0.196) 0.195 (0.158-0.239) 0.248 (0.198-0.323) 0.295 (0.228-0.386) 0.346 (0.258-0.464) 0.403 i (0.288-0.554) 0.486 (0.333-0.683) 0.554 (0.367-0.782) 24 -hr 0.063 (0.052-0.076) 0.074 i (0.061-0.090) 0.095 (0.078-0.115) 0.114 (0.093-0.138) 0.142 (0.114-0.182) 0.166 (0.129-0.214) 0.192 (0.144-0.253) 0.220 (0.158-0.298) 0.260 (0.179-0.361) 0.293 (0.196-0.408) 2 -day 0.036 (0.030-0.043) 0.043 (0.036-0.051) 0.055 (0.046-0.066) 0.066 (0.054-0.080) 0.081 (0.065-0.102) 0.094 (0.073-0.119) 0.106 (0.080-0.138) 0.120 (0.087-0.159) 0.138 (0.096-0.189) 0.153 (0.103-0.211) 3 -day 0.026 (0.022-0.031) 0.031 (0.026-0.037) 0.039 (0.033-0.047) 0.046 (0.038-0.056) 0.057 (0.046-0.071) 0.065 (0.051-0.082) 0.074 (0.056-0.095) 0.083 (0.060-0.109) 0.095 (0.066-0.129) 0.105 (0.071-0.144) 4 -day 0.021 (0.017-0.025) 0.024 (0.020-0.029) 0.031 (0.026-0.036) 0.036 (0.030-0.043) 0.044 (0.035-0.054) 0.050 (0.039-0.063) 0.057 (0.043-0.073) 0.063 (0.046-0.083) 0.073 (0.051-0.098) 0.080 (0.055-0.109) 7 -day 0.013 (0.011-0.016) 0.016 (0.013-0.018) 0.019 (0.016-0.023) 0.023 (0.019-0.027) 0.027 (0.022-0.034) 0.031 (0.024-0.038) 0.035 (0.026-0.044) 0.039 (0.028-0.050) 0.044 (0.031-0.058) 0.048 (0.033-0.065) 10 -day 0.010 (0.009-0.012) 0.012 (0.010-0.014) 0.015 (0.012-0.017) 0.017 (0.014-0.020) 0.021 (0.017-0.025) 0.023 (0.018-0.029) 0.026 (0.020-0.033) 0.028 (0.021-0.037) 0.032 (0.023-0.043) 0.035 (0.024-0.047) 20 -day 0.006 (0.005-0.007) 0.007 (0.006-0.009) 0.009 (0.008-0.011) 0.010 (0.009-0.012) 0.012 (0.010-0.015) 0.014 (0.011-0.017) 0.015 (0.012-0.019) 0.016 (0.012-0.021) 0.018 (0.013-0.024) 0.020 (0.014-0.026) 30 -day 0.005 (0.004-0.006) 0.006 i (0.005-0.007) 0.007 (0.006-0.008) 0.008 (0.007-0.009) 0.009 (0.008-0.011) 0.010 (0.008-0.012) 0.011 (0.009-0.014) 0.012 (0.009-0.016) 0.013 (0.010-0.018) 0.014 (0.010-0.019) 45 -day 0.004 (0.003-0.004) 0.004 (0.004-0.005) 0.005 (0.005-0.006) 0.006 (0.005-0.007) 0.007 (0.006-0.009) 0.008 (0.006-0.010) 0.009 (0.007-0.011) 0.009 (0.007-0.012) 1 0.010 1 (0.007-0.013) 0.011 (0.008-0.014) 60 -day 0.003 (0.003-0.004) 0.004 (0.003-0.004) 0.004 (0.004-0.005) 0.005 (0.004-0.006) 0.006 (0.005-0.007) 0.007 (0.005-0.008) 0.007 (0.006-0.009) 0.008 1 (0.006-0.010) 0.008 (0.006-0.011) 0.009 (0.006-0.012) 1 Precipitation frequency (PF) estimates in this table are based on frequency analysis of partial duration series (PDS). Numbers in parenthesis are PF estimates at lower and upper bounds of the 90% confidence interval. The probability that precipitation frequency estimates (for a given duration and average recurrence interval) will be greater than the upper bound (or less than the lower bound) is 5%. Estimates at upper bounds are not checked against probable maximum precipitation (PMP) estimates and may be higher than currently valid PMP values. Please refer to NOAA Atlas 14 document for more information. 1 Estimates from the table in CSV format: Precipitation frequency estimates v Submit Main Link Categories: Home I OWP US Department of Commerce National Oceanic and Atmospheric Administration National Weather Service Office of Water Prediction (OWP) 1325 East West Highway Silver Spring, MD 20910 Page Author: HDSC webmaster Page last modified: April 21, 2017 Map Disclaimer Disclaimer Credits Glossary Privacy P Aboi Career Opportur PDS-based precipitation frequency estimates with 90% confidence intervals (in inches/hour Duration 9.8 -min 10 -min 15 -min 16.5 -min 21.9 -min 30 -min 60 -min 2 -hr 3 -hr 6 -hr 12 -hr 24 -hr . 2 -day 3 -day 4 -day 7 -day 10 -day 20 -day 30 -day 45 -day 60 -day 1 2.90 (2.33-3.66) 2.13 (1.70-2.68) 1.73 (1.38-2.18) 1.16 (0.928-1.46) 0.714 (0.571-0.900) 0.424 (0.341-0.529) 0.307 (0.249-0.382) 0.181 (0.147-0223) 0.106 (0.087-0.130) 0.063 (0.052-0.076) 0.036 (0.030-0.043) 0.026 (0.022-0.031) 0.021 (0.017-0.025) 0.013 (0.011-0.016) 0.010 (0.009-0.012) f _ 0.006 (0.005-0.007) 0.005 (0.004-0.006) 0.004 (0.003-0.004) 0.003 (0.003-0.004) 2 3.53 (2.82-4.45) 2.59 (2.06-3.26) 2.10 (1.68-2.65) 1.40 (1.12-1.77) 0.856 (0.683-1.08) 0.504 (0.405-0.630) 0.363 (0.293-0.451) 0.211 (0.172-0.260) 0.125 (0.103-0.153) 0.074 (0.061-0.090) 0.043 (0.036-0.051) 0.031 (0.026-0.037) 0.024 (0.020-0.029) 0.016 (0.013-0.018) 0.012 (0.010-0.014) 0.007 (0.006-0.009) 0.006 (0.005-0.007) 0.004 (0.004-0.005) 0.004 (0.003-0.004) 5 4.70 (3.74-5.95) 3.44 (2.74-4.36) 2.80 (2.23-3.54) 1.87 (1.49-2.36) 1.13 (0.900-1.43) 0.665 (0.533-0.833) 0.475 (0.382-0.593) 0.273 (0.221-0.337) 0.160 (0.131-0.196) 0.095 (0.078-0.115) 0.055 (0.046-0.066) 0.039 (0.033-0.047) 0.031 (0.026-0.036) 0.019 (0.016-0.023) 0.015 (0.012-0.017) 0.009 (0.008-0.011) 0.007 (0.006-0.008) 0.005 (0.005-0.006) 0.004 (0.004-0.005) 10 5.83 (4.61-7.40) 4.27 (3.37-5.42) 3.47 (2.74-4.40) 2.31 (1.83-2.94) 1.40 (1.11-1.78) 0.826 (0.658-1.04) r 0.590 (0.472-0.738) 0.335 (0.270-0.416) 0.195 (0.158-0.239) 0.114 (0.093-0.138) 0.066 (0.054-0.080) 0.046 (0.038-0.056) 0.036 (0.030-0.043) 0.023 (0.019-0.027) 0.017 (0.01 4-0.020) 0.010 (0.009-0.012) 0.008 (0.007-0.009) 0.006 (0,005-0.007) 0.005 (0.004-0.006) Average recurrence interval (years 25 7.60 (5.89-10.2) 5.56 (4.31-7.50) 4.52 (3.50-6.10) 3.02 (2.34-4.07) 1.84 (1.43-2.50) 1.09 (0.855-1.46) 0.778 (0.615-1.04) 0.438 (0.350-0.582) 0.248 (0.198-0.323) 0.142 (0.114-0.182) 0.081 (0.065-0.102) 0.057 (0.046-0.071) 0.044 (0.035-0.054) 0.027 (0.022-0.034) 0.021 0.012 (0.010-0.015) 0.009 (0.008-0.011) 0.007 (0.006-0.009) 0.006 (0.005-0.007) 50 9.13 (6.85-12.4) 6.68 (5.02-9.08) 100 10.8 (7.82-15.0) 8.04 7.92 (5.72-11.0) 200 12.7 (8.76-18.1) 9.29 (6.41-13.2) 500 15,4 (10.2-22.5) 11.3 (7.46-16.5) 5.44 6.44 7.55 9.16 (4.08-7.38) (4.66-8.94) i (5.22-10.8) (6.06-13.4) i 3.63 (2.734.94) 2.23 (1.68-3.04) 1.32 (1.00-1.79) 0.947 (0.724-1.28) 0.531 (0.409-0.708) 0.295 (0.228-0.386) 0.166 (0.129-0.214) 4 0.094 (0.073-0.119) 0.065 (0.051-0.082) 0.050 (0.039-0.063) 0.031 (0.024-0.038) 0.023 (0.018-0.029) 5.47 4.31 (3.12-5.99) 2.66 (1.93-3.71) 1.58 1 (1.16-2.19) 1.14 (0.837-1.56) 0.636 (0.472-0.866) 0.346 (0.258-0.464) 0.192 (0.144-0.253) i _ 5.06 (3.50-7.21) 3.14 (2.18-4.49) 1.88 (1.31-2.66) 1.35 (0.951-1.91) 0.754 (0.535-1.05) 0.403 (0.288-0.554) 0.220 (0.158-0.298) 0.106 (0.080-0.138) 0.074 (0.056-0.095) 0.057 (0.043-0.073) 0.035 (0.026-0.044) 0.120 (0.087-0.159) 0.083 (0.060-0.109) i _ 0.063 (0.046-0.083) i 0.039 (0.028-0.050) r 6.16 (4.08-8.99) 1 2.31 (1.55-3.35) 3.85 (2.5x5.63) 3.8 5 (2.55-5.63) 1000 17.6 (11.3-25.8) 12.9 (8.25-18.9) 10.5 (6.71-15.4) 7.06 (4.51-10.3) 4.44 (2.84-6.50) 1.67 (1.12-2.41) 0.929 (0.632-1.32) 0.486 (0.333-0.683) 0.260 (0.179-0.361) 0.138 (0.096-0.189) 0.095 (0.066-0.129) i 0.073 (0.051-0.098) 0.044 (0.031-0.058) 2.67 (1.73-3.87) 1.94 (1.26-2.79) 1.08 (0.704-1.53) 0.554 (0.367-0.782) 0.293 (0.196-0.408) 0.153 (0.103-0.211) 0.105 (0.071-0.144) 0.080 (0.055-0.109) 0.048 (0.033-0.065) 0.026 0.028 1 0.032 0.035 (0.020-0.033) (0.021-0.037) (C.023-0.043 (0.024-0.047) 0.014 0.015 0.016 0.018 (0.011-0.017) e (0.012-0.019) (0.012-0.021) (0.013-0.024) 0.010 (0.008-0.012) 0.008 (0.006-0.010) 0.007 (0.005-0.008) 0.011 (0.009-0.014) 0.009 (0.007-0.011) 0.012 (0.009-0.016) 0.007 (0.006-0.009) 0.009 (0.007-0.012) 0.008 (0.006-0.010) 0.013 (0.010-0.018) 0.010 (0.007-0.013) 0.020 (0.014-0.026) 0.014 (0.010-0.019) 0.011 (0.008-0.014) 0.008 (0.006-0.011) 0.009 (0.006-0.012) Table 5-3 Runoff Coefficient Equations for Weld County/2007 MHFD (HSG-A►) Equation Hydrologic Soil Group A 5 -Year 10 -Year 100 -Year (1.3113- C5 = (-0.08i 1.44i2+ - 0.12) + 0.09) 1.135i + (1.31i3- C10 = (-0.14i 1.44i2+ - 0.12) + 0.17) 1.135i + C100 (1.31i3 = (-0.251 -1.4412+1.135i - 0.12) + 0.32) + 2% 0.00 0.07 0.22 5% 0.02 0.10 0.24 10% 0.06 0.14 0.28 15% 0.10 0.17 0.30 20% 0.13 0.20 0.33 22.33% 0.339 23.32% 0.343 25% 0.16 0.23 0.35 26.05% 0.354 30% 0.19 0.25 0.37 35% 0.22 0.28 0.39 39.53% 0.408 40% 0.25 0.30 0.41 45% 0.27 0.33 0.43 50% 0.30 0.35 0.45 55% 0.33 0.38 0.47 60% 0.37 0.41 0.50 65% 0.41 0.45 0.53 70% 0.45 0.49 0.56 75% 0.50 0.54 0.61 80% 0.56 0.60 0.66 85% 0.63 0.66 0.72 90% 0.71 0.73 0.79 95% 0.80 0.82 0.86 100% 0.90 0.92 0.96 PEAK RUNOFF PREDICTION BY THE RATIONAL METHOD Version 1.02a, Released August 2005 Urban Drainage and Flood Control District Denver, Colorado Purpose: Function: Content: Intro Weighted C Tc and PeakQ Design Info Notation Acknowledgements: Comments? Revisions? This workbook applies the Rational Method to estimate stormwater runoff and peak flows from small urban catchments, i.e., typically less than 90 acres. 1. To apply the area -weighting method to calculate the representative runoff coefficient C for a catchment. 2. To calculate the time of concentration, and then compare with the empirical time of concentration limit used for the Denver region. The smaller one is recommended as the rainfall duration for use with the Rational Method. 3. To calculate the design rainfall intensity and peak flow rate. The workbook consists of the following five sheets: Describes the purpose of each sheet in the workbook. Applies the area -weighting method to determine the runoff C. Calculates Tc and Q -peak. Provides the recommended runoff C's for various land uses. Defines the variables used. Spreadsheet Development Team: Dr. James C.Y. Guo, P.E. Professor, Department of Civil Engineering University of Colorado at Denver Ken A. MacKenzie, P.E. Urban Drainage and Flood Control District Wright Water Engineers, Inc. Denver, Colorado Direct all comments regarding this spreadsheet workbook to: UDFCD E -Mail Check for revised versions of this or any other workbook at: Downloads ud-rational-v1.02a.xls, Intro 2/16/2024, 9:51 AM Area -Weighting for Runoff Coefficient Calculation Project Title: Catchment ID: Mountain Peak Power Station A Illustration Instructions: For each catchment subarea, enter values for A and C. Subarea Area Runoff Product ID acres Coeff. A C* CA input input input output 1 8.73 0.34 2.97 2 2.30 0.41 0.94 3 1.50 0.34 0.51 Sum: 12.53 sum: 4.42 Area -Weighted Runoff Coefficient (sum CA/sum A) = 0.35 rED: Flow D it action Cat elm. eat By *See sheet "Design Info" for inperviousness-based runoff coefficient values. ud-rational-v1.02a.xls, Weighted C 2/16/2024, 9:51 AM CALCULATION OF A PEAK RUNOFF USING RATIONAL METHOD Project Title: Catchment ID: Mountain Peak Power Station A I. Catchment Hydrologic Data Catchment ID = Area = Percent Imperviousness = NRCS Soil Type = A 12.53 2.00 A II. Rainfall Information Design Storm Return Period, Tr = C1 = C2= C3= P1= Acres A, B, C, or D I (inchlhr) = Cl * P1 /(C2 + Td)AC3 5 years 28.50 10.00 0.786 1.35 inches (input return period for design storm) (input the value of C1) (input the value of C2) (input the value of C3) (input one -hr precipitation --see Sheet "Design Info") III. Analysis of Flow Time (Time of Concentration) for a Catchment Runoff Coefficient, C = Overide Runoff Coefficient, C = 5-yr. Runoff Coefficient, C-5 = Overide 5-yr. Runoff Coefficient, C = 0.00 0.00 Reach 3 (enter an overide C value if desired, or leave blank to accept calculated C.) (enter an overide C-5 value if desired, or leave blank to accept calculated C-5.) Illustration Reach 2 _-------- overland Reach 1 flow a LEGEND) O Big Flow Direction C atc }carte Tit Bound NRCS Land Type Conveyance Heavy Meadow 2.5 Tillage/ Field 5 Short Pasture/ Lawns 7 Nearly Bare Ground 10 Grassed Swales/ Waterways 15 Paved Areas & Shallow Paved Swales (Sheet Flow) 20 Calculations: Reach ID Overland Slope S ft/ft input Length L ft input 5-yr Runoff Coeff C-5 output NRCS Convey- ance input 0.00 N/A 1 2 3 4 5 0.0050 0.0050 0.0050 Sum 1,100 1,100 IV. Peak Runoff Prediction Rainfall Intensity at Computed Tc, I = Rainfall Intensity at Regional Tc, I = Rainfall Intensity at User -Defined Tc, I = 2.30 2.96 2.53 inch/hr inch/hr inch/hr 10.00 10.00 10.00 Flow Velocity V fps output 0.00 0.71 Flow Time Tf minutes output 0.00 25.93 Computed Tc = Regional Tc = User -Entered Tc = Peak Flowrate, Qp = Peak Flowrate, Qp = Peak Flowrate, Qp = 25.93 16.11 21.90 0.00 0.00 0.00 cfs cfs cfs ud-rational-v1.02a.xls, Tc and PeakQ 2/16/2024, 9:51 AM Runoff Coefficient vs. Watershed Imperviousness Based on Runoff Coefficient estimating equation published by Urbonas, et.al. (1990) & WEF (1998) Basic equation for NRCS Soil Types C & D: CCD =KCD + (0.858*i3 - 0.786*i2 + 0.774*i+ 0.04) Basic equation for NRCS Soil Type A: + (1.31*i3 3 - 1.44*i2 + 1.135*i - 0.12) in which use values for C;, > 0 in which: i = 1„ /100, imperviousness ratio 1„ = watershed imperviousness in percent CA = Runoff Coefficient for NRCS Soil Type A KA = Correction factor for C;, when the storm return period is greater than 2 -years CCD = RunoffCoefficient for NRCS Soil Types C and D KCD = Correction factor for Cco when the storm return period is greater than 2 -years Values of Correction Factors KcD & K;4 NRCS Storm Return Period Soil Types • 2-yr 5-yr 10-yr 25-yr 50-yr 100-yr C & D 0.00 [-0.10*i+0.11] [-0.18*i+0.21] [-0.28*i+O.33] [-0.33*i+0.40] [-0.39*i+O.46] A 0.00 [-0.08*i+0.09] [-0.14*i+0.17] [-0.1 9*i +0.24] [-0.22*i+0.28] [-0.25*i+0.32] Values of Runoff Coefficient CCD Values of Runoff Coefficient CA Imperv. Type C and D NRCS Hydrologic Soil Groups Type A NRCS Hydrologic Soils Group Ratio r i 2-yr 5-yr 1 0-yr 25-yr 5U-yr 1 UU-yr 2-yr 5-yr 10-yr 25-yr 50-yr 1 00-yr 0.00 0.04 0.15 0.25 0.37 0.44 0.50 -0.12 -0.03 0.05 0.12 0.16 0.20 0.05 0.08 0.18 0.28 0.39 0.46 0.52 -0.07 0.02 0.10 0.16 0.20 0.24 0.10 0.11 0.21 0.30 0.41 0.48 0.53 -0.02 0.06 0.14 0.20 0.24 0.28 0.15 0.14 0.24 0.32 0.43 0.49 0.54 0.02 0.10 0.17 0.23 0.27 0.30 0.20 0.17 0.26 0.34 0.44 0.50 0.55 0.06 0.13 0.20 0.26 0.30 0.33 0.25 0.20 0.28 0.36 0.46 0.52 0.56 0.09 0.16 0.23 0.29 0.32 0.35 0.30 _ 0.22 0.30 0.38 0.47 0.53 0.57 0.13 0.19 0.25 0.31 0.34 0.37 0.35 0.25 0.33 0.40 0.48 0.54 0.57 0.16 0.22 0.28 0.33 0.36 0.39 0.40 0.28 0.35 0.42 0.50 0.55 0.58 0.19 0.25 0.30 0.35 0.38 0.41 0.45 0.31 0.37 0.44 0.51 0.56 0.59 0.22 0.27 0.33 0.37 0.40 0.43 0.50 0.34 0.40 0.46 0.53 0.57 0.60 0.25 0.30 0.35 0.40 0.42 0.45 0.55 0.37 0.43 0.48 0.55 0.59 0.62 0.29 0.33 0.38 0.42 0.45 0.47 0.60 0.41 0.46 0.51 0.57 0.61 0.63 0.33 0.37 0.41 0.45 0.47 0.50 0.65 _ 0.45 0.49 0.54 0.59 0.63 0.65 0.37 0.41 0.45 0.49 0.51 0.53 0.70 0.49 0.53 0.57 0.62 0.66 0.68 0.42 0.45 0.49 0.53 0.54 0.56 0.75 0.54 0.58 0.62 0.66 0.69 0.71 0.47 0.50 0.54 0.57 0.59 0.61 0.80 0.60 0.63 0.66 0.70 0.73 0.74 0.54 0.56 0.60 0.63 0.64 0.66 0.85 0.66 0.68 0.71 0.75 0.78 0.79 0.61 0.63 0.66 0.69 0.70 0.72 0.90 0.73 0.75 0.77 0.80 0.83 0.83 0.69 0.71 0.73 0.76 0.77 0.79 0.95 0.80 0.82 0.84 0.87 0.89 0.89 0.78 0.80 0.82 0.84 0.85 0.86 1.00 0.89 0.90 0.92 0.94 0.96 0.96 0.89 0.90 0.92 0.94 0.95 0.96 Runoff Coefficient 1.00 0.90 0.80 0.70 0.60 0.50 0.40 0.30 0.20 0.10 0.00 Notes: For Type B Soils, use the average of coefficients Ca) and C,4 . When the Runoff Coefficient in above table is < 0, use 0. When compositing the Runoff Coefficient for different soil types, use the table values above regardless if they are < 0. Runoff Coefficient vs. Imperviousness NRCS Hydrologic Soils C & D 0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 Watershed Impervious Ratio 1.0 ). 100-yr '- 25-yr 10-yr 5-yr 2-yr Runoff Coefficient Runoff Coefficient vs. Imperviousness NRCS Hydrologic Soil A 1.00 0.90 0.80 0.70 0.60 0.50 0.40 0.30 0.20 0.10 0.00 0.0 0.1 0.20.30.4 0.50.60.7 0.8 0.9 1.0 Watershed Impervious Ratio -+-100-yr —0— 25-yr 10-yr 5-yr 2-yr ud-rational-v1.02a.xls, Design Info 2/16/2024, 9:51 AM I. One -hr Precipitation Values for Metro Denver Area Return period in years 2 5 10 50 100 Depth in inches 0.93 1.35 1.61 2.20 2.60 IL Recommended Runoff Coefficients for Metro Denver Land Use or Surface Characteristics Percent Imper- viousness Business: Commercial areas 95 Neighborhood areas 85 Residential: Single-family Multiunit (detached) 60 Multiunit (attached) 75 Half -acre lot or larger * Apartments 80 Industrial: Light areas 80 Heavy areas 90 Parks, cemeteries: 5 Playgrounds: 10 Schools: 50 Railroad yard areas: 15 Undeveloped areas: Historical Flow Analysis 2 Greenbelts, agricultural Off -site flow analysis (when land use not defined) 45 Streets: Paved 100 Gravel (packed) 40 Driveways and sidewalks: 90 Roofs: 90 Lawns, sandy soil 0 Lawns, clayey soil 0 *Refer to Figures RO-3 through RO-5 in Runoff Chapter of USDCM. ud-rational-v1.02a.xls, Design Info 2/16/2024, 9:51 AM List of Variables A= C= C1, C2, and C3 C5 = I= ID = L= S= P1 Tc = Td Tf = Tr - Qp = v= watershed area in acres runoff coefficient coefficients in IDF formula 5-yr runoff coefficient rainfall intensity in inches/hour user defined identification number flow length in ft slope for flow length in ft/ft one hour precipitation value in inches time of concentration in minutes design rainfall duration in minutes flow time in minutes return period in years peak runoff rate in cfs flow velocity in ft/second ud-rational-v1.02a.xls, Notation 2/16/2024, 9:51 AM DETENTION BASIN VOLUME ESTIMATING WORKBOOK Purpose: Function: Version 2.35, Released January 2015 Urban Drainage and Flood Control District Denver, Colorado This workbook aids in the estimation of stormwater detention storage volume for urban watersheds that are smaller than 160 acres. 1. To apply the Rational Method (sometimes called the Modified FAA Method) and Hydrograph Method to estimate stormwater detention volume. 2. To approximate the storage volume of a detention basin given the basin geometry. 3. To estimate a stage -storage -discharge relationship for a detention basin Content: This workbook consists of the following sheets: Modified FAA Detention Volume Estimating Calculations: Estimates detention storage volume using the Rational -Modified FAA method. Hydrograph Estimates detention storage volume using the Hydrograph Method. Full -Spectrum Estimates detention storage volume using the Full Spectrum Control Method. Stage -Storage Tables for Detention Basins: Basin Tabulates stage -storage relationship estimates for various detention basin shapes. Stage -discharge Tables Using Outlets with Inlet & Outlet Control: WQCV Tabulates a stage -discharge relationship for the water quality capture volume outlet structure (inlet contra Restrictor Plate Sizes a choking plate over a circular vertical orifice and dimensions an equivalent rectangular orifice. Outlet Tabulates a stage -discharge relationship for the final outlet structure (inlet control). Culvert Tabulates a stage -discharge relationship for the outlet culvert, comparing inlet vs. outlet control. Spillway Tabulates a stage -discharge relationship for a spillway. Reservoir Routing Estimation: Routing Uses modified Puls method to perform reservoir routing of storm hydrographs through a detention basin. Design Info Provides runoff coefficient vs. watershed imperviousness relationships. Acknowledgements: Comments? Revisions? Spreadsheet Development Team: Dr. James C.Y. Guo, P.E. Professor, Department of Civil Engineering University of Colorado at Denver Ken MacKenzie, P.E. Urban Drainage and Flood Control District Direct all comments regarding this spreadsheet workbook to: UDFCD email Check for revised versions of this or any other workbook at: Downloads ud-detention v2.35.xls, INTRO 2/16/2024, 10:22 AM Runoff Coefficient vs. Watershed Imperviousness Based on Runoff Coefficient estimating equation published by Urbonas, et.al. (1990) & WEF (1998) Basic equation for NRCS Soil Types C & D: Ca) =KcO + (0.858*13 - 0.786'12 + 0.774*1+ 0.04) Basic equation for NRCS Soil Type A: C,4 = KA + (1.31'13 - 1.44*12 + 1.135*i - 0.12) in which use values for CA>0 0 in which: i = /a/100, imperviousness ratio la = watershed imperviousness in percent CA = RunoffCoefficient for NRCS Soil Type A K4 = Correction factor lhr C.4 when the storm return period is greater than 2 -years Ccjj = Runoff Coefficient for NRCS Soil Types C and D Ku) = Correction factor for Cu) when the storm return period is greater than 2 -years NRCS Soil Types_ Values of Correction Factors Kcv& KA Storm Return Period 2-yr 5-yr I 0-yr 25-yr 50-yr 100-yr C & D 0.00 i-0.IO*i+0.111 i-0.18*i+0.211 1-0.28*i+0.331 i-033*i+0.401 i-039*i+0.461 A 0.00 i-0.08*i+0.091 1-0.14*i+0.171 i-0.19*i+0.241 i-0.22*i+0.281 f-0.25*i+0.321 Table A Recommended Unit Flow Release Rate in cfs/acre of tributary catchment within UDFCD boundaries. Design Frequency NRCS Hydrologic Soil Group A B C&D 2 -year 0.02 0.03 0.04 5 -year 0.07 0.13 0.17 10 -year 0.13 0.23 0.30 25 -year 0.24 0.41 0.52 50 -year 0.33 0.56 0.68 100 -year 0.50 0.85 1.00 Imperv. Values of Runoff Coefficient Ccv Values of Runoff Coefficient CA Type C and D NRCS hydrologic Soil Groups - Type A NRCS hydrologic Soils Group Kano t 1) 2-yr 5-yr. 10-yr 25-yr 0.37 50-yr. 0.44 100-yr. 2-yr 5-yr 10-yr. 25-yr I 50-yr 100-yr. 0.00 0.04 0.15 0.25 0.50 -0.12 -0.03 0.05 0.12 0.16 0.20 0.05 0.08 0.18 0.21 0.24 0.28 0.39 0.46 0.52 -0.07 0.53 -0.02 0.54 0.02 0.02 0.10 0.16 0.20 0.24 0.10 0.11 0.15 0.14 0.30 0.32 0.41 0.43 0.48 0.49 0.06 0.10 0.14 0.17 0.20 0.23 0.24 0.27 0.28 0.30 0.20 0.17 0.26 0.34 0.44 0.50 0.52 0.55 0.06 0.13 0.20 0.26 0.30 0.32 0.33 0.25 0.20 0.28 0.36 0.46 0.56 0.09 0.16 0.23 0.29 0.35 0.30 0.22 0.30 0.38 0.47 0.53 0.57 0.13 0.19 0.25 0.31 0.34 0.37 0.35 0.25 0.33 0.40 0.42 0.48 0.54 0.57 0.16 0.22 0.28 0.33 0.36 0.39 0.41 0.40 0.28 0.45 0.31 0.50 0.34 0.55 0.37 0.35 0.37 0.44 0.50 0.51 0.55 0.56 0.57 0.58 0.19 0.59 0.22 0.25 0.27 0.30 0.33 0.35 0.37 0.38 0.40 0.42 0.43 0.40 0.46 0.53 0.60 0.25 0.62 0.29 0.30 0.35 0.40 0.42 0.45 0.47 0.43 0.48 0.55 0.59 0.33 0.38 0.45 0.60 0.41 0.46 0.51 0.54 0.57 0.61 0.63 0.33 0.37 0.41 0.41 0.45 0.47 0.51 0.50 0.65 0.45 0.49 0.59 0.63 0.65 0.37 0.45 0.49 0.53 0.70 0.49 0.53 0.57 0.62 0.66 0.68 0.42 0.45 0.49 0.53 0.54 0.56 0.75 0.54 0.58 0.62 0.66 0.69 0.71 0.47 0.74 0.54 0.50 0.54 0.57 0.59 0.64 0.61 0.80 0.60 0.63 0.66 0.70 0.73 0.56 0.60 0.63 0.66 0.85 0.66 0.68 0.71 0.75 0.78 0.79 0.61 0.63 0.71 0.66 0.69 0.70 0.77 0.72 0.90 0.73 0.95 0.80 0.75 0.82 0.77 0.84 0.92 0.80 0.87 0.83 0.89 0.83 0.69 0.89 0.78 0.80 0.73 0.82 0.92 0.76 0.84 0.94 0.85 0.79 0.86 1.00 0.89 0.90 0.94 0.96 0.96 0.89 0.90 0.95 0.96 Runoff Coefficient Notes: 1.00 0.90 0.80 0.70 0.60 0.50 0.40 0.30 0.20 0.10 0.00 0.0 For Type B Soils, use the average of coefficients Cc9 and C i . When the Runoff Coefficient in above table is < 0, use 0. When compositing the RunolTCoefficient for different soil types, use the table values above regardless if they arc < 0. Runoff Coefficient vs. Imperviousness NRCS Hydrologic Soils C & D C-•�,._- 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 Watershed Impervious Ratio A, IOC`-yr -e- 25 -sr - 10-yr —�-5ar 2 , r Runoff Coefficient 1.00 0.90 0.80 0.70 0.60 0.50 0.40 0.30 0.20 0.10 0.00 Runoff Coefficient vs. Imperviousness NRCS Hydrologic Soil A 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 0.0 Watershed Impervious Ratio Ion Coe cianI ks 1.4 12 1.0 0.6 0M 0.4 0. 0 t — I I 1 r t — r p — ,l _ — Bend No at Manhole g'^�'ial Sneping Deflector — _,,, Curved -- `— I — c '-' Bend at Nta4ioie. rived rx De — lector r — _ coved swrer rip a r 1 1 _ 2 ^Server _ rAa6 J 1.0 20 40 CO Deflection ley. Degrees Values nl' Kh 80 90 100 ud-detention_v2.35.xls, Design Info 2/16/2024, 10:25 AM DETENTION VOLUME BY THE MODIFIED FAA METHOD Project: Basin ID: (For catchments less than 160 acres only. For larger catchments, use hydrograph routing method) (NOTE: for catchments larger than 90 acres, CUHP hydrograph and routing are recommended) Project: Basin ID: Determination of MINOR Detention Volume Using Modified FAA Method Determination of MAJOR Detention Volume Using Modified FAA Method Design Information (Input): Design Information (Input): Catchment Drainage Imperviousness la = 35.00 percent Catchment Drainage Imperviousness la = 35.00 percent Catchment Drainage Area A = 12.530 acres Catchment Drainage Area A = 12.530 acres Predevelopment NRCS Soil Group Type = A A, B, C, or D Predevelopment NRCS Soil Group Type = A A, B, C, or D Return Period for Detention Control T = 5 years (2, 5, 10, 25, 50, or 100) Return Period for Detention Control T = 100 years (2, 5, 10, 25, 50, or 100) Time of Concentration of Watershed Tc = 16 minutes Time of Concentration of Watershed Tc = 16 minutes Allowable Unit Release Rate q = 0.13 cfs/acre Allowable Unit Release Rate q = 0.50 cfs/acre One -hour Precipitation P1 = 1.40 inches One -hour Precipitation P1 = 2.66 inches Design Rainfall IDF Formula i = CI* Pi/(C2+Tc)^C3 Design Rainfall IDF Formula i = C,* P1/(C2+Tj^C3 Coefficient One C1 = 28.50 Coefficient One C, = 28.50 Coefficient Two C2 = 10 Coefficient Two C2 = 10 Coefficient Three C3 = 0.789 Coefficient Three C3 = 0.789 Determination of Average Outflow from the Basin (Calculated): Determination of Average Outflow from the Basin (Calculated): Runoff Coefficient C = 0.22 Runoff Coefficient C = 0.39 Inflow Peak Runoff Qp-in = 8.41 cfs Inflow Peak Runoff Qp-in = 28.34 cfs Allowable Peak Outflow Rate Qp-out = 1.63 cfs Allowable Peak Outflow Rate Qp-out = 6.27 cfs Mod. FAA Minor Storage Volume = 10,516 cubic feet Mod. FAA Major Storage Volume = 33,017 cubic feet Mod. FAA Minor Storage Volume = 0.241 acre -ft Mod. FAA Major Storage Volume = 0.758 acre -ft 5 <- Enter Rainfall Duration Incremental Increase Value Here (e.g. 5 for 5 -Minutes) Rainfall Duration minutes (input) Rainfall Intensity inches / hr (output) Inflow Volume acre-feet (output) Adjustment Factor "rn" (output) Average Outflow cfs (output) Outflow Volume acre-feet (output) Storage Volume acre-feet (output) Rainfall Duration minutes (input) Rainfall Intensity inches / hr (output) Inflow Volume acre-feet (output) Adjustment Factor "m" (output) Average Outflow cfs (output) Outflow Volume acre-feet (output) Storage Volume acre-feet (output) 0 0.00 0.000 0.00 0.00 0.000 0.000 0 0.00 0.000 0.00 0.00 0.000 0.000 5 4.71 0.089 1.00 1.63 0.011 0.078 5 8.95 0.301 1.00 6.27 0.043 0.258 10 3/5 0.143 1.00 1.63 0.022 0.120 10 7.13 0.480 1.00 6.27 0.086 0.394 15 3.15 0.179 1.00 1.63 0.034 0.146 15 5.98 0.604 1.00 6.27 0.129 0.474 20 2.73 0.207 0.90 1.47 0.040 0.167 20 5.18 0.697 0.90 5.64 0.155 0.542 25 2.41 0.229 0.82 1.34 0.046 0.183 25 4.59 0.772 0.82 5.14 0.177 0.595 30 2.17 0.247 0.77 1.25 0.052 0.196 30 4.13 0.833 0.77 4.80 0.198 0.635 35 1.98 0.263 0.73 1.19 0.057 0.206 35 3.76 0.886 0.73 4.56 0.220 0.666 40 1.82 0.277 0.70 1.14 0.063 0.214 40 3.46 0.932 0.70 4.39 0.242 0.690 45 1.69 0.289 0.68 1.10 0.068 0.220 45 3.21 0.972 0.68 4.25 0.263 0.709 50 1.58 0.300 0.66 1.08 0.074 0.225 50 3.00 1.009 0.66 4.13 0.285 0.724 55 1.48 0.309 0.65 1.05 0.080 0.230 55 2.81 1.042 0.65 4.04 0.306 0.735 60 1.40 0.318 0.63 1.03 0.085 0.233 60 2.65 1.072 0.63 3.97 0.328 0.744 65 1.32 0.327 0.62 1.01 0.091 0.236 65 2.51 1.100 0.62 3.90 0.349 0.750 70 1.26 0.334 0.61 1.00 0.096 0.238 70 2.39 1.126 0.61 3.85 0.371 0.754 75 1.20 0.341 0.61 0.99 0.102 0.239 75 2.28 1.150 0.61 3.80 0.393 0.757 80 1.15 0.348 0.60 0.98 0.108 0.240 80 2.18 1.172 0.60 3.76 0.414 0.758 85 1.10 0.354 0.59 0.97 0.113 0.241 85 2.09 1.193 0.59 3/2 0.436 0.758 90 1.05 0.360 0.59 0.96 0.119 0.241 90 2.00 1.214 0.59 3.69 0.457 0.756 95 1.01 0.366 0.58 0.95 0.125 0.241 95 1.93 1.233 0.58 3.66 0.479 0.754 100 0.98 0.371 0.58 0.94 0.130 0.241 100 1.86 1.251 0.58 3.63 0.501 0.750 105 0.94 0.376 0.58 0.94 0.136 0.241 105 1.79 1.268 0.58 3.61 0.522 0.746 110 0.91 0.381 0.57 0.93 0.141 0.240 110 1.73 1.284 0.57 3.59 0.544 0.741 115 0.88 0.386 0.57 0.93 0.147 0.239 115 1.68 1.300 0.57 3.57 0.565 0.735 120 0.86 0.391 0.57 0.92 0.153 0.238 120 1.63 1.315 0.57 3.55 0.587 0.729 125 0.83 0.395 0.56 0.92 0.158 0.237 125 1.58 1.330 0.56 3.53 0.608 0.722 130 0.81 0.399 0.56 0.91 0.164 0.235 130 1.54 1.344 0.56 3.52 0.630 0.714 135 0.79 0.403 0.56 0.91 0.169 0.234 135 1.49 1.358 0.56 3.50 0.652 0.706 140 0.77 0.407 0.56 0.91 0.175 0.232 140 1.45 1.371 0.56 3.49 0.673 0.698 145 0.75 0.411 0.56 0.90 0.181 0.230 145 1.42 1.384 0.56 3.48 0.695 0.689 150 0.73 0.414 0.55 0.90 0.186 0.228 150 1.38 1.396 0.55 3.47 0.716 0.680 155 0.71 0.418 0.55 0.90 0.192 0.226 155 1.35 1.408 0.55 3.46 0.738 0.670 160 0.69 0.421 0.55 0.90 0.197 0.224 160 1.32 1.419 0.55 3.45 0.759 0.660 165 0.68 0.425 0.55 0.89 0.203 0.222 165 1.29 1.431 0.55 3.44 0.781 0.650 170 0.66 0.428 0.55 0.89 0.209 0.219 170 1.26 1.442 0.55 3.43 0.803 0.639 175 0.65 0.431 0.55 0.89 0.214 0.217 175 1.23 1.452 0.55 3.42 0.824 0.628 180 0.64 0.434 0.54 0.89 0.220 0.214 180 1.21 1.463 0.54 3.41 0.846 0.617 185 0.62 0.437 0.54 0.88 0.225 0.212 185 1.18 1.473 0.54 3.40 0.867 0.606 190 0.61 0.440 0.54 0.88 0.231 0.209 190 1.16 1.483 0.54 3.40 0.889 0.594 195 0.60 0.443 0.54 0.88 0.237 0.206 195 1.14 1.492 0.54 3.39 0.910 0.582 200 0.59 0.446 0.54 0.88 0.242 0.204 200 1.12 1.502 0.54 3.38 0.932 0.570 205 0.58 0.449 0.54 0.88 0.248 0.201 205 1.10 1.511 0.54 3.38 0.954 0.557 210 0.57 0.451 0.54 0.88 0.254 0.198 210 1.08 1.520 0.54 3.37 0.975 0.545 215 0.56 0.454 0.54 0.88 0.259 0.195 215 1.06 1.529 0.54 3.37 0.997 0.532 220 0.55 0.456 0.54 0.87 0.265 0.192 220 1.04 1.538 0.54 3.36 1.018 0.519 225 0.54 0.459 0.54 0.87 0.270 0.189 225 1.02 1.546 0.54 3.36 1.040 0.506 230 0.53 0.461 0.53 0.87 0.276 0.186 230 1.00 1.554 0.53 3.35 1.061 0.493 235 0.52 0.464 0.53 0.87 0.282 0.182 235 0.99 1.563 0.53 3.35 1.083 0.480 240 0.51 0.466 0.53 0.87 0.287 0.179 240 0.97 1.571 0.53 3.34 1.105 0.466 245 0.50 0.469 0.53 0.87 0.293 0.176 245 0.96 1.578 0.53 3.34 1.126 0.452 250 0.50 0.471 0.53 0.87 0.298 0.173 250 0.94 1.586 0.53 3.33 1.148 0.438 255 0.49 0.473 0.53 0.87 0.304 0.169 255 0.93 1.594 0.53 3.33 1.169 0.424 260 0.48 0.475 0.53 0.86 0.310 0.166 260 0.91 1.601 0.53 3.33 1.191 0.410 265 0.47 0.478 0.53 0.86 0.315 0.162 265 0.90 1.608 0.53 3.32 1.212 0.396 270 0.47 0.480 0.53 0.86 0.321 0.159 270 0.89 1.616 0.53 3.32 1.234 0.382 275 0.46 0.482 0.53 0.86 0.326 0.155 275 0.88 1.623 0.53 3.31 1.256 0.367 280 0.46 0.484 0.53 0.86 0.332 0.152 280 0.86 1.630 0.53 3.31 1.277 0.353 285 0.45 0.486 0.53 0.86 0.338 0.148 285 0.85 1.637 0.53 3.31 1.299 0.338 290 0.44 0.488 0.53 0.86 0.343 0.145 290 0.84 1.643 0.53 3.31 1.320 0.323 295 0.44 0.490 0.53 0.86 0.349 0.141 295 0.83 1.650 0.53 3.30 1.342 0.308 300 0.43 0.492 0.53 0.86 0.354 0.137 300 0.82 1.657 0.53 3.30 1.363 0.293 Mod. FAA Minor Storage Volume (cubic ft.) = 10,516 Mod. FAA Major Storage Volume (cubic ft.) = Mod. FAA Minor Storage Volume (acre -ft.) = 0.2414 Mod. FAA Major Storage Volume (acre -ft.) = UDFCD DETENTION BASIN VOLUME ESTIMATIN WORKBOOK Version 2.35, Released January 2015 Volume (acre-feet) 1.8 1.6 1.4 1.2 0.8 0.6 0.4 0.2 33,017 0.7580 ud-detention_v2.35.xls, Modified FAA 2/16/2024, 10:07 AM DETENTION VOLUME BY THE MODIFIED FAA METHOD Inflow and Outflow Volumes vs. Rainfall Duration ••••••••••••• H }OOi �nOOOp 0 OGl^ -� ��,OOO CJOUC}Ors 50 100 150 200 Duration (Minutes) 250 300 - Minor Storm Inflow Volume — s—Major Storm Inflow Volume —ry— Minor Storm Outflow Volume —a— Major Storm Outflow Volume o Minor Storm Storage Volume • Major Storm Storage Volume 350 UDFCD DETENTION BASIN VOLUME ESTIMATING WORKBOOK Version 2.35, Released January 2015 ud-detention_v2.35.xls, Modified FAA 2/16/2024, 10:07 AM MOUNTAIN PEAK POWER STATION WELD COUNTY, COLORADO Calculate Design Flows - 100 -Year Based on Rational Method Rational Equation: Q=ciA The Rational equation requires the following units: Q = Peak discharge, cfs c = Rational method runoff coefficient, Modified based on Weld County coefficients i = Rainfall intensity, inch/hour A = Drainage area, acre Locations Q C I A tc ti tt flowrate runoff coefficient rainfall intensity 100-Yr area area impervious area percent impervious time of concentration initial time flow channelized travel time (cfs) (in/hr) (acre) (sq ft) (sq ft) (%) (min) (min) 1 16.19 0.34 5.47 8.73 380283 84936 22.33% 21.86 5.36 16.50 1 5.13 0.41 5.47 2.30 100364 37088 39.53% 21.86 5.36 16.50 1+2 21.36 0.35 5.47 11.03 480471 122024 26.05% 21.86 5.36 16.50 3 3.21 0.34 6.23 1.50 65340 15237 23.32% 16.50 0.00 16.50 4 10.49 0.22 8.04 5.93 258389 5175 2.00% 9.80 9.80 0.00 Location 1: Location 2: Location 3: Location 4: North of Access Road West of Access Road, flow from the west Tributary to Pond Existing Substation Lt 60K JSo 700 60 • 10V1005 16.499 1 i 0.395(1.1 — C,}. Li X0.33 O 0.395(1.1 - 0.56)1400 0.5033 = 5.362 t 0.395(1.1 - COIL, 5%0 33 O 0.395(1.1 - O,S6)-030 0.20.33 = 9.802 Construction Drawings • Site Plan • 1041 USR Map • Grading Plan CADD D3-RSIda`U C 4, cm E-�r o N ---N---._ 1062' 1062' F -...Y GI,_ 111 1 CCIP �j e in V V n G1 , co , cm 496.5' � \--- r— C— V 0 Z _, i l Y' „,, ,, , f 7 �_SJ, 01 C'% m o u n , _ i 1 (I -Fr _ . 41'x" tee' E Kt 05GI\ ,.....445€2, 1954' � 40`_r3� \.\ \� � � 49 49 0' �+ AV 111 Co cn - It \ \ [y Ln 4 \ ,r r.� ii��v nn¢ni i f i S I r NJ r al o o ` \) Orlj 66 N. Lo 0up o eh E 4950' 4950' �--+� l 1> wr &3J 435^ 51 19x2' �� - m NO. REVISIONS DSGN CHKD APVD. DATE 1053' 4053' p 93 v Lc y 1 195F' `a1^�51F' 3 4953' _Lrom7 .,en - -N \it\ i 1------- f i r_____ si, I i gds U♦e 4Hg0, Stanley Consultants INC. s ,, 8000 South Chester Street, Suite 500, Centennial, Colorado 80112-3516 � www.stanleyconsultants.com r9g -s MOUNTAIN PEAK POWER, LLC Mkt I CY MOUNTAIN PEAK POWER STATION 4 / / WELD COUNTY, COLORADO -49601.s '"�� GRADING PLAN Q I DESIGNED M BOYAJIAN AT FULL •IZE DRAWN M ROYA.IIAN SCALE: 0 1 , 2 3 IN CHECKED NO. REV. APPROVED OVED % ' 0 1 2 3 4 5 1 7 8 Ltd cm DATE ` 1 2 3 4 5 A 7 R 9 10 03 STANL EY CONSULTANTS 11 E c Mountain Peak Power, LLC Mountain Peak Power Project Attachment 3111041 Submittal Application Attachment 31 Environmental Site Evaluation Mountain Peak Power Weld County 1041 Application Stanley Consultants MEMO Project name Project no. Client Prepared by Checked by Approved by Kindle Tesla Substation Environmental Site Evaluation 1940104362 Kindle Energy Mandi Miller Sara Copp Franz Tekla Taylor 1 Introduction Ramboll US Consulting was retained by Kindle Energy to perform an Environmental Site Evaluation for a proposed Kindle Energy (Kindle) electric generating unit (EGU) that will be co -located at the United Power Tesla Substation near Keenesburg, Weld County, Colorado. The Site is approximately 21 acres located off county road 55 and 20, Northwest of Keenesburg, Colorado (Figure 1). As part of the Environmental Site Evaluation, Ramboll conducted a desktop review using publicly available information to determine the potential presence of; federal and state -listed threatened and endangered species and their habitat, migratory birds/habitat, cultural and historical resources, sensitive receptors, floodplains, waters of the U.S. including wetlands, and federally or locally protected areas. A site visit was conducted on August 17, 2023, to confirm desktop findings and to determine if there was habitat or prairie dog colonies at the site that may require relocation. 2 Study Area Description: The site is a relatively flat grassland property with three old, dilapidated steel framed barns and a mobile home on the property with a dirt parking area and sub -station owned by United Power. There are also 4-6 cottonwoods and juniper trees on -site next to the barns (Figure 2). Google Earth imagery depicts the barns and mobile home to have been on the site since at least 1999 and the land seems to have been used for agricultural purposes in the past. A review of Weld County Assessor records indicates that the two larger barns were constructed in 1967 and 1974. The deed to the property was transferred to United Power on March 1, 2018. ENVIRONMENT & HEALTH Date August 23, 2023 Ramboll 1999 Broadway Suite 2225 Denver, CO 80202 USA T+1 303 382 5460 F+1 303 991 9834 https://ramboll.com 1/8 Doc ID / Version Confidential 3 Preliminary Data Gathering and Analysis Prior to performing the site visit, several resources were reviewed to assist with identifying Waters of the United States, Threatened and Endangered Species, and Cultural and Historical Properties at the Site. 3.1 Wetland and Waters of the United States Desktop Assessment Ramboll reviewed the United States Fish and Wildlife Service (USFWS) National Wetland Inventory (NWI) maps, the United States Geological Survey (USGS) 2022 Greeley, Colorado 7.5 -Minute topographic map series, the United States Department of Agriculture (USDA) Natural Resources Conservation Service (NRCS) Web Soil Survey (WSS), and aerial imagery, to identify potential wetlands and waters of the US within the Site. The NWI mapper tool indicated no evidence of wetland or water features on the Site (Figure 3). In addition, the topography data shows a 10-15 ft elevation change within the site boundary (USGS 2022) and no evidence of wetland or water features located on or near the Site. The NRCS Web Soil Survey indicates two different soil categories, Olney loamy sand (1-3% slopes) and Osgood sand (0-3% slopes). Neither of these are listed as hydric soil types (i.e., soils that can support wetlands) (NRCS 2023). Hydric soils are generally mapped within the same swaths of land indicated as wetland areas on the NWI map and are one of three indicators that must be present for an area to be identified as a wetland. 3.1.1 Federal -Listed Threatened and Endangered (T&E) Species Review Ramboll referenced the USFWS IPaC database on August 8, 2023, to evaluate the potential presence and habitat of federally listed species within the site boundary. According to the IPaC database, nine federally threatened, endangered, or candidate species could occur on Site. The species are presented in the table below. According to the database, no critical habitats are identified on or near the Site (USFWS 2023). Scientific Name I I Common Name Federal Habitat Description ii Haitat Present Findings Status Mammals Canis lupus Gray Wolf E Lone, may state activity management consider environmental be dispersing of includes present Colorado. this program, species review. throughout a gray If your predator in wolves please your the The not predator management programs. critical Site include project habitat does No on No impact Zapus hudsonius preblei Preble's Meadow Jumping Mouse T Well vegetation undisturbed communities -developed and adjacent (USFWS riparian relatively grassland 2018). None, vegetation observed near the no riparian on Site. was or No impact Birds Laterallus jamaicensis ssp. jamaicensis Eastern Rail Black T Wetland cover (USFWS marsh with 2020a). overhead None no were observed or near the wetlands Site. on No impact 2/8 Doc ID / Version Confidential Scientific Nam- Common Name Federal Status ilabitat Description.. m.abit. t P esent indings Charadrius melodus Piping Plover T If activities Platte, River Nebraska water project Basins, -related S. involves or Platte, may use then use. dewatering in the and species be affected N. Laramie in with The not water activities. critical Site involve project -related habitat does No on No impact Grus americana Whooping Crane E If activities Platte, River Nebraska water project Basins, -related S. involves or Platte, may use then use. dewatering in the and species be affected N. Laramie in with The not water activities. critical Site involve project -related habitat does No on No impact Fishes Scaphirhynchus a/bus Pallid Sturgeon E If activities Platte, River Nebraska water project Basins, -related S. involves or Platte, may use then use. dewatering in the and species be affected Laramie N. in with The not water activities involve project -related does No impact Insects Danaus p/exippus monarch butterfly C Breeding milkweed 2020b) requires host plant obligate (USFWS None, milkweed identified no was on Site. No impact Flowering Plants P/atanthera praec/ara Western Fringed Prairie Orchid T Sedge native meadows prairies and (USFWS wet 1996). None, wetlands prairies observed near the no or wet were on or Site. No impact Spiranthes diluvialis Ute Ladies'- tresses T Small, represented mesic, meadow with facultative classification sporadic temporarily vegetation in shallow wet by (USFWS microhabitat calcareous, falling or inundated obligate wetlands into 1992). the wet wet None, wetlands observed near critical Site the no habitat Site. were on or No on No impact T= Threatened, E= Endangered, C= Candidate 3.1.2 State -Listed T&E Species Review Ramboll referenced several resources to evaluate the documented and potential presence and habitat of state -listed species on and near the site. Colorado does not have species -specific geospatial information for state -listed species; however, a list of these species along with their preferred habitat type, range, and other details can be found on Colorado Parks and Wildlife website (CPW 2023). According to the range maps these species are not found in this area of the state, and they are unlikely to use such a disturbed habitat. Colorado Natural Heritage Program (CNHP) has statewide GIS layers illustrating Potential Conservation Areas, Networks of Conservation Areas, and Terrestrial Ecological System Patches. None of these areas are found within the Site (CNHP 2022 and 2011). 3/8 Doc ID / Version Confidential 3.2 Floodplains Ramboll reviewed FEMA Floodplains, and none were found within the site boundary (Figure 3). 3.3 Cultural and Historical Resources Ramboll conducted a review of the Weld County Assessor files to determine the age of the buildings located onsite. According to the property records, the two larger barn structures were constructed in 1967 and 1974. These structures are considered "old" under the State Historic Preservation Act (SHPO) as they are not significant or no historical significance has been identified. A review of the Weld County historic property records indicated that they have not been designated as "significant" nor have either of the buildings been designated as a local landmark and/or listed on the National or State Register. 4 Field Assessment A field assessment was performed on August 17, 2023, by a trained Ecologist. A meander survey was conducted during the site visit to characterize existing site conditions, identify the presence of federal and state -listed T&E species, if any, and identify presence of wetlands conditions such as hydric soils, hydrology, or hydrophytic vegetation. Ramboll found no evidence of wetlands or waters of the United States on site including no wetland plants or signs of any hydrologic features. Most of the site was composed of a mix of grasses, tall wheatgrass (Thinopyrum ponticum, FACU), intermediate wheatgrass (Thinopyrum intermedium, FACU), cheatgrass (Bromus tectorum, FACU), and there were a few patches of forbs, carelessweed (Cyclachaena xanthiifolia, FAC) and sunflowers (Helianthus annuus, FACU). There was a small man- made depression on the northeast area of the site but there was no change in the plant community. In addition, Ramboll found no evidence of any listed state or federal species or their habitats; it was a highly disturbed grassland with few resources. No burrowing animals were seen on -site. There was no evidence of any active prairie dog burrows or holes. The only burrows observed were one to two-inch diameter holes under the grass layer and had the appearance of field mice or vole burrows. A barred owl (not a listed species) was seen just outside the eastern site boundary perching on a powerline, most likely hunting for voles. 5 Findings and Conclusion It is our opinion that the Site does not support federal or state T&E species or their associated habitat. There was no evidence of Waters of the United States or of wetland (hydrophytic) vegetation, wetland (hydric) soils, or hydrology on site. Additionally, there was no evidence of prairie dog colonies onsite. 6 References Colorado Natural Heritage Program (CNHP) 2022. Statewide Potential Conservation Areas and Statewide Networks of Conservation Areas. https://cnhp.colostate.edu/maps/cnhp-spatial-layers/ Colorado Natural Heritage Program (CNHP) 2011. Terrestrial Ecological System Patches. https://cnhp.colostate.edu/maps/cnhp-spatial-layers/ 4/8 Doc ID / Version Confidential Colorado Parks and Wildlife (CPW). 2023. Threatened and Endangered List. https://cpw.state.co. us/learn/Pages/SOC-ThreatenedEnciangeredList.aspx U .S. Geological Survey. 2022. National Geospatial Program, 20220429, USGS NED 1/3 arc -second Contours for Greeley E, Colorado 20220429 1 X 1 degree Shapefile: U.S. Geological Survey U nited States Fish and Wildlife Service (USFWS). 2023. National Wetlands Inventory. Wetlands Mapper. http: //www.fws.gov/wetlands/Data/Mapper.html. U SFWS 2022. Information for Planning and Consultation (IPaC) Report for 'KE' Project. Colorado Ecological Services Field Office. August 8. https://ipac.ecosphere.fws.aov/ U SFWS. 2020a. Recovery Outline for the Eastern black rail (Lateral/us jamaicensis jamaicensis). South Atlantic -Gulf & Mississippi -Basin (Regions 2 & 4). 10 pages. U SFWS. 2020b. Monarch (Danaus plexippus) Species Status Assessment Report. V2.1 96 pp + appendices. U SFWS. 2018. Preble's Meadow Jumping Mouse Recovery Plan, Colorado. Region 6, Lakewood, Colorado. 148 pages. U SFWS. 1996. Platanthera praeclara (western prairie fringed orchid) recovery plan. U.S. Fish and Wildlife Service, Ft. Snelling, Minnesota. vi + 101 pp Natural Resources Conservation Service (NRCS). 2023. United States Department of Agriculture. Web Soil Survey. http://websoilsurvey.sc.egov.usda.gov/. Federal Emergency Management Agency (FEMA) Flood Rate Insurance. 2023. https://msc.fema.gov/portal/home. 7 Appendices • Appendix A: Figures • Appendix B: Photolog • Appendix C: Threatened and Endangered Species Agency Inquiries 5/8 Doc ID / Version Confidential Figures 6/8 Doc ID / Version Confidential Ireland ReServoir Service Layer Cr i6agery: Earthsta Hybq�i;;�e,erence Layer: Esri, HERE, Garm:, i J 111 !!!!! :!.apire!sH;!e!e!yer:Esri::mrnunftyMapsco::butofsutors, ® Open RE, Germin, Safeeraph, GeoTechnologies, Inc, METI/NASA, USGS, EPA, NPS, US Census Bu World Imagery: Maxar, Microsoft C ri a t O Q w w C z Iu C O) C w C Y >. p C C w Ti C Y , 4) C w C UN U L a Ct c5 PROJECT: 169000XXXX I DATED: 8/14/2023 I DESIGNER: ALMILLER Service Layer Credits: Hybrid Reference Layer Esri , Garrrsin, SafeGraph, GeoTechnologies, Inc, METI NASA, USGS, EPA, NPS, US Census Bureau, USDA Tesla Substation Boundary NWI Wetlands Riverine FEMA Floodplain 1% Annual Chance Flood Hazard l National Register of Historic Places Building Structure District Site Object 0 500 1,000 I Feet NATIONAL WETLANDS INVENTORY (NWI), FEDERAL EMERGENCY MANAGEMENT AGENCY (FEMA) FLOODPLAIN AND NATIONAL REGISTER OF HISTORIC PLACES Kindle Energy Weld County, Colorado FIGURE 3 RAMBOLL US CONSULTING, INC. A RAMBOLL COMPANY Photolog 7/8 Doc ID / Version Confidential 410'108°48.r N1:04;133°00 .8 Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 f T L`.6rI. 8/1 7/23 ICt9 PM Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 eG Ftakgn f ,≥a2:O1PM,mac 8**18_5144104''32151.614/ rtr 1 'c 32' 51.6 Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 Photographic Log Weld County, Colorado August 2023 Threatened and Endangered Species Agency Inquiries 8/8 Doc ID / Version Confidential United States Department of the Interior FISH AND WILDLIFE SERVICE Colorado Ecological Services Field Office Denver Federal Center P.O. Box 25486 Denver, CO 80225-0486 Phone: (303) 236-4773 Fax: (303) 236-4005 In Reply Refer To: Project Code: 2023-0114086 Project Name: KE Site August 08, 2023 Subject: List of threatened and endangered species that may occur in your proposed project location or may be affected by your proposed project To Whom It May Concern: The enclosed species list identifies threatened, endangered, proposed and candidate species, as well as proposed and final designated critical habitat, that may occur within the boundary of your proposed project and/or may be affected by your proposed project. The species list fulfills the requirements of the U.S. Fish and Wildlife Service (Service) under section 7(c) of the Endangered Species Act (Act) of 1973, as amended (16 U.S.C. 1531 et seq.). New information based on updated surveys, changes in the abundance and distribution of species, changed habitat conditions, or other factors could change this list. Please feel free to contact us if you need more current information or assistance regarding the potential impacts to federally proposed, listed, and candidate species and federally designated and proposed critical habitat. Please note that under 50 CFR 402.12(e) of the regulations implementing section 7 of the Act, the accuracy of this species list should be verified after 90 days. This verification can be completed formally or informally as desired. The Service recommends that verification be completed by visiting the ECOS-IPaC website at regular intervals during project planning and implementation for updates to species lists and information. An updated list may be requested through the ECOS-IPaC system by completing the same process used to receive the enclosed list. The purpose of the Act is to provide a means whereby threatened and endangered species and the ecosystems upon which they depend may be conserved. Under sections 7(a)(1) and 7(a)(2) of the Act and its implementing regulations (50 CFR 402 et seq.), Federal agencies are required to utilize their authorities to carry out programs for the conservation of threatened and endangered species and to determine whether projects may affect threatened and endangered species and/or designated critical habitat. A Biological Assessment is required for construction projects (or other undertakings having similar physical impacts) that are major Federal actions significantly affecting the quality of the human environment as defined in the National Environmental Policy Act (42 U.S.C. 4332(2) 08/08/2023 2 (c)). For projects other than major construction activities, the Service suggests that a biological evaluation similar to a Biological Assessment be prepared to determine whether the project may affect listed or proposed species and/or designated or proposed critical habitat. Recommended contents of a Biological Assessment are described at 50 CFR 402.12. If a Federal agency determines, based on the Biological Assessment or biological evaluation, that listed species and/or designated critical habitat may be affected by the proposed project, the agency is required to consult with the Service pursuant to 50 CFR 402. In addition, the Service recommends that candidate species, proposed species and proposed critical habitat be addressed within the consultation. More information on the regulations and procedures for section 7 consultation, including the role of permit or license applicants, can be found in the "Endangered Species Consultation Handbook" at: http://www.fws.gov/endangered/esa-library/pdf/TOC-GLOS.PDF Migratory Birds: In addition to responsibilities to protect threatened and endangered species under the Endangered Species Act (ESA), there are additional responsibilities under the Migratory Bird Treaty Act (MBTA) and the Bald and Golden Eagle Protection Act (BGEPA) to protect native birds from project -related impacts. Any activity, intentional or unintentional, resulting in take of migratory birds, including eagles, is prohibited unless otherwise permitted by the U.S. Fish and Wildlife Service (50 C.F.R. Sec. 10.12 and 16 U.S.C. Sec. 668(a)). For more information regarding these Acts see https://www.fws.gov/birds/policies-and-regulations.php. The MBTA has no provision for allowing take of migratory birds that may be unintentionally killed or injured by otherwise lawful activities. It is the responsibility of the project proponent to comply with these Acts by identifying potential impacts to migratory birds and eagles within applicable NEPA documents (when there is a federal nexus) or a Bird/Eagle Conservation Plan (when there is no federal nexus). Proponents should implement conservation measures to avoid or minimize the production of project -related stressors or minimize the exposure of birds and their resources to the project -related stressors. For more information on avian stressors and recommended conservation measures see https://www.fws.gov/birds/bird-enthusiasts/threats-to- birds.php. In addition to MBTA and BGEPA, Executive Order 13186: Responsibilities of Federal Agencies to Protect Migratory Birds, obligates all Federal agencies that engage in or authorize activities that might affect migratory birds, to minimize those effects and encourage conservation measures that will improve bird populations. Executive Order 13186 provides for the protection of both migratory birds and migratory bird habitat. For information regarding the implementation of Executive Order 13186, please visit https://www.fws.gov/birds/policies-and-regulations/ executive-orders/e0-13186.php. php. We appreciate your concern for threatened and endangered species. The Service encourages Federal agencies to include conservation of threatened and endangered species into their project planning to further the purposes of the Act. Please include the Consultation Code in the header of this letter with any request for consultation or correspondence about your project that you submit to our office. 08/08/2023 3 Attachment(s): ■ Official Species List OFFICIAL SPECIES LIST This list is provided pursuant to Section 7 of the Endangered Species Act, and fulfills the requirement for Federal agencies to "request of the Secretary of the Interior information whether any species which is listed or proposed to be listed may be present in the area of a proposed action". This species list is provided by: Colorado Ecological Services Field Office Denver Federal Center P.O. Box 25486 Denver, CO 80225-0486 (303) 236-4773 08/08/2023 4 PROJECT SUMMARY Project Code: 2023-0114086 Project Name: KE Site Project Type: Acquisition of Lands Project Description: Natural Resource Assessment Project Location: The approximate location of the project can be viewed in Google Maps: https:// www.google.com/maps/@40.14686505,-104.54904065659909,14z Counties: Weld County, Colorado l u M I 08/08/2023 5 ENDANGERED SPECIES ACT SPECIES There is a total of 9 threatened, endangered, or candidate species on this species list. Species on this list should be considered in an effects analysis for your project and could include species that exist in another geographic area. For example, certain fish may appear on the species list because a project could affect downstream species. Note that 3 of these species should be considered only under certain conditions. IPaC does not display listed species or critical habitats under the sole jurisdiction of NOAA Fisheriesl, as USFWS does not have the authority to speak on behalf of NOAA and the Department of Commerce. See the "Critical habitats" section below for those critical habitats that lie wholly or partially within your project area under this office's jurisdiction. Please contact the designated FWS office if you have questions. 1. NOAA Fisheries, also known as the National Marine Fisheries Service (NMFS), is an office of the National Oceanic and Atmospheric Administration within the Department of Commerce. MAMMALS NAME Gray Wolf Canis lupus Population: U.S.A.: All of AL, AR, CA, CO, CT, DE, FL, GA, IA, IN, IL, KS, KY, LA, MA, MD, ME, MI, MO, MS, NC, ND, NE, NH, NJ, NV, NY, OH, OK, PA, RI, SC, SD, TN, TX, VA, VT, WI, and WV; and portions of AZ, NM, OR, UT, and WA. Mexico. There is final critical habitat for this species. This species only needs to be considered under the following conditions: ■ Lone, dispersing gray wolves may be present throughout the state of Colorado. If your activity includes a predator management program, please consider this species in your environmental review. Species profile: https://ecos.fws.gov/ecp/species/4488 Preble's Meadow Jumping Mouse Zapus hudsonius preblei There is final critical habitat for this species. Your location does not overlap the critical habitat. Species profile: https://ecos.fws.gov/ecp/species/4090 General project design guidelines: https://ipac.ecosphere.fws.gov/proj ect/DHSOYWCMW5BN3KQYKYM3MMI4IE/ documents/generated/6861.pdf STATUS Endangered Threatened 08/08/2023 6 BIRDS NAME Eastern Black Rail Laterallus jamaicensis ssp. jamaicensis No critical habitat has been designated for this species. Species profile: https://ecos.fws.gov/ecp/species/10477 Piping Plover Charadrius melodus Population: [Atlantic Coast and Northern Great Plains populations] - Wherever found, except those areas where listed as endangered. There is final critical habitat for this species. Your location does not overlap the critical habitat. This species only needs to be considered under the following conditions: ■ Project includes water -related activities and/or use in the N. Platte, S. Platte, and Laramie River Basins which may affect listed species in Nebraska. Species profile: https://ecos.fws.gov/ecp/species/6039 Whooping Crane Grus americana Population: Wherever found, except where listed as an experimental population There is final critical habitat for this species. Your location does not overlap the critical habitat. Species profile: hops://ecos.fws.gov/ecp/species/758 FISHES NAME STATUS Threatened Threatened Pallid Sturgeon Scaphirhynchus albus No critical habitat has been designated for this species. This species only needs to be considered under the following conditions: • Project includes water -related activities and/or use in the N. Platte, S. Platte, and Laramie River Basins which may affect listed species in Nebraska. Species profile: https://ecos.fws.gov/ecp/species/7162 INSECTS NAME Endangered STATUS Endangered Monarch Butterfly Danaus plexippus No critical habitat has been designated for this species. Species profile: https://ecos.fws.gov/ecp/species/9743 FLOWERING PLANTS NAME Ute Ladies' -tresses Spiranthes diluvialis No critical habitat has been designated for this species. Species profile: https://ecos.fws.gov/ecp/species/2159 Western Prairie Fringed Orchid Platanthera praeclara No critical habitat has been designated for this species. Species profile: https://ecos.fws.gov/ecp/species/1669 STATUS Candidate STATUS Threatened Threatened 08/08/2023 7 CRITICAL HABITATS THERE ARE NO CRITICAL HABITATS WITHIN YOUR PROJECT AREA UNDER THIS OFFICE'S JURISDICTION. YOU ARE STILL REQUIRED TO DETERMINE IF YOUR PROJECT(S) MAY HAVE EFFECTS ON ALL ABOVE LISTED SPECIES. 08/08/2023 8 IPAC USER CONTACT INFORMATION Agency: Private Entity Name: Mandi Miller Address: 3208 Laramie St City: Cheyenne State: WY Zip: 82001 Email amandamil133@gmail.com Phone: 8287078055 Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 30 11041 Submittal Application Attachment 30 Environmental Survey Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Environmental Review11041 1041 Submittal Application Table of Contents Table of Contents i Figures i 1. Introduction ii 2. Project Area Description ii 3. Potential Impacts of the Proposed EGU ii 3.1 Physical Features ii 3.2 Federal -Listed Threatened and Endangered (T&E) Species Review iii 3.3 State -Listed T&E Species Review iii 3.4 Federally Designated Historic and Cultural Resources iii 3.5 Wetland and Waters of the United States iii 3.6 Floodplains iv 3.7 Groundwater iv 3.8 Natural Hazards iv 3.9 Recreational Areas iv 4 Conclusions v 5 References vi Figures Project Area Map Figure 1 e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Environmental Review11041 1041 Submittal Application 1. Introduction Mountain Peak Power, LLC ("Mountain Peak") has engaged Stanley Consultants to provide preliminary consulting services for the initial development of combustion turbine power plant facilities for United Power. The electric generating unit (EGU) will be co -located north of and adjacent to the existing United Power Tesla Substation near Keenesburg, Weld County, Colorado (Project Area). The Site is approximately 10.8 acres located off county road 55 and 20, Northwest of Keenesburg, Colorado (Figure 1). The purpose of this Desktop Environmental Review was to determine the potential presence of; federal and state -listed threatened and endangered species and their habitat, migratory birds/habitat, cultural and historical resources, sensitive receptors, floodplains, waters of the U.S. including wetlands, and federally or locally protected areas within the Project Area using publicly available information. 2. Project Area Description The Project Area is a relatively flat grassland property with three old, dilapidated steel framed barns and a mobile home on the property with a dirt parking area and sub -station owned by United Power. There are also 4-6 cottonwoods and juniper trees on -site next to the barns. Google Earth imagery depicts the barns and mobile home to have been on the Project Area since at least 1999 and the land seems to have been used for agricultural purposes in the past. A review of Weld County Assessor records indicates that the two larger barns were constructed in 1967 and 1974. The deed to the property was transferred to United Power on March 1, 2018. 3. Potential Impacts of the Proposed EGU The desktop analysis was conducted by gathering data from a variety of sources including: the NWI wetlands mapping; FEMA floodplain mapping; U.S. Fish and Wildlife Service's (USFWS) Information for Planning and Consultation (IpaC) and other publicly available documents on species reviews and rulings; USFWS critical habitat mapper; U.S. Department of Agriculture's (USDA) National Resources Conservation Service (NRCS) soil mapping; Colorado Geological Survey; National Register of Historic Places (NRHP) mapper; county records; Colorado's Decision Support System; and aerial photography. 3.1 Physical Features The Project Area is in the Great Plains (level I), South Central Semi -arid Prairies (Level II), High Plains (Level III), Rolling Sand Plains (Level IV) (Chapman et al., 2006). The Rolling Sand Plains ecoregion is characterized by grass-stablized sand plains, sand dunes, and sand sheets. The sandy soils of this ecoregion formed from eolian deposits and support sandsage prairie vegetation (Chapman et al., 2006). The topography within this ecoregion is flat to slightly irregular plains that support a high percentage of cropland (Chapman et al., 2006). Bedrock within the Project Area consists of sand deposits of more than one age (Holocene and late Pleistocene) separated by buried soils (USGS, 1979). Locally may include sheetwash deposits or reworked aeolian sand and marsh or pond deposits in low lying areas (USGS, 1979). Soils within the Project Area consist of Olney loamy sand, 1 to 3 percent slopes and Osgood sand, 0 to 3 percent slopes. Both soils are well drained, have no frequency of flooding or ponding, and are not considered hydric soils (NCRS, 2023). The biotic communities mapped within the Project Area consist of Sandsage natural vegetation types. These vegetation types include sand sagebrush, rabbitbrush, sand bluestem, prairie sandreed, and Indian ricegrass (Chapman et al., 2006; Figure 1). These plant species are not hydrophytic. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Environmental Review11041 1041 Submittal Application 3.2 Federal -Listed Threatened and Endangered (T&E) Species Review Special status species analyzed in this report include species listed by the USFWS under the Endangered Species Act (ESA) that have been identified by the USFWS Colorado Ecological Services Field Office through the IpaC online query. Based on the special status species lists generated from the above sources, a screening analysis was performed to evaluate the potential for special status species or designated or proposed critical habitat to occur within the Project Area. Results from the IpaC query identified a total of nine special status species for assessment. According to the IPaC database, none of the special status species were found to have potential to occur within the Project Area. There is no designated or proposed critical habitat within the Project Area. State -Listed T&E Species Review 3.3 State -Listed T&E Species Review Special status species analyzed in this report include species identified by Colorado Parks and Wildlife (CPW) through the Threatened and Endangered List on the CPW website. Colorado does not have species - specific geospatial information for state -listed species; however, a list of these species along with their preferred habitat type, range, and other details can be found on Colorado Parks and Wildlife website (CPW 2023). According to the range maps these species are not found in this area of the state, and they are unlikely to use disturbed habitat. Colorado Natural Heritage Program (CNHP) has statewide GIS layers illustrating Potential Conservation Areas, Networks of Conservation Areas, and Terrestrial Ecological System Patches. None of these areas are found within the Site (CNHP 2022 and 2011). According to the field assessment performed by Ramboll on August 17, 2023, no evidence of any listed state or federal species or their habitats were identified within the Project Area. No burrowing animals were seen on -site. There was no evidence of any active prairie dog burrows or holes. The only burrows observed were one to two-inch diameter holes under the grass layer and had the appearance of field mice or vole burrows. 3.4 Federally Designated Historic and Cultural Resources A cultural resources desktop review was conducted to identify documented historic sites within or near the Project Area. According to Weld County Assessor Office and the National Register of Historic Places (NRHP), previously recorded historic districts, sites, buildings, structures, and objects deemed worthy of preservation are not located within the project area or the 0.5 -mile records search area (Figure 1). No publicly available cultural surveys could be located and therefore undocumented historical resources may exist. According to property records, the two larger barn structures were constructed in 1967 and 1974. These structures are considered "old" under the State Historic Preservation Act (SHPO) as they are not significant or no historical significance has been identified. A review of the Weld County historic property records indicated that they have not been designated as "significant" nor have either of the buildings been designated as a local landmark and/or listed on the National or State Register. 3.5 Wetland and Waters of the United States The United States Fish and Wildlife Service (USFWS) National Wetland Inventory (NWI) maps, the United States Geological Survey (USGS) 2022 Greeley, Colorado 7.5 -Minute topographic map series, the United States Department of Agriculture (USDA) Natural Resources Conservation Service (MRCS) Web Soil Survey (WSS), and aerial imagery, were reviewed to identify potential wetlands and waters of the US within the Project Area. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Environmental Review11041 1041 Submittal Application According to NWI maps, there are no wetlands present within the Project Area (Figure 1). Based on aerial imagery and the desktop evaluation, there is no wetland hydrology the Project Area. As discussed above in Section 3.1, two different soil categories are present in the Project Area, Olney loamy sand 1-3% slopes and Osgood sand 0-3% slopes. Neither of these soils are listed as hydric soil types (i.e., soils that can support wetlands) (MRCS, 2023). As discussed above in Section 3.2, the dominant vegetation types in the Project Area are not hydrophytic (i.e., vegetation indicative of wetlands). Based on this desktop review, there are no wetlands in the Project Area as the three indicators that must be present for an area to be identified as a wetland were not observed. 3.6 Floodplains The FEMA Flood Map Service Center is a public source for flood hazard information produced in support of the National Flood Insurance Program. This mapping tool provides information on whether a project is being proposed within a floodplain/floodway. FEMA Flood Insurance Rate Map Panel # 08123C 1975E, dated January 20, 2016, was reviewed to determine if the Project Area is located within the 100 -year floodplain. The Project Area is in Zone X, areas determined to be outside the 500 -year floodplain. Therefore, the Project Area is not located within a 100 -year floodplain. 3.7 Groundwater The Project Area is located in the South Platte River Basin. Recharge in the South Platte River Basin is comprised predominately of precipitation, irrigation, reservoir seepages, and groundwater pumping (Brown and Caldwell, 2017). According to Colorado's decision support system mapper, there is one well located in the southeast corner of the Project Area. The well is 710 feet deep and permitted for domestic uses. There are no reservoirs within the Project Area and the land is not used for agricultural purposes (Brown and Caldwell, 2017). Therefore, the Project Area contributes to groundwater recharge though the infiltration of precipitation. 3.8 Natural Hazards Weld County 2021 Multi -Jurisdictional Hazard Mitigation Plan was reviewed to identify potential natural hazards within the Project Area. The closet geographical location to the Project Area with identified natural hazards is the Town of Keenesburg. The Town of Keenesburg is located approximately 3 miles southeast of the Project Area along the I-76 corridor in southeast Weld County (Weld County, 2021). The natural hazards Keenesburg is vulnerable to include agricultural diseases and pests, drought, earthquakes, extreme temperatures, floods, land subsidence, prairie fires, severe storms, and tornados (Weld County, 2021). The risk and vulnerability assessment conducted for the Town revealed that Keenesburg was at high risk for agricultural, drought, extreme temperature, flood, severe storms, and tornado hazards (Weld County, 2021). However, The Town of Keenesburg's overall vulnerability to the previously listed hazards was not noticeably different from the rest of Weld County (Weld County, 2021). 3.9 Recreational Areas The Weld County Property Portal was reviewed to identify potential recreational areas within the Project Area. There are three recreational districts within Weld County: Eaton Area Park and Recreation, Thompson River Park and Recreation, and Carbon Valley Park and Recreation. The Project Area is not located in any of the districts listed previously. Carbon Valley Park and Recreation is the closest recreational area located approximately 18 miles west of the Project Area. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Environmental Review11041 1041 Submittal Application 4 Conclusions • It is not anticipated that ESA permitting would be required for this Project. • No unique areas of geologic importance in the vicinity of the Project Area. • No forests or woodlands in the vicinity of the Project Area. • No USFWS critical habitat in the vicinity of the Project Area. • No floodplains or floodways in the vicinity of the Project Area. • No NWI mapped wetlands in the vicinity of the Project Area. • No National Register of Historic Places in the vicinity of the Project Area. • No natural hazards in the vicinity of the Project Area. • No public outdoor recreation areas in the vicinity of the Project Area. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Environmental Review11041 1041 Submittal Application VI 5 References Barkmann, Peter E., Lauren D. Broes, Martin J. Palkovic, John C. Hopkins, Kenneth Swift Bird, Lesley A. Sebol, and F. Scot Fitzgerald. "ON -010 Colorado Groundwater Atlas." Geohydrology. ON - 010 Colorado Groundwater Atlas, 08 January 2020. https://coloradogeologicalsurvey.org/water/colorado-groundwater-atlas/ Brown and Caldwel1.2017. South Platte Decision Support System Alluvial Groundwater Model Update Documentation (report). Colorado Water Conservation Board and Division of Water Resources.https://dnrweblink.state.co.us/CWCB/0/edoc/212818/SPDSS%20 Alluvial% 20Groundwater%20Model%20Update%20Report%20FINAL%20- %20Executive%20Summary.pdf Chapman, S.S., Griffith, G.E., Omernik, J.M., Price, A.B., Freeouf, J., and Schrupp, D.L.. Ecoregions of Colorado (color poster with map, descriptive text, summary tables, and photographs) [map]: 1:1,200,000. Reston, Virginia: U.S. Geological Survey, 2006. Colorado Parks and Wildlife (CPW). 2023. Threatened and Endangered List. https://cpw.state.co.us/learn/Pages/SOC-ThreatenedEndangeredList.aspx Federal Emergency Management Agency (FEMA) Flood Rate Insurance. 2023. https://msc.fema.gov/portaUhome. Natural Resources Conservation Service (NRCS). 2023. United States Department of Agriculture. Web Soil Survey. http://websoilsurvey.sc.egov.usda.gov/. Olson, Steve. 2019. Endangered, Threatened, Proposed, and Regional Forester's Sensitive Species in the Rocky Mountain Region (R2): What 's Important for the Pike and San Isabel National Forests and the Cimarron and Comanche National Grasslands (PSICC). April 30, 2019. U.S. Fish and Wildlife Service (USFWS). 1995. Ute Ladies '-tresses (Spiranthes diluvialis) Recovery Plan. U.S Fish and Wildlife Service: Denver, Colorado. 46 pp. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Environmental Review11041 1041 Submittal Application U.S. Fish and Wildlife Service (USFWS). 1996. Platanthera praeclara (western prairie fringed orchid) recovery plan. U.S. Fish and Wildlife Service: Ft. Snelling, Minnesota. 101 pp. U.S. Fish and Wildlife Service (USFWS). 2007. Pallid Sturgeon (Scaphirhynchus albus) 5 -year review summary and evaluation. U.S. Fish and Wildlife Service Pallid Sturgeon Recovery Coordinator: Billings, Montana. 120 pp. U.S. Fish and Wildlife Service (USFWS). 2019. Species Status Assessment Report for the Eastern Black Rail (Laterallusjamaicensisjamaicensis), Version 1.3. Southeast Region, Atlanta, GA. U.S. Fish and Wildlife Service.2023a.Piping plover (Charadrius melodus). https://www.fws.gov/species/piping-plover-charadrius-melodus U.S. Fish and Wildlife Service 2023b. Whooping Crane (Grus americana). https://www.fws.gov/species/whooping-crane-gnus-americana U.S. Fish and Wildlife Service.2023c.Monarch Butterfly (Danaus plexippus). https://www.fws.gov/species/monarch-danaus-plexippus U.S. Fish and Wildlife Service.n.d./pac: Information for planning and consultation. https://ipac.ecosphere.fws.gov/ United States Fish & Wildlife Service (USFWS).2O23. Wetlands Mapper. https://www.fws.gov/program/national-wetlands-inventory/wetlands mapper United States Geological Survey (USGS). Geologic map of Colorado [Report]. 1:50,000 1" 8 miles. Washington D.C.: Colorado Geological Survey, 1979. Weld County Emergency Management. 2021. Weld County 2021 Multijurisdictional Hazard Mitigation Plan. Weld County: Colorado. 570 pages e Stanley Consultants Mountain Peak Power, LLC 0 Mountain Peak Power Project Environmental Review 11041 Submittal Application Figures viii Stanley Consultants a C" <N KindleEnergy_TesIaSS_31324.apix KindleE iergy TeslaSS 31324.apn< Federal Public Land Bureau of Land Management Department of Defense Fish and Wildlife Service Forest Service LANDCOVER, PUBLIC LAND, OUTDOOR RECREATION AREAS, & NATURAL HAZARDS Mountain Peak Kindle Tesla Substation, Kennesburg, CO Figure 2 H2O H2O H2O H2O Kpm H2O H2O H2O c, iV d N N N KindleE iergy TeslaSS 31324.apn< KindleE iergy TeslaSS 31324.apn< NATIONAL WETLANDS INVENTORY, FEMA FLOODPLAIN, USFW CRITICAL HABITAT, & NATIONAL REGISTER OF HISTORICAL PLACES Mountain Peak Kindle Tesla Substation, Kennesburg, CO mry Figure 4 Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 221 1041 Submittal Application Attachment 22 Emergency Response Plan Mountain Peak Power Weld County 1041 Application Stanley Consultants /P Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 1 of 20 Emergency Response Plan Mountain Peak Power Peaking Station 10001 County Road 55, Keenesburg, CO 80643 Weld County "Uncontrolled When Printed, Discard after use." /P Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 2of20 Table of Contents 1.0 Purpose 2.0 Scope 3.0 Certification of Plan Accuracy and Effectiveness 4.0 Definitions 5.0 Facility Information 6.0 Emergency Equipment 7.0 Transportation Routes 8.0 Emergency Response Procedures 8.1 Medical Emergencies 8.2 Fires 8.3 Tornado/Severe Weather 8.4 Hazardous Material Release 8.5 Bomb Threat 8.6 Active Shooter 9.0 Training Requirements 10.0 References 11.0 Revision History Appendices Appendix A. Emergency Contact Information Appendix B. Bomb Threat Questionnaire Appendix C. Emergency Response Plan Training Log Appendix D. Emergency & Evacuation Map 3 3 3 4 5 6 6 6 7 7 9 9 10 11 12 14 15 "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 3 of 20 1.0 Purpose Mountain Peak Power, LLC ("MPP") is committed to the safe operation and responsible generation of power at all its facilities. The purpose of this Emergency Response Plan ("ERP" or "Plan") is to establish formal emergency prevention and preparedness procedures with the intent of protecting human health, environment, and the facility in the event of an emergency. The Plan includes uniform preparation and response guidelines for the following emergency situations: •:• Medical, •;• •:• •:• •;• •:• Fire, Severe Weather, Hazardous Material Releases, Bomb Threats, and Active Shooter. 2.0 Scope This Plan applies to all personnel working at MPP facilities. These procedures and response guidelines will be used in conjunction with any other authorized programs set forth by MPP and applicable regulatory requirements for the facility. A complete copy of this ERP will be maintained at the MPP Peaking Station (10001 County Road 55, Keenesburg, Colorado). In addition, a copy is maintained at MPP's Corporate Headquarters office (500 Alexander Park Drive, Suite 300, Princeton, New Jersey). The ERP will be made available to MPP employees and will provide a basis for training employees, contractors, visitors, and emergency responders. The ERP is not required to be certified by a registered professional engineer, but has been reviewed and authorized by MPP management. 3.0 Certification of Plan Accuracy and Effectiveness "I have reviewed the contents of this Emergency Response Plan and certify that the policies and procedures contained within are accurate and effective in managing emergencies at MPP facilities." Environmental Health & Date Safety Manager MPP Plant Manager Date "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 4 of 20 4.0 Definitions DOT United States Department of Transportation Emergency Standardized within alarm a system, given system facility rapid of notification capable any emergency of system, notifying situation radio all alert (i.e., personnel audible/visual system). located Notification System Evacuation To withdraw, in an organized manner, to a safe assembly area. Hazardous Materials A results employees petroleum or may who product result are or any in adverse exposed DOT to it. or affects OSHA on hazardous the health material or safety which of HSE The individual(s) responsible for compliance with Health, Safety and Representative(s) Environmental (HSE) programs. Incipient Stage A extinguished small breathing fire in hose the apparatus. initial by systems portable or without beginning fire extinguishers, the stage need that for can class protective be II controlled standpipe, clothing or or or Muster Location Designated employees areas can find refuge located in away a serious from or critical life -threatening locations situation. where National Service WARNING Weather National been sighted Weather in the Service bulletin area. stating that severe weather has National WATCH Weather National weather Weather could Service develop. bulletin stating the possibility that severe Service OSHA United States Occupational Safety and Health Administration PPE Personal Protective Equipment (PPE) is equipment worn to minimize and with workplace illnesses. chemical, exposure hazards. These radiological, to injuries hazards physical, and that illnesses cause electrical, serious may mechanical, workplace result from injuries contact or other Standard Classification Industrial Standard numerical the activity. industries Industrial codes to which assigned Classification companies by the U.S. belong (SIC) government codes by their that primary are categorize four -digit business "Uncontrolled When Printed, Discard after use." Procedure No: ENV-ERP-V01 Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Revision: 1.0 Page: 5 of 20 5.0 Facility Information Facility Name: Mountain Peak Power Peaking Station Location (Street Address): 1001 Weld County Road (CR) 55 City: Keenesbur• State: Colorado Zip: 80643 County: Weld Phone Number: (XXX) XXX-XXXX Fax No.: Latitude: Degrees 40 Minutes 8 Seconds 48 Longitude: Degrees -104 Minutes 32 Seconds 55 Owner: Mountain Peak Power LLC Owner Location (Street Address): c/o Kindle Ener• LLC 500 Alexander Park Drive Suite 300 City: Princeton State: NJ Zip: 08540 County: _Mercer_ Phone Number: (609) 250-7702 Operator (if not Owner): Same Facility Description: _The Mountain Peak Power Peaking Facility is located at 10001 County Road (CR) 55, approximately 3 miles northwest of Keenesburg, Colorado. The facility is co - located at the United Power 69kV Tesla Substation on approximately 20 acres of land. The site is relatively flat, open grassland surrounded by oil & gas well pads, a retention pond, agricultural land and a couple single-family residences. The MPP portion of the facility consists of six (6) General Electric (GE) LM2500 Xpress simple cycle combustion turbines (CT) generating a total of approximately 165 megawatts (gross) of power. The only fuel for the combustion turbines is natural gas. The auxiliary equipment consists of a 355 -hp emergency firewater pump engine and its associated 572 -gallon diesel storage tank. The facility consists of a control building and storage tanks where some hazardous materials are stored (e.g., diesel fuel, aqueous ammonia for SCR). It is possible that fires, explosions, or any unplanned sudden or non -sudden releases of hazardous material constituents to air, soil, or surface water could potentially occur at this facility. Current Operations: _Electric Power Generation: SIC Code 4911 "Uncontrolled When Printed, Discard after use." Procedure No: ENV-ERP-V01 Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Revision: 1.0 Page: 6 of 20 6.0 Emergency Equipment Location PPE & Equipment Available Control Building Boots, Gloves, Hard Hats, Ear and Eye Protection Fire Extinguishers Control Pump Building, Gas Metering Yard & Fire First Aid Supplies Control Building Foam Trailer Fire Fighting Equipment Southeast Weld Fire Department Miscellaneous Emergency Equipment Control Building Self (SCBA) -Contained Breathing Apparatus Control Building & Southeast Weld Fire Dept. Spare -Compressed Breathing Air Bottles Southeast Weld Fire Department Spill Cleanup Kit Control Building & Aqueous Ammonia AST 7.0 Transportation Routes The MPP Peaking Station is co -located with United Power's Tesla Substation and Keenesburg Energy Storage LLC's BESS Facility. Access will be via County Road 18 (either eastbound or westbound depending on point of origination) and then northbound on County Road 55. The dedicated ingress/egress to the facilities will require turning west/left off County Road 55 and into the parking area located in the southeast corner of the facility. Chemicals/products, non -potable water, and petroleum/lubricants/oils for will be delivered to site by various contractors of MPP (varies greatly). The only regular shipments of materials or chemicals anticipated at the MPP facility will be deliveries of aqueous ammonia1 offloaded to the aboveground storage tank (AST) located in the northwest quadrant of the site. The aqueous ammonia AST will be within a dedicated secondary containment and equipped with audible and visual emergency notification alarm system in the event of a release. Other chemicals of interest that will be delivered to the facility on an "as needed" basis could be diesel fuel, dielectric fluids such as mineral oil, lubricants, and miscellaneous small quantities of chemicals necessary to perform equipment work and maintenance. 8.0 Emergency Response Procedures The primary concern in any emergency situation is to protect personnel, the public, environment, and the facility from harm. In most cases, the employee first observing the incident will be able to access the general type of hazard involved and the safety precautions required. If in doubt or if the incident is observed at one of the co -located operations, additional assistance should be obtained prior to approaching the emergency area. MPP's facility response management system and the essential steps to be taken during different types of emergencies are provided in the following sections. 1 <= 19% by weight for use in the selective catalytic reduction (SCR) system which, along with dry low NOx (DLE) combustion system, is utilized for NOx control "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 7 of 20 8.1 Medical Emergencies 1. All medical emergencies shall be immediately reported to the Control Room. 2. Ensure the person who discovers an injured person or one with a serious illness immediately informs the Control Room of the following information and that proper basic first aid is provided until help arrives: • Discoverer's name and location • Exact location of person needing assistance • Name, approximate age, and any known medical conditions of the injured person(s) • Nature and severity of injury/illness • Any apparent conditions or hazards which could increase the level of danger (i.e., chemicals, falling hazards, space confinements) in the area of the incident • Description of any action being taken or about to be taken • Maintain open lines of communication with the Control Room • If you are trained and willing, perform CPR as necessary A. Assess victim B. Establish airway C. Call for an AED D. Do not move victim unless necessary • Control heavy bleeding or spurting blood by using direst pressure • Use universal precautions when providing first aid • Stay with the victim until help arrives 3. If professional help is needed (e.g., ambulance), the Control Room will call for this assistance (i.e., 911) while Responder remains with injured person(s). SAFETY ALERT: Do not hang up until told to do so by the emergency agency receiving your call. 4. Notify appropriate management. In the event of an occupational death, hospitalization, or serious injury, MPP's EHS Director and Chief Operating Officer (COO) should be contacted immediately, as well as other staff that may require emergency event notification. 8.2 Fires 1. The person who discovers a fire shall immediately inform the Control Room of the following information: • Discoverer's name and location • Exact location of the fire "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 8 of 20 • Size and type of fire (i.e., electrical, combustible, flammable liquids) • Any existing injuries (see section 8.1) • Any apparent conditions or hazards which could increase the level of danger (i.e., chemicals, flammable liquids or gases) in the area of the fire • Description of any action being taken or about to be taken 2. If the fire is in its incipient stage and is in the process of being extinguished, then the Control Room (person receiving the emergency call) shall send appropriate personnel to the area of the incident to assist. If the fire is small and contained (e.g., in a trash can) and can be easily extinguished with one fire extinguisher, do so as follows: a. Yell "FIRE! FIRE! FIRE!" to warn others of danger b. Report to the Control Room c. Give your name, location and type of fire d. Notify the Control Room of your intent to extinguish the fire DO NOT ATTEMPT TO CONTROL OR EXTINGUISH A FIRE IF YOU ARE NOT CURRENTLY TRAINED. 4. Clear and isolate the area to reduce spreading DO NOT PUT YOURSELF OR ANYONE ELSE IN DANGER. 5. Using the training techniques (PASS System), attempt to extinguish the fire: a. Pull the safety pin b. Aim at the base of the fire c. Squeeze the trigger d. Sweep the spray from side to side 6. Keep the control room apprised of the situation 7. If the fire has progressed beyond incipient stage, or there are hazards near the fire that could quickly elevate the danger of the situation, then the Control Room shall: a. Initiate facility evacuation to the Safe Assembly Area (see Appendix D). b. Notify the appropriate outside agencies (i.e., 911). c. Notify system dispatcher and management of emergency situation. d. Notify third -party water supplier(s) to initiate fire water tank refill deliveries. DO NOT ATTEMPT TO CONTROL A LARGE FIRE. Remain at the Safe Assembly Area until dismissed by emergency personnel "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 9 of 20 SAFETY ALERT: Never attempt to fight a fire in any electrical facility with water without consent and instruction from MPP, United Power, or Keenesburg Energy Storage staff. NOTE: For fire protection, 125,000 gallons of water is available on -site in an AST located east of the Control Building and provides pressurized fire water connected to hydrants encircling the MPP site. Additionally, each GE CT is equipped with fire detection and a CO2 fire extinguishing system equipped with visual and audible alarms. 8.3 Tornado/Severe Weather 1. Ensure the following in the event that a "National Weather Service WATCH" is issued: a. Notify all on -site personnel that a "National Weather Service Watch" pertaining to the area has been issued. b. Monitor weather bulletins for further development. c. Ensure field personnel maintain an awareness of developing weather conditions in the surrounding area. 2. Ensure the following in the event that a "National Weather Service WARNING" is issued: a. Notify all on -site personnel that a "National Weather Service Warning" pertaining to the area has been issued. b. Ensure the facility is storm ready. c. This may include: i. Removing personnel from rooms with windows during high wind events and move to interior rooms. ii. Ensure all personnel in vehicles have been located and are directed to remain indoors until otherwise notified. iii. Alternative lighting (flashlight) is available and working properly. iv. Radio, phones, and communication equipment is available and working properly. Report the sighting of any impending weather threat immediately to the Control Room and activate the Emergency Notification System, as appropriate. 4. Ensure personnel proceed to designated safe shelter areas. 8.4 Hazardous Material Release 1. Ensure the person who discovers a hazardous material release immediately informs the Control Room of the following information: a. Discoverer's name and location b. Exact location of release c. Size and type of release "Uncontrolled When Printed, Discard after use." Procedure No: ENV-ERP-V01 Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Revision: 1.0 Page: 10 of 20 d. Personnel exposed to or injured by hazardous material (see section 8.1) e. Any apparent conditions or hazard that could increase the level of danger/exposure in the area of the hazardous material release f. Description of any action being taken or about to be taken; in an area where hazardous vapors may be released and unconscious personnel are observed, this area will not be entered unless rescue personnel are equipped with SCBA 2. Ensure the Control Room (person receiving the emergency call) notifies HSE Representative, facility management, and, if applicable, Emergency Spill Response Contractors, as appropriate. Ensure the Control Room, HSE Representative and/or facility management evaluate the incident and issue necessary directives for appropriate situation control which may include implementing facility evacuation to the Safe Assembly Area (see Appendix D). 8.5 Bomb Threat 1. No telephone calls, notes, or letters relating to bombs or bomb threats will be disregarded. Ensure, for bomb threats received by telephone, the person who receives the threat shall: • REMAIN CALM and try to keep the caller talking. If possible, immediately notify the Control Room if you can do so while remaining on the line with the caller. • Record all information and comments made by the caller as accurately as possible; use the exact words spoken by the caller. • Try to obtain the following information (see Appendix B): o Date and time of the call. o Location of the bomb. o When it is expected to go off. o Gender of caller. o Mood of caller, for example, angry, intoxicated, calm, intelligent, etc. o Background noise. o Unusual characteristics, such as an accent or key word repeatedly used • When the caller disconnects, then notify Facility Management IMMEDIATELY (provided this has not already been accomplished) 3. If any employee receives a bomb threat by sources other than telephone, they must notify Facility Management as soon as possible. 4. Control Room and/or Facility Management will do the following: • Evacuate the facility immediately. • Remember visitors/vendors are the responsibility of the personnel they are visiting (all visitors must have a liaison). • Report any suspicious items or behaviors observed during evacuation. "Uncontrolled When Printed, Discard after use." Procedure No: ENV-ERP-V01 Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Revision: 1.0 Page: 11 of 20 • Notify proper authorities/law enforcement agencies via 911. • Provide information and assistance to authorities upon their arrival. • Let the authorities determine when it is safe to re-enter the facility. SAFETY ALERT: Do not use cell phones or radios in close vicinity of notified bomb location. As a PRECAUTION, do not disturb any foreign packages or objects. 8.6 Active Shooter 1. If you are aware of an active shooter onsite and can do so safely, call 911 2. If you have a safe escape route, away from the shooter and the immediate area: • Run to the nearest safe exit, stay quiet (silence cell phones and radios). • Leave all belongings behind. • Evacuate even if others do not follow. • Assist others willing to escape with you. • Notify Control Room of your location and situation when it is safe to do so. 3. When Police arrive — KEEP YOUR HANDS VISIBLE 4. Follow any instructions given by Police. 5. If you do not know the location of the shooter, hide in place and secure the area as best you can. 6. Lock doors if possible. 7. Push desks, tables bookshelves (anything heavy) in front of the entrance door. 8. Turn off lights and noisy items. 9. Do not move wounded personnel. 10. Do not pull a fire alarm or respond to one if an active shooter is onsite. 11. Do not run in a straight line. 12. Hide in place when you are unsure of the shooter's whereabouts. 13. Stay out of view, stay hidden until help arrives. 14. Do not huddle in groups. 15. Contact the Control Room with a situational update only when you are sure it is safe to do so. "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 12 of 20 9.0 Training Requirements The HSE Representative will assure that all personnel covered by this ERP receive proper training. Training will be conducted annually and whenever the ERP is modified or ones' responsibilities under the Plan changes. All training will be documented, with records maintained by the safety department for the length of employment. Training will include the following information: ✓ Overview and general information regarding the contents of this program. ✓ Evacuation routes and designated muster locations, both inside, and outside of the facility. ✓ In the event an employee discovers an emergency, they are to immediately notify a supervisor. ✓ The difference between a notification to evacuate to the Safe Area outside of the building (i.e., muster points), versus the notification to evacuate to the Shelter In Place inside of the building. ✓ The information contained in Evacuation Map (see Appendix D). ✓ Any unique fire and/or chemical hazards that exist in the department. ✓ Where the written ERP is stored. An evacuation drill will be conducted at least annually to assure that all employees know their role in the event of an actual emergency. The local Fire Department, Office of Emergency Management, and/or other emergency responders may be notified of the drill in advance and invited to participate. A follow up meeting will be conducted with Facility Management to discuss and resolve any problems discovered during the drill, such as alarms not heard in specific areas of the facility, employees reporting to the wrong location, etc. The following information pertains to the OSHA standard for Emergency & Evacuation: 1. Emergency Exits and Aisles: a. All exits must be clearly marked with a readily visible sign that is illuminated and can be read in the dark. Any doors that would be mistaken for an exit must be clearly marked as Not an Exit' or otherwise identify what lies beyond the other side, for example "Storage Area". c. If an exit door cannot be readily seen by all users, the route to the exit must be clearly marked. Exit signs with arrows directing people to the nearest exit, strategically placed along the main aisles are required whenever direction to the nearest exit is not immediately apparent. d. In addition to illumination, the letters on exit signs must be at least 6 inches high and 3/4 inch wide. (These are standard measurements) e. Exits cannot be locked shut to the point that occupants of the building cannot easily escape. f. All exits must empty out of the facility into an area where public access can be obtained. g. Make sure that the outside of all emergency exits do not present hazards such as potholes, snow, or ice cover, etc. h. Aisles leading to an exit door should be clearly marked and must be at least 28 inches wide. "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 13 of 20 i. Emergency aisles should be in the straightest path possible to the exit. (Do not designate an escape aisle to pass through a 'building' inside of the facility.) "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 14 of 20 10.0 References Department of Transportation (DOT) — Hazardous Materials Regulations. 49 CFR Subchapter C. Occupational Safety and Health Administration (OSHA). Hazardous Communication Standard (HCS) 2012 Final Rule. 29 CFR §1910.1200. OSHA. Emergency Action Plans. 29 CFR §1910.38. OSHA. Electric power generation, transmission, and distribution. 29 CFR §1910.269. "Uncontrolled When Printed, Discard after use." it\ Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 15 of 20 11.0 Revision History Revision History Document Owner: Shawn Donovan Revision Description of p Change g Revision mm/dd/yyyy d/yyyy Date q p p roved B y 1.0 Initial Release XX-XX-XXXX "Uncontrolled When Printed, Discard after use." Procedure No: ENV-ERP-V01 Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Revision: 1.0 Page: 16 of 20 APPENDIX A. Emergency Contact Information Designated Incident Commanders/Response1. Coordinators [PLANT MGR] [PLANT MGR] (XXX) XXX-XXXX U nited Power Jon Howard, VP — Engineering Thomas Flexon, VP — Development Phone Numbers (XXX) XXX-XXXX 1-800-468-8809 or (303) 659-0551 (609) 250-7709 (609) 250-7227 Environmental, Health and Safety (EHS) [PLANT HSE REP] S hawn Donovan, Director — Environmental Freddie Guyote, Director — EHS (XXX) XXX-XXXX (609) 436-9020 (609) 250-7702 Federal and State Agencies N ational Response Center CDPHE Spill Hotline Colorado State Police U S EPA, Region 8 Chemical Transportation Emergency Center (CHEMTREC) Poison Control S heriff/Police/Fire Department Platte Valley Hospital (nearest 24hr ER) Weld County Office of Emergency Management Southeast Weld Fire District Fire Chief 1-800-424-8802 (877) 518-5608 (303) 239-4501 (non - emergency incident reporting) (303) 312-6054 1-800-424-9300 1-800-222-1222 911 (303) 498-1600 (970) 304-6540 (800) 436-9276 x3809 (303) 732-4203 Office Emergency Spill Response Contractors TBD "Uncontrolled When Printed, Discard after use." itP Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 17of20 APPENDIX B. BOMB THREAT - CALLER QUESTIONNAIRE Remain calm and proceed down the list. Any information you can obtain may be helpful to authorities. Date: ASK CALLER Where is the Bomb? What does it look like? When will it go off? Why did you plant it? Time: I, I, I, 'I Phone Ext. Call Received at: RESPONSE (Quote Caller if Possible) Why would you want to hurt innocent people? Information on caller: Mental Condition: Sober: Gender: Possible Age: Intoxicated: II 'V II ,f Angry: Calm: Accent, Voice Inflection, Unusual Words: What was said (as exact as possible)? " Area of Call Background Noise: Quiet: Street Noise: Noisy: Bar/Party: Person receiving this call (sign please) "Uncontrolled When Printed, Discard after use." /P Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Procedure No: ENV-ERP-V01 Revision: 1.0 Page: 18 of 20 APPENDIX C. INSTRUCTOR: EMERGENCY RESPONSE PLAN TRAINING LOG I have trained the employees listed below on the facility Emergency & Evacuation Plan. A copy of the training outline is attached. INSTRUCTOR'S SIGNATURE: I have received training in this program. I understand the information provided and have no further questions regarding this information. EMPLOYEE'S NAME (PRINT) EMPLOYEE'S SIGNATURE COMPANY DATE "Uncontrolled When Printed, Discard after use." Procedure No: ENV-ERP-V01 Mountain Peak Power MOUNTAIN PEAK POWER EMERGENCY RESPONSE PLAN Revision: 1.0 Page: 19 of 20 APPENDIX D. EMERGENCY & EVACUATION MAP "Uncontrolled When Printed, Discard after use." Mountain Peak Power, LLC Mountain Peak Power Project Attachment 20 — Rev 2 11041 Submittal Application Attachment 20 Landscaping Plan - Rev 2 Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Landscaping Plan 11041 Submittal Application Landscaping Plan Background Mountain Peak Power, LLC is proposing construction of a supplemental, natural gas fired power plant in Weld County off County Road 55 northwest of the Town of Keenesburg. The site will be co -located with the existing United Power Tesla Substation. Refer to site plan drawing 31324-GG 101 located in Attachment 3 for landscaping and site finishing details described herein. Construction During construction, the project shall direct contractors to preserve the natural landscape and conduct construction operations so as to prevent any unnecessary destruction, scarring, or defacing of the natural surroundings in the vicinity of the work. Except where clearing is required for permanent works, vegetation shall be preserved and protected from damage by the contractor's construction operations and equipment. Areas for temporary construction access and laydown will be minimized to the best extent possible and planned to be located on the southeastern side of the site. Construction laydown will include staging areas for equipment, materials, and construction parking. Construction equipment access throughout the site will be limited to the planned permanent road around the site as shown on the Site Plan. This will minimize disturbances to open areas. During construction, any topsoil removed will be preserved for future use in site finishing. Erosion control measures will be installed prior to any soil or earth work. Site Finishing The final site landscaping follows the site as it currently exists, with native grasses reseeding planned where possible. The site lacks a source for irrigation to support the planting of trees or shrubs around the site. Site Roads — As shown on the Site Plan, site access will be from County Road 55 with two roads traversing the site from south to north. These roads will provide access to essential areas on the south part of the site and then connect to a road that encircles or loops around the main power generating equipment on the north side of the site. All major equipment and facilities will be accessible from this road. Roads widths will comply with Weld County requirements for emergency vehicle access, including minimum turning radius. Roads will be finished with gravel. Control Trailer - The Control Trailer will be located on the north side of the site accessible from the road with employee parking located on the south side of Control Trailer. The Control Trailer will be similar to a double -wide trailer (roughly 24" x 60") where plant operators will be stationed. Parking area is planned to include provisions for eight (8) parking spaces with a minimum of two (2) ADA compliant handicap parking spaces. Parking spaces will be finished with gravel. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Landscaping Plan 11041 Submittal Application Equipment Areas — Areas around equipment will be finished with rock mulch, similar to the existing Tesla Substation currently located on the site. The area encircled by the site road loop will be completely covered by rock much. The rock mulch serves multiple purposes for the site, specifically for areas with permanent equipment and machinery. The rock will ensure the electrical ground grid installed under grade performs as designed. Site grading and drainage will benefit from the rock mulch and allows for accessing equipment and machinery for maintenance purposes. This will minimize potential for dust or accessibility issues for vehicles. Native grass areas - Reseeding is planned for areas disturbed by construction or areas located away from equipment maintenance access areas. This would include areas that are not graveled or covered with rock. Post seeding mulch (native and region -based seed) will be utilized during reclamation activities to help reduce wind erosion and blowing dust. The reseeding will be performed as soon as possible after completion of Project activities to minimize potential fugitive dust generation as revegetation occurs. Trees or Shrubs - No trees or shrubs or similar type of vegetation will be planted as the site lacks an irrigation water source. Site Security — A site security fence will encompass the site along property boundaries on the north and west sides of the site. Security fence will extent along portions of the eastern property boundary. On the south portion of the site, the security fence will encircle the detention pond and then connect to existing security fence for Tesla Substation. The southern boundary of the property will be open as the security fence will not extent to the southern boundary. This will ensure access to existing facility. Gates will be provided for both north -south site road where security fence is located. Each gate will allow site access from south side of the property. Main security and access gate will be the access road on the eastern side of the property. This site road is also connected to the main site access point off County Road 55. Signs will indicate to drivers or personnel which gate to use. Please refer to sign plan for the site for more details. Site security cameras will be installed across site for critical areas allowing remote viewing by operators and off -site monitoring. Lighting — Site lighting will be provided by cutoff or hooded light poles installed along internal side roads to allow operators safe traversing of the site. Cutoff or hooded light fixtures will minimize or remove the amount of horizontal light emitted from the light fixtures. This includes strategic aiming of light fixture downwards for focused luminance. This will avoid nuisance lighting for adjacent properties and reduce potential for light pollution. Motion sensing lights will be installed to greatest extent to minimize any potential for light pollution or nuisance lighting during nighttime hours. Screening — A fence will be constructed around the Project, as shown on mark up to Attachment 3 below. Mountain Peak will work with United Power to construct a concrete wall along the North and West boundaries lines as depicted in the image below. This wall will range up to 20 ft, with the ultimate height contingent on safety, viability, engineering, and design. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Landscaping Plan 11041 Submittal Application •+•tats-. •wt 7:•j•ia ♦.A► ••• s.aata ntt c. •g1 .7 �s1 ea j " 0 •y •.• pee, r I. � t. r. •. 1. 1. /... r.• • .. •.i-•, • •.•, r. •. •. r.i;L•,1a4Ia• •.••_•_•.•. •. •.•-•_ r. •..or & cf.,. re *eV . =ice Clio, tr Y••• •A.••.iJ•C HO * e Stanley Consultants liiii3i11iii meat wavt t Me !PS nf. MO Jolt •341103 t• 1'441 •.t1•.•O. M •. ••a rV• -• ti a .5 • I '1.. •'_t4•► •^• :0..'. •?A u • tent •4 •.ao LOWS •• •• re Sr 1 I I I 1 I I I I I at like Xi - AZ Ot a •a: asCr0. *4 worn e• is -t •t ca..•• •••••-0c M •• $.44 es -•r 4, • •• iii Mountain Peak Power, LLC Mountain Peak Power Project Attachment 23 — Rev 1 11041 Submittal Application Attachment 23 Noise Study - Rev 1 Mountain Peak Power Weld County 1041 Application Stanley Consultants C Power Acoustics, Inc. CONSULTANTSIN ACOUSTICS AND NOISE CONTROL Community Noise Impact and Acoustical Analysis of the Kindle Energy LLC Mountain Peak Power Project Report Number 24-1226-01 Date: February 15, 2024 Prepared at the request of: Stanley Consultants 8000 S Chester Street Suite 500 Centennial, CO 80112 Submitted by: 00. David J. Parzych, INCE.Bd.Cert. d. Cert. Principal Consultant Power Acoustics, Inc. Specializing in Acoustics and Noise Control for the Power Industry 2730 NORTHAMPTON AVE. • ORLANDO, FLORIDA • 32828 PHONE: (407) 381-1439 email: info@poweracoustics.com Power Acoustics, Inc. Mountain Peak Power Project Sound Study Contents 1.0 INTRODUCTION 1 2.0 EXECUTIVE SUMMARY 1 3.0 SIMPLE CYCLE GAS TURBINE ADDITION 2 4.0 MEASUREMENT METHODOLOGY, INSTRUMENTATION AND CONDITIONS 3 4.1 Sound Measurements and Methodology 3 4.2 Sound Measurement Instrumentation 3 4.3 Personnel Performing the Sound Survey 3 4.4 Weather Conditions 4 5.0 SOUND MEASUREMENT RESULTS 4 5.1 Measurement Locations 4 5.2 Sound Level Data 5 6.0 PROJECT NOISE REQUIREMENTS 8 6.1 Colorado Revised Statutes 2022[la] 8 6.2 Weld County CHAPTER 14 - Health and Animals - ARTICLE IX Noise [1b] 8 6.3 USEPA and American National Standards Institute (ANSI) Acceptable Audible Sound 9 6.4 Sound Level Goals to Achieve a Negligible Increase in Community Noise 10 6.5 Low Frequency Infrasound Goals 10 6.6 Tonal/Impulsive Noise Goals and Requirements 10 7.0 COMMUNITY NOISE MODEL AND ESTIMATED SOUND LEVELS 10 7.1 Estimated A -weighted Sound Levels of the Mountain Peak Power Project 11 7.2 Estimated C -weighted Sound of the Mountain Peak Power Project 12 8.0 REFERENCES 16 APPENDIX A - Reporting Consultant's R�sum� APPENDIX B - Discussion of Acoustical Terms APPENDIX C — Colorado Revised Statutes 2022, ARTICLE 12, Noise Abatement APPENDIX D — Weld County, CHAPTER 14 - Health and Animals - ARTICLE IX, Noise APPENDIX E — Modeled Equipment Sound Sources APPENDIX F — Equipment Sound Levels & Property Boundary Sound Wall Effectiveness i Power Acoustics, Inc. Mountain Peak Power Project Sound Study 1.0 INTRODUCTION Kindle Energy LLC has proposed to add six (6) LM2500Xpress simple cycle Gas Turbines to the property north/adjacent to the existing United Power Tesla Substation on County Road 55 in Weld County, Colorado. The new facility is designated as the Mountain Peak Power Project. Power Acoustics, Inc. was contracted to measure existing sound in the area and assess the acoustical impacts of the new Gas Turbine equipment on nearby community residential properties. The acoustical study consisted of: 1.) Measuring the ambient sound levels at representative critical locations in the vicinity of the proposed facility. The baseline ambient sound survey data was used as the basis of determining facility impacts, 2.) Setting noise goals for the new facility based on Colorado Revised Statutes 2022 TITLE 25, ARTICLE 12, "Noise Abatement" [la], The Weld County, Colorado, Charter and County Code CHAPTER 14 — "Health and Animals", ARTICLE IX, "Noise" [ib] and other USEPA/American noise standards [6,7], 3.) estimating the sound levels generated by the proposed facility, and 4.) assessing conceptual noise abatement strategies and determining the feasibility of the facility achieving the desired sound levels. Power Acoustics obtained ambient sound data over a period of three (3) calendar days from December 14th through 16th 2023. The data include sound measured near critical residential locations and reference sound level measurements made on the Tesla property adjacent to the future simple cycle Gas Turbine units. 2.0 EXECUTIVE SUMMARY Each of the LM2500Xpress simple cycle Gas Turbines (GT) packages (without exhaust noise contributions) are estimated to achieve approximately 59 dB(A) at 400 feet. The GT units' exhaust systems will include and SCR and exhaust stack silencer. The SCR provides a substantial amount of low and mid -frequency noise reduction, thus minimizing the chances of infrasound related noise issues. When an exhaust silencer is added to the GT package, the overall plant community sound levels are reduced by more than 10 dB(A) and the exhaust system becomes a minor audible noise source that does not appreciably contribute to the overall gas turbine package noise. Additional recommended facility noise abatement includes insulation and lagging to the fuel gas conditioning and metering piping and valves. With the above noise abatement, the facility is estimated to achieve approximately 72 dB(A) at the plant boundary lines and approximately 48 dB(A) at the nearest resident located approximately 0.4 miles south-south-east of the facility along County Road 55. All other existing residents are estimated to experience sound levels less than 45 dB(A). The proposed Pioneer Village development, located more than one mile west of the Mountain Peak Power Project, is estimated to experience sound levels between 35 and 40 dB(A) at the closest points of the development located along County Road 22 and less than 35 dB(A) for most of the development located farther to the west -north-west. The sound levels of the facility will be comparable to the normal background sound usually observed in typical quiet suburban 1 Power Acoustics, Inc. Mountain Peak Power Project Sound Study neighborhoods. The Mountain Peak Power facility is not anticipated to be noticeable within most of the Pioneer Village development. A twenty-five (25) foot tall property boundary sound wall was evaluated and determined to be effective at reducing sound close to the wall (25 feet from the property boundary), but was not found to be effective at reducing community sound (<1 dB(A) improvement at 1/2 mile). The existing community sound was observed to be low, mostly in the mid -30's dB(A) range, but dipped as low as the mid -20's dB(A) during a brief period of low/no wind. Since the area is rural with minimal noise sources, low sound levels can occur throughout the daytime and nighttime. The existing ambient sound was observed to be primarily related to distant road traffic from Interstate 76 and County Road 49, occasional local road traffic and wind. Because of the low existing sound levels, the facility will be slightly audible within the community. 3.0 SIMPLE CYCLE GAS TURBINE ADDITION Kindle Energy LLC has proposed to add six (6) aeroderivative LM25OOXpress simple cycle Gas Turbines adjacent to the existing United Power Tesla Substation in Weld County, Colorado. A representative conceptual view of the Mountain Peak Power Project can be seen in Figure F3-1. The LM25OOXPRESS Gas Turbines are 95% factory assembled modules to expedite site installation. Figure F3-1. Proposed Conceptual Layout of the Mountain Peak Power Project (showing main noise sources only) 2 Power Acoustics, Inc. Mountain Peak Power Project Sound Study 4.0 MEASUREMENT METHODOLOGY, INSTRUMENTATION AND CONDITIONS 4.1 Sound Measurements and Methodology The existing ambient sound levels, from which the impacts for this facility were evaluated, were measured over a three -calendar day period December 14th through 16th 2023. The ambient sound levels were measured at representative locations near the proposed site with emphasis given to residential locations. The sound survey principles were based on the on Colorado Statutes, Weld County Noise Code, ANSI, ASME and ASTM standards such as ASTM E 1503 "Standard Test Method for Conducting Outdoor Sound Measurements Using a Digital Statistical Sound Analysis System" [1,2,3,4,5]. The metrics used* for evaluating the sound include: A -weighted statistical sound level data LA10, - the loudest 10% of the measurement period LA50 - the median sound level of the measurement period LA90 — the residual sound level, or quietest 10% of the measurement period. * See Appendix B for all definitions of acoustical terminology. 4.2 Sound Measurement Instrumentation The community sound level measurements were made using RION NL-52ex Precision Sound Level Meters and Frequency Analyzers. Sound analyzers were equipped with a half -inch microphones and windscreens. The instrumentation meets ANSI 51.4 [2] Type 1 (precision) requirements for acoustical measuring devices. Specific equipment used in the measurements is shown in Table 4.1. Table 4.1. Sound Measurement Equipment Model and Serial Numbers Equipment Norsonic Field Calibration Source RION Type 1 Logging SLM RION Type 1 Logging SLM RION Type 1 Logging SLM RION Type 1 Logging SLM Model 1251 NL-52ex NL-52ex NL-52ex NL-52ex Serial Number 32841 00610182 00610181 00610180 00610179 Last Laboratory Calibration Location Used 05/16/2023 All 11/29/2023 11/29/2023 11/30/2023 11/30/2023 M-1 M-2 M-3 M-4 The sound measurement equipment was field calibrated immediately before and after each survey. The post calibration check indicated the measurement equipment had no significant drift in sensitivity (≤0.5 dB). All sound measurement equipment conforms to manufacturer's recommended intervals and standard practices for laboratory calibration. Copies of laboratory certificates of calibration are on file and available for review upon request. 4.3 Personnel Performing the Sound Survey All Sound Survey measurements were made by David Parzych, INCE.Bd.Cert., Principal Consultant, Power Acoustics, Inc. Qualifications and r�sum� are provided in Appendix A. Power Acoustics, Inc. Mountain Peak Power Project Sound Study 4.4 Weather Conditions Time histories of the weather conditions (temperature, humidity and wind) are provided in Figure F4-1. There was no precipitation during testing although the area had a dusting of fresh snow on evening of the 13t' (prior to the sound measurements). Mornings were foggy followed by clearing later in the day. 100 90 80 70 60 50 40 30 20 10 SSW 0 Heavy Fog ENE WNW ENE SSW SW WSW SW WSW SW 6:00 12:00 18:00 0:00 6:00 12:00 18:00 0:00 6:00 12:00 Decenber 14th 2023 December 15th 2023 December 16th 2023 Temperature (°F) Humidity (%) Wind Speed (mph) Figure F4-1. Weather Conditions 5.0 SOUND MEASUREMENT RESULTS 5.1 Measurement Locations Community sound level measurements were made at four (4) locations, M -1, M-2, M-3, and M-4. M-4 is a reference sound monitor located toward the south portion of the Tesla Substation property. The approximate UTM coordinates are shown in Table 5.1. The corresponding locations are presented in Figure F5-1 Table 5.1. Location of Noise Measurement Measurement Location UTM Coordinates, Zone 13T M-1 538573 E 4443242 N M-2 538217 E 4442427 N M-3 535443 E 4444010 N M-4 538432 E 4444048 N The community noise monitors' microphones were located on tripods approximately 5 feet above the ground. Power Acoustics, Inc. Mountain Peak Power Project Sound Study Figure F5-1. Ambient Sound Measurement Locations 5.2 Sound Level Data Ten (1O) minute time samples of the A -weighted LAio, LAso and LA90 sound level time histories are shown in Figure F5-2 through F5-6 for locations M -1, M-2, M-3 and M-4 respectively (see Appendix B for an explanation of terms). The character of the area is quiet, rural -agricultural land. The A -weighted LA90 sound levels (the residual sound levels) were found to be low with the quietest community levels observed to be between 24 to 30 dB(A) occurring during times of low to no wind. During times of moderate wind, typical LA90 sound levels were in the 35 dB(A) range. Most of the sound observed was from distant traffic from County Road 49 (to the west) and Interstate 76 (to the south) and wind related sound. Short duration "spikes" (LA10) in sound are primarily due to external sound sources such as wind gusts, aircraft or local road traffic. In general, the LA50 median sound levels, LA90 residual sound levels and LAio short duration "spikes" are found to all exist within a 1O dB(A) band indicating the sound levels are consistently low throughout the measurement sample period. �c c Power Acoustics, Inc. Mountain Peak Power Project Sound Study The typical and lowest A -weighted LA90 sound levels are summarized in Table 5.2 Table 5.2. Representative Lower Sound Levels Measured at Each Monitoring Location 70 65 60 55 50 45 40 35 30 25 20 15 10 5 0 6:00 70 65 60 55 50 45 40 35 30 25 20 15 10 5 0 6:00 Measurement Location Lowest LA90 Typical LA90 dB(A) dB(A) M-1 35 25 M-2 35 24 M-3 35 26 M-4 35 30 las ar T.A90= 35 48 A with levels as low as 75 dB(A)) Thursday Friday Saturday Dec 14, 2023 Dec 15, 2023 Dec 16, 2023 10:00 14:00 18:00 22:00 2:00 6:00 10:00 14:00 18:00 22:00 2:00 6:00 10:00 Time of Day, MST Figure F5-2. Location M-1 Sound Levels I \ - , :MIPW on Ili aii. as,` i 1 r z .,ART%;..mil!. i.Qs a a •aria'. a tag k 1 �`� ` LA90 = 35 dB(A) level 24 dB(A)) with minim mi — Thursday Friday Saturday Dec 14, 2023 > Dec 15, 2023 Dec 16. 2023 %< 1 1 I I I I I 1 I 1 11 1 >' 10:00 14:00 18:00 22:00 2:00 6:00 10:00 14:00 18:00 22:00 2:00 6:00 10:00 Time of Day, MST Figure F5-3 Location M-2 Sound Levels 6 -+- LA10 LA50 - LA90 -+- LA10 LA50 --- LA90 Power Acoustics, Inc. Mountain Peak Power Project Sound Study Sound Level, in dB re 20 micropascals Sound Level, in dB re 20 micropascals 70 65 60 55 50 45 40 35 30 25 20 15 10 5 0 I I an fm LA90 = 35 dB(A) with levels as low as 26 dB(A)) EMS alb Thursday Friday Saturday Dec 14, 2023 Dec 15, 2023 Dec 16, 2023 6:00 10:00 14:00 18:00 22:00 2:00 6:00 10:00 14:00 18:00 22:00 2:00 6:00 10:00 70 65 60 55 50 45 40 35 30 25 20 15 10 5 0 Time of Day, MST Figure F5-4. Location M-3 Sound Levels I I M - ...._ LA = 35 dB(A) with levels as low as 30 (1B(A)) 9 Thursday Friday Saturday Dec 14, 2023 Dec 15, 2023 Dec 16, 2023 I I r I I I , 1 I I I I I i 6:00 10:00 14:00 18:00 22:00 2:00 6:00 10:00 14:00 18:00 22:00 2:00 6:00 10:00 Time of Day, MST Figure F5-5. Location M-4 Sound Levels 7 LA10 - LA50 - LA90 -+- LA10 LA50 --- LA90 Power Acoustics, Inc. Mountain Peak Power Project Sound Study 6.0 PROJECT NOISE REQUIREMENTS The current minimum noise standards are defined in the Colorado Statutes [la] and Weld County Code [ib] requirements. In addition to the minimum standards, other accepted A -weighted criterion for audible sound and C -weighted criterion for infrasound have been included for evaluation purposes. 6.1 Colorado Revised Statutes 2022[la] The full text of the Colorado Revised Statutes 2022, ARTICLE 12 can be found in Appendix C. A condensed version, with the main applicable sections, is provided here for clarity. Legislative declaration 25-12-101. The general assembly finds and declares that noise is a major source of environmental pollution which represents a threat to the serenity and quality of life in the state of Colorado. Excess noise often has an adverse physiological and psychological effect on human beings, thus contributing to an economic loss to the community. Accordingly, it is the policy of the general assembly to establish statewide standards for noise level limits for various time periods and areas. Noise in excess of the limits provided in this article constitutes a public nuisance. 25-12-103. Maximum permissible noise levels. (1) Every activity to which this article is applicable shall be conducted in a manner so that any noise produced is not objectionable due to intermittence, beat frequency, or shrillness. Sound levels of noise radiating from a property line at a distance of twenty-five feet or more therefrom in excess of the dB(A) established for the following time periods and zones shall constitute prima facie evidence that such noise is a public nuisance: Zone 7:00 a.m. to 7:00 p.m. 7:00 p.m. next 7:00 a.m. Residential 55 dB(A) 50 dB(A) Commercial 60 dB(A) 55 dB(A) Light Industrial 70 dB(A) 65 dB(A) Industrial 80 dB(A) 75 dB(A) (2) In the hours between 7:00 a.m. and the next 7:00 p.m., the noise levels permitted in subsection (1) of this section may be increased by ten dB(A) for a period of not to exceed fifteen minutes in any one -hour period. (3) Periodic, impulsive, or shrill noises shall be considered a public nuisance when such noises are at a sound level of five dB(A) less than those listed in subsection (1) of this section. 6.2 Weld County CHAPTER 14 - Health and Animals - ARTICLE IX Noise [lb] The full text of the Weld County ordinance be found in Appendix D. A condensed version, with the main applicable sections, is provided here for clarity. Sec. 14-9-40. Maximum permissible noise levels. A. Sound levels shall be measured as provided for in Section 14-9-50 below. B. Sound levels are hereby established for each type of property during specific hours of the day. Any sound level which exceeds the level set for a type of property at any time of day is prohibited. Power Acoustics, Inc. Mountain Peak Power Project Sound Study Land Use Maximum 7:00 a.m. Noise — 9:00 (dB(A)) p.m. Maximum 9:00 p.m. Noise (dB(A)) — 7:00 a.m. Residential Property or Commercial Area 55 dB(A) 50 dB(A) Industrial Area or Construction Activities 80 dB(A) 75 dB(A) Nonspecified Areas 55 dB(A) 50 dB(A) C. Between the hours of 9:00 p.m. and 7:00 a.m., the noise levels set forth above may be exceeded by up to ten (10) decibels for up to fifteen (15) minutes in a one -hour period. Sec. 14-9-50. Measurement and classification of noise. A. For the purpose of measuring a noise to determine if a person has violated Section 14-9-40 above, the following requirements for measurements must be met: 1. A noise originating within a public right-of-way or other public land shall be measured at a distance of at least twenty-five (25) feet from the source of the noise. 2. A noise originating on private property shall be measured at or within the boundary of the property from which the noise complaint is made. 3. A noise shall be measured on a weighing scale on a sound level meter of standard design and quality and in accordance with the standards promulgated with the American National Standards Institute. 4. Measurements with sound level meters shall be made when a wind velocity at the time and place of such measurement is not more than five (5) miles per hour, or more than twenty-five (25) miles per hour with a windscreen properly attached to the microphone. (Weld County Code Ordinance 2008-4) Sec. 14-9-60. Exceptions. The provisions of this Article shall not apply to: I. Any noise made by public utilities regulated pursuant to Title 40, C.R.S. 6.3 USEPA and American National Standards Institute (ANSI) Acceptable Audible Sound The USEPA [6] has published a report to define applicable goals for community noise levels. The report, often referred to as "the levels document," defines sound levels in terms of day/night average sound level, or DNL, for compatible land uses. The American National Standard, ANSI 512.9-2007(R2012), "Quantities and Procedures for Description and Measurement of Environmental Sound - Part 5: Sound Level Descriptors for Determination of Compatible Land Use"[7], uses an updated database to expand the EPA guidelines. The day/night average sound level, DNL, is a 24 -hour measurement with a mathematical weighting or penalty of 10 dB(A) applied to sound levels generated at nighttime between the hours of 10 PM and 7 AM. For residential * suburban homes* with extensive outdoor use, a DNL of 55 would be considered fully compatible with the ANSI S12.9 part 5 requirements. In addition, this aligns with the DNL level requirement of 55 used by the Federal Energy Regulatory Commission when siting gas compressor station projects located near all residential use properties. Although atypical, the new Gas Turbines could operate 24 hours per day. Therefore, to account for the DNL 10 dB(A) nighttime penalty, the facility would need to achieve the 55 DNL criterion Power Acoustics, Inc. Mountain Peak Power Project Sound Study less 7 dB(A). For a Gas Turbine -based power plant, this translates into a continuous 24 -hour A - weighted sound level (LAeq) of 48 dB(A). Beneficial Goal 1: Achieve 48 dB(A) or less at the noise critical receptors. 6.4 Sound Level Goals to Achieve a Negligible Increase in Community Noise A more difficult goal for the new Gas Turbine facility would be achieving no significant increase in sound levels measured at the residential properties. This would require setting the facility sound requirements equal to the existing lower envelope of the measured residential use sound levels. This goal, when added to the existing sound, will result in sound levels approximately 3 dB(A) higher than the existing sound. A 3 dB(A) increase is the smallest incremental change that a human's hearing can perceive. It should be noted that it is very unlikely that any facility could achieved this level of "quiet" at all locations given the extremely low existing sound levels. Beneficial Goal 2: Achieve a Negligible Noticeable Increase in Sound Level by meeting the sound level goals presented in Table 6.1. Table 6.1 Sound Level Goals for No (or Negligibly) Noticeable Increase Measurement Location Low/Typical dB(A) LA90 M-1 25-35 M-2 24-3 5 M-3 26-35 M-4 3 0-3 5 6.5 Low Frequency Infrasound Goals Simple cycle Gas Turbines can produce substantial levels of low frequency noise (Infrasound) that has the potential to induce vibration in framed structures. The low frequency sound is generally not heard, but felt as vibration in the structure. According to ASME's B133.8 - 2011(R2022)[8], "Gas Turbine Installation Sound Emissions, Nonmandatory Appendix B, Guide To Determining Specified GWeighted Sound Levels," the C -weighted sound level outside the nearest framed structure with noise sensitive receptors should not exceed an upper limit of 75 dB(C) to 80 dB(C). The range of values is given because there is some uncertainty as to the sound level required to induce structural vibration in a framed structure. Beneficial Goal 3: Achieve the lower envelope suggested in the ASME B133.8 standard of 75 dB(C) or less at residential locations. 6.6 Tonal/Impulsive Noise Goals and Requirements Gas turbine facilities generally do not produce significant tonal or impulsive sounds in the community. 7.0 COMMUNITY NOISE MODEL AND ESTIMATED SOUND LEVELS The environmental noise modeling was performed with a 3-D computer -based sound propagation model for calculating outdoor noise propagation in community and industrial environments. The computer model is based on the International Standard ISO 9613, parts 1 and 2[9,10]. The worldwide accepted standard specifies methods for calculating noise attenuation of outdoor 10 Power Acoustics, Inc. Mountain Peak Power Project Sound Study (environmental) noise sources at specified distances from a large variety of equipment under favorable (downwind) noise propagation conditions. Predictions made under favorable noise propagation conditions result in predicted sound levels that are usually conservatively high. However, there are anomalous situations that can occur that could result in occasional higher sound levels than those predicted. This would be associated with combinations of atmospheric conditions such as a temperature inversion combined with downwind conditions or sound traveling over a body of water that is cooler than the air above it. The sound propagation model accounts for the following attenuation and reinforcement of sound: Spherical (or Hemispherical) Divergence. Atmospheric Absorption. Ground Absorption. Screening (sound barriers). Sound Reflections. The geometric representation of the sound sources and structures considered are shown in Figure F7-1. Each sound source is modeled as a three-dimensional surface source. Large surfaces, such as the buildings, enclosures and tanks are modeled as surfaces that create sound barriers and sound reflectors to the Gas Turbines and other noise sources. All sound receivers are modeled to be 5 feet above ground unless noted. The analytical noise model includes the Gas Turbines and associated packages [11], exhaust system [12], air compressors, and transformers sound sources [13,14] only (i.e. no noise is modeled or included from the road or air traffic in the model). Figure F7-1. Wireframe of 3-D Analytical Acoustical Model of the Facility 7.1 Estimated A -weighted Sound Levels of the Mountain Peak Power Project Each GE LM2500Xpress simple cycle Gas Turbine package design meets approximately 59 dB(A) at 400 feet. The SCR and exhaust components include a silencer and do not appreciably add to the GE LM2500Xpress Gas Turbine Package sound levels. The facility modeling includes the GE LM2500Xpress noise components [11] and the exhaust equipment[ 1 2] and balance of plant equipment such as the main generator step up transformers, fuel gas conditioning and metering 11 Power Acoustics, Inc. Mountain Peak Power Project Sound Study and instrument air compressors [13,14]. Additional noise abatement includes insulation and lagging to the fuel gas conditioning and metering piping and valves. Sound levels used in the analysis are provided in Appendix E. The estimated A -weighted sound contours of the Mountain Peak Power Project are shown in Figure F7-2 relative to the property boundaries. The maximum sound level at the property boundary is estimated to be approximately 72 dB(A). The estimated community noise A -weighted sound contours of the facility are shown in Figure F7- 3. The closest critical noise receptor located approximately 0.4 miles south-south-east of the proposed Mountain Peak Power Project facility along County Road 55 is estimated to be less than 48 dB(A). Other residents living farther south on County Road 55 will experience sound levels between 40 dB(A) and 45 dB(A). South of County Road 20 and west of County Road 53 sound levels are estimated to be below 40 dB(A). The proposed Pioneer Village development, located more than one mile west of the Mountain Peak Power Project, is estimated to experience sound levels between 35 and 40 dB(A) at the closest points of the development located along County Road 22 and less than 35 dB(A) for most of the development located farther to the west -north-west. The sound levels of the facility is estimated to be comparable to the normal background sound usually observed in typical quiet suburban neighborhoods. The Mountain Peak Power facility is not expected to be a noticeable noise source within the majority of the Pioneer Village development. The existing community sound was observed to be low, mostly in the mid -30's dB(A) range, but dipped as low as the mid -20's dB(A) during a brief period of low/no wind. Since the area is rural, the low sound levels occur throughout the daytime and nighttime. The existing ambient sound was observed to be primarily related to distant road traffic from Interstate 76 and County Road 49, local road traffic and wind. With the low existing sound levels, the facility will be occasionally audible within the community. The highest contributing noise sources of the Gas Turbine packages are the generator compartments and ventilation. Reducing the Gas Turbine package noise further would require sound walls that are taller than the generator/ventilation system, (25 -foot tall walls) before a noticeable noise reduction (about 12 dB(A)) would occur near the facility's property boundaries. However, the benefits of the walls are significantly diminished with increased distance from the barrier walls and would provide little improvement (< 1 dB(A)) for community locations more than %2 mile from the project. See Appendix F for the detailed estimates/evaluation. 7.2 Estimated C -weighted Sound of the Mountain Peak Power Project The C -weighted sound provides an indication of the facility's ability to cause an infrasound issue. The estimated C -weighted sound contours Mountain Peak Power Project are shown in Figure F7- 4. The C -weighted sound levels are estimated to be below the 75 dB(C) design goal at the residential receptors and therefore meet the ASME B133.8 recommended criteria for minimizing the likelihood of infrasound induced vibrations. Power Acoustics, Inc. -, , Mountain Peak Power Project Sound Study 69 TER. t SERVICE cairmaa ROOM i LOCKER WAIER TANK 30147 1b9ild},(h) -- LOADING 131-1Or crier'? CSI; -1 (3W?i31'X21' N TYP) •— PROPERTY ECUkDRY �~ GROUNDI / RFTFNTC?7 FOND WJILDINCi 1RANSI-UKMER TRRAN,4FFR B'NTrQH lTX1A'XS AIR COMPRF.4,Sr)AS FIRE rump ENCLOSURE 32;(169{10' {hl LIG UTILITY AND ELIUIPMEriTACCEGS AREA rsu-1 •'l$U-3 18O1X23C. <1/ way FENCE 8 GAT= rUCL SAS CONDITIONING EQUIPMENT 2OO6%1C' rI PARKING HAZAAJOUS AREA I1'P) U- CS)J-I 7 G9Ur9 GSUsl FUTURE ^5FGT1ONAI I? BREMERANO . DISCONNECTS+ alS • D 47XMAUI' iIII • IY IJ F . PrnvFR HAZARDOUS AREA (TYP; DETP)i - CTG EQUIPMENT GSU 6 GSU& GSU-5 GSihS SWITCHYARD :AY DOMPRIEFO SCSTING NC1R I H -HOUND F kV T -I INF EXThithEIED EXISTING SUBSTATION {6S' WM 9.2A'I 1422'-I? X 133'-6 XAPPROX OUR' 4k) MAXIMUM) r- .iYROAD 2a 3O DRA1 EASEINENT NNECTS ICIIIEILC Urcnau r l TAKE OFF S'Nkx:- r IJRE Nal EXISTING PUMP ROUSE ITC BE*2A'C 161$ EXISTING WELL (10 DE ABANDONED} — NONCONTROL BUILDING — EXISTING SUBSTATION CUPJRIJI BOIL DINO EXIS-1hC FENCE{TYP) NEW FENCE S IRATE r.•, 377 DRAJ EASEMENT Sc' C -CUNT` RIGHT-OF-WAY (—x_x tx_ Figure F7-2. Analytically Estimated A -weighted Sound Levels of the Mountain Peak Power Project Relative to Property Boundaries 13 Figure F7-3. Analytically Estimated Community Noise A -weighted Sound Levels of the Mountain Peak Power Project Figure F7-4. Analytically Estimated Community Noise C -weighted Sound Levels of the Mountain Peak Power Project Power Acoustics, Inc. Mountain Peak Power Project Sound Study 8.0 REFERENCES 1. Statutes and Codes a.) Colorado Revised Statutes 2022, ARTICLE 12, Noise Abatement b.) Weld County CHAPTER 14 - Health and Animals - ARTICLE IX, Noise 2. ANSI/ASA S 1.4-2014/Part 1/ IEC 61672-1:2013 "American National Standard Electroacoustics - Sound Level Meters - Part 1: Specifications (a nationally adopted international standard)". 3. ANSI S 12.9-2013/Part 3 "Quantities and Procedures for Description and Measurement of Environmental Sound - Part 3: Short-term Measurements with an Observer Present" 4. ASME PTC-36 — 2018, "Measurement of Industrial Noise" 5. ASTM E 1503 - 14, "Standard Test Method for Conducting Outdoor Sound Measurements Using a Digital Statistical Sound Analysis System" 6. U.S. EPA (U.S. Environmental Protection Agency). Information on Levels of Environmental Noise Requisite to Protect Public Health and Welfare with an Adequate Margin of Safety. 1974. 7. ANSI 512.9-2007(R2012), Part 5 "AMERICAN NATIONAL STANDARD, Quantities and Procedures for the Description and Measurement of Environmental Sound. Part 5: Sound Descriptors for Determination of Compatible Land Use." 8. ASME B133.8 2011(R2022 "Gas Turbine Installation Sound Emissions" 9. ISO 9613-1:1993, "Acoustics - Attenuation of Sound During Propagation Outdoors - Part 1: Calculation of The Absorption of Sound by the Atmosphere" 10. ISO 9613-2:1996, "Acoustics - Attenuation of Sound During Propagation Outdoors - Part 2: General Method of Calculation" 11. GE LM2500Xpress Sound Power Level Data, dated 12/13/2023 12. Energy Link International Exhuast System Design Project: Q23089, dated 12/21/2023 13. Power Acoustics, Inc. equipment sound level database 14. Edison Electric Institute, "Electric Power Plant Environmental Noise Guide", Volume I, 2nd Edition, Published 1978 and Updated 1983. Power Acoustics, Inc. Mountain Peak Power Project Sound Study APPENDIX A - Reporting Consultant's R�sum� Power Acoustics, Inc. Mountain Peak Power Project Sound Study DAVID J. PARZYCH Power Acoustics, Inc. March 1998 to present Dave Parzych has over 30 years of experience in acoustical engineering and noise control design and is the principal and founder of Power Acoustics, Inc. Since 1998, he has provided a full range of acoustical consulting services for over 300 clients and several hundred projects including; sound measurements, analytical modeling studies and working as an expert witness in industrial, commercial, transportation and residential applications. Mr. Parzych has also developed a commercial software package, SPM9613, used worldwide in community noise modeling. He is known as an expert in outdoor sound propagation and modeling, power plant noise and Gas Turbine silencing. He has developed suitable community noise criteria, designed noise controls for and/or verified facility acoustical compliance through specialized sound tests for several dozen power plants situated throughout the world. He has also designed noise abatement for many industrial, commercial and residential buildings. Dave has been an invited speaker and author in conference sessions sponsored by the Acoustical Society of America and the Institute of Noise Control Engineering on noise modeling and measurements of power plants, industrial facilities and modeling the performance of sound barrier walls. He has testified in several court cases, including Federal court, on noise prediction, acoustical measurements and data interpretation. October 1992 to February 1998 Mr. Parzych was a Senior Noise Control Engineer and Technical Group Leader of Acoustics in the Environmental Engineering group at Westinghouse Power Generation. From 1992 through February of 1998 he led the development of noise control and state-of-the-art research in modeling and diagnostics techniques. Mr. Parzych was responsible for the acoustical silencing and design of combustion turbines, aerodynamic source modeling of turbo -machinery noise, overall acoustical design of combustion turbine, steam turbine and cogeneration projects and environmental modeling to determine community impacts and worker noise exposure. October 1983 to October 1992 From 1983 to 1992, Mr. Parzych gained experience in aircraft noise through an intensive effort to develop a quiet counter -rotating Prop -Fan aircraft engine as an Analytical Acoustical Engineer at United Technologies Corp., Hamilton Standard Division. Mr. Parzych has been an investigator on several NASA funded research projects involving acoustics and unsteady aerodynamics of propellers, Prop -Fans and wind turbines. Power Acoustics, Inc. Mountain Peak Power Project Sound Study May 1982 to October 1983 Dave began his professional career as an acoustical engineer in 1982 with General Dynamics, Electric Boat Division in Groton, Connecticut working in airborne and structureborne silencing for the on -board nuclear power plants used in the US NAVY submarine fleet. EDUCATION Bachelor of Science in Engineering, Acoustics, University of Hartford 1982 Continuing education in acoustics and noise control including aero-acoustics offered at the Catholic University in Washington D.C. and many seminars and conferences on acoustics and noise control. CERTIFICATION AND PROFESSIONAL ACTIVITIES • Board Certified - Institute of Noise Control Engineering • Licensed Professional Engineer, State of Oregon, with specialty in Acoustical Engineering (PE 18940) • Full Member Acoustical Society of America • Principal/Firm Member National Council of Acoustical Consultants • Full Member ASME • Full Member ASTM • Chairman of ANSI B133.8, subcommittee 7, Gas Turbine Installation Sound Emissions (1997-2000) • Member of ANSI B133.8, subcommittee 7, Gas Turbine Installation Sound Emissions (2000-2008) • Member ASTM E33 Committee on Environmental Noise (current) • Chairman ASME Codes and Standards Committee PTC-36 "Measurement of Industrial Sound" (2012-2015), Vice Chair (2015-2018) PATENTS Patent Number 5,709,529, January 20, 1998, "Optimization of Turbomachinery Harmonics" TECHNICAL PAPERS INTERNOISE 2018 Resolution of an Environmental Noise Problem Caused by a 345 KV Power Pole, 2018. INTERNOISE 2015 ASME Noise Standards; Present and Future, 2015. (Invited Paper) INTERNOISE 2012 Proceedings, Combustion turbine silencer design, selection and applications, 2012. (Invited Paper) INTERNOISE 2009 Proceedings, Challenges of unanticipated power plant startup noise, 2009. (Invited Paper) NOISE CON 2007 Proceedings, Methods to Eliminate Continuous and Variable Background Noise Sources, October 2007. (Invited Paper) INTER -NOISE 2006 Proceedings, Modeling the reduced insertion loss of a sound barrier in a downward refracting atmosphere for a petrochemical plant, December 2006. (Co-authored) Power Acoustics, Inc. Mountain Peak Power Project Sound Study INTER -NOISE 2006 Proceedings, Modeling uncertainty creep due to variability in model constituents, December 2006. (Co-authored) NOISE CON'2004 Proceedings, Handling of Barriers in ISO 9613-2, July 2004. (Invited Paper) NOISE CON'2003 Proceedings, Issues In Determining Sound Power Levels of Gas Turbine Exhausts, June 2003. (Invited Paper) Air and Waste Management 94th Annual Conference Proceedings, Paper #603, Estimating Community Sound Levels of Large Industrial Facilities, June 2001. Joint ASA, INCE, NOISE CON'2000 Proceedings, Using A Prediction Model To Allocate Allowable Noise Between Sources And Establish Equipment Noise Limits, 2000. (Invited Paper) INTERNOISE'99 Proceedings, Predicting Far Field Sound Levels of Large Industrial Noise Sources Using Point Source Radiation Models, 1999. (Invited Paper) NOISE CON' 98 Proceedings, An Experimental Investigation of Combustion Turbine Exhaust Stack Silencer Performance, 1998. NOISE CON'96 Proceedings, An Experimental Investigation of Combustion Turbine Exhaust Noise Sources, 1996 INTERNOISE'96 Proceedings, Low Frequency Noise - Approaches and Designs for Combustion Turbines, 1996, (Co-authored) INTERNOISE'95 Proceedings, Understanding the Noise Generation Mechanisms of Industrial Combustion Turbines and Designing Effective Noise Control Treatments, 1995. DGLR/AIAA, An Assessment of Wake Structure Behind Forward Swept and Aft Swept Prop -Fans at High Loading, 1992, (Co-authored) DGLR/AIAA-92-02-049, Near Field Noise Theory for Propellers with Angular Inflow, 1992, (Co- authored) AIAA-91-0705, Temporally and Spatially Resolved Flows Within and Aft of a Single Rotation Prop -Fan, 1991, (Co-authored) AIAA-3979, Modal Evaluation of Noise Generated by the Front Rotor of a Counter -Rotating Prop -Fan, 1990. AIAA-90-3978, Vortex Structure of Wakes Behind an Advanced Propeller at Take -off Load Conditions, 1990, (Co-authored) AIAA-89-1094, Interaction Noise Mechanisms for Advanced Propellers, Analytical Evaluation, 1989. SAE 871839, Prop-Fan/Turboprop Acoustic Terminology, 1987. AIAA-86-1895, Noise of the Fairey Gannett Counter Rotating Propeller, 1986. Power Acoustics, Inc. Mountain Peak Power Project Sound Study APPENDIX B - Discussion of Acoustical Terms Power Acoustics, Inc. Mountain Peak Power Project Sound Study Assessing sound requires relationships between the physical properties of sound, which can be measured by instruments, and the corresponding human reaction through empirical means. Discussed within this Appendix is a description of terms necessary to understand the report. Sound Level (Decibel) Current sound measurement standards use a logarithmic decibel (dB) scale, which compares the measured sound pressure to a reference pressure of 20 micropascals. A sound pressure of zero (0) dB is approximately the lowest sound level humans can hear. Actual sounds, however, often cannot be distinguished if they are substantially below the existing ambient sound. As a basis of comparison, a 10 dB increase of a steady state sound (continuous, non -varying sound) is generally perceived as a doubling of sound level while increases in steady state sounds of 3 dB are considered to be just perceivable. Note sound levels described in decibels do not add arithmetically but the "sound pressures" do. Therefore, two sounds of equal magnitude will be 3 dB louder than a single sound source - i.e. 50 dB + 50 dB = 53 dB — not 100 dB and ten sound sources of equal magnitude will be 10 dB louder than a single sound source. Sound Spectrum (Frequency) Sound is comprised of a broad range of frequencies. The frequencies typically heard by humans are considered to range between 20-20,000 cycles per second (cps). A cycle per second is also called a "Hertz" or abbreviated as "Hz". To illustrate typical audible frequencies, we've annotated a piano keyboard as shown below. An increase in frequency of one octave means the frequency has doubled. RR cjIA r2 4 AO 27.5 Hz Al A2 A3 A4 A5 A6 55 Hz 110 Hz 220 Hz /M0 Hz 880 Hz 1760 Hz Range of Frequencies on a Standard Piano Keyboard A? 3520 Hz For scientific and industrial use, fixed "bands" or ranges of frequencies are used to describe the summation of many frequencies of the sound. Standardized octave band center frequencies are 31.5 Hz, 63 Hz, 125 Hz, 250 Hz, 500 Hz, 1000 Hz, 2000 Hz, 4000 Hz and 8000 Hz. The lower range of the frequency is the octave band center frequency times -\/2/2 (0.707) and the upper range is the octave band center frequency times the J2 (1.414). The frequency content of noise sources is necessary to develop appropriate noise control. A -weighting (Simulated Perceived Loudness By Humans) The A -weighted sound level, dB(A), simulates (electronically through a filter network) the perceived response of the human ear. A -weighting deemphasizes very low frequencies and very high frequencies where humans hear the poorest. Although all frequencies of sound contribute to the A -weighted level, sounds between 250 Hz to 4000 Hz generally have the largest impact on measured A -weighted sound levels. Power Acoustics, Inc. Mountain Peak Power Project Sound Study C -weighting (Often Used for Assessing Infrasound Induced Vibrations) The C -weighted sound level, dB(C), is primarily a "flat frequency weighting" and is often used to characterize the effects of very low frequency sound (Infrasound) and its potential to induce vibration in structures. Time Averaging of Sound and Statistics Leq, Lio, Lso, and L90 The equivalent sound pressure level, or Leq, is the time -averaging of a fluctuating sound. The Lea has the equivalent sound level as a steady state or non -varying sound that would be observed over the same period of time that the fluctuating sound was measured. When evaluating ambient noise or sound that is influenced by transient or moving sources, statistical sound data are often used. Statistical sound data allows extraneous sounds to be deemphasized or shorter term transient sounds to be extracted. Sound statistics often used in evaluating environmental noise are Lio, Lso, and L9o. These statistics correspond to the sound level exceeded 10% of the time, the sound exceeded 50% of the time (the median sound level) and the sound exceeded 90% of the time respectively. Note the average or equivalent sound level, (Leq), can be substantially different than the median sound level (Lso). L9o, or the sound level exceeded 90 percent of the time, is commonly used to understand community sound levels since it tends to reduce the effect of short duration extraneous sounds not necessarily typical of the environment being measured. The L90 is thought of as the residual or broad area sound level in the community — basically the sound you hear when all the local traffic passes, no airplanes are overhead and localized human or mechanical noise are minimal. Think of the brief moment of quiet when you only hear the sound of distant road traffic. Another way of thinking about L90 is that data taken over a measurement time of 10 minutes would provide sound levels at or below the L90 for a total duration of only one (1) minute. Nine (9) minutes of the ten (10) minute data sample time, the sound level will exceed the L90 level. Lio, or the sound exceeded 10% of the time, indicates that 1 minute out of ten, the sound level was equal to or higher than the value given. The Lio is useful in defining sounds that change in level due to transient sound sources, such as nearby movement of vehicles. L50 is the "median sound level." Half the time the sound level was lower than the reported L50 and half the time it is higher than the reported L50. Compounding of Sound Descriptors The use of dB(A) or dBA indicates the sound pressure level (in dB) has been A -weighted. Similarly, the use of LAeq, LAio, LAso, and LA90 indicates the average or statistical values reported have been "A -weighted" where standard Leq, Lio, Lso, and L90 represent unweighted or linear sound levels. Occasionally, a more cumbersome description, such as "A -weighted LXX" or other statistic is used represent the LAeq, LAio, LAso, or LA90 Sound Power Level Sound power is the rate which sound energy is emitted per unit time. Sound power is not dependent on distance from the sound source or the environment the sound source is in. On the other hand, sound pressure is highly sensitive to its environment and distance from the sound source. Sound power is analogous to the power rating on a light bulb. For a given type of light Power Acoustics, Inc. Mountain Peak Power Project Sound Study bulb technology, a bulb with a higher power rating would produce more light. However, the environment the light bulb is put in (room paint color, lamp shape, distance from the light bulb, etc.) will determine how much light is ultimately observed. When sound power is presented as a "level", it shares the same logarithmic decibel (dB) scale as sound pressure level but uses a reference of 1 picowatt as its basis. Sound Losses, Noise Reduction or Attenuation In an overly simplistic view, sound attenuation is the difference, in dB, between the sound incident on a device (such as a wall or muffler) and the sound that is transmitted through the device. It is typically reported as a function of frequency. Some typical losses include: • Transmission Loss (TL) is used to describe effectiveness in reducing noise from walls, silencers or enclosures after corrections for the influences of the environment have been made. • Sound Transmission Class (STC) is a single number descriptor of Transmission Loss values that have been curve fit to a prescribed frequency spectrum shape. Higher numerical ratings are generally better at reducing noise than lower numerical ratings are but the detail of the reduction at individual frequencies is lost in the simplification. • Noise Reduction (NR) is used to describe the in -situ difference of sound on the source side and receiver side of a noise control device. • Insertion Loss (IL) is used to describe the difference of sound measured or calculated on the receiver side of a noise control device before and after the noise control device was put into service. Examples of Typical Sound Source Levels COMMON OUTDOOR ACTIVITIES NOISE LEVEL dB(A) COMMON INDOOR ACTIVITIES ---110--- Rock Band Jet Fly -over at 1000 ft ---100--- Gas Lawn Mower at 3 ft ---90--- Diesel Truck at 50 ft, at 50 mph ---80--- Food Blender at 1 m (3 ft) Garbage Disposal at 1 m (3 ft) Noise Urban Area (Daytime) Gas Lawn Mower at 100 ft ---70--- Vacuum Cleaner at 10 ft Commercial Area Heavy Traffic at 300 ft ---60--- Normal Speech at 3 ft Large Business Office Quiet Urban Daytime ---50--- Dishwasher Next Room Quiet Urban Nighttime Quiet Suburban Nighttime ---40-- ---30--- Theater, Large Conference Room (Background) Library Quiet Rural Nighttime ---20--- Bedroom at Night, Concert Hall (Background) Lowest Threshold of Human Hearing ---10--- Lowest Threshold of Human Hearing ---0--- Source: California Dept. of Transportation Technical Noise Supplement, Oct. 1998. Page 18. APPENDIX C — Colorado Revised Statutes 2022, ARTICLE 12, Noise Abatement APPENDIX D — Weld County, CHAPTER 14 - Health and Animals - ARTICLE IX, Noise Sec. 14-9-10. Intent and applicability. A. It is hereby declared to be the intent of the Board of County Commissioners to protect the citizens of the County from excessive, unreasonable and unnecessary noise. B. This provision of the Code shall apply within the unincorporated territory of the County. (Weld County Code Ordinance 2008-4) Sec. 14-9-20. Definitions. For purposes of this Article, certain terms or words used herein shall be interpreted as defined in this Section. The following specific words and phrases, when appearing in this Chapter in uppercase letters, shall have the meanings stated in this Section. Agricultural Equipment means any equipment, vehicle, machine or device which is used on a farm or ranch, as those terms are defined in Sections 31-1-102(3.5) and 31-1-102(13.5), C.R.S., for the planting, growing and harvesting of agricultural products, or for the raising, care, maintenance, breeding and production of livestock. Agricultural equipment includes airplanes used for crop dusting. Ambient Noise Level means the lowest sound level repeating itself during a six -minute period, as measured with a sound level meter. The minimum sound level shall be determined with the noise source silent and in the same location as the measurement of the sound level of the source when emitting the sound under investigation. Commercial Area means an area where offices, clinics and the facilities needed to serve them are located; an area with local shopping and service establishments located within walking distance of the residents served; a tourist -oriented area where hotels, motels and gasoline stations are located; a large integrated shopping center; a business strip along a main street containing offices, retail business and commercial enterprises; a central business district; or a commercially dominated area with limited multiple - unit dwellings. Construction Activities means any and all activity incidental to the erection, demolition, assembling, alteration, installation or equipping of buildings, structures, roads and appurtenances thereof, including land clearing, grading, excavating and filling. dB(A) means a sound level in decibels measured in the "A" scale of a standard sound level meter having characteristics defined by the American National Standards Institute, Publication S1.4-1971. Decibel means a unit used to express the magnitude of a change in sound level. The difference in decibels between two (2) sound pressure levels is twenty (20) times the common logarithm of the ratio of that sound pressure level to a reference level of 2x10-5N/m2 . Device means any equipment or mechanism which is intended to produce or which produces sound when installed, used or operated. Excessive Noise means any sound which is, or may be: a. Harmful or injurious to the health, safety or welfare of any individual; b. Of such a volume, frequency and/or intensity that it unreasonably interferes with the enjoyment of life, quiet, comfort or outdoor recreation of an individual of ordinary sensitivity and habits; or c. Unreasonably interferes with the value of real property or any business conducted thereon. industrial Area means an area where manufacturing, processing or fabrication of any commodity, storage and warehousing, wholesale sales of equipment, materials and supplies, repair, servicing and rental of vehicles and other commodities and other similar activities are conducted. Muffler means a device consisting of a series of chambers or baffle plates or other mechanical design for the purpose of receiving exhaust gas from an internal combustion engine and which is effective in reducing noise. Person means any individual, association, partnership or corporation, and includes any officer, employee, department, agency or instrumentality of any association, partnership or corporation, the State or any instrumentality of the State. Property Boundary means an imaginary line along the ground surface and its vertical extension, which separates the real property owned by one (1) person from that owned by another person, but not including property divisions within a building. Public Right -of -Way means any street, avenue, boulevard, highway, sidewalk, alley or similar place which is owned or controlled by a governmental entity. Public Space means any real property or structures thereon which are owned or controlled by a governmental entity. Residential Property means any property which is occupied by a residence, including single-family or multi -family dwellings and apartments, and is located in a platted major residential subdivision, planned unit development or minor subdivision, or is located in the R, R-1, R-2, E, E-1, M or M-1 Zone District. It also includes hotels and motels, educational facilities, hospitals, nursing homes and similar institutions. Undeveloped areas adjacent to residential areas are considered to be residential areas for purposes of this Article. Sound means an oscillation in pressure, stress, particle displacement, particle velocity or other physical parameter, in a medium with internal forces. The description of sound may include any characteristic of such sound, including duration, intensity and frequency. Sound Level means the weighted sound pressure level obtained by the use of the sound level meter and frequency weighing network, as specified in the American National Standards Institute Specifications. Sound Pressure means the instantaneous difference between the actual pressure and the average or barometric pressure at a given point in space as produced by sound energy. Sound -Producing Device means any equipment or machine for the production, reproduction or amplification of speech, music or other sound, including but not limited to radios, televisions, phonographs, tape or compact disc players, musical instruments, walkie-talkies, CB radios or synthesizers. Vehicle means any device which is capable of moving itself or of being moved from place to place upon wheels or endless tracks. Vehicle does not include any wheelchair, as defined by Section 42-1-102(113), C.R.S.; any farm tractor or implement of husbandry designed primarily or exclusively for use and used in agricultural operations; any device moved by muscle power; any device moved exclusively over stationary rails or tracks; or any device designed to move primarily through the air. Sec. 14-9-30. Prohibition of excessive noise. No person shall engage in the following activities: A. Knowingly make, cause or permit to be made, or continue any excessive noise, as defined in this Article. B. Exceed the sound levels provided for in Section 14-9-40 below, and as measured in Section 14-9-50 below. C. Operate a vehicle in a public right-of-way and exceed the sound level provided for in Section 14-9-50 below. Sec. 14-9-40. Maximum permissible noise levels. A. Sound levels shall be measured as provided for in Section 14-9-50 below. B. Sound levels are hereby established for each type of property during specific hours of the day. Any sound level which exceeds the level set for a type of property at any time of day is prohibited. Land Use Maximum 7:00 Noise — 9:00 (dB(A)) Maximum Noise 9:00 — 7:00 (dB(A)) p.m. a.m. a.m. p.m. Residential Property or Commercial Area 55 dB(A) 50 dB(A) Industrial Area or Construction Activities 80 dB(A) 75 dB(A) Nonspecified Areas 55 dB(A) 50 dB(A) C. Between the hours of 9:00 p.m. and 7:00 a.m., the noise levels set forth above may be exceeded by up to ten (10) decibels for up to fifteen (15) minutes in a one -hour period. D. Vehicles operating in the public right-of-way are subject to the following maximum noise levels: Vehicle Class (GVWR) Maximum Noise in Speed Limit 35 m.p.h. or less zone Maximum Noise in Speed Limit over 35 m.p.h. zone Manufacturer's over vehicles 10,000 towed pounds gross by (4,536 such vehicle motor weight kg), or vehicle any rating combination (MGWR) of 86 90 limited Any vehicles trucks, than other 10,000 towed to automobiles, with motor a gross pounds vehicle by any vehicle (4,536 motor motorcycles, or any combination vehicle, weight kg) rating including vans or (GVWR) of light but less not 80 84 E. No person shall operate, anywhere in the County, any vehicle that is not equipped with a muffler in constant operation which is properly maintained to prevent noise in excess of that set forth in this Section; nor shall any person operate, in unincorporated Weld County, any vehicle having a muffler that has been equipped or modified with a cutoff, bypass or similar device or modification. Sec. 14-9-50. Measurement and classification of noise. A. For the purpose of measuring a noise to determine if a person has violated Section 14-9-40 above, the following requirements for measurements must be met: 1. A noise originating within a public right-of-way or other public land shall be measured at a distance of at least twenty-five (25) feet from the source of the noise. 2. A noise originating on private property shall be measured at or within the boundary of the property from which the noise complaint is made. 3. A noise shall be measured on a weighing scale on a sound level meter of standard design and quality and in accordance with the standards promulgated with the American National Standards Institute. 4. Measurements with sound level meters shall be made when a wind velocity at the time and place of such measurement is not more than five (5) miles per hour, or more than twenty-five (25) miles per hour with a windscreen properly attached to the microphone. 5. Vehicle noise shall be measured at a distance of at least twenty-five (25) feet from the mid -point of the lane being monitored, and at a height of at least four (4) feet above the immediate surrounding surface. B. No person shall operate or cause to be operated a motor vehicle, including a motorcycle, off a public right- of-way in a manner that causes the emission of a sound level which exceeds the limits set forth in Section 14- 9-40 above. Sec. 14-9-60. Exceptions. The provisions of this Article shall not apply to: A. Any noise resulting from any authorized emergency vehicle responding to an emergency call or acting in time of emergency. B. The sound made by any burglar, fire, personal safety or other warning device. C. Any noise made during the operation of aircraft or other activities which are preempted by federal law, with respect to noise control. D. Any noise made during the operation of agricultural equipment which is used on a farm or ranch in the production of agricultural products. E. Sounds made by dogs and by farm animals, including but not limited to bovines, goats, horses, fowl and llamas. F. Any noise related to the operation of a railroad. G Any noise related to the production, promotion or holding of cultural, entertainment, athletic or patriotic events (including but not limited to concerts), which are sponsored by the State, any political subdivision of the State or any of its lessees, licensees or permittees. H. Any noise related to the use of property for the purposes of conducting speed or endurance events involving motor or other vehicles, but only where such use has been authorized by resolution, variance permit or nonconforming use authorized by the political subdivision or governmental agency having jurisdiction to authorize such use, and only during the specific period of time that such use is authorized. I. Any noise made by public utilities regulated pursuant to Title 40, C.R.S. J. The sound made by a lawnmower, snow blower or other power or hand tool. K. Any noise related to a temporary assemblage permitted by the Board of County Commissioners pursuant to the provisions set forth in Chapter 12, Article I, of this Code. L. Any noise produced in the course of normal mining operations or oil and gas exploration, drilling and production. M. Any noise produced by persons engaged in lawful hunting activities or from properties used by gun clubs. N Any noise produced at a construction site. Sec. 14-9-70. Violations and penalties. A. Any law enforcement officer, authorized officers of the Department of Planning Services or the Health Official of the County is authorized to issue citations, summonses and complaints for violations of Sections 14-9-40 and 14-9-50 of this Article. B. Violations of provisions of this Article shall constitute a Class II petty offense. In addition, violations of this Article may be enforced through the penalty assessment procedure set forth in Section 16-2-201, C.R.S. C. The graduated fine schedule for the penalty assessment procedure is: 1. Thirty dollars ($30.00) for the first violation. 2. Sixty dollars ($60.00) for the second violation within twelve (12) months of the first violation. 3. Three hundred dollars ($300.00) for each successive violation within twelve (12) months of the first violation. In addition to any other penalty, persons convicted of a violation of this Article shall be subject to a surcharge of ten dollars ($10.00), payable to the Clerk of the Court. Sec. 14-9-80. Prosecution. It is the responsibility of the County Attorney to enforce the provisions of this Article, according to the County Court Rules of Criminal Procedure. Sec. 14-9-90. Civil enforcement. The Board of County Commissioners may seek civil relief, including but not limited to injunctive relief and mandamus, to enforce the provisions of this Article. APPENDIX E — Modeled Equipment Sound Sources Generator Skid Module Generator lube Oil System Switch. e it 1 Control House Module MCC GCP Battery System Generator Ventilation System RH Side Package and Associated Equipment Turbine Exhaust Turbine Ventilation Silencer Turbine Ventilation Fan Turbine Static Filter Modules 'for illustration purposes only. Always refer to your site -specific drawings. r • turbin.• Moduli, Gas Turbi cu. tube Oil System Exhaust Collector Fuel System Hydraulic Start Auxiliary Skid TCP Turbine Static Filter Module. Water Wash Cart T urbine Ventilation an Turbine Ventilation Silencer Control House Module MCC GCP Battery System Turbine Module Gas Turbine Lube Oil System Exhaust Collector Fuel System Hydraulic Start Auxiliary Skid TCP Generator Ventilation System LH Side Package and Associated Equipment 'for illustration purposes only. Always refer to your site -specific drawings. Generator Skid Module Generator l ubc Oil System sw;tthgear © COPYRIGHT 2023 General Electric Company (USA). All rights reserved. The information herein is Proprietary and Technically Exclusive content that is solely owned by General Electric Company and/or its affiliates. Thus, it is being provided with the explicit expectation of restricted and privileged use. All persons, or legal entities receiving this information shall be deemed by the act of its receipt to have contractually agreed to make no duplications, reproductions of any nature by any means, modifications, disclosures, or use any portion of this material; except as is expressly authorized in writing by General Electric Company and/or its legitimate affiliates. CUSTOMER: 1652466 PROJECT: PURPOSE: PWL for study - NOT FOR GUARANTEE ENGINEER: DATE: Quoc Nguyen 12/13/2023 Assumption: Outdoor, Lmxpress 60Hz, Andritz air cooled, gas Fuel. Exhaust noise is not included. Ref ft Name Sound Power Level PWL Day (dB(A)) A (+/- 2dB) 31.5 63 125 250 500 1000 2000 4000 8000 Lmxpress 78.8 93.3 106.3 100.8 100.7 102 101.1 92.1 83.5 110 CNTRROOM 54.9 63.6 71.4 60.2 70.5 73.5 72.8 70 60.2 79.1 GLO 60Hz 67.3 77.8 89.5 80.6 78.4 85.8 77.9 71.6 60.3 92 TURBINE VENTILATION-60hz 70.3 82.3 89.8 86.5 83.6 92.8 86.7 79 72.5 96.3 FAN 65.4 78.9 86.2 89.8 95.6 94.7 90 84.7 72.1 99.7 AUX Skid 68.4 82.1 89.5 88.7 88.9 85.4 83.8 78 66.3 95.1 TURBINE ENCLOSURE 72.4 89 93 93.3 90.8 91.4 91.7 85.7 78.4 99.7 AIR_FILTER LTE R 71.6 86.1 98.5 95.9 96.5 97.5 92.6 85.1 76.1 103.8 GEN_TB_COUPLING 60Hz 53.6 67.3 71.1 64.9 66.8 70.3 70 64 65.5 77.3 GEN 72.4 86.4 104.9 95.6 91.4 94.8 98.9 86.5 78.6 106.8 LM2500Xpress with Un-weighted Sound Power Levels Octave Band Center Frequency (Hz) Type Description 16 31.5 63 125 250 500 1000 2000 4000 8000 dB(A) dB(C) Un-weighted Sound Power Levels of GE LM2500xpress Components Lw: CNTRROOM Lw: G LO 60Hz Lw: TURBINE VENTILATION-60hz Lw: FAN Lw: AUX Skid Lw: TURBINE ENCLOSURE Lw: AIR_FILTER Lw: GEN_TB_COUPLING 60Hz Lw: GEN N 94.3 106.7 109.7 104.8 107.8 111.8 111.0 93.0 111.8 89.8 104.0 108.5 105.1 108.3 115.2 112.3 93.5 112.6 87.5 105.6 105.9 102.3 105.6 109.1 114.6 87.2 121.0 68.8 89.2 95.1 98.4 97.3 101.9 104.5 73.5 104.2 73.7 81.6 86.8 98.8 92.1 94.0 99.7 70.0 94.6 73.5 85.8 92.8 94.7 85.4 91.4 97.5 70.3 94.8 71.6 76.7 85.5 88.8 82.6 90.5 91.4 68.8 97.7 69.0 70.6 78.0 83.7 77.0 84.7 84.1 63.0 85.5 61.2 61.3 73.5 73.1 67.3 79.4 77.1 66.5 79.6 79 92 96 100 95 100 104 77 107 94 109 112 109 111 117 117 95 122 Lw: Linear sound power of All Sources of LM2500xpress 118.2 119.5 122.5 109.4 103.9 101.9 99.9 91.1 84.5 110 125 Exhaust System (preferred with Silencer) Acoustic Performance Summary LM2500+G4 - SCR & Stack - Low Noise 31.5 Gas Path Summary 63 125 250 Energy Link Project: Q23089 500 1000 2000 Date: 12/21/2023 4000 8000 dBA By: CG dB 31.5 63 125 250 500 1000 2000 4000 8000 LM2500 Exhaust LW Dynamic Insertion Loss Stacktop LW Casing Sound Power Levels 133 140 139 139 138 123 116 111 104 19 25 33 41 52 43 41 40 36 114 115 106 98 86 80 75 71 68 137 145 95 118 Inlet Expansion Joint Inlet Duct SCR/CO/DG Duct Silencer 1 Stack Base Silencer 2 & Tailpipe TA Fan 107 105 99 94 93 78 71 66 59 116 110 95 87 80 60 51 39 41 121 115 100 92 85 65 56 44 46 111 105 90 82 75 55 45 32 33 110 98 77 64 49 15 5 -7 17 107 92 67 51 34 22 16 4 10 92 110 87 117 91 122 82 112 74 110 70 107 Attenuated Inlet & Casing Lw 113 111 107 95 82 74 77 78 76 94 116 Stack 12ft 468 oC Angle 31.5 63 125 250 500 1000 2000 4000 8000 0 1.7 3.7 6.2 8.9 10.9 12.2 12.8 13 13 15 2.1 4 6.2 8.1 8.8 9 8.9 9 8.8 30 1.7 2.9 4.4 5.7 6.3 6.4 6.4 6.4 6.3 45 1.1 1.8 2.5 2.9 3 2.9 2.3 0.4 -1.9 60 0.6 0.6 0.4 0.2 -0.3 -1.2 -3.2 -5.9 -8.7 75 -0.2 -0.6 -1.5 -2.7 -4.3 -6.3 -8.9 -11.7 -14.5 90 -0.5 -1.3 -2.5 -4.3 -6.8 -10 -13.9 -17.5 -21 105 -1.5 -2.7 -4.4 -6.8 -10 -13.4 -16.9 -20.2 -23.6 120 -2 -3.1 -4.9 -7.7 -11 -14.3 -17.8 -21 -24.3 135 -2.1 -3.3 -5.2 -8.1 -11.6 -15.1 -18.8 -22.3 -25.7 150 -2.2 -3.5 -5.5 -8.5 -12.2 -15.9 -19.8 -23.5 -27.2 165 -2.2 -3.5 -5.5 -8.5 -12.2 -15.9 -19.8 -23.5 -27.2 180 -2.2 -3.5 -5.5 -8.5 -12.2 -15.9 -19.8 -23.5 -27.2 EN ERGY LINK INTERNATIONAL These are preliminary free -field exhaust noise emission values. For info, please contact chris.giesbrecht@energylinkcorp.com Exhaust System (not recommended without Silencer) Acoustic Performance Summary LM2500+G4 - SCR & Stack - 85 dBA @ 3ft at ground level 31.5 63 125 Gas Path Sound Power Level 250 Energy Link Project: Q23089 Date: 12/21/2023 By: CG 500 1000 2000 4000 8000 dBA dB 31.5 63 125 250 500 1000 2000 4000 8000 LM2500 Exhaust Lin Dynamic Insertion Loss Stacktop Lw Casing Sound Power Levels 133 140 139 139 138 123 116 111 104 11 9 10 13 19 28 22 16 16 122 131 129 126 119 95 94 95 88 137 145 121 134 Inlet Expansion Joint Inlet Duct SCR/CO/DG Duct Stack Base Silencer & Tailpipe TA Fan Sound Power Level 107 105 99 94 93 78 71 66 59 116 110 95 87 80 60 51 39 41 121 115 100 92 85 65 56 44 46 119 113 98 90 83 63 53 40 41 117 108 91 80 66 37 35 28 30 92 110 87 117 91 122 90 120 84 117 Attenuated Inlet & Casing Lw Angle 0 15 30 45 60 75 90 105 120 135 150 165 180 EN ERGY LINK INTERNATIONAL These are preliminary free -field exhaust noise emission values. For info, please contact chris.giesbrecht@energylinkcorp.com 113 111 107 95 82 74 77 78 76 Stack Directivity 10ft d 468 oC 31.5 63 125 250 500 1000 2000 4000 8000 1.4 3 5.5 8.3 10.5 11.9 12.7 13 13 1.7 3.3 5.6 7.8 8.8 9 8.9 9 8.8 1.4 2.5 4 5.5 6.2 6.4 6.4 6.4 6.3 0.9 1.6 2.3 2.9 3 3 2.5 1 -1.3 0.5 0.6 0.5 0.2 -0.1 -0.9 -2.6 -5.1 -7.9 - 0.1 -0.4 -1.2 -2.3 -3.8 -5.8 -8.2 -11 -13.8 - 0.5 -1.1 -2.1 -3.8 -6.1 -9.1 -12.8 -16.6 -20.1 - 1.4 -2.3 -3.8 -6.1 -9.1 -12.5 -16 -19.3 -22.7 - 1.8 -2.7 -4.3 -6.8 -10.1 -13.5 -16.9 -20.2 -23.4 -1.9 -2.9 -4.5 -7.2 -10.7 -14.2 -17.8 -21.4 -24.8 - 2 -3 -4.7 -7.5 -11.2 -14.9 -18.8 -22.6 -26.2 - 2 -3 -4.7 -7.5 -11.2 -14.9 -18.8 -22.6 -26.2 - 2 -3 -4.7 -7.5 -11.2 -14.9 -18.8 -22.6 -26.2 94 116 Estimated Transformer Sound Power Level CTG STD Transformer Spectrum*, Lw MVA rating = Measurement Surface Area = 33 MVA 60 m2 Correction from Pressure at 0.3 meter to Sound Power = 18 dB Approximate Standard NEMA Rating = 73 dB Estimated Standard A -weighted Sound Power Level = 91 dB Lw Octave Band Spectum Estimate, Lw 31.5 63 125 250 500 1000 2000 4000 8000 dB(A) 88 94 96 91 91 85 80 75 68 91 Atmospheric Absorption Spherical divergence Ground Plane Correction Sound Propagation Attenuation 0 - 53 3 - 50 0 - 53 3 - 50 0 - 53 3 - 50 0 -53 3 -50 0 - 53 3 - 50 - 1 - 53 3 - 50 -1 - 53 3 - 51 - 3 - 53 3 - 53 - 9 - 53 3 -59 ............................................................................................................ ............................................................................................................ ............................................................................................................. ..................................................................................................................... •. .... mow . . . . . ... .. ... STD Radiated SPL at 122 meters 38 44 46 41 41 35 29 23 9 41 * Spectrum base on Edison Electric Institute "Electric Power Plant Environmental Noise Guide" Estimated Transformer Sound Power Level SUS Transformer STD Transformer Spectrum*, Lw MVA rating = 3.125 MVA Measurement Surface Area = 33 m2 Correction from Pressure at 0.3 meter to Sound Power = 15 dB Approximate Standard NEMA Rating = 61 dB Estimated Standard A -weighted Sound Power Level = 76 dB Lw Octave Band Spectum Estimate, Lw 31.5 63 125 250 500 1000 2000 4000 8000 dB(A) 73 79 81 76 76 70 65 60 53 77 Atmospheric Absorption Spherical divergence Ground Plane Correction Sound Propagation Attenuation 0 -53 3 - 50 0 - 53 3 - 50 0 -53 3 - 50 0 -53 3 -50 0 -53 3 - 50 - 1 - 53 3 - 50 -1 -53 3 - 51 - 3 - 53 3 - 53 - 9 -53 3 - 59 ..................................................................................................................... ..................................................................................................................... ..................................................................................................................... ..................................................................................................................... STD Radiated SPL at 122 meters 23 29 31 26 26 20 14 8 -6 26 * Spectrum base on Edison Electric Institute "Electric Power Plant Environmental Noise Guide" Air Compressors and Gas Conditioning/metering Octave Band Center Frequency, Hertz 31.5 63 125 250 500 1000 2000 4000 8000 dB(A) Lw Spectrum of EEI Guide Compressor 90 86 91 90 88 91 96 93 86 100 .......................................................... ........................................................... .......................................................... ........................................................... .......................................................... Lw, Gas Conditioning and metering 119 117 107 96 86 79 82 82 80 96 gas piping/valves include a minimum of 2 inches of insulation, a 1 lbs/ft2 mass loaded wrap, and aluminum jacketing. APPENDIX F — Equipment Sound Levels & Property Boundary Sound Wall Effectiveness Sound levels are shown for each of the plant noise sources modeled and are sorted according to its contribution to the overall sound level. Equipment listed toward the top of the table are the loudest contributors to the overall sound. 25 foot tall wall 1/2 Mile • (f) 25 ft Two positions are provided as examples: a.) 25 feet from the property boundary, b.) 1/2 mile west. N 0 on Lib° Lib' 0 O n n 14, n Location With Barrier 25 Foot Wall Tall Improvement Without Barrier 25 Wall Foot Tall 25 Feet from Property Boundary 67.9 dB(A) 56.3 dB(A) 11.6 dB(A) 1/2 Mile West 42.6 dB(A) 42.2 dB(A) 0.4 dB(A) Benefits of a property boundary sound wall are effective at close distances but diminish at locations further from the wall, where residents are/would be be located. See next two contour figures comparing sound levels with and without a 25 ft tall property boundary wall. Comparison of A -weighted Sound Levels with 25 ft Tall Sound Wall (Red labels) and No Sound Wall (White Labels) Comparison of C -weighted Sound Levels with 25 ft Tall Sound Wall (Red labels) and No Sound Wall (White Labels) Octave Band Center Frequency, Hertz 31.5 63 125 250 500 1000 2000 4000 8000 d6(A) d6(C) Total of Sources 83.8 81.2 80 66.9 60.8 60.3 58.1 49.2 39.7 67.9 85.2 Generator 71.7 71.9 78 58.1 49.6 51.8 54.9 42.1 33.8 63.6 79.1 Air Inlet LH 69.8 71.1 71.6 58.5 54.6 54.4 48.4 40.6 31.4 60.1 74.9 Turbine Fan 65 65.3 60.9 53.9 55.3 53.4 47.7 41.9 28.8 57.5 68.1 Air Inlet RH 0 64.1 61 62 52.1 49.2 47.7 41.1 31 57.2 67.2 Turbine Enclosure 71.2 73.4 64.5 54.7 47.7 47.1 46.3 39.8 32.1 55 74.4 Turbine Ventilation 69.2 67.1 63.1 50.8 43.5 51.6 44.5 36.4 29.4 54.5 70.3 Generator unit #2 63.9 62.7 66.7 48.7 38.9 39.8 42.7 29.6 18.3 52.3 68.6 Aux Module 66.9 66.2 60.8 49.7 45,3 40.8 38.1 31.8 19.5 49.7 68.6 Air Inlet RH unit #2 0 57.7 54.1 54.9 44.2 39.6 37.1 28.9 15.1 49.1 60.4 Generator unit #3 60.4 59.1 62.6 44,7 34.8 35.4 38 23.2 13.4 48.1 64.8 GLO 66 62.3 61.3 41.9 36.2 42.6 33.8 27.1 15 48.1 66.8 Air Inlet LH unit#2 60.8 60.5 58.7 47.4 42.1 40.1 35.6 26.3 12.8 47.2 63.7 Inlet Blower 70.3 66.8 59.1 46.1 33.3 29.9 33.5 33.5 27.6 46.7 70 Stack Exit 69.6 70 57.9 43.9 30.9 24.8 16.2 7.3 0 46.6 71.3 Exhaust Duct (SCR) 77.3 70.4 53.1 42.3 36.1 20.3 11.6 0 0 46.3 75.6 Turbine Fan unit #2 57.1 55.9 49.1 44.3 44.6 41.3 35.5 28.9 12.7 46.1 58.6 Generator unit #4 58 56.7 59.8 41.8 32.2 32.8 35.3 19.8 2.1 45.4 62.1 Air Inlet RH unit #3 0 54.4 50.3 51.1 40.4 35.7 33 24 7.1 45.3 56.8 Turbine Enclosure unit#2 63.9 64.9 53.9 45.3 36.7 34.3 32.8 24.6 12.6 44,3 66.1 Exhaust Expansion Joint 65.7 61.6 51 44,3 42.9 29.3 22.7 16.9 7.3 43.4 65.1 Turbine Ventilation unit #2 62 59.3 52.7 41 32.5 39.3 31.9 22.6 11.9 43.1 62.3 Generator unit #5 56.1 54.6 57.5 39.6 30 30.5 32.7 16.2 0 43 60 Air Inlet LH unit #3 57.2 56.9 54.5 43.4 38.2 36.1 29.3 18.9 2.5 43 59.9 Air Inlet RH unit#4 0 52.2 47.5 48.4 37.8 33.1 30.3 20.8 3.2 42.6 54.3 Turbine Fan unit #3 53.3 52 45.1 40.3 40.7 37.2 31.3 23.8 4.5 42 54.8 Stack Exit unit#2 63.8 65.4 53.1 38 25.3 19.9 11.3 1.6 0 41.9 66.3 Exhaust Duct 1 (Inlet) 73.5 65.4 46.6 37.3 30.3 12.5 4.1 0 0 41.4 71.5 Generator unit #6 54.8 53.3 55.6 37.8 28.4 28.8 30.9 1.3.8 0 41.2 58.4 Air Inlet RH unit#5 0 50.6 45.3 46.3 35.8 31 28.1 17.8 0 40.5 52.5 Turbine Enclosure unit#3 60.5 61.5 49.8 41.4 32.9 30.4 28.8 19.9 4.9 40.5 62,6 Air Inlet LH unit #4 54.9 54.6 51.7 40.5 35.6 33.6 26.8 15.8 0 40.3 57.4 Inlet Blower unit #2 64.3 60.8 52.7 39.7 26.5 19 21.7 20,5 11.6 40 64 Exhaust Duct (SCR) unit #2 71.6 63.8 44.9 35.8 28.7 9.7 1.6 0 0 39.7 69.7 Max Module unit#2 59.8 58.1 50.5 40.8 35 28.4 27 19 2.3 39.7 60.6 Air Compressor 1 39.5 33.9 33.7 31.7 29.2 32.3 36.4 29.9 12.8 39.6 42.5 Air Compressor 2 39.2 33.6 33.3 31.4 28.9 32.1 36.2 29.7 12.2 39.4 42.2 Turbine Fan unit #4 50.6 49.4 42.2 37.2 37.9 34.4 28.3 20.1 2.5 39.2 52.1 Turbine Ventilation unit #3 58.2 55.5 48.7 37 28.6 35.2 27.7 17.7 4.1 39 58.5 Control House 56.2 51.7 47.6 25.9 31.7 33.5 31.7 28.6 18.6 38.9 56 Air Inlet RH unit #6 0 49.3 43.5 44.6 34.1 29.3 26.1 15.1 0 38.8 51 Air Inlet LH unit #5 53.2 53 49.4 38.3 33.6 31.6 24.7 13.1 0 38.2 55.6 Turbine Enclosure unit #4 58.1 59 47 38.5 30.1 27.4 25.5 15.8 0 37.7 60.2 Turbine Fan unit #5 48.9 47.7 40 35 35.8 32.2 25.9 17 0 37 50.3 GLOunit#2 58.8 54 50.6 32.8 24.4 28.6 18.7 9.9 0 36.9 58.5 Air Inlet LH unit #6 51.9 51.6 47.5 36.5 31.9 29.9 23 10.8 0 36.5 54.1 Inlet Blower unit #3 60.8 57.3 49 36 22.9 15.2 17.8 15.9 9.3 36.3 60.5 Exhaust Duct (SCR) unit#3 68.2 60.1 41.3 32.2 24,8 5 0 0 0 36 66.2 Stack Exit unit#3 60 58.9 47.3 34,3 21.8 16.6 7.9 0 0 36 60.8 Turbine Enclosure unit #5 56.5 57.4 44.8 36.4 28.1 25.5 23.6 13.3 0 35.8 58.5 Aux Module unit #3 56.5 54.7 46.6 37.1 31.2 24.6 20.9 12 0 35.8 57.2 GSU 43.3 45.2 43.8 36.9 34.9 27.5 20.7 13.6 2.9 35.6 48.4 Turbine Ventilation unit #4 55.1 51.9 45.7 33.9 25.3 31.3 23.1 11.7 0 35.4 55.2 Fuel Gas Conditioning and Monitoring 63.7 59.5 43.2 31.9 21,5 14.6 17.1 11.7 0 35.4 62.9 Turbine Fan unit #6 47.7 46.5 38.1 33.3 34.1 30.4 23.9 14.2 0 35.2 49 Exhaust Expansion Joint unit#2 58.3 53.7 43.5 36.5 33.9 17.9 8.9 0.1 0 35 57,5 Turbine Enclosure unit#6 55.1 56 42.9 34.7 26.7 24.2 22.3 11.5 0 34,3 57.1 Exhaust Duct 1(Inlet) unit #2 66.7 58 39.6 29.9 21.7 1.1 0 0 0 34.1 64.6 Inlet Blower unit #4 58.6 55 46.3 33.3 20.3 12.6 15.1 12.5 0 33.8 58.3 Exhaust Duct (SCR) unit#4 65.9 57.5 38.7 29.6 22.4 2.4 0 0 0 33.5 63.8 GLO unit #3 55.5 50.7 46.9 29.3 21 25.2 15.2 5.6 0 33.3 55.1 Turbine Ventilation unit #5 53.5 50 43.4 31.7 23.2 29.1 20.5 7.7 0 33.2 53.4 Aux Module unit #4 54.3 52.6 43.8 34.2 28.7 22.1 18.5 9.1 0 33.2 54.9 Stack Exit unit #4 57.6 56 43.3 31.8 19.3 14.2 5.2 0 0 32.8 58.1 GSU unit #2 38.5 40.5 40 34.1 32.2 24.5 17.5 9.3 0 32.6 44.3 Turrbine to Generator Coupling 52.3 51,2 41.7 25.6 22.7 24.9 23.5 17 18 31,9 53.2 Exhaust Duct (SCR) unit #5 64.2 55.9 36.6 27.7 20.5 0.6 0 0 0 31.8 62.2 Inlet Blower unit #5 57 53.2 44.2 31.2 18.3 10.5 12.8 9.3 0 31.8 56.6 Turbine Ventilation unit #6 52.2 48.8 41.6 30 21.7 27.8 19.3 6.2 0 31.8 52.1 Exhaust Expansion Joint unit#3 54.8 50.3 39.7 32.9 30.5 14.6 5.7 0 0 31.5 54 Ammonia Skid 53.1 51 42.8 34,4 24.5 14.5 1.3 0 0 31.4 53.6 Aux Module unit #5 52.7 51 41.5 32.1 26.7 20.1 16.5 6.6 0 31.2 53.3 Exhaust Duct 1 (Inlet) unit#3 63.5 54.8 36 26.6 18.5 0 0 0 0 30.8 61.4 GLO unit#4 53.4 48.6 44.1 26.5 18.5 22.8 12.8 2.9 0 30.7 52.9 Stack Exit unit#5 55.8 54.1 40.8 29.9 16.9 9.6 3 0 0 30.6 56.2 Exhaust Duct (SCR) unit #6 62.9 54.6 35 26.1 19 0 0 0 0 30.5 60.8 Inlet Blower unit #6 55.8 52 42.4 29.5 16.7 8.9 11 6.9 0 30.3 55.3 GSU unit #3 35.1 37.3 37.1 31.1 29.3 21.6 14.4 5.4 0 29.7 41.3 Aux Module unit#6 51.3 49.6 39.7 30.3 25 18.4 14.7 4.1 0 29.5 51.9 Exhaust Expansion Joint unit #4 52.8 48.3 36.9 30.5 28.2 12.5 3.7 0 0 29.2 52 Stack Exit unit #6 54.3 52.5 39 28.3 14.7 6.5 0 0 0 29 54.6 Exhaust Duct 1 (Inlet) unit#4 61.4 52.7 33.3 24.2 16.3 0 0 0 0 28.7 59.3 GLO unit #5 51.7 47 41.9 24.4 16.6 20.9 11 0.5 0 28.6 51.2 Stack Walls (Lower) 64.9 51.6 28.6 12.8 0 0 0 0 0 28.6 62.3 Exhaust Expansion Joint unit#5 51.3 46.8 34.8 28.4 26.4 10.9 2.2 0 0 27.4 50.4 GSU unit#4 32.8 34.9 34.5 28.7 27 19.3 11.9 2 0 27.3 38.8 Exhaust Duct 1(Inlet) unit #5 59.8 51.3 31.2 22.1 14.5 0 0 0 0 27.1 57.7 GLO unit #6 50.3 45.6 40 22.6 15 19.3 9.3 0 0 26,9 49.7 Stack Walls (Upper) 63.2 48.3 21.3 1 0 0 0 0 0 26.2 60.5 Ammonia Skid unit #2 48.2 46 37 28.8 18.9 8.5 0 0 0 25.9 48.6 Exhaust Expansion Joint unit #6 49.9 45.5 32.9 26.7 24.9 9.5 0.9 0 0 25.8 49.1 Exhaust Duct 1(Inlet) unit #6 58.5 50 29.4 20.5 12.9 0 0 0 0 25.8 56.5 GSU unit#5 31.1 33.3 32.4 26.8 25 17.5 9.9 0 0 25.4 37 Control House unit#2 47.3 41.2 34.4 14.3 18.4 18 14.8 9 0 24.1 46.1 GSU unit#6 29.8 32 30.7 25.2 23.5 15.7 8 0 0 23.8 35.5 Stack Walls (Lower) unit #2 59.6 45.2 20.9 6.8 0 0 0 0 0 22.7 56.8 Ammonia Skid unit #3 45.4 43.3 33.4 25.5 15.6 5.1 0 0 0 22.7 45.8 Control House unit #3 43.8 37.7 30.3 10.5 14.6 14.3 11.2 7 0 20.4 42.6 Ammonia Skid unit#4 43.4 41.3 30.9 23.1 1.3.3 2.7 0 0 0 20.4 43.7 Turrbine to Generator Coupling unit #2 44.6 42.2 31.1 15.5 10.6 10.1 7 0 0 20.3 44.7 Stack Walls (Lower) unit#3 56.6 42.1 17.6 3.5 0 0 0 0 0 19.7 53.8 Stack Walls (Upper) unit#2 56.9 41.3 14.8 0 0 0 0 0 0 19.5 54.1 SUS -A 23.4 27.8 24.8 18.7 18.1 12.1 6.4 0 0 18.7 30.3 Ammonia Skid unit #5 41.6 39.6 28.8 21.3 11.5 0.9 0 0 0 18.5 42 Control House unit#4 41.7 35.6 27.4 7.7 12.1 11.8 8.8 1.9 0 17.8 40.4 Stack Walls (Lower) unit #4 54.5 40 15.2 1.1 0 0 0 0 0 17.6 51.7 Ammonia Skid unit #6 40.1 38 27.2 19.9 10 0 0 0 0 17 40.4 Turrbine to Generator Coupling unit #3 41.2 38.7 27.2 11.9 7.1 6.6 3.3 0 0 16.6 41.3 Stack Walls (Lower) unit#5 52.8 38.3 13.2 0 0 0 0 0 0 16 50.1 Control House unit #5 39.9 33.9 25.2 5.6 10.2 10 7 0 0 15.9 38.6 Stack Walls (Upper) unit#3 53.4 36.5 8.9 0 0 0 0 0 0 15.6 50.6 Stack Walls (Lower) unit #6 51.5 37.1 11.5 0 0 0 0 0 0 14.7 48.8 Control House unit #6 38.5 32.4 23.3 3.8 8.7 8.5 5.6 0 0 14.3 37.2 Turrbine to Generator Coupling unit #4 39 36.6 24.5 9.5 4.8 4.5 1.4 0 0 14.3 39.1 SUS -B 19.3 23.7 19.6 13.5 13.7 8.1 2.5 0 0 14.3 25.8 Stack Walls (Upper) unit#4 51.1 34 5.9 0 0 0 0 0 0 13.2 48.2 Turrbine to Generator Coupling unit #5 37.4 35 22.3 7.4 3 2.7 0 0 0 12.5 37.5 Stack Walls (Upper) unit#5 49.3 32.1 3.7 0 0 0 0 0 0 11.3 46.4 Turrbine to Generator Coupling unit #6 36 33.7 20.5 5.7 1.5 1.4 0 0 0 11 36.1 Stack Walls (Upper) unit#6 47.8 30.6 2.1 0 0 0 0 0 0 9.8 44.9 • 25 Feet from Property Boundary NO BARRIER WALL Octave Band Center Frequency, Hertz 31.5 63 125 250 500 1000 2000 4000 8000 d6(A) d6(C) Total of Sources 79.6 73.4 69.7 56.5 47 43.2 41.6 32.7 22.4 56.3 78.6 Generator 66.5 62.7 66.9 46.3 34.8 34 36.9 24 15.5 51.6 69.3 Air Inlet RH 0 57 54 52.5 40.4 34.8 32.7 25.8 15.6 46.4 59.3 Air Inlet LH 63.8 60.5 58.5 44,6 37.8 34.8 28.8 20.8 11.5 45.1 64.5 Generator unit #2 59.7 55.9 59.7 39.3 26.8 27.7 30.6 16.7 4.7 44.5 62.3 Turbine Enclosure 66.1 64.6 54.2 43.2 33 30.4 29.6 23.1 15.2 43.2 66.8 Turbine Fan 59.9 55.8 48.9 41.2 39.8 34 28 22.1 8.9 41,2 59.6 Generator unit #3 56.1 52.3 55.6 35.4 22.8 22.1 27.2 12.5 0 40.4 58.4 Air Inlet RH unit #2 0 50.7 47.4 46.1 33.1 28.7 26.7 18.9 5.3 40 52.9 Turbine Ventilation 64.7 59.1 52.3 37.7 27.4 32.1 24.8 16.6 9.5 39.9 63.7 Stack Exit 65.6 63.5 50.3 37.9 21,3 10.8 0 0 0 39,9 65.8 Exhaust Duct (SCR) 73.1 62.8 43.6 32 23.6 2.9 0 0 0 39.1 70.8 Inlet Blower 66 59.5 51.2 35.5 20.2 12.2 15.3 15.4 9.9 38.3 64.6 Aux Module 61.8 57.5 50.5 38.3 31.1 24.1 21.4 15 2.7 38.1 61.3 Generator unit #4 53.8 50.1 53 33 20.3 19.3 23.5 8.2 0 37.8 56 Air Inlet LH unit #2 56.5 53,2 51 37.3 29.6 28.3 22.7 13.6 0.5 37.7 57.2 Turbine Enclosure unit #2 59.5 58 47.2 36.4 25.5 23.9 23.1 15.6 4.4 36.4 60.1 Air Inlet RH unit #3 0 47.6 43.7 42.6 29.5 23.7 23 14.4 0 36.3 49.5 GLO 60.9 53.3 50.6 30.3 21.3 25.1 16.2 9.3 0 36.2 59.5 Generator unit #5 52.2 48.5 50.9 31.1 18.5 17,6 20 4.3 0 35.7 54.2 Exhaust Duct 1 (Inlet) 69.3 58.7 39.4 27.6 18.4 0 0 0 0 35 66.9 Exhaust Expansion Joint 61.2 54.5 44.2 35.4 32 16.5 9.6 3.9 0 34.5 59.7 Generator unit #6 50.9 47.3 49.3 29.7 19 16.9 19 1.9 0 34,1 52.8 Turbine Fan unit #2 52.9 48.8 41.5 34,1 31.6 28.2 22.3 15.4 0 34.1 52.5 Air Inlet RH unit#4 0 45.5 41.1 40.1 27 20.9 19.1 10.4 0 33.7 47.2 Air Inlet LH unit #3 53 49.9 47.1 33.6 25.8 22.2 17.9 8.2 0 33.7 53.7 Stack Exit unit#2 60.4 57.5 43.5 30.7 1.3.7 2.7 0 0 0 33.6 60.2 Exhaust Duct (SCR) unit#2 67.7 57.3 37.8 26.3 16.4 0 0 0 0 33.5 65.3 Turbine Ventilation unit #2 57.7 52 44.9 30.5 19.3 26.3 19 9.7 0 33 56.6 GSU 41.2 42.8 40.6 34.3 31.8 24.7 19.5 13.6 3.1 32.8 45.8 Turbine Enclosure unit#3 56.1 54.7 43.3 32.7 21.8 18.7 19.3 11 0 32.7 56.8 Inlet Blower unit #2 60 53.5 45 29.5 13.6 4.7 7.7 7 0 32.1 58.6 Air Inlet RH unit#5 0 44.1 39 38.3 25.1 19.1 16.5 7.4 0 31.8 45.6 Aux Module unit #2 55.5 51.2 43.7 31.8 23.7 17.9 15.5 8.2 0 31.5 54.9 Air Inlet LH unit #4 50.8 47.8 44.4 31.1 23.3 19.2 15.2 4.7 0 31.1 51.4 Air Inlet RH unit #6 0 42.9 37.3 36.8 26.2 19.2 16.2 5.1 0 30.8 44.2 Exhaust Duct (SCR) unit #3 64.6 54.3 34.3 23 13.1 0 0 0 0 30.5 62.3 Turbine Enclosure unit#4 54 52.6 40.6 30.2 19.2 15.9 16 7 0 30.3 54.6 Stack Exit unit#3 57.2 54 39.6 26.9 9.7 0 0 0 0 30 56.8 Turbine Fan unit#3 49.1 45 37.5 30.2 27.7 22 19 11.2 0 29.8 48.7 GLOunit#2 54.5 47 43.8 23.8 13.3 17.9 9 1.3 0 29.5 53.1 Fuel Gas Conditioning and Monitoring 60.2 53.8 36.4 23.3 9.9 1.8 4.6 1.3 0 29.4 58.6 Air Inlet LH unit #5 49.3 46.3 42.4 29.3 21,5 17.2 10.7 1.6 0 29.1 49.8 Turbine Ventilation unit #3 54 48.4 41.1 26.9 15.7 20.2 15.8 5.7 0 28.9 52.9 Exhaust Duct 1(Inlet) unit #2 63.2 52.5 32.9 21.4 11.5 0 0 0 0 28.8 60.8 Inlet Blower unit #3 56.7 50.3 41.6 26.2 10.3 0.7 5.2 3.7 0 28.8 55.2 Air Compressor 1 35.3 26.9 26.3 22 17 18.5 25.7 20.3 4.2 28.7 35.1 Turbine Enclosure unit#5 52.4 51.1 38.5 28.3 17,3 13.8 12.5 3.9 0 28.4 53.1 Exhaust Duct (SCR) unit#4 62.5 52,2 31.8 20.7 10,7 0 0 0 0 28.3 60.1 Air Compressor 2 35 26.7 26 21.6 16.7 18.1 25.4 19.8 3.4 28.3 34.8 Aux Module unit #3 52.2 47.9 39.9 28.2 20 12.7 11.1 3.1 0 27.8 51.6 Exhaust Expansion Joint unit#2 54.5 47.8 37.3 28.7 24.8 9.7 2.8 0 0 27.7 53 Air Inlet LH unit #6 48 45.2 40.7 27.8 21.1 16 9.2 0 0 27.7 48.5 GSU unit#2 35.9 37 35.3 28.3 26.5 20 15.1 8.6 0 27,6 40.3 Stack Exit unit #4 54.8 51.5 36.9 24.3 7.1 0 0 0 0 27.4 54.4 Turbine Enclosure unit#6 51.1 49.9 36.8 26.8 17.7 13.2 11.6 0.9 0 27.2 51.8 Turbine Fan unit #4 46.6 42.6 34.9 27.9 25.3 19.2 15.6 7 0 27.1 46.2 Exhaust Duct (SCR) unit #5 60.9 50.7 29.9 19 8.9 0 0 0 0 26.8 58.6 Inlet Blower unit #4 54.6 48.3 39.1 23.9 7.9 0 1.5 0.1 0 26.5 53.2 Turbine Ventilation unit #4 51,5 46 38.5 24,5 13.3 17.3 12 1.2 0 26.2 50.5 GLOunit#3 51.3 43.9 40.1 20.3 9.7 13.1 5.9 0 0 25.8 49.9 Exhaust Duct 1(Inlet) unit #3 60 49.4 29.3 17.9 8 0 0 0 0 25.6 57.6 Exhaust Duct (SCR) unit #6 59.7 49.5 28.4 19.1 9.2 0 0 0 0 25.6 57.3 Stack Exit unit #5 53 49.7 34.8 22.3 5.1 0 0 0 0 25.5 52.5 Aux Module unit#4 50.1 45.9 37.2 25.7 17.5 9.9 7.9 0 0 25.3 49.5 Turbine Fan unit #5 45 41.1 33 26.1 23.5 17.8 11.5 4.4 0 25.3 44.6 Inlet Blower unit #5 53.3 47.1 37.2 22.3 6.2 0 0 0 0 24,9 51.9 Turbine Fan unit #6 43.9 40.1 31.3 24.7 24.1 17.4 10.6 0.5 0 24.8 43.6 Ammonia Skid 48.7 44 36.5 26.8 16.9 7.3 0 0 0 24.5 48 Turbine Ventilation unit #5 50.2 44.8 36.6 22.8 11.5 15.4 7.7 0 0 24.5 49.2 Exhaust Expansion Joint unit #3 51.1 44.4 33.5 25.1 21.1 5.2 0 0 0 24 49.5 Stack Exit unit #6 51.5 48.2 33.1 20.8 3.5 0 0 0 0 24 51 Inlet Blower unit #6 52.2 46 35.6 20.9 7.2 0 0 0 0 23.7 50.8 Exhaust Duct 1 (Inlet) unit #4 57.9 47.4 26.7 15.5 5.5 0 0 0 0 23.5 55.5 Aux Module unit #5 48.5 44.4 35.2 23.8 15.6 7.8 4.6 0 0 23.5 47.9 Stack Walls (Lower) 61.1 44.8 19.5 2.9 0 0 0 0 0 23.4 58.2 GSU unit#3 32.5 33.8 32.1 24.7 21.7 15.3 11.3 4 0 23.4 36.9 Turbine Ventilation unit #6 49.1 43.8 34.9 21.4 12.1 15.4 7.3 0 0 23,3 48 GLOunit#4 49.2 41.9 37.5 17.9 7.2 10.3 2.1 0 0 23.3 47.8 Control House 50 40.7 34.1 11.6 14.1 13.7 11.9 8.7 0 22.4 48 Aux Module unit#6 47.2 43.1 33.4 22.3 16 7.3 3.7 0 0 22.2 46.6 Exhaust Duct 1(Inlet) unit #5 56.4 45.9 24.7 13.7 3.6 0 0 0 0 22 54 Exhaust Expansion Joint unit #4 49.1 42.5 30.8 22.5 18.5 2.4 0 0 0 21,7 47.5 GLOunit#5 47.6 40.4 35.4 16 5.3 8.2 0 0 0 21.4 46.2 Turrbine to Generator Coupling 47.4 42.9 32.3 14.7 8.9 9.3 7.9 1.5 2.5 21 46.6 Exhaust Duct 1 (Inlet) unit#6 55.2 44.7 23 12.2 4.2 0 0 0 0 20.8 52.8 Stack Walls (Upper) 58.9 40.8 12.2 0 0 0 0 0 0 20.7 56 GSU unit#4 30.1 31.4 29.4 22.1 19.1 12.5 7.4 0.1 0 20.6 34.4 Exhaust Expansion Joint unit#5 47.6 41 28.7 20.6 16.6 0.3 0 0 0 19.9 46 GLOunit#6 46.3 39.1 33.7 14,5 5.8 7.8 0 0 0 19.9 44.8 Ammonia Skid unit#2 43.9 39.3 30.9 21.4 10.4 2 0 0 0 19.1 43.1 Exhaust Expansion Joint unit #6 46.3 39.8 26.9 19.1 16.1 0 0 0 0 18.7 44,7 GSU unit#5 28.4 29.7 27.2 20.1 17 10.4 5 0 0 18.5 32.6 Stack Walls (Lower) unit #2 56.1 39.7 14.1 0 0 0 0 0 0 18.4 53.2 GSU unit#6 27.1 28.4 25.5 18.5 15.6 8.5 2.9 0 0 16.9 31.1 Ammonia Skid unit#3 41.2 36.7 27.4 18.1 7.1 0 0 0 0 15,9 40.5 Stack Walls (Lower) unit#3 53.3 36.9 10.8 0 0 0 0 0 0 15.6 50.4 Control House unit #2 43 33.9 26.9 4.6 6.6 7.4 5.6 1.3 0 15.5 41 Stack Walls (Upper) unit#2 53.7 35.1 5.9 0 0 0 0 0 0 15.4 50.8 Turrbine to Generator Coupling unit #2 40.6 36.2 25.2 7.9 1,4 2.6 1.2 0 0 14.1 39.8 Ammonia Skid unit #4 39.2 34.7 24.9 15.7 4.6 0 0 0 0 13.6 38.4 Stack Walls (Lower) unit #4 51.2 34.9 8.5 0 0 0 0 0 0 13.6 48.4 Stack Walls (Upper) unit#3 50.5 31.7 2.2 0 0 0 0 0 0 12.1 47.6 Stack Walls (Lower) unit #5 49.6 33.4 6.6 0 0 0 0 0 0 12 46.8 Ammonia Skid unit #5 37.6 33.1 22.8 13.8 2.7 0 0 0 0 11.8 36.8 Control House unit #3 39.6 30.7 23 0.9 2.8 2.4 2.2 0 0 11.7 37.6 Ammonia Skid unit#6 36.2 31.7 21.2 14,3 4 0 0 0 0 11.1 35.4 Stack Walls (Lower) unit #6 48.4 32.2 5.5 0 0 0 0 0 0 10.8 45.6 Turrbine to Generator Coupling unit #3 37.3 32.9 21.3 4.1 0 0 0 0 0 10.4 36.5 Stack Walls (Upper) unit #4 48.2 29.3 0 0 0 0 0 0 0 9.8 45.2 Control House unit#4 37.6 28.8 20.3 0 0.3 0 0 0 0 8.8 35.6 SUS -A 19.2 20.8 17.4 9 6 0.7 0 0 0 8.2 23.2 Stack Walls (Upper) unit#5 46.4 27.5 0 0 0 0 0 0 0 8 43.5 Turbine to Generator Coupling unit #4 35.1 30.8 18.5 1.6 0 0 0 0 0 7.9 34.3 Control House unit #5 36 27.3 18.3 0 0 0 0 0 0 6.7 34 Stack Walls (Upper) unit#6 44.9 26.1 0 0 0 0 0 0 0 6.5 42 Turrbine to Generator Coupling unit #5 33.5 29.3 16.4 0 0 0 0 0 0 6.1 32.7 Control House unit #6 34.6 26 16.6 0 0 0 0 0 0 5.2 32.6 Turrbine to Generator Coupling unit #6 32.2 28 14.7 0 0 0 0 0 0 4.7 31.4 SUS -B 15.3 17 12.4 4.4 1.3 0 0 0 0 3 19 25 Feet from Property Boundary WITH BARRIER WALL Octave Band Center Frequency, Hertz 31.5 63 125 250 500 1000 2000 4000 8000 d6(A) dB(C) Total of Sources 66.3 63 54.6 42.1 28.3 31.6 30.4 7.4 0 42.6 66.1 Generator 47.1 47.1 46.3 25.6 9.9 17 20.9 0 0 31.7 50.4 Generator unit #2 45.9 45.7 45.7 25.1 9.3 16.4 20.1 0 0 31 49.4 Generator unit #3 45.5 45.4 45.1 24,6 8.8 15.7 19.3 0 0 30.4 48,9 Generator unit #4 45.2 45.1 44.7 24.2 8,3 15.2 18.5 0 0 29.9 48.5 Generator unit #5 44.8 44.8 44.2 23.7 7.8 14.6 17.7 0 0 29.5 48.2 Generator unit #6 44.5 44.5 43.8 23.3 7.3 14 16.9 0 0 29 47.8 Air Inlet RH 0 41 34.4 33.5 17.3 17.9 15.8 0 0 27.4 41.9 Air Inlet RH unit #2 0 40.5 33.9 33 16.7 17.3 15 0 0 26.9 41.4 Air Inlet RH unit#3 0 40.1 33.5 32.5 16.2 16,7 14.2 0 0 26.4 41 Air Inlet LH 44.2 45.5 38.3 24 12.8 18.1 13.1 0 0 26 46.9 Air Inlet RH unit #4 0 39.8 33 32.1 15.7 16.2 13.4 0 0 25,9 40.6 Air Inlet RH unit#5 0 39.4 32.5 31.6 15.2 15.6 12.6 0 0 25.4 40.2 Fuel Gas Conditioning and Monitoring 53 50.3 30.7 16.7 0 0 3.4 0 0 25.2 52.8 Turbine Enclosure 46.7 48.9 33.6 22.7 8.9 12.3 11.9 0 0 25.1 49.5 Air Inlet RH unit#6 0 39 32.1 31.2 14.7 15.1 11.9 0 0 25 39.8 Air Inlet LH unit #2 42.4 42.4 37.3 23.5 12.2 17.4 11.9 0 0 24.7 44.6 Exhaust Duct (SCR) 55.8 49.2 26 14,3 0.8 0 0 0 0 24.2 54.2 Air Inlet LH unit #3 42 42.1 36.8 23 11.7 16.9 11.3 0 0 24.2 44.2 Turbine Enclosure unit#2 45.8 47.2 32.9 22.2 8.4 11.7 11 0 0 23,9 48.1 Exhaust Duct (SCR) unit#2 55.2 48.8 25.5 13.8 0.3 0 0 0 0 23,8 53.6 Air Inlet LH unit #4 41.6 41.7 36.3 22.6 11.2 16.3 10.6 0 0 23.7 43.8 Exhaust Duct (SCR) unit#3 54.9 48.4 24.9 13.3 0 0 0 0 0 23.4 53.3 Turbine Enclosure unit#3 45.4 46.8 32.4 21.7 7,9 11.1 10.3 0 0 23.4 47.7 Air Inlet LH unit #5 41.2 41.4 35.9 22.1 10.7 15.7 9.9 0 0 23.3 43.4 Exhaust Duct (SCR) unit#4 54.5 48.1 24.5 12.8 0 0 0 0 0 23.1 52.9 Turbine Enclosure unit #4 45 46.4 31.9 21.2 7.4 10.5 9.5 0 0 23 47.3 Air Inlet LH unit #6 40.9 41.1 35.5 21.7 10.2 15.1 9.1 0 0 22.8 43.1 Exhaust Duct (SCR) unit #5 54.2 47.8 24 12.4 0 0 0 0 0 22.8 52.6 Stack Exit 47.2 47.5 30.2 16.4 0 0 0 0 0 22.6 48.7 Turbine Enclosure unit#5 44.6 46.1 31.5 20.8 6.9 9.9 8.7 0 0 22.5 47 Turbine Fan 40.3 40.7 28.9 20.9 14.8 18.3 13.5 0 0 22.5 42.1 Exhaust Duct (SCR) unit #6 53.9 47.4 23.6 12 0 0 0 0 0 22.4 52.3 Stack Exit unit #2 46.9 47.2 29.6 15.9 0 0 0 0 0 22,2 48.4 Turbine Enclosure unit#6 44.3 45.8 31.1 20.4 6.4 9,4 7.9 0 0 22.1 46.6 Turbine Ventilation 44.5 42.6 32.5 17.6 2.8 16.4 10.2 0 0 22 45 Stack Exit unit#3 46.6 46.9 29.1 15.4 0 0 0 0 0 21,9 48.1 Turbine Fan unit #2 39.1 38,9 28.3 20.4 14.3 17.6 12.6 0 0 21.7 40.6 Stack Exit unit #4 46.3 46.6 28.5 15 0 0 0 0 0 21,5 47.8 Air Compressor 1 25.5 21.4 16.5 11.5 3 13.8 19.4 0 0 21.4 26.6 Air Compressor 2 25.5 21.4 16.4 11.5 3.3 13.7 19.3 0 0 21.4 26.6 Inlet Blower 47.6 44.4 33.1 17.3 0 0 1.1 0 0 21.4 47.3 Turbine Ventilation unit #2 44 41.9 31.9 17.1 2.3 15.7 9.3 0 0 21.4 44.3 Stack Exit unit #5 46 46.3 28.1 14.6 0 0 0 0 0 21.2 47.5 Turbine Fan unit #3 38.7 38.7 27.7 19.9 13.7 17 11.8 0 0 21.1 40.3 Stack Exit unit #6 45.7 46 27.6 14,1 0 0 0 0 0 20.9 47.2 Inlet Blower unit #2 47.2 44 32.6 16.8 0 0 0.3 0 0 20.9 46.9 Turbine Ventilation unit #3 43.6 41.6 31.3 16.6 1.7 15.1 8.5 0 0 20.8 43.9 Turbine Fan unit #4 38.4 38.5 27.2 19.4 13.2 16.4 11 0 0 20.6 40 Inlet Blower unit #3 46.8 43.6 32.1 16.4 0 0 0 0 0 20.5 46.5 Turbine Ventilation unit #4 43.2 41.2 30.8 16.1 1.2 14.5 7.7 0 0 20,3 43.6 Turbine Fan unit#5 38 38.3 26.7 19 1.2.7 15.9 10.2 0 0 20.1 39.7 Inlet Blower unit #4 46.4 43.2 31.6 15.9 0 0 0 0 0 20 46.1 Turbine Ventilation unit #5 42.9 40.9 30.3 15.7 0.7 14 6.9 0 0 19.9 43.3 Aux Module 42.9 42.3 30.4 18.3 7.2 6.7 4.6 0 0 19.7 44 Inlet Blower unit #5 46 42.9 31.1 15.5 0 0 0 0 0 19.6 45.7 Turbine Fan unit #6 37.7 38.1 26.2 18,5 1.2.2 15.3 9.4 0 0 19.6 39.5 Turbine Ventilation unit #6 42.5 40.6 29.8 15.2 0.2 13.4 6.1 0 0 19.4 42.9 Inlet Blower unit #6 45.6 42.6 30.7 15 0 0 0 0 0 19.3 45.4 Aux Module unit#2 41.9 40.4 29.7 17.8 6.6 6.1 3.6 0 0 18,5 42,5 Aux Module unit#3 41.4 40 29.2 17.3 6.1 5.4 2.9 0 0 18 42.1 Exhaust Duct 1 (Inlet) 50.3 42.6 20.2 9 0 0 0 0 0 17.9 48.4 GLO 42.1 38.6 30.8 10.6 0 7.6 0 0 0 17.7 41,9 Exhaust Duct 1 (Inlet) unit #2 50 42.3 20 8.8 0 0 0 0 0 17.6 48.1 Aux Module unit#4 41.1 39.7 28.7 16.9 5.6 4.8 2.1 0 0 17.6 41.7 Exhaust Duct 1(Inlet) unit#3 49.6 41,9 19.5 8.3 0 0 0 0 0 17.2 47.7 Aux Module unit#5 40,7 39.3 28.3 16.4 5.1 4.3 1.3 0 0 17.1 41.3 Exhaust Duct 1(Inlet) unit #4 49.2 41.5 19.1 7.9 0 0 0 0 0 16.8 47.3 Aux Module unit #6 40.3 39 27.9 16 4.6 3.7 0.5 0 0 16.7 41 GLO unit#2 41.1 37 30.1 10.1 0 6.9 0 0 0 16.7 40.6 Exhaust Duct 1(Inlet) unit #5 48.8 41.2 18.7 7.4 0 0 0 0 0 16.4 46.9 GLOunit#3 40.5 36 29.6 9.6 0 6.3 0 0 0 16.1 39.9 Exhaust Duct 1 (Inlet) unit#6 48.4 40.8 18.3 7 0 0 0 0 0 16.1 46.5 GLO unit#4 40.1 35.7 29.1 9.1 0 5.8 0 0 0 15.6 39.5 GLOunit#5 39.7 35.4 28.7 8,7 0 5.2 0 0 0 15.2 39.2 Exhaust Expansion Joint 41.6 37.7 23.6 15.6 8.9 0 0 0 0 15.1 40.9 GLOunit#6 39.3 35.1 28.2 8.3 0 4.7 0 0 0 14.8 38.8 Exhaust Expansion Joint unit#2 40.8 36.7 23 15.2 8.3 0 0 0 0 14.3 40 Exhaust Expansion Joint unit#3 40.3 36.2 22.6 14.7 7.8 0 0 0 0 13.8 39.6 Exhaust Expansion Joint unit #4 39.9 35,9 22.2 14.2 7.3 0 0 0 0 13.4 39.2 GSU 21.1 24 21.9 15.4 9.6 7.6 0 0 0 13.2 26.8 Exhaust Expansion Joint unit#5 39.6 35.5 21.8 13.8 6.8 0 0 0 0 13 38.8 GSU unit#2 20.7 23.6 21.5 14,9 9.1 7 0 0 0 12.6 26.3 Exhaust Expansion Joint unit#6 39.2 35.1 21.5 13.4 6.3 0 0 0 0 12.6 38.5 GSU unit #3 20.3 23.2 21.1 14.5 8.5 6.5 0 0 0 12.2 25.9 GSU unit #4 19.9 22.8 20.6 14 8 5.9 0 0 0 11.6 25.5 GSU unit#5 19.4 22.3 20.2 13.5 7.4 5.2 0 0 0 11 25 GSU unit #6 19 21.8 19.6 13 6.9 4 0 0 0 10.3 24.5 Stack Walls (Lower) 44.6 32 3 0 0 0 0 0 0 8.6 42 Stack Walls (Lower) unit #2 44.1 31.6 2.4 0 0 0 0 0 0 8.2 41,5 Stack Walls (Lower) unit #3 43.8 31.3 1.9 0 0 0 0 0 0 7.9 41.2 Ammonia Skid 31.3 29.6 18.6 9.8 0 0 0 0 0 7.8 31.8 Stack Walls (Lower) unit #4 43.4 31 1.4 0 0 0 0 0 0 7.5 40.8 Ammonia Skid unit #2 30.8 29.2 18.2 9.3 0 0 0 0 0 7,3 31.4 Stack Walls (Lower) unit #5 43.1 30.7 1 0 0 0 0 0 0 7.2 40.5 Stack Walls (Lower) unit #6 42.8 30.4 0.6 0 0 0 0 0 0 6,9 40.2 Ammonia Skid unit #3 30.4 28.8 17.8 8.8 0 0 0 0 0 6.9 30,9 Ammonia Skid unit #4 30 28.4 17.4 8.4 0 0 0 0 0 6.4 30.5 Ammonia Skid unit #5 29.6 28 17 7.9 0 0 0 0 0 6 30.2 Ammonia Skid unit #6 29.2 27.6 16.6 7.5 0 0 0 0 0 5.7 29.8 Control House 30.7 26.1 14.2 0 0 0 0 0 0 4.7 29.8 Stack Walls (Upper) 41.4 26.3 0 0 0 0 0 0 0 4.2 38.6 Stack Walls (Upper) unit#2 41 26 0 0 0 0 0 0 0 3.8 38.2 Stack Walls (Upper) unit #3 40.7 25.6 0 0 0 0 0 0 0 3.5 37.9 Stack Walls (Upper) unit #4 40.4 25.3 0 0 0 0 0 0 0 3.2 37.6 Stack Walls (Upper) unit #5 40 25 0 0 0 0 0 0 0 2.8 37.3 Control House unit#2 28.8 22.8 13 0 0 0 0 0 0 2.7 27.4 Turrbine to Generator Coupling 27.7 26.6 11.2 0 0 0 0 0 0 2.6 28.4 Stack Walls (Upper) unit #6 39.7 24.7 0 0 0 0 0 0 0 2.5 37 Control House unit#3 28.3 22.4 12.5 0 0 0 0 0 0 2,2 27 Control House unit#4 27.9 22 12.1 0 0 0 0 0 0 1.8 26.6 Control House unit #5 27.6 21.7 11.7 0 0 0 0 0 0 1.4 26.3 Turrbine to Generator Coupling unit #2 26.8 24.9 10.4 0 0 0 0 0 0 1.2 27.1 Control House unit #6 27.2 21.3 11.3 0 0 0 0 0 0 0.9 25.9 Turrbine to Generator Coupling unit #3 26.4 24.5 9.9 0 0 0 0 0 0 0.8 26.6 Turrbine to Generator Coupling unit #4 26 24.1 9.5 0 0 0 0 0 0 0.3 26.3 Turrbine to Generator Coupling unit #5 25.6 23.7 9.1 0 0 0 0 0 0 0 25.9 Turrbine to Generator Coupling unit #6 25.2 23.4 8.7 0 0 0 0 0 0 0 25,5 SUS -A 8.6 14.6 6.7 0 0 0 0 0 0 0 15.2 SUS -B 7.8 13.8 5.6 0 0 0 0 0 0 0 14.3 1/2 Mile from Property Boundary NO BARRIER WALL Octave Band Center Frequency, Hertz 31.5 63 125 250 500 1000 2000 4000 8000 d6(A) d6(C) Total of Sources 64.9 61.7 54.3 42 28.6 32 30.6 6.9 0 42.2 64.9 Generator unit #2 43.8 42.9 45.5 25.1 9.2 16.2 19.7 0 0 30.6 47.9 Generator unit #3 43.6 43,2 45.1 24.6 8.7 15.7 19.9 0 0 30.3 47.8 Generator 44.1 42,9 45.4 25.5 9.7 15.9 17.4 0 0 30.3 47.9 Generator unit #4 43.5 44 44.7 24.1 8.2 15.1 19.4 0 0 29.9 47.8 Generator unit #5 43.5 44.4 44.2 23.7 7.7 16.5 18.9 0 0 29.6 47.8 Generator unit #6 43.6 44.2 43.8 23.3 10 16.7 19.3 0 0 29.3 47.5 Air Inlet RH unit#2 0 38.3 33.5 32.8 16.7 16.8 14.7 0 0 26.5 39,9 Air Inlet RH 0 38.4 33.3 33 17.2 16 10.9 0 0 26.4 40 Air Inlet RH unit #3 0 38.3 33.3 32.4 16.2 16.4 14.7 0 0 26.2 39.8 Air Inlet RH unit #6 0 38 32 31.2 17.5 18.8 15.9 0 0 26 39.2 Air Inlet RH unit #4 0 38.6 32.9 32 15.7 15.9 14.3 0 0 25.8 39.8 Air Inlet RH unit#5 0 38.4 32.5 31.6 15.2 17.7 14 0 0 25.7 39.5 Fuel Gas Conditioning and Monitoring 51.3 49.1 30.7 16.7 0 2.3 5.5 0 0 24.2 51.3 Air Inlet LH unit #3 40.2 40.4 36.8 23 11.7 16.9 11.6 0 0 24 42.8 Air Inlet LH unit #2 40.5 40.3 36.7 23.5 12.2 16.8 10.1 0 0 23,9 42.9 Air Inlet LH 40.9 40.6 36.9 24 12.8 15.8 6.8 0 0 23.8 43.1 Air Inlet LH unit #4 40.1 40.9 36.3 22.6 11.2 16.3 11.1 0 0 23.6 43 Air Inlet LH unit#5 40.1 41.4 35.9 22.1 10.7 16.8 10.5 0 0 23,5 43.1 Air Inlet LH unit#6 40.3 41.1 35.5 21.7 12.6 16.6 10.2 0 0 23,3 42.9 Exhaust Duct (SCR) unit #4 53.3 47.9 24.4 12.8 0 0 0 0 0 22,8 52 Stack Exit 47.2 47.5 30.2 16.4 0 0 0 0 0 22.6 48.7 Exhaust Duct (SCR) unit#5 53.4 47.6 23.9 12.4 0 0 0 0 0 22.5 52 Exhaust Duct (SCR) unit#3 53.3 47.6 24.9 13.3 0 0 0 0 0 22.5 51.9 Turbine Enclosure 43.9 45 32.5 22.4 8.7 10.7 7.2 0 0 22.4 46.1 Turbine Enclosure unit #2 43.6 44.8 32.4 22.1 8,3 11.2 9.8 0 0 22.4 45.8 Turbine Enclosure unit #3 43.3 44.8 32.3 21.6 7.8 10.9 10.5 0 0 22.3 45.8 Exhaust Duct (SCR) unit#6 53.7 47.3 23.5 13.7 0.1 0 0 0 0 22.3 52.1 Turbine Enclosure unit#4 43.1 45.2 31.9 21.2 7.3 10.4 9.9 0 0 22.3 45,9 Stack Exit unit #2 46.9 47.2 29.6 15.9 0 0 0 0 0 22,2 48.4 Turbine Enclosure unit#5 43 45.3 31.5 20.7 6,8 11.6 9.3 0 0 22.2 46 Turbine Enclosure unit #6 43 45 31 20.3 9.1 12.2 10.4 0 0 22.1 45.7 Air Compressor 2 22.3 17 16.1 11.5 3.3 13.7 20.2 0.1 0 22.1 24.8 Exhaust Duct (SCR) unit #2 53.4 46.9 25.4 13.7 0.2 0 0 0 0 22 51.8 Air Compressor 1 22.3 16.9 16.1 11.5 3 13.8 20.1 0.3 0 22 24.8 Stack Exit unit#3 46.6 46.9 29.1 15.4 0 0 0 0 0 21.9 48.1 Exhaust Duct (SCR) 53.6 46.5 25.6 14.2 0.8 0 0 0 0 21.8 51.8 Stack Exit unit #4 46.3 46.6 28.5 15 0 0 0 0 0 21.5 47.8 Turbine Fan unit #2 37.1 36.2 28 20.4 14.3 17.6 12.6 0 0 21.4 38.4 Turbine Fan unit #6 37.4 38.1 26.2 18,5 14.9 17.9 11.9 0 0 21.3 39.4 Turbine Fan unit #5 37.1 38.3 26.7 19 12.7 18 12 0 0 21,2 39.4 Stack Exit unit #5 46 46.3 28.1 14,6 0 0 0 0 0 21.2 47.5 Turbine Fan unit #3 37 36.7 27.7 19.9 13.7 17 12.7 0 0 21 38.5 Stack Exit unit#6 45.7 46 27.6 14.1 0 0 0 0 0 20.9 47.2 Turbine Fan 37.4 36.2 27.7 20.9 14.8 17.1 8.9 0 0 20.8 38.5 Turbine Fan unit #4 37 37.7 27.2 19.4 13.2 16.4 12.3 0 0 20.7 39 Turbine Ventilation unit #5 41.9 40.9 30.3 15.7 0.7 16.1 7.9 0 0 20.6 42.8 Turbine Ventilation unit #2 42.1 39.5 3L3 17.1 2.3 15.7 9.3 0 0 20.6 42.3 Turbine Ventilation unit #6 42.1 40.6 29.8 15.2 2.9 16 8.6 0 0 20.4 42.7 Turbine Ventilation unit #3 4L9 39.8 31.3 16.6 1.7 15.1 8.9 0 0 20.4 42.3 Turbine Ventilation 42.4 39.7 31.3 17.6 2.8 15.1 5.4 0 0 20.2 42.5 Turbine Ventilation unit #4 41.8 40.6 30.8 16.1 1.2 14.5 8.3 0 0 20.2 42.6 Inlet Blower unit #4 45.1 43.2 31.6 15.9 0 0 0 0 0 20 45.5 Inlet Blower unit #2 45.3 42 32.5 16.8 0 0 0.3 0 0 19,9 45.1 Inlet Blower 45.7 42.1 32.3 17.3 0 0 0 0 0 19.9 45.3 Inlet Blower unit #3 45.2 42.4 32.1 16.4 0 0 0.2 0 0 19.8 45.1 Inlet Blower unit #5 45.2 42.9 31.1 15.5 0 0 0 0 0 19.6 45.3 Inlet Blower unit #6 45.5 42.6 30.7 15 0 0 0 0 0 19.3 45.3 Aux Module 40 38.2 29.1 18 7 4.5 0 0 0 17.3 40.6 Aux Module unit#2 39.6 38 29 17.7 6.5 5.2 1.8 0 0 17.2 40.3 Aux Module unit#3 39.3 38 29.1 17.3 6 5.1 3 0 0 17.2 40.2 Aux Module unit #4 39.1 38.3 28.6 16.8 5.5 4.6 2.3 0 0 17 40.2 Aux Module unit#5 39 38.5 28.2 16.4 5 5.8 1.7 0 0 16.9 40.2 Aux Module unit #6 39 38.2 27.8 16 7.3 6.5 2.9 0 0 16.8 40 Exhaust Duct 1 (Inlet) 48.5 40.6 19.4 8.8 0 0 0 0 0 16,1 46.5 Exhaust Duct 1(Inlet) unit #2 48.2 40.5 19.5 8.4 0 0 0 0 0 15.9 46.3 Exhaust Duct 1(Inlet) unit #4 47.7 40.7 18.8 7.6 0 0 0 0 0 15,9 46 Exhaust Duct 1(Inlet) unit #3 47.9 40.5 19.2 8 0 0 0 0 0 15.8 46.1 Exhaust Duct 1 (Inlet) unit#5 47.6 40.3 18.4 7.1 0 0 0 0 0 15.6 45.8 GLO 39.1 34.3 29.6 10.4 0 5.5 0 0 0 15.6 38.5 GLOunit#3 38.4 34 29.5 9.5 0 6.2 0 0 0 15.5 38.1 GLOunit#2 38.7 34 29.4 10 0 6.2 0 0 0 15.5 38.2 Exhaust Duct 1 (Inlet) unit#6 47,5 40 18 6.7 0 0 0 0 0 15.3 45.6 GLO unit#4 38.2 34.3 29.1 9.1 0 5.7 0 0 0 15.2 38 GLOunit#5 38.1 34.7 28.6 &7 0 6.8 0 0 0 15.2 38.1 GLO unit#6 38.1 34.5 28.2 8.2 0 7.4 0 0 0 15 37.9 Exhaust Expansion Joint 39.3 35.1 22.6 14.9 8.6 0 0 0 0 13.5 38.6 Exhaust Expansion Joint unit#2 39 35 22.6 14.9 8.2 0 0 0 0 13.4 38.4 Exhaust Expansion Joint unit#3 38.8 34.9 22.3 14.5 7.7 0 0 0 0 13.1 38.2 Exhaust Expansion Joint unit#4 38.5 34.7 22 14,1 7.2 0 0 0 0 12,8 37,9 GSU 20.2 23.9 21.7 15.2 9.6 6.7 0 0 0 12.8 26.5 GSU unit #2 19.8 23.6 21.4 14.9 9.1 6.8 0 0 0 12.5 26.2 Exhaust Expansion Joint unit#5 38.3 34.4 21.7 13.7 6.7 0 0 0 0 12.5 37.7 Exhaust Expansion Joint unit #6 38.1 34 21.3 13.3 8.3 0 0 0 0 12.4 37.4 GSU unit #3 19.4 23.2 21 14.4 8.5 6.3 0 0 0 12.1 25.8 GSU unit #4 19 22.8 20.7 14 8 5.8 0 0 0 1L6 25.4 GSU unit#5 1&6 22.5 20.3 13.6 7.5 5.5 0 0 0 11.2 25 GSU unit #6 18.3 22.1 19.9 13.3 7.7 4,7 0 0 0 10,9 24.7 Stack Walls (Lower) unit #4 42.3 30.8 1.1 0 0 0 0 0 0 6.9 39.8 Stack Walls (Lower) unit #5 42.5 30.5 0.7 0 0 0 0 0 0 6.8 39.9 Stack Walls (Lower) unit #3 42.2 30.6 1.6 0 0 0 0 0 0 6.8 39.7 Stack Walls (Lower) unit#6 42.5 30,2 0.7 0 0 0 0 0 0 6.7 39.9 Stack Walls (Lower) unit #2 42.3 30.3 2.1 0 0 0 0 0 0 6.7 39.7 Ammonia Skid 29.3 27.4 17.8 9.8 0 0 0 0 0 6.6 29.8 Stack Walls (Lower) 42.5 29.9 2.5 0 0 0 0 0 0 6.5 39.9 Ammonia Skid unit #2 28.9 27.3 17.9 9.3 0 0 0 0 0 6.5 29.6 Ammonia Skid unit #3 28.5 26.9 17.6 8.8 0 0 0 0 0 6.1 29.2 Ammonia Skid unit #4 28.1 26.5 17.3 8.4 0 0 0 0 0 5.7 28.8 Ammonia Skid unit#6 27.4 25.8 16.5 8.8 0 0 0 0 0 5.6 28.1 Ammonia Skid unit #5 27.8 26.2 16.9 7.9 0 0 0 0 0 5.4 28.4 Stack Walls (Upper) 41.2 26.3 0 0 0 0 0 0 0 4.1 38.4 Stack Walls (Upper) unit#2 40.8 26 0 0 0 0 0 0 0 3.7 38 Stack Walls (Upper) unit#3 40.6 25.6 0 0 0 0 0 0 0 3.4 37.8 Stack Walls (Upper) unit #4 40.3 25.3 0 0 0 0 0 0 0 3.2 37.6 Stack Walls (Upper) unit #5 40 25 0 0 0 0 0 0 0 2.8 37.3 Stack Walls (Upper) unit #6 39.7 24.7 0 0 0 0 0 0 0 2.5 37 Control House unit#3 26.6 20.8 12.5 0 0 0 0 0 0 L8 25.4 Control House unit #4 26.4 21.1 12.1 0 0 0 0 0 0 1.5 25.4 Control House unit #5 26.4 21.6 11.7 0 0 0 0 0 0 1.4 25.5 Control House unit#2 26.9 20.9 12.5 0 0 0 0 0 0 L4 25.6 Control House unit#6 26.5 21.3 11.3 0 0 0 0 0 0 L1 25.4 Control House 27.3 21.1 12.6 0 0 0 0 0 0 0.9 25.9 Turrbine to Generator Coupling 25 23.2 10.4 0 0 0 0 0 0 0 25.3 Turrbine to Generator Coupling unit #2 24.7 22.9 10.2 0 0 0 0 0 0 0 25.1 Turrbine to Generator Coupling unit #3 24.4 22.8 9.9 0 0 0 0 0 0 0 24.9 Turrbine to Generator Coupling unit #4 24.2 22.9 9.4 0 0 0 0 0 0 0 24.8 Turrbine to Generator Coupling unit #5 24 22.6 9.1 0 0 0 0 0 0 0 24.6 Turrbine to Generator Coupling unit #6 23.9 22.3 8.7 0 0 0 0 0 0 0 24.3 SUS -A 5.4 9.9 6 0 0 0 0 0 0 0 11.7 SUS -B 5.1 10.8 5.6 0 0 0 0 0 0 0 12 1/2 Mile from Property Boundary WITH BARRIER WALL Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 191 1041 Submittal Application Attachment 19 Nuisance Plan Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Nuisance Plan 11041 Submittal Application Nuisance Plan Background Mountain Peak Power, LLC is proposing construction of a supplemental, natural gas fired power plant in Weld County off County Road 55 northwest of the Town of Keenesburg. The site will be co -located with the existing United Power Tesla Substation. Refer to Site Plan drawing 31324-GG101 located in Attachment 3 for sign locations described herein. Possible Nuisances The project design is intended to reduce any nuisances to adjacent property owners and surround areas, which may arise from construction and operations. Nuisances addressed are: • Dust • Light • Noise • Odor • Visual Construction Construction is planned to only occur during the hours of 7:00 am to 5:00 pm and is expected to last roughly 8 months or less, weather dependent. Possible nuisances during construction and how they will be mitigated are: • Dust — Soils will be disturbed on the site during construction, the project will be employing water trucks to suppress dust over the course of construction. • Light — Due to planned hours of construction, no light nuisances are expected. • Noise — Typical noise generated from construction equipment and vehicles is he only expected source of noise. The construction noise will be intermittent and not reach any levels greater than those that would be considered a nuisance to adjacent properties. For reference, there are no residences within 1,500 feet of the stie. • Odor — No odors that would affect adjacent properties are expected to be generated during course of construction. • Traffic — Construction employee traffic will occur twice a day over the course of construction along with larger vehicles for equipment or material deliveries. Please see Traffic Study in Attachment 17 for estimated construction traffic. • Visual — Since construction will be a temporary endeavor, the project is not expected to create any line of sight or visual disturbances to the surrounding areas. Operations Once the plant starts commercial operations, nuisances from the site will decrease significantly, particularly dust and traffic. Possible nuisances during the facility operations and how they will be mitigated are: e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Nuisance Plan 11041 Submittal Application • Dust — Since roads and employee parking will be gravel, there potentially could be dust issues. If necessary, a water truck will be employed to suppress dust. • Light — Site lighting will be provided by cutoff or hooded light poles installed along internal side roads to allow operators safe traversing of the site. Cutoff or hooded light fixtures will minimize or remove the amount of horizontal light emitted from the light fixtures. This includes strategic aiming of light fixture downwards for focused luminance. This will avoid nuisance lighting for adjacent properties and reduce potential for light pollution. • Noise — Applicant has contracted a Noise Study (See Attachment 23) to identify compliance with Weld County noise levels measured 25' off of the property lines. The Noise Study includes an overlay of estimated sound levels into adjacent properties on Page 13. Using Industrial noise ordinance levels, the Project is expected to be well under the day and nighttime levels. The Noise Study helps Applicant establish equipment noise mitigation techniques and best practices to ensure levels are well below the established acceptable levels. Applicant will use the Study to help define specifications for equipment suppliers to mitigate possible sources of noise. • Odor — No odors that would affect adjacent properties are expected to be generated during operations. • Traffic — Traffic will be very limited with 2 employees per shift. Highest traffic volume will occur twice a day during shift change over. • Visual — For majority of the facilities operation life, it is not expected to create any visual nuisance. No additional visual mitigation is planned for the Project at this time. Please see the Landscaping Plan in Attachment 20 for further details on this. e Stanley Consultants Mountain Peak Power, LLC Mountain Peak Power Project Attachment 14 11041 Submittal Application Attachment 14 Sewage Disposal Plan Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Sewage Disposal Plan 11041 Submittal Application Sewage Disposal Plan Background Mountain Peak Power, LLC is proposing construction of a supplemental, natural gas fired power plant in Weld County off County Road 55 northwest of the Town of Keenesburg. The site will be co -located with the existing United Power Tesla Substation. Refer to Site Plan drawing 31324-GG 101 located in Attachment 3 for sign locations described herein. Control Trailer For the plant Control Trailer, the project is planning to install a double -wide trailer. The double -wide trailer will include a dedicated area for operator control room, server and control system hardware area, operator offices, and locker room. The double -wide is expected to be 24 -ft x 60 -ft and will have Americans with Disabilities Act (ADA) accessible ramps to entrance/exit doors. Employee parking will be located in front of the Control Trailer. Control Trailer Example: Sewage/Septic Disposal — The project will employee two (2) Operators per shifts with two (2) — 12 hour shifts each day. There is currently no plans to install a dedicated indoor bathroom with septic system on the site. Mobile/temporary bathroom and washroom facilities will be separate from and external to the trailer and will include tanks to contain generated sanitary wastewater. The temporary sanitary wastewater holding tanks will be emptied by vacuum septic truck on a regular basis and disposed off site. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 18 11041 Submittal Application Attachment 18 Sign Plan Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC Q Mountain Peak Power Project Sign Plan 11041 Submittal Application Sign Plan Background Mountain Peak Power, LLC is proposing construction of a supplemental, natural gas fired power plant in Weld County off County Road 55 northwest of the Town of Keenesburg. The site will be co -located with the existing United Power Tesla Substation. Refer to Site Plan drawing 31324-GG 101 located in Attachment 3 for sign locations described herein. Freestanding Sign An identification freestanding sign will be posted prior to the main access security gate for the Mountain Peak Power Plans. The sign will indicate the facility name and contact number to control room for emergencies, deliveries, and any other site visitors. The sign will be limited to 2 sq. ft. in accordance with Appendix 23-C through E of the Weld County Code for corresponding site zoning. MOUNTAIN PEAK POWER Call XXX-XXX-XXX For Emergencies & Deliveries Site Signage Control Trailer & Parking — Will have sign posted on exterior identifying "Control Trailer". Parking area. will have appropriate CDOT ADA equivalent for handicap parking spots. Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Sign Plan 11041 Submittal Application EgUlpm2►1t Areas — Areas around equipment and process areas will have appropriate levels of Personnel Protective Equipment (PPE) identified, particularly hard hat and hearing protection requirements. CAUTION HARD HATS. SAFETY GLASSES AND HEARING PROTECTION REQUIRED IN ALL PROCESS AREAS OF ELECTRIC DEPT. FACiLITIES Overhead Lines - Project will coordinate with United Power for warnings for areas and site roads the cross under existing overhead lines. Site Safety — The project will be performing HAZOP reviews during the course of project development to identity any areas on the site requiring additional signage related to PPE or emergency response instructions. Site Construction During construction, the project shall install temporary signs directing construction related site traffic to designated areas for the following: Construction Parking )) Construction Laydown Area for • Equipment and material lydown • Staging Areas )) Directing construction vehicle traffic while onsite to use designated temporary site roads and minimize disturbance to vegetation. e Stanley Consultants Mountain Peak Power, LLC Mountain Peak Power Project Attachment 17 — Rev 1 11041 Submittal Application Attachment 17 Traffic Study Narrative - Rev 1 Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Weld County Traffic Report— Rev 1 11041 Submittal Application Weld County Department of Planning Services 1402 N. 17th Avenue, PO Box 758 Greeley, CO 80632 RE: Mountain Peak Power Plant Traffic Impact Memo — Rev 1 Mountain Peak Power, LLC (Mountain Peak) is proposing construction of a supplemental, natural gas fired power plant in Weld County off County Road 55 northwest of the Town of Keenesburg. The site will be co -located with the existing United Power, "Tesla" substation facility and Battery Energy Storage Facility (BESS) approximately two miles north of the intersection of County Road 55 and County Road 18, as depicted in the vicinity map below. The site is located at the intersection of County Road 55 and County Road 22. General Requirements Questions addressed by this traffic narrative 1. Describe how many roundtrips/day are expected for each vehicle type: Passenger Cars/Pickups, Tandem Trucks, Semi-Truck/Trailer/RV (Roundtrip = One (1) trip in and One (1) trip out of site). 2. Describe the expected travel routes or haul routes for site traffic. 3. Describe the travel distribution along the routes (e.g. 50% of traffic will come from the north, 20% from the south, 30% from the east, etc.). 4. Describe the time of day that you expect the highest traffic volumes. 1. Describe how many roundtrips/day are expected for each vehicle type: Passenger Cars/Pickups, Tandem Trucks, Semi-Truck/Trailer/RV (Roundtrip = One (1) trip in and One (1) trip out of site). Construction of Mountain Peak's new plant will occur over a 11- to 12 -month period starting in July of 2024 thru June of 2025. The construction will be broken into three different phases. The table below shows the anticipated Daily vehicular traffic for each phase along with the duration of each construction phase. Vehicle Type (Daily Trips) Phase 1 Phase 2 Phase 3 ("2 months) (~8 months) ("2 months) Passenger cars 30 60 35 Pickup Trucks 12 15 18 Semi -trucks/ Construction Heavy Vehicles 4 6 2 2. Describe the expected travel routes or haul routes for site traffic. To access the Mountain Peak site, most traffic will utilize the I-76 interchange in Keenesburg, head north to County Road 18, turn left onto County Road 18 then turn right onto County Road 55. This route is anticipated to serve traffic accessing the site during and post construction. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Weld County Traffic Report — Rev 1 1 1041 Submittal Application Figure 1: Vicinity Map 3. Describe the travel distribution along the routes (e.g. 50% of traffic will come from the north, 20% from the south, 30% from the east, etc.). Travel distribution is expected to be 100% from the south from County Road 18. County Road 55 and County Road 22 do not allow traffic access from any other direction. 4. Describe the time of day that you expect the highest traffic volumes. Construction activities are expected to be during the daylight hours from 6am to 6pm, with one security vehicle posted at the construction site overnight. The peak hours will be when crews arrive and depart for the day, mostly concentrated between 6:OOam and 7:3Oam and between 4pm and 6pm. Deliveries of construction equipment and supplies will occur throughout the day at various times. After construction activities are completed and the plant is operational, the plant will have approximately two (2) operators per shift, with two shifts per day. It is also expected that normal maintenance will occur once per year and may require site access for additional equipment and operators. When the site is active e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Weld County Traffic Report— Rev 1 1 1041 Submittal Application it is expected that the only weekly vehicles accessing the site will be pickup trucks, smaller delivery box trucks, small equipment vehicles, such as forklifts, and one (1) or two (2) 19% aqueous ammonia delivery trucks. Given that Mountain Peak's operations will produce minimal traffic once the plant is operational, this project is not expected to negatively impact traffic operations around the site or on any of the roadways used to access the site. All existing roadways used to access the site will be able to support the additional traffic without needing any additional capacity. During construction there will be a higher number of vehicles utilizing the roadways, but the additional, temporary construction -related traffic is also not expected to negatively impact the roadway during construction. After Mountain Peak's plant is constructed the increase in traffic is negligible; as such, a full traffic report should not be required for this project. Development Review will review the Traffic Narrative and advise the applicant if more information or an engineered traffic impact study is required. Sincerely, TJ Scarberry Traffic Department Manager Stanely Consultants, Inc. e Stanley Consultants Mountain Peak Power, LLC Mountain Peak Power Project Attachment 13 — Rev 111041 Submittal Application Attachment 13 Site Water Plan - Rev 1 Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 271 1041 Submittal Application Attachment 27 Names & Address with Property Disturbed by Project Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Easement Crossing 11041 Submittal Application Easement Crossing The Project will most likely cross the following easement rights holders listed below. Easements/Reception Number Green River DevCo, LP. Pipeline and electric line right of way grant. 4360161 Green River Devco LP has Noble Energy as its sole member. The easement is associated with an underground pipeline corridor that crosses the southeast corner of the site. Please see the 1041 URS Map in Attachment 29 for specific location of easement. This easement is located at the current site access point from County Road 55 for the property. This access point will continue to be used during construction and operation of the planned Mountain Peak Power Project. Applicant has contacted easement holder (Noble Energy) to discuss the Project and expected construction traffic over easement. Easement holder has communicated that existing underground pipelines will not be damaged if maximum construction wheel load is kept under 27,000 lbs. Applicant will provide measures to ensure that the corridor is protected during construction using steel plates and other mitigating measures. Applicant is working with the largest equipment supplier to verify expected vehicles loads. The following was provided by Noble Energy to show pipeline routing. e Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Easement Crossing 11041 Submittal Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 8 11041 Submittal Application Attachment 8 Property Traverses Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Property Traverses 11041 Submittal Application Names & Owners of Property Easement Traverses 8 — Easements/Reception Number Weld County Road right of way 34283 Electric facilities owned by United Power, Inc. Right of way 2239296 & 2817765 DRAJ LLC Waterline easement 4380178 & 4616042 C Stanley Consultants Continental Oil Company Pipeline right of way in public highways 6302111 Board of County Commissioners of Weld County License agreement for maintenant of right of way 3968135 Lone Tree Turkey Farm, Inc. Roadway right of way use 1399149 Green River DevCo, LP. Pipeline and electric line right of way grant. 4360161 Mountain Peak Power, LLC Mountain Peak Power Project Attachment 25 11041 Submittal Application Attachment 25 Community Meetings Plan Mountain Peak Power Weld County 1041 Application Stanley Consultants Mountain Peak Power, LLC I Mountain Peak Power Project Community Meetings 11041 Submittal Application Community Meetings Plan To date, the Applicant has been meeting individually with stakeholders and owners of surrounding property, including the Town of Keenesburg and Joel Farkas. In addition to these individual meetings, the Applicant will hold a community meeting for surrounding landowners. The Applicant intends to send out written notice of this hearing in mid -to -late January 2024 and hold the hearing in February 2024. The Applicant is currently inquiring with the Town of Keenesburg about a public location for this meeting. The Applicant will submit meeting minutes and a list of attendees when available. e Stanley Consultants MOUNTAIN PEAK POWER STATION PROJECT COMMUNITY MEETING UPDATE The Applicant held a community meeting on Wednesday February 14th. The Applicant sent notice of the meeting to the addresses identified on the Certified List of Adjacent Property Owners submitted with the Application. The notices were sent via priority mail, a list of the tracking numbers is set forth below. USPS #9114 9023 0722 4755 4254 19 USPS#9114 9023 0722 4755 4254 02 USPS#9114 9023 0722 4755 4254 33 USPS#9114 9023 0722 4755 4253 96 USPS#9114 9023 0722 4755 4253 89 USPS#9114 9023 0722 4755 4254 57 USPS#9114 9023 0722 4755 4254 40 USPS#9114 9023 0722 4755 4254 26 Attached hereto are copies of (i) the mailed Notice of Community Meeting, (ii) the sign -in sheet from the community meeting, and (iii) confirmation of the booking at Hoff Elementary School for the community meeting. NOTICE OF COMMUNITY MEETING On January 18, 2024, Mountain Peak Power, LLC ("Mountain Peak") filed a 1041 application (the "Application") with Weld County (the "County") requesting approval for the construction and operation of a peaking power generation facility comprised of natural gas simple -cycle combustion turbines (the "Project") located on the real property depicted on Exhibit A attached hereto. A COMMUNITY MEETING regarding the Application will be held as follows: WEDNESDAY, FEBRUARY 14, 2024 4:30-6:30 p.m. Hoff Elementary School Library 7558 WCR 59 Keenesburg, CO 80643 Interested persons may appear and be heard regarding the above -described matter. Representatives from Mountain Peak will be present at the community meeting to answer questions from the public. The County contact for the Application is: Maxwell Nader Planning Manager, Dept. of Planning Services mnader@weld.gov Phone: (970)-400-3527 From: To: Subject: Date: no-reply@rei.gofmx.com Shawn Donovan Hoff Elementary School schedule request updated Friday, February 9, 2024 11:16:14 AM Warning External Email Hello Shawn Donovan, Your request "2646523 - Mountain Peak Power Project Community Meeting" was updated. Schedule request details Request type Community Event Event name 2646523 - Mountain Peak Power Project Community Meeting Buildings Hoff Elementary School Resources Hoff Commons Event time Wed, Feb 14, 2024, 4:00pm - 6:30pm 01: Number of 20 Attendees 02: Event Setup Library Details 03: Technology Projector Details 08: Additional We need a table and chairs enough for 15 people Event Details please. agree to the Yes Facilities Use Agreement and Associated Fees View request Thank you for your email. Your request cannot be processed at this time. Please go to https://re3j.gofmx.com to enter your request you must first log into FMX.com. Thank You ©2024 FMX ALL Rights Reserved Unsubscribe Notice of Inquiry Weld County Pre -application Case # PRE23-0285 Date of Inquiry 11/30/2023 Municipality Keenesburg CPA Name of Person Inquiring Mountain Peak Power, LLC c/o Jon Baylor Property Owner United Power Inc. Planner Maxwell Nader Planner Phone Number 970-400-3527 Planner Email Address mnader@weld.gov Le al g Description p Being County, a part of CO the SE4SE4 of Section 9, T2N, R64W of the 6th P.M., Weld Parcel Number 130509000005 Nearest Intersection CR 22 and CR 55 of Inquiry Peaker Plant for United Power Type The above person met with County Planning staff about developing a parcel of land inside your designated Intergovernmental Agreement/Coordinated Planning Agreement Boundary. /7/ ///77 /4/ County Planner's signature Would you like to pursue annexation of this property? NO X YES Date of Contact OZ C1.O7 P Comments: i'Lekte-rti /Yege- tb- i 7aruistot ce airitaii TO agp h re (ki tif CP kfialA-44,7 e nt , - ciimiNtaited c; C / 7.1t- coneoitec 41,,cseir_ alie<fr-s37 ‘rqs. toolb of. O7 y Signature of Municipality Representative Title Date Please sign and date to acknowledge that the applicant has contacted you and return this signed form to Weld County Department of Planning Services. Weld County Planning Department 1402 N 17th Ave, Greeley, CO 80631 ' (970) 400-6100 ' (970) 304-6498 Fax 20181107 Mountain Peak Power, LLC I Mountain Peak Power Project Attachment 12 11041 Submittal Application Attachment 12 Signed Statement of Taxes Mountain Peak Power Weld County 1041 Application Stanley Consultants Weld County Treasurer Statement of Taxes Due Account Number R5070686 Parcel 130509000005 Assessed To UNITED POWER INC 500 COOPERATIVE WAY BRIGHTON, CO 80603-8728 Legal Description Situs Address 8370A PT SE4 9 2 64 BEG AT SE COR SEC 9 W1005' N825' E1005' S825' TO BEG EXC UPRR RES 10001 COUNTY ROAD 55 WELD Year Tax Interest Fees Payments Balance Grand Total Due as of 11/15/2023 $0.00 ALL TAX LIEN SALE AMOUNTS ARE SUBJECT TO CHANGE DUE TO ENDORSEMENT OF CURRENT TAXES BY THE LIENHOLDER OR TO ADVERTISING AND DISTRAINT WARRANT FEES. CHANGES MAY OCCUR AND THE TREASURER'S OFFICE WILL NEED TO BE CONTACTED PRIOR TO REMITTANCE AFTER THE FOLLOWING DATES: PERSONAL PROPERTY, REAL PROPERTY, AND MOBILE HOMES - AUGUST 1. TAX LIEN SALE REDEMPTION AMOUNTS MUST BE PAID BY CASH OR CASHIER'S CHECK. POSTMARKS ARE NOT ACCEPTED ON TAX LIEN SALE REDEMPTION PAYMENTS. PAYMENTS MUST BE IN OUR OFFICE AND PROCESSED BY THE LAST BUSINESS DAY OF THE MONTH. 1400 N. 17th Avenue, Greeley, CO 80631. PO Box 458, Greeley, CO 80632. (970) 400-3290 Page 1 of 1 Hello