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Home My WebLink AboutAPPLICATION - FINAL DRAFT _Huslia REF_GrantApRenewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 1 of 43 10/04/2022 Application Forms and Instructions This instruction page and the following grant application constitutes the Grant Application Form for Round 15 of the Renewable Energy Fund (REF). A separate application form is available for projects with a primary purpose of producing heat (see Request for Applications (RFA) Section 1.5). This is the standard form for all other projects, including projects that will produce heat and electricity. An electronic version of the RFA and both application forms is available online at: https://www.akenergyauthority.org/What-We-Do/Grants-Loans/Renewable-Energy-Fund/2022- REF-Application. What follows are some basic information and instructions for this application: • If you are applying for grants for more than one project, provide separate application forms for each project. • Multiple phases (e.g. final design, construction) for the same project may be submitted as one application. • If you are applying for grant funding for more than one phase of a project, provide milestones and grant budget for each phase of the project (see Sections 3.1 and 3.2.2). • In order to ensure that grants provide sufficient benefit to the public, AEA may limit recommendations for grants to preliminary development phases in accordance with 3 Alaska Administrative Code (ACC) 107.605(1). • If some work has already been completed on your project and you are requesting funding for an advanced phase, submit information sufficient to demonstrate that the preceding phases are completed and funding for an advanced phase is warranted. Supporting documentation may include, but is not limited to, reports, conceptual or final designs, models, photos, maps, proof of site control, utility agreements, business and operation plans, power sale agreements, relevant data sets, and other materials. Please provide a list of supporting documents in Section 11 of this application and attach the documents to your application. • If you have additional information or reports you would like the Authority to consider in reviewing your application, either provide an electronic version of the document with your submission or reference a web link where it can be downloaded or reviewed. Please provide a list of additional information; including any web links, in Section 12 of this application and attach the documents to your application. For guidance on application best practices please refer to the resource-specific Best Practices Checklists; links to the checklists can be found in the appendices list at the end of the accompanying REF Round 15 RFA. • In the Sections below, please enter responses in the spaces provided. You may add additional rows or space to the form to provide sufficient space for the information, or attach additional sheets if needed. • If you need assistance with your application, please contact AEA’s Grants Coordinator by email at grants@akenergyauthority.org or by phone at (907) 771-3081. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 2 of 43 10/04/2022 REMINDER: • AEA is subject to the Public Records Act AS 40.25, and materials submitted to AEA may be subject to disclosure requirements under the act if no statutory exemptions apply. • All applications received will be posted on the Authority web site after final recommendations are made to the legislature. Please submit resumes as separate PDFs if the applicant would like those excluded from the web posting of this application. • In accordance with 3 AAC 107.630 (b) Applicants may request trade secrets or proprietary company data be kept confidential subject to review and approval by AEA. If you want information to be kept confidential the applicant must: o Request the information be kept confidential. o Clearly identify the information that is the trade secret or proprietary in their application. o Receive concurrence from the Authority that the information will be kept confidential. If the Authority determines it is not confidential, it will be treated as a public record in accordance with AS 40.25 or returned to the applicant upon request. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 3 of 43 10/04/2022 SECTION 1 – APPLICANT INFORMATION Please specify the legal grantee that will own, operate, and maintain the project upon completion. Name (Name of utility, IPP, local government, or other government entity) Tanana Chiefs Conference Tax ID # 920040308 Date of last financial statement audit: Audit for year ending 9/30/21 was completed 1/31/22 Mailing Address: Physical Address: 122 1st Ave Suite 300 same Fairbanks, AK 99701 Telephone: Fax: Email: (907) 452-8251 (907) 459-3852 dave.pm@tananachiefs.org 1.1 Applicant Point of Contact / Grants Coordinator Name: Title: Dave Messier Infrastructure Division Director Mailing Address: 122 1st Ave Suite 300 Fairbanks, AK 99701 Telephone: Fax: Email: (907) 452-8251 (907) 459-3852 dave.pm@tananachiefs.org 1.1.1 Applicant Signatory Authority Contact Information Name: Brian Ridley Title: Chief/Chairman Mailing Address: 122 1st Ave Suite 300 Fairbanks, AK 99701 Telephone: 907-452-8251 Fax: Email: brian.ridley@tananachiefs.org 1.1.2 Applicant Alternate Points of Contact Name Telephone: Fax: Email: Amber Vaska 907-452-8251 amber.vaska@tananachiefs.org Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 4 of 43 10/04/2022 1.2 Applicant Minimum Requirements Please check as appropriate. If applicants do not meet the minimum requirements, the application will be rejected. 1.2.1 Applicant Type ☐ An electric utility holding a certificate of public convenience and necessity under AS 42.05 CPCN #______, or ☒ An independent power producer in accordance with 3 AAC 107.695 (a) (1) CPCN #______, or Draft PPA attached ☐ A local government, or ☐ A governmental entity (which includes tribal councils and housing authorities) Additional minimum requirements ☒ 1.2.2 Attached to this application is formal approval and endorsement for the project by the applicant’s board of directors, executive management, or other governing authority. If the applicant is a collaborative grouping, a formal approval from each participant’s governing authority is necessary. (Indicate yes by checking the box) ☒ 1.2.3 As an applicant, we have administrative and financial management systems and follow procurement standards that comply with the standards set forth in the grant agreement (Section 3 of the RFA). (Indicate yes by checking the box) ☒ 1.2.4 If awarded the grant, we can comply with all terms and conditions of the award as identified in the Standard Grant Agreement template at https://www.akenergyauthority.org/What-We-Do/Grants-Loans/Renewable-Energy- Fund/2022-REF-Application (Any exceptions should be clearly noted and submitted with the application.) (Indicate yes by checking the box) ☒ 1.2.5 We intend to own and operate any project that may be constructed with grant funds for the benefit of the general public. If no please describe the nature of the project and who will be the primary beneficiaries. (Indicate yes by checking the box) Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 5 of 43 10/04/2022 SECTION 2 – PROJECT SUMMARY 2.1 Project Title Provide a 4 to 7 word title for your project. Type in the space below. Huslia Community-Scale Solar PV and Battery Project 2.2 Project Location 2.2.1 Location of Project – Latitude and longitude (preferred), street address, or community name. Latitude and longitude coordinates may be obtained from Google Maps by finding you project’s location on the map and then right clicking with the mouse and selecting “What is here? The coordinates will be displayed in the Google search window above the map in a format as follows: 61.195676.-149.898663. If you would like assistance obtaining this information, please contact AEA’s Grants Coordinator by email at grants@akenergyauthority.org or by phone at (907) 771- 3081. Latitude 65.69997 Longitude -156.39288 The project will take place in Huslia, Alaska, a community in the Doyon and Tanana Chiefs Conference (TCC) region. Huslia is an isolated, rural community located in the interior of Alaska on the north bank of the Koyukuk River, about 290 air miles west of Fairbanks. The community is home to approximately 275 residents; 92% of the residents are Alaska Native. The Huslia Tribal Council (HTC) is the governing body for Huslia Tribal members. The HTC works closely and shares governing responsibilities in the community with the City of Huslia. 2.2.2 Community benefiting – Name(s) of the community or communities that will be the beneficiaries of the project. TCC will operate this system as an Independent Power Producer with a power sales agreement to the Alaska Village Electric Cooperative (AVEC). All benefits from this project will be passed through to the rate payers of Huslia. 2.3 Project Type Please check as appropriate. 2.3.1 Renewable Resource Type ☐ Wind ☐ Biomass or Biofuels (excluding heat-only) ☐ Hydro, Including Run of River ☐ Hydrokinetic ☐ Geothermal, Excluding Heat Pumps ☐ Transmission of Renewable Energy ☒ Solar Photovoltaic ☒ Storage of Renewable ☐ Other (Describe) ☐ Small Natural Gas 2.3.2 Proposed Grant Funded Phase(s) for this Request (Check all that apply) Pre-Construction Construction ☐ Reconnaissance ☒ Final Design and Permitting Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 6 of 43 10/04/2022 ☐ Feasibility and Conceptual Design ☒ Construction 2.4 Project Description Provide a brief, one-paragraph description of the proposed project. Huslia Community-Scale Solar PV and Battery Project proposes to install a 350 KW solar photovoltaic (PV) and 500 kWh battery energy storage system (BESS). This project will be integrated into Alaska Village Electric Cooperative’s (AVEC’s) existing stand-alone diesel electric generation and distribution grid in Huslia and save the community approximately 32,243 gallons of diesel fuel annually and about 806,075 gallons over the projected 25-year life of the installation. The project will be installed on City land above certified flood level and will use a combination of contracted and local labor. This clean energy initiative will build on recent efforts that include powerplant upgrades to automated switchgear, improved diesel generator controls and higher efficiency engines, transformer upgrades and changeouts that have already saved several thousand gallons of fuel annually, LED lighting improvements, and a highly trained workforce. TCC is seeking $2,082,000 from the AEA Renewable Energy Fund. If awarded, it is expected that final design, permitting, and long lead-time equipment procurement will occur in 2023 and early 2024, construction will commence in summer of 2024, and system performance verification and reporting will continue through the end of 2024. TCC will serve as an Independent Power Producer and AVEC will purchase the renewable power through a Power Purchase Agreement (PPA). 2.5 Scope of Work Provide a short narrative for the scope of work detailing the tasks to be performed under this funding request. This should include work paid for by grant funds and matching funds or performed as in-kind match. The scope of work that would occur under this funding request includes final design, permitting, and construction of a 350 kW bifacial solar PV and 500 kWh BESS that would be integrated into the AVEC diesel powerplant and power distribution system in Huslia. Specific tasks include the following: • Finalize system design, including exact size of PV array and BESS, and capital budget. TCC and the design firm will collaborate with equipment suppliers to minimize engineering costs. • Procure equipment. • Issue RFP for construction contractor. • Finalize site control. • Secure all necessary permits. • Ship all equipment to site. • Hire local labor for installation. • Install, commission, and integrate PV array and BESS. • Train local utility and IPP staff for ongoing O&M, troubleshooting, system optimization with the installation contractor and TCC staff. • Conduct ongoing system performance monitoring and verification, community education and outreach so that community members understand the value of the solar panels, and grant reporting to funders and other stakeholders. 2.6 Previous REF Applications for the Project See Section 1.15 of the RFA for the maximum per project cumulative grant award amount Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 7 of 43 10/04/2022 Round Submitted Title of application Application #, if known Did you receive a grant? Y/N Amount of REF grant awarded ($) None SECTION 3 – Project Management, Development, and Operation 3.1 Schedule and Milestones Please fill out the schedule below (or attach a similar sheet) for the work covered by this funding request. Be sure to identify key tasks and decision points, including go/no go decisions, in your project along with estimated start and end dates for each of the milestones and tasks. Please clearly identify the beginning and ending of all phases (I. Reconnaissance, II. Feasibility and Conceptual Design, III. Final Design and Permitting, and IV. Construction) of your proposed project. See the RFA, Sections 2.3-2.6 for the recommended milestones for each phase. Add additional rows as needed. Task # Milestones Tasks Start Date End Date Deliverables 1.1 (Final Design & Permitting) Grant in Place, Project Kick-off • Kickoff Meeting 7/1/23 8/31/23 • Signed Grant Agreement, kickoff mtg notes 2.1(Final Design & Permitting) Site Control • Finalize Location for Solar Array 8/1/23 12/31/23 • Signed Site Control Agreement 2.2 (Final Design and Permitting) Procurement for Design Team • Issue invitation to bid/RFP for Design Contract • Determine selection committee • Score and select Contractors • Negotiate and Sign Contracts 8/1/23 9/31/23 • Selection Process 2.3 (Final Design and Permitting) Complete Design and Permitting • Finalize system sizing • 65% Engineering Design • 95% Engineering Design • Construction Ready Prints • Permit applications • Order Equipment 10/1/23 3/31/24 • Final Design Drawing • Permits • PO’s for equipment purchase 2.4 (Final Design and Permitting) Finalize PPA and Business Plan • Sign PPA • IPP Budget and O&M Plan 10/1/23 2/28/24 • Signed PPA • IPP Business Plan Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 8 of 43 10/04/2022 3.1 (Construction) Mobilization and Site Prep • Construction Plans 4/1/24 6/31/24 • Detailed Construction Timeline 3.2 (Construction) Construction • Solar PV Install • Battery Building and Battery install • Electrical and Controls Integration 7/1/24 9/30/24 • Photos of construction progress • Contractor monthly reports 3.3 (Construction) Commissioning • Construction Checkout • Engineering Checkout • Start-up • Community Outreach 10/1/24 12/31/24 • Commissioning Punchlist 4.1 (Closeout) Performance Data Collection 1/1/25 12/31/35 Annual performance reports 4.2 (Closeout) Final Reports • Confirm completion of punch list • Confirm proper operation 1/1/25 2/28/25 • Completed punch list • Final performance report 4.3 (Closeout) Grant Close-out Close-out reports 3/1/25 3/31/25 Grant closeout forms 3.2 Budget 3.2.1 Funding Sources Indicate the funding sources for the phase(s) of the project applied for in this funding request. Grant funds requested in this application $2,082,000 Cash match to be provideda $25,000 In-kind match to be provideda $85,000 Energy efficiency match providedb $ Total costs for project phase(s) covered in application (sum of above) $2,192,000 Describe your financial commitment to the project and the source(s) of match. Indicate whether these matching funds are secured or pending future approvals. Describe the impact, if any, that the timing of additional funds would have on the ability to proceed with the grant. TCC will be providing $25,000 in cash match for the engineering design and permitting of this project. These funds are secured. TCC will provide $10,000 in In-Kind support for technical support, construction management, and project administration including the IPP business plan/PPA for this project. This will come from salaries for Dave Messier, Edward Dellamary, and Ben Shilling at TCC. These funds are secured. AVEC will provide $75,000 of In-Kind match for integration design, technical support, construction oversite, and commission related to the battery integration with the Power Plant by Forest Button, Dan Allis, and other AVEC technical staff. These funds are secured and are noted in the Letter of Commitment from AVEC in the appendices. If this REF grant application is funded, there will be no need for additional funds. All required funds will have been procured. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 9 of 43 10/04/2022 a Attach documentation for proof (see Section 1.18 of the Request for Applications) b See Section 8.2 of this application and Section 1.18 of the RFA for requirements for Energy Efficiency Match. 3.2.2 Cost Overruns Describe the plan to cover potential cost increases or shortfalls in funding. If there are cost increases and shortfalls in funding, TCC and AVEC have reserve accounts that could be tapped for small funding needs. If there are continued significant cost increases, TCC and project partners will pursue additional grant funding through the Denali Commission and Federal Grant and loan opportunities to complete the project. In addition, Huslia Tribe is expected to receive annual funding of $62,663 annually for the next 5 years from the Office of Grid Resiliency through the IAJA section 40101d. If there are cost overruns on this project Huslia will be able to utilize their 40101d money to assist with the project costs. 3.2.3 Total Project Costs Indicate the anticipated total cost by phase of the project (including all funding sources). Use actual costs for completed phases. Indicate if the costs were actual or estimated. Reconnaissance [Actual/Estimated] $Provided by NREL - statewide Feasibility and Conceptual Design [Actual/Estimated] $Provided by NREL as technical assistance - complete Final Design and Permitting [Actual/Estimated] $78,000 Construction [Actual/Estimated] $2,114,000 Total Project Costs (sum of above) Estimated $2,192,000 Metering/Tracking Equipment [not included in project cost] Estimated $ included in project cost 3.2.4 Funding Subsequent Phases If subsequent phases are required beyond the phases being applied for in this application, describe the anticipated sources of funding and the likelihood of receipt of those funds. • State and/or federal grants • Loans, bonds, or other financing options • Additional incentives (i.e. tax credits) • Additional revenue streams (i.e. green tag sales or other renewable energy subsidies or programs that might be available) N/A 3.2.3 Budget Forms Applications MUST include a separate worksheet for each project phase that was identified in Section 2.3.2 of this application — I. Reconnaissance, II. Feasibility and Conceptual Design, III. Final Design and Permitting, and IV. Construction. Please use the tables provided below to detail your proposed project’s total budget. Be sure to use one table for each phase of your project, and delete any unnecessary tables. The milestones and tasks should match those listed in 3.1 above. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 10 of 43 10/04/2022 If you have any question regarding how to prepare these tables or if you need assistance preparing the application please feel free to contact AEA’s Grants Coordinator by email at grants@akenergyauthority.org or by phone at (907) 771-3081. Phase 1 — Reconnaissance Milestone or Task Anticipated Completion Date RE- Fund Grant Funds Grantee Matching Funds Source of Matching Funds: Cash/In- kind/Federal Grants/Other State Grants/Other TOTALS (List milestones based on phase and type of project. See Sections 2.3 thru 2.6 of the RFA ) $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ TOTALS $ $ $ Budget Categories: Direct Labor & Benefits $ $ $ Travel & Per Diem $ $ $ Equipment $ $ $ Materials & Supplies $ $ $ Contractual Services $ $ $ Construction Services $ $ $ Other $ $ $ TOTALS $ $ $ Phase 2 — Feasibility and Conceptual Design Milestone or Task Anticipated Completion Date RE- Fund Grant Funds Grantee Matching Funds Source of Matching Funds: Cash/In- kind/Federal Grants/Other State Grants/Other TOTALS (List milestones based on phase and type of project. See Sections 2.3 thru 2.6 of the RFA ) $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 11 of 43 10/04/2022 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ TOTALS $ $ $ Budget Categories: Direct Labor & Benefits $ $ $ Travel & Per Diem $ $ $ Equipment $ $ $ Materials & Supplies $ $ $ Contractual Services $ $ $ Construction Services $ $ $ Other $ $ $ TOTALS $ $ $ Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 12 of 43 10/04/2022 Phase 3 — Final Design and Permitting Milestone or Task Anticipated Completion Date RE- Fund Grant Funds Grantee Matching Funds Source of Matching Funds: Cash/In- kind/Federal Grants/Other State Grants/Other TOTALS (List milestones based on phase and type of project. See Sections 2.3 thru 2.6 of the RFA ) $ $ $ Grant in Place, Project Kick-off in Community, grants administration $ - $ 3,000 TCC - in-kind $ 3,000 Site Control including surveying $ - $ 6,000 TCC - in-kind $ 6,000 IPP Business Plan and PPA $ 2,000 TCC - in-kind $ 2,000 Procurement $ - $ 2,000 TCC - in-kind $ 2,000 Complete Design and Permitting $ - $ 25,000 TCC - cash $ 25,000 Solar PV/Battery Design Technical Support and Powerplant Integration design $ 40,000 AVEC - in- kind $ 40,000 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ TOTALS $ $ 78,000 $ 78,000 Budget Categories: Direct Labor & Benefits $ $ 53,000 $ 53,000 Travel & Per Diem $ $ $ Equipment $ $ $ Materials & Supplies $ $ $ Contractual Services $ $ 25,000 $ 25,000 Construction Services $ $ $ Other $ $ $ TOTALS $ $ 78,000 $ 78,000 Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 13 of 43 10/04/2022 Phase 4 — Construction Milestone or Task Anticipated Completion Date RE- Fund Grant Funds Grantee Matching Funds Source of Matching Funds: Cash/In- kind/Federal Grants/Other State Grants/Other TOTALS (List milestones based on phase and type of project. See Sections 2.3 thru 2.6 of the RFA ) $ $ $ Equipment Procurement $ 1,089,755 $ - $ 1,089,755 Shipping $ 167,246 $ 167,246 Construction- Renewable Energy $ 750,000 $ - $ 750,000 Construction - Power Plant Integration $ 75,000 $ 5,000 AVEC - in- kind $ 80,000 Commissioning $ - $ 25,000 TCC/AVEC - in-kind $ 25,000 Final Reports $ $ 1,000 TCC - in-kind $ 1,000 Grant Close-out $ $ 1,000 TCC - in-kind $ 1,000 TOTALS $ 2,082,000 $ 32,000 $ 2,114,000 Budget Categories: Direct Labor & Benefits $ $ 32,000 $ 32,000 Travel & Per Diem $ $ $ Equipment $ $ $ Materials & Supplies $ $ $ Contractual Services $ 2,082,000 $ $ Construction Services $ $ $ Other $ $ $ TOTALS $ 2,082,000 $ 32,000 $ 2,114,000 Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 14 of 43 10/04/2022 3.2.4 Cost Justification Indicate the source(s) of the cost estimates used for the project budget, including costs for future phases not included in this application. The National Renewable Energy Lab provided a HOMER feasibility study that identified equipment sizing, diesels off hours and fuel savings in early 2022. Overall system size and expected output will be confirmed during the first stage of the design process. Equipment and construction price quotes were received from various equipment suppliers who recently participated in a very similar project in Shungnak. The HOMER study and price quotes are included in the appendices and are the basis for the budget. Similar cost estimates over the past year have been provided from other vendors that are very experienced in designing and constructing similar projects in remote Alaska. Further, the quotes were vetted with the broader project team, which has been involved in the design and installation of five similar systems in Deering, Buckland, Hughes, Shungnak, and Noatak. There are no future phases of the project not included in this construction application. TCC will operate and maintain this system once operational as an IPP. 3.3 Project Communications 3.3.1 Project Progress Reporting Describe how you plan to monitor the progress of the project and keep AEA informed of the status. Who will be responsible for tracking the progress? What tools and methods will be used to track progress? Project performance reports will compare accomplishments to the objectives stated in this proposal and the final grant agreement. The project performance report will identify completed tasks with supporting documentation and identify objectives for the next reporting period. Compliance with any special conditions on the use of award funds will be discussed as necessary. Reports will be submitted by the deadlines as found in the grant agreement. Dave Messier, Tanana Chiefs Infrastructure Division Director, will oversee and provide the performance reports, with significant input from project contractors and performance data from AVEC’s utility staff in the powerhouse. Within the contractual terms of the future agreement, contractors will be required to provide monthly updates of the most recent month and expected activities and expenditures for the next month. Once the systems are installed, we will check diesel consumption and energy expenditures compared to expected baseline on a quarterly basis, as well as solar PV production and battery output, to monitor system performance and compare against our goals. This will be reported to AEA as required in the grant agreement. If the project were to fall behind schedule, the project performance report will discuss the problems or delays that may affect completion of the project. Solutions to any project delays will be discussed in the report and with the AEA project manager. If any changes to the scope or objectives are needed, TCC will obtain prior written approval from AEA. We do not anticipate project delays or changes to scope, however, as we have a qualified and experienced team for managing the project and a successful track record for similar projects. When all required work is completed and administrative actions related to the completion of work have been accomplished, we will submit the final project report to AEA for review and comment. After AEA accepts the expenditure of funds and associated documentation, and the final project report, the project will officially be closed. TCC acknowledges that we may remain responsible in accordance with the terms of the grant agreement for compliance with conditions on property acquired through grant funds. 3.3.2 Financial Reporting Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 15 of 43 10/04/2022 Describe the controls that will be utilized to ensure that only costs that are reasonable, ordinary and necessary will be allocated to this project. Also discuss the controls in place that will ensure that no expenses for overhead, or any other unallowable costs will be requested for reimbursement from the REF Grant Program. The TCC Finance and Accounting department will provide financial oversight, ensuring grant compliance, and providing timely documentation as required for reporting purposes. The Finance and Accounting department processes all fiscal transactions that flow through TCC. The department verifies all expenses, ensuring that they follow state and federal procurement regulations and internal TCC policies, and that they are compliant with granting agencies overseeing all financial transactions on over 300 grants and 700 individual programs. TCC’s FY20 revenue totaled $246 million, up $37.8 million from the previous year. A companywide grant management tool tracks all TCC grants, and Oracle Software is used for our accounting program. Tanana Chiefs Conference has exemplary financial accounting and over the last 6 years has received only one audit finding from our annual audits. This is significant considering TCC holds over $470 million worth of assets and manages over $240 million per year in operating revenue spread across over 300 grants and contracts that operate our more than 700 individual programs. SECTION 4 – QUALIFICATIONS AND EXPERIENCE 4.1 Project Team Include resumes for known key personnel and contractors, including all functions below, as an attachment to your application. In the electronic submittal, please submit resumes as separate PDFs if the applicant would like those excluded from the web posting of this application. 4.1.1 Project Manager Indicate who will be managing the project for the Grantee and include contact information. If the applicant does not have a project manager indicate how you intend to solicit project management support. If the applicant expects project management assistance from AEA or another government entity, state that in this section. Dave Messier, TCC Infrastructure Division Director, has been working with rural communities in the Alaskan interior for over 13 years. He is a subject matter expert on rural energy in the state and serves on numerous state and federal boards regarding energy issues. He has managed over $15 million in federal, state, and private funds in that time, focused on projects in the interior. Over the past 8 years, that work has included rebuilds in 12 Interior powerplants, multiple DERA funded projects, and over a dozen community and residential solar and battery installations. Dave also led the installation and design of the Hughes, AK 120kW solar, 353 kWh battery project and led the design of the award winning 223kW, 384 kWh storage project in Shungnak, AK. 4.1.2 Project Accountant Indicate who will be performing the accounting of this project for the grantee. If the applicant does not have a project accountant indicate how you intend to solicit financial accounting support. Ben Shilling will oversee all financial aspects of this grant. Ben oversees TCC’s financial reporting, accounting and procurement departments which are directly responsible for the financial management of grants and managing procurement. Within these departments Ben has a team of 22 employees under him at TCC. TCC has over $470 million in assets and over $240 million of annual revenues. Under Mr. Shilling’s leadership TCC has maintained an A+ Bond Rating and has many years of clean audits with only one finding. Ben has been a certified CPA since 1989 and Certified Information Systems Auditor since 1994. Ben also leads the distribution of both restricted and unrestricted funds to our tribes. In 2020, that amount was over $40 million. Mr. Shilling began Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 16 of 43 10/04/2022 working with TCC in January 2013 as the Internal Auditor. In July of 2013 he transferred to the Deputy Financial Officer position. He has a Bachelor of Business Administration in Accounting degree as well as an Associate of Arts in Computer Information Systems. He holds a CPA license as well as a CISA certificate. He has over 17 years of experience in public accounting. 4.1.3 Expertise and Resources Describe the project team including the applicant, partners, and contractors. For each member of the project team, indicate: • the milestones/tasks they will be responsible for; • the knowledge, skills, and experience that will be used to successfully deliver the tasks; • how time and other resource conflicts will be managed to successfully complete the task. If contractors have not been selected to complete the work, provide reviewers with sufficient detail to understand the applicant’s capacity to successfully select contractors and manage complex contracts. Dave Messier will be the project manager and responsible for the successful completion of the overall project. He will lead Tasks 1 and 2 – the project administration and the engineering design, including conducting design reviews with key stakeholders. The procurement for this project will be a design/procure approach using a model that proved very successful for the very similar Shungnak Solar PV and Battery project. TCC procurement standards will be used for the competitive RFP. Mr. Messier will provide technical support during the construction process – Task 3, along with technical support for the checkout and commissioning of the system. He will also manage the long-term operation of the IPP. His experience is listed above in section 4.1.1. Dave will be assisted by Edward Dellamary, the new TCC Energy Specialist. Mr. Dellamary has a master’s in Advanced Materials Engineering and Science and has experience as a marine mechanic and as a commissioning lead in a manufacturing facility. He has worked in Cordova, exploring options for a microgrid connecting three remote towns, and was part of the commissioning and operations/maintenance team for the Hughes Solar PV and Battery installation. Mr. Dellamary will be responsible for the construction oversight and will be an integral part of the commissioning team - Tasks 3.1 to 3.4. He will also be responsible for completing the final reports, closing out the grant, and performance reporting – Tasks 4.1 to 4.3. Forest Button, AVEC Manager of Project Development, and his staff of engineers will provide technical support to the design team and lead the integration design with the AVEC powerplant – Task 2. Forest leads a team focused on stabilizing the cost of energy in rural Alaskan villages through improved power plant efficiency, solar and other renewable power generation, and interties between villages. Mr. Button has led this Department within AVEC since 2016 and has over 25 years of experience in the management, design and construction of capital projects in rural Alaska. Mr. Button’s technical team at AVEC will provide this support as needed for the project. Daniel Allis, AVEC Manager of Operations, came to AVEC in 2005 with an extensive background in Diesel Mechanics. Directly prior to his employment, he was owner and operator of his own business for more than 15 years. Dan began his career with AVEC as a Field Technician. In 2017, he was promoted to Generation Superintendent, and in 2019, he was once again promoted to his current position as Manager of Operations. As Manager of Operations, Daniel has oversight of the Construction, Distribution, Generation, and Renewable Energy Departments. Daniel graduated from Williamsport Area Community College with his degree in Diesel Mechanics. He Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 17 of 43 10/04/2022 currently holds multiple certifications in various areas of Diesel Mechanics, Diesel Engine Electronic, and Fuel Systems. Dan will provide technical support to the design team in Task 2, monitor construction quality for task 3.1 to 3.4 with a focus on the AVEC powerplant integration, and will lead the AVEC commissioning team for Task 3.5. Edwin Bifelt, owner of Alaska Native Renewable Industries based in Interior Alaska, has become a reliable supplier of solar PV equipment, and his construction company has been the successful bidder on three large solar PV projects in Alaska. Mr. Bifelt will most likely bid on this project, if funded. He has created a successful model of utilizing local labor combined with a small, experienced staff of technicians to complete the solar PV installation. Please see the appendices for resumes of our team members. This project team will meet on a regular basis during the design and on a weekly basis during the construction, using this meeting to manage the detailed project timeline and budget. Priorities will be identified with assigned accountabilities and deliverables to keep the project on schedule. 4.2 Local Workforce Describe how the project will use local labor or train a local labor workforce. The RFP selection process for the construction contractor will be based in part on evaluating the various contactors’ proposed plans for training and hiring local labor. Recent solar PV and battery projects within remote Alaska have been completed with significant support of local labor. The same processes will be utilized to identify and train local labor for the Huslia project. One of TCC’s charters is the development of capacity in our communities and this solar PV project has many roles that can be filled with entry-level workers. Solar PV is the perfect training ground for young construction crews. AVEC powerplant operators in Huslia will also be involved in the construction and operations/maintenance of the battery within this solar PV system. SECTION 5 – TECHNICAL FEASIBILITY 5.1 Resource Availability 5.1.1 Assessment of Proposed Energy Resource Describe the potential extent/amount of the energy resource that is available, including average resource availability on an annual basis. For pre-construction applications, describe the resource to the extent known. For design and permitting or construction projects, please provide feasibility documents, design documents, and permitting documents (if applicable) as attachments to this application (See Section 11). Likelihood of the resource being available over the life of the project. See the “Resource Assessment” section of the appropriate Best Practice Checklist for additional guidance. In 2016, Paul Schwabe of the National Renewable Energy Lab authored the report “Solar Energy Prospecting in Remote Alaska - An Economic Analysis of Solar Photovoltaics in the Last Frontier State”. The following figure was included in the report and has become the source of reconnaissance level solar insolation for Alaska projects. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 18 of 43 10/04/2022 This report illustrates the solar potential for the Interior region of Alaska and discusses the likelihood of high solar production predominantly from March through August, with a steep drop off in the shoulder months and little to no production in the winter. Huslia has an estimated value of 3.4 kWh/m2/Day for solar insolation and is among the highest insolation sites in Alaska. Solar PV production has been affirmed across the state and is now considered a commercially available and technically mature industry globally with continued growth across Alaska. In many instances, solar PV production has been shown to outperform the expected values from standard modeling software and on a $/installed kW basis, often outperforms wind energy in rural Alaska because of the high maintenance requirements of small wind turbines. PV Watts, the solar performance software developed by NREL, uses McGrath as the nearest community with Solar Insolation data and estimates a 3.01 kWh/m2/Day. 5.1.2 Alternatives to Proposed Energy Resource Describe the pros and cons of your proposed energy resource vs. other alternatives that may be available for the market to be served by your project. The community goals of reducing diesel fuel use and increasing energy security can be met to varying degrees with the following technologies: 1. Energy efficiency – power plant generation, system distribution, and buildings 2. Diesel heating fuel reduction through biomass 3. Low penetration solar Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 19 of 43 10/04/2022 4. Wind energy 5. River Hydrokinetics 6. High Penetration solar and energy storage Technologies 1-3 above have all been deployed with significant success, as discussed in other sections of this application. Specifically, for Technology 1, power plant efficiency improvements have been achieved—through a US EPA DERA award to upgrade diesel engines and switchgear in the power plant. This has resulted in many thousands of gallons of fuel savings annually. Technology 2 has also resulted in several thousand gallons of fuel savings with harvesting local biomass for use in a small district heating loop that supplies the water system and clinic. Regarding Technology 3, there are several “behind the meter” solar PV systems across the TCC region that have demonstrated the viability and reliability of solar energy production, and these individual residences and institutions are saving significant amounts on their electric bills. Wind energy, Technology 4 listed above, has been explored in Huslia and it has been determined that there is not a viable wind resource to provide cost-effective electric generation. Technology 5, River Hydrokinetics, is still an experimental technology and though it does hold promise in general, the Koyukuk River presents significant challenges in terms of icing and in-river debris that have not yet been solved, thus resulting currently in very high cost and unreliable power. This may be an option in the future but is not presently a commercially viable option. This leaves Technology 6, which is the basis of this application. We have studied this option in great detail, including a stand-alone HOMER analysis conducted by NREL in 2022. The results of the HOMER analysis show an optimized solar and storage option at approximately 350 kWdc for the solar PV array and 500 kWh of battery storage, though these values vary based on expected future fuel prices over the 25-year life of the project. As well, the battery energy storage benefits are not fully captured in the HOMER analysis with regard to achieving diesels-off operation for part of the year, which is not possible without batteries, and the full value of extending time between diesel gen-set overhauls that are achieved with diesels-off. The ultimate system sizing will be determined in the final design and permitting stage of the project as proposed above. 5.1.3 Permits Provide the following information as it may relate to permitting and how you intend to address outstanding permit issues. See the “Environmental and Permitting Risks” section of the appropriate Best Practice Checklist for additional guidance. • List of applicable permits • Anticipated permitting timeline • Identify and describe potential barriers including potential permit timing issues, public opposition that may result in difficulty obtaining permits, and other permitting barriers The following permits are required for a Solar PV installation: • Analysis of wetlands and floodplain avoidance • NEC compliance/PE stamps • Consultation with State Historical Preservation Office • Critical Habitat avoidance Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 20 of 43 10/04/2022 The permitting consultations and applications will start as soon as the location of the PV array is finalized. The permitting is expected to take three months to complete and is shown in the project timeline. Contractors with appropriate expertise will be selected through a competitive RFP process to lead the pursuit of these permits. This is generally a well-known process with very little anticipated risk; however, it is a necessary step to ensure approval from all regulatory bodies. 5.2 Project Site Describe the availability of the site and its suitability for the proposed energy system. Identify potential land ownership issues, including whether site owners have agreed to the project or how you intend to approach land ownership and access issues. See the “Site control” section of the appropriate Best Practice Checklist for additional guidance. The proposed project site is owned by the City of Huslia and is located to the northeast of the AVEC powerhouse. It is identified on DCRA maps as Birchgrove Subdivision Plant No. 2005-2 Tract H. Please see the appendices for a map of the site. The City of Huslia has submitted a resolution committing the land and authorizing the City Manager to negotiate and enter into a minimum of a 25-year lease agreement for the project site. This lease agreement will be completed during the design phase of this project. The final lease agreement will be signed once construction funding is awarded. 5.3 Project Technical & Environmental Risk 5.3.1 Technical Risk Describe potential technical risks and how you would address them. • Which tasks are expected to be most challenging? • How will the project team reduce the risk of these tasks? • What internal controls will be put in place to limit and deal with technical risks? See the “Common Planning Risks” section of the appropriate Best Practice Checklist for additional guidance. Solar PV and battery installations are now very common and commercially mature technologies that have been successfully demonstrated globally and across rural Alaska, including in nearby communities. Based on NASA’s Technology Readiness Level (TRL) scale, this proposed system is at TRL 9, which is the lowest risk level, represented by existing technology with commercial warranties provided by large, stable companies and currently operating in the field under similar conditions. Installed and successfully commissioned solar PV and battery projects in places like Shungnak, Kotzebue, Deering, and Buckland, among other locations throughout rural Alaska, along with smaller scale systems in the TCC region such as Hughes, clearly demonstrate the overall low risk of the general technology. New bifacial solar panels are increasing the output of PV panels by 10 to 15% further reducing project risk. That said, there is always some risk associated with a multi-million dollar construction project in rural Alaska. In this case, one of the larger challenges is unknowns associated with PV ground mount foundations in soils that could be potentially located in melting permafrost- though geotechnical data from the Huslia site and local knowledge shows the site has 20’ of sandy non-frost susceptible soil underlaying much of the community. As well, the system integration will present site-specific challenges associated primarily with computer programming and digital communication compatibility among various vendor platforms that will require an explicit plan for activities at the powerhouse, including SCADA improvements for remote monitoring and access. These have been mitigated by the use of the same microgrid control technology that AVEC is using in other regions. Project risks will be reduced with detailed planning and regular reviews, reporting, clear lines of communication, and monthly evaluation of performance with necessary adjustments as required and will include AEA Project Manager as appropriate to keep them informed and solicit input. More Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 21 of 43 10/04/2022 specifically, starting with budgeting and system design, the design/procure team will be accountable to the Project Manager and, as needed, we will access additional oversight and review, including input from NREL analysts and AEA Project Manager to confirm system design and project costs. The Geotech consultants, if required, will be selected in large part based on their experience and track record in the region to reduce any unexpected foundation issues with the ground mount system. This will represent a go/no go decision point with regards to site selection. System integration challenges will be addressed by the construction contractor and contract language that will protect the community and the funders (primarily AEA) through requiring proper bonding and/or withholding payment until the project performs to pre-determined specifications. Much of the risk associated with incompatibility across vendor platforms can be addressed at the system design phase by ensuring that the different system components have effectively communicated in previous projects and working with the various vendors to ensure the communication protocols are inter-operable. For example, Huslia’s new switchgear and diesel generator controllers will need to be able to communicate with the microgrid controller, which will be specified in the system design equipment list. One of the selection criteria for the microgrid controller will be to ensure that it is using the same communication protocols as Huslia’s Com Ap controllers on AVEC’s generators. SCADA functionality that provides remote access will be required for project completion. The Com Ap controller has already successfully integrated with the Ageto microgrid control platform on an AVEC system in the community of Shungnak and both AVEC and Ageto are confident in the ability of the systems to integrate in other communities. The technical project team will meet regularly, especially during critical decision-making times associated with major milestones, to ensure such risks are mitigated. All project participants will have an opportunity to voice their concerns and ensure they are addressed by the responsible parties. The AEA Project Manager will be an integral part of this team to ensure full communication and inclusion of agency expertise. 5.3.2 Environmental Risk Explain whether the following environmental and land use issues apply, and if so which project team members will be involved and how the issues will be addressed. See the “Environmental and Permitting Risks” section of the appropriate Best Practice Checklist for additional guidance. • Threatened or endangered species • Habitat issues • Wetlands and other protected areas • Archaeological and historical resources • Land development constraints • Telecommunications interference • Aviation considerations • Visual, aesthetics impacts • Identify and describe other potential barriers Situated on the north bank of the Koyukuk River, 290 air miles west of Fairbanks, Huslia is frequently subject to seasonal flooding, especially during spring break up. The project team has identified the project site at Birch Grove Subdivision Plant No. 2005-2 Tract H for the solar array, this site is at roughly the same elevation as the AVEC powerhouse and has never been known to flood. Final permitting will be completed during the design phase. The project will be sited above known flood levels. There are no known threatened or endangered species, sensitive areas or wetlands. The siting permitting process will include consultation with the relevant agencies for: Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 22 of 43 10/04/2022 • Threatened or endangered species • Habitat issues • Wetlands and other protected areas • Archaeological and historical resources • Telecommunications interference • Aviation considerations Land development constraints: There are no identified land development constraints. The site was selected based in part on City ownership of the site and the ability of the location to support solar production. There are limited archaeological and historical resources in the area. The principal land development constraint is the short construction season in the Interior from June through September for earth work. Identify and discuss other potential barriers: There are no other potential environmental barriers identified. 5.4 Technical Feasibility of Proposed Energy System In this section you will describe and give details of the existing and proposed systems. The information for existing system will be used as the baseline the proposal is compared to and also used to make sure that proposed system can be integrated. Only complete sections applicable to your proposal. If your proposal only generates electricity, you can remove the sections for thermal (heat) generation. 5.4.1 Basic Operation of Existing Energy System Describe the basic operation of the existing energy system including: description of control system; spinning reserve needs and variability in generation (any high loads brought on quickly); and current voltage, frequency, and outage issues across system. See the “Understanding the Existing System” section of the appropriate Best Practice Checklist for additional guidance. The Huslia AVEC power plant is a traditional design that is very common throughout rural Alaska. AVEC’s power plant has 3 diesel powered gen-sets in the line-up that are automatically controlled with renewable-ready ComAp controls integrated into automated switchgear that was upgraded in 2018. Spinning reserve is typically provided by running a 2nd gen-set at low loads a considerable amount during the year, which is one of the drivers for a battery system that can supply the synthetic spinning reserve to where the traditional method of adding a 2nd engine on-line can be replaced by the battery providing the instantaneous spinning reserve, thereby allowing the system to be optimized with running on a single gen-set operation a majority of the time. Another realized benefit is the battery storage can supply power if a plant outage were to occur to increase system reliability and the battery storage along with the PV can provide power to the entire village by going “diesels-off” with a realized reduction of diesel fuel consumption. According to the FY 2022 PCE data, the diesel engines are averaging a 13.10 kWh/gallon fuel efficiency and the system has losses of 2.7%, which also includes transformer losses at the power plant step-up transformers along with the distribution transformer losses. Both of these metrics indicate a well-run and well-maintained utility operation. The lead power plant operator in Huslia is Dustin Noller, who has been in this role for 6 years. Huslia also benefits significantly with daily ongoing operational and engineering support from AVEC. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 23 of 43 10/04/2022 The largest loads in the community are the school and the water treatment plant. There are no known significant load swings in the community that adversely affect the existing generation system including the need for excess spinning reserve above what is conventional in AVEC power plants. Over the past 2 years, Huslia has experienced approximately 12 recorded outages on a system wide basis. There is currently not a waste heat recovery system installed in the Huslia powerplant as the power plant is located approximately ½ mile away from any potential building that could benefit from waste heat. 5.4.2.1 Existing Power Generation Units Include for each unit include: resource/fuel, make/model, design capacity (kW), minimum operational load (kW), RPM, electronic/mechanical fuel injection, make/model of genset controllers, hours on genset Unit 1: Electronic, Detroit Diesel, S60K4 1200 RPM, 236 kW, installed 7/21 – 4998 hrs, ComAp (2018) Unit 2: Mechanical, Cummins LTA10 1800 RPM, 250 kW, installed 6/87 – 14,863 hrs, ComAp (2018) Unit 3: Electronic, Detroit Diesel, S60D3 1800 RPM, 314 kW, install 10/22 – 508 hrs, ComAp (2018) Unit 4: Unit 5: Unit 6: 5.4.2.2 Existing Distribution System Describe the basic elements of the distribution system. Include the capacity of the step-up transformer at the powerhouse, the distribution voltage(s) across the community, any transmission voltages, and other elements that will be affected by the proposed project. In conjunction with implementing the automated 480-volt switchgear and ComAp generation controls, the generation at the power plant was converted from single-phase, 120/240 volt to three- phase, 480 volt system in 2018. The distribution system has losses of 2.7%, which also includes transformer losses at the power plant step-up transformers along with the distribution transformer losses. No transmission voltages are present as Huslia along with all other AVEC communities operated in isolation in a micro-grid. 5.4.2 Existing Energy Generation Infrastructure and Production In the following tables, only fill in areas below applicable to your project. You can remove extra tables. If you have the data below in other formats, you can attach them to the application (see Section 11). Is there operational heat recovery? (Y/N) If yes estimated annual displaced heating fuel (gallons) No – the power plant is not located near any buildings. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 24 of 43 10/04/2022 The existing plant step-up transformers at the power plant are comprised of (3) – 100 kVA pad- mounted transformers connected 480 volts from the generation bus to 7200/12470 volts to supply a three-phase, 4 wire multi-grounded distribution system. This step-up 300 kVA transformer bank will need to be increased to accommodate the solar generation and battery storage. The proposed project is not expected to impact the existing distribution system other than the plant step-up transformer size increases noted above. A step-up transformer is required at the solar PV production site to interconnect the PV secondary voltage to the 12470 volt distribution system. The PV power will be exported back to the power plant and 480 volt switchgear, along with the battery and microgrid power converter, which will be located adjacent to the power plant and interconnected directly on to the 480 volt generator bus through a dedicated 480 volt plant breaker to the BESS. 5.4.2.3 Existing Thermal Generation Units (if applicable to your project) Generation unit Resource/ Fuel type Design capacity (MMBtu/hr) Make Model Average annual efficiency Year Installed Hours N/A 5.4.2.5 Annual Electricity Production and Fuel Consumption (Existing System) Use most recent year. Replace the section (Type 1), (Type 2), and (Type 3) with generation sources Month Generation (Type 1) (kWh) Genera tion (Type 2) (kWh) Generatio n (Type 3) (kWh) Fuel Consumptio n (Diesel- Gallons) Fuel Consump tion [Other] Peak Load Minimum Load January 110,770 8,220 246 Not available 5.4.2.4 O&M and replacement costs for existing units Power Generation Thermal Generation i. Annual O&M cost for labor AVEC has calculated a rate of $2.75/kWh for O&M costs for its DD Series 60 gen-sets. AEA estimates from the B/C ratio model are used for the economic analysis. N/A ii. Annual O&M cost for non-labor iii. Replacement schedule and cost for existing units AVEC has calculated a rate of $.60/kWh for replacement costs of the DD Series 60 gen-sets. AEA estimates from the B/C ratio model are used for the economic analysis. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 25 of 43 10/04/2022 February 114,717 8,612 228 March 103,642 7,759 210 April 89,017 6,630 203 May 92,413 7,170 194 June 80,989 5,922 237 July 74,268 5,507 182 August 79,878 5,835 183 September 80,338 6,119 190 October 88,161 6,468 199 November 109,610 8,022 239 December 108,929 10,179 243 Total 1,132,732 86,443 5.4.2.6 Annual Heating Fuel Consumption (Existing System) Use most recent year. Include only if your project affects the recovered heat off the diesel genset or will include electric heat loads. Only include heat loads affected by the project. Month Diesel (Gallons) Electricity Propane (Gallons) Coal (Tons) Wood (Cords, green tons, dry tons) Other January N/A February March April May June July August September October November December Total 5.4.3 Future Trends Describe the anticipated energy demand in the community, or whatever will be affected by the project, over the life of the project. Explain how the forecast was developed and provide year by year forecasts. As appropriate, include expected changes to energy demand, peak load, seasonal variations, etc. that will affect the project. Based on US Census data, the population has increased in Huslia from 275 to 310 Between 2010 and 2022. Energy demand increased by approximately 3.7% between 2015 and 2021 according to PCE data. These changes are modest and not expected to outgrow the power plant or renewable energy system design. Currently, there are no large construction projects planned that will increase overall or seasonal demand or make any significant changes to peak loading. The powerplant is sized to provide a redundant power supply. 5.4.4 Proposed System Design Provide the following information for the proposed renewable energy system: Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 26 of 43 10/04/2022 • A description of renewable energy technology specific to project location • The total proposed capacity and a description of how the capacity was determined • Integration plan, including upgrades needed to existing system(s) to integrate renewable energy system: Include a description of the controls, storage, secondary loads, distribution upgrades that will be included in the project • Civil infrastructure that will be completed as part of the project—buildings, roads, etc. • Include what backup and/or supplemental system will be in place See the “Proposed System Design” section of the appropriate Best Practice Checklist for additional guidance. The proposed project is a high penetration distributed solar-battery hybrid system that will be connected to the Huslia electric grid. The system was sized to maximize the diesels-off potential during the months of highest solar availability using HOMER software. The exact details of the proposed project are subject to the final design and specifications developed in the engineering project phase. Preliminary price and equipment quotes were provided by various supplies and are attached to this proposal in the appendices. The equipment design includes the following major components: 350 KW DC Solar PV • 650-Watt Bifacial Mono Solar Panels (or similar) – we are estimating a conservative 12% improved output over the standard solar panel system modeled in the NREL HOMER analysis due to the bifacial panels. • 558 solar panels total (includes breakage allowance) • Ground Screw racking system with 35 degree tilt able to withstand 136 mph wind speed and 79 psf snow load. 250 kW AC Battery Energy Storage System • _3 SMA Sunny Highpower Peak3 (3-phase) 125 kW string inverters • _Construction of an inverter and battery building • _500 kWh of Lithium-Ion Battery Energy Storage System • _Estimated 1,145,000 kWh (1.145 GWh) of energy production annually • _30-35% renewable energy power generation of total annual load 500 kW EPC Power Conversion System • PD 500 converter • 50-100118 Power Drawer Cabinet with Arctic HVAC system 3 - 125 KVA inverters Microgrid Controller The core component of the system will most likely be an ABB or Ageto supervisory microgrid controller with power electronic inverters and controls, coupled with a lithium-ion battery, that will allow for periods of diesels-off operation when there is sufficient solar energy production and/or adequate charge in the batteries to safely run the entire grid. In our case, this will most frequently occur for hours at a time between April and August, when there is significant solar availability and the total system loads decrease because of warmer temperatures, less need for electric lighting, and the local schools close for summer. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 27 of 43 10/04/2022 In terms of the integration plan, the required upgrades to the existing systems are complete. Specifically, this includes new automated switchgear, new ComAp generator controls, new diesel gen-sets funded through the EPA DERA program and upgraded SCADA. These were all completed by AVEC with an intention for integration of renewables in the future and followed a similar upgrade that was completed in Shungnak prior to installation of high penetration solar PV and battery. Civil work associated with the solar PV ground mount system will likely be using pre-drilled helical piles similar to the recent projects in Hughes, Shungnak, and Kotzebue. As well, a 3-phase ground mount transformer to connect the solar PV production to the existing distribution system will require basic civil work that is well understood and will be addressed in the final design. Overall, this project will be patterned off of the similar projects noted above that are successfully integrating solar PV and battery storage, especially Shungnak. TCC is leading that effort, along with AVEC, and we intend to leverage lessons learned to streamline the effort in Huslia. 5.4.4.1 Proposed Power Generation Units Unit # Resource/ Fuel type Design capacity (kW) Make Model Expected capacity factor Expected life (years) Expected Availability 558 Solar Panels Solar PV 350 Casol CS7N – 650MB-AG (650 W bifacial 13% annually due to improved bifacial panels 25-30 95% - snow coverage 5.4.4.2 Proposed Thermal Generation Units (if applicable) Generation unit Resource/ Fuel type Design capacity (MMBtu/hr) Make Model Expected Average annual efficiency Expected life N/A 5.4.5 Basic Operation of Proposed Energy System • To the best extent possible, describe how the proposed energy system will operate: When will the system operate, how will the system integrate with the existing system, how will the control systems be used, etc. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 28 of 43 10/04/2022 • When and how will the backup system(s) be expected to be used See the “Proposed System Design” section of the appropriate Best Practice Checklist for additional guidance. When there is limited solar availability, namely from September through late February, the proposed solar PV system will simply operate as a low penetration, supplemental generation asset to the diesel backbone. This can be viewed as load reduction and efficiency optimization for the diesel generators, along with redundant backup for the system to the degree the batteries are charged. However, when there is sufficient solar energy production and/or adequate charge in the batteries, the proposed solar-battery hybrid system will safely run the entire grid. This typically occurs between April and August due to higher solar availability and power production as well as lower loads on the overall system when school is out of session. Integrating a battery energy storage system increases the usable amount of solar energy production, especially during high snow reflection in spring and long sunny days in the summer. The BESS for this project will be comprised of a bi-directional inverter, Lithium-Ion battery bank, and an advanced control system with Black Start, Cycle Charging, and Load Following capabilities. The battery bank enables solar production to be shifted to better match the community load profile, which maximizes solar utilization while minimizing excessive solar penetration levels. Despite an annual solar capacity factor of about 12% according to the latest HOMER modeling (estimated to increase to 13% with bifacial panels), which would be considered low in most cases, the extreme annual pattern of sub-Arctic summers and winters results in very high solar penetration during spring and summer days. Instantaneous solar penetration levels above 50% can cause issues with grid stability, and excessive wear-and-tear on the generator due to low load-ratios and rapid ramping. The BESS and grid forming inverter will prevent these issues, allow for diesel off operation and protect the diesel generators from experiencing under-loading, wet stacking, and rapid ramping, thus enhancing fuel efficiency and maximizing the use of the solar PV production. Annual Load Profile vs. Renewable Penetration as Percent of Load By including an appropriately sized BESS, the system will enable maximum renewable penetration, with excess electricity stored for use during hours of low solar production in both the mornings and evenings. The battery bank will also enable the future integration of additional solar PV. The BESS is designed to avoid the excessive wear-and-tear on the generator that comes from underloading and rapid ramping, while supporting longer life and delay gen-set overhauls by providing virtual spinning reserve, maintaining a stable band of diesel generation output within the highest efficiency range of the power curve, and turning the diesel generators off for periods of time, thereby delaying the need for the next system overhaul. 5.4.3.1 Expected Capacity Factor 13% - this is slightly higher than the recent 11 to 12% experienced in the Northwest Arctic Borough. The improved performance is due to bifacial panel technology advances. 5.4.5.2 Annual Electricity Production and Fuel Consumption (Proposed System) Month Generation (Proposed System) (kWh) Generation (Type 2) (kWh) Generation (Type 3) (kWh) Fuel Consumption (Diesel- Gallons) Fuel Consumption [Other] Secondary load (kWh) Storage (kWh) Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 29 of 43 10/04/2022 January 1844 108,926 February 9587 105,130 March 38718 64,924 April 55681 33,336 May 68218 24,195 June 58263 22,727 July 57894 16,374 August 57524 22,354 September 36506 43,832 October 15856 72,305 November 2950 106,660 December 0 108,929 Total 403043 729691 5.4.5.3 Annual Heating Fuel Consumption (Proposed System) Month Diesel (Gallons) Electricity Propane (Gallons) Coal (Tons) Wood (Cords, green tons, dry tons) Other January N/A February March April May June July August September October November December Total 5.4.6 Proposed System Operating and Maintenance (O&M) Costs O&M costs can be estimated in two ways for the standard application. Most proposed renewable energy projects will fall under Option 1 because the new resource will not allow for diesel generation to be turned off. Some projects may allow for diesel generation to be turned off for periods of time; these projects should choose Option 2 for estimating O&M. Option 1: Diesel generation ON For projects that do not result in shutting down diesel generation there is assumed to be no impact on the base case O&M. Please indicate the estimated annual O&M cost associated with the proposed renewable project. $ Option 2: Diesel generation OFF For projects that will result in shutting down diesel generation please estimate: Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 30 of 43 10/04/2022 1. Annual non-fuel savings of shutting off diesel generation 2. Estimated hours that diesel generation will be off per year. 3. Annual O&M costs associated with the proposed renewable project. 1. $31,152 – From AEA/s B/C ratio model 2. Hours diesel OFF/year: 3132 – Per NREL HOMER modeling (actual hours will likely be higher dur to bifacial panels) 3. 1% of the capital cost. Although AEA recommends an annual O&M cost of 2% of the capital cost (the same as the recommendations for wind systems), experience in the Northwest Arctic Borough communities of Deering, Buckland, and Shungnak have shown that the O&M cost for Solar PV/storage systems are slightly less than 1% of the capital cost. Solar PV costs have been negligible, and the battery O&M costs are driven by the replacement of the batteries at 12-15 years. 5.4.7 Fuel Costs Estimate annual cost for all applicable fuel(s) needed to run the proposed system (Year 1 of operation) Diesel (Gallons) Electricity Propane (Gallons) Coal (Tons) Wood Other Unit cost ($) N/A Annual Units Total Annual cost ($) 5.5 Performance and O&M Reporting For construction projects only 5.5.1 Metering Equipment Please provide a short narrative, and cost estimate, identifying the metering equipment that will be used to comply with the operations reporting requirement identified in Section 3.15 of the Request for Applications. Metering equipment will be provided by the project and will be critical for the successful operation of the control system that will dispatch the different energy resources in the most cost effective and efficient way. Metering equipment will measure solar PV production, production from each gen-set and battery charge and discharge. Station service will be measured for the Battery Building. All of the metering will be integrated with the supervisory controller that will maximize the use of solar production with the diesel gen-sets and the battery. The supervisory controller will also provide real- time performance visualization of the system that will supplement the “hard” metering. This AVEC supplied metering equipment will also be used for the PPA payments 5.5.2 O&M reporting Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 31 of 43 10/04/2022 Please provide a short narrative about the methods that will be used to gather and store reliable operations and maintenance data, including costs, to comply with the operations reporting requirement identified in Section 3.15 of the Request for Applications The solar and battery storage systems have sophisticated controls and data collection software. The IPP will collect detailed solar production data, including resource availability, and submit this information monthly to AVEC with the invoice for the power sales. AVEC will continue to collect detailed gen-set operational data and will also collect battery round trip efficiency and parasitic load. A monthly report showing total production of the system will be published to support troubleshooting and prioritization of maintenance activities within both the IPP and AVEC. Communications between the entities will be critical for a successful operation that maximizes diesels-off time. Tanana Chiefs Conference as the IPP will log any and all maintenance required for the system and segregate costs within our accounting system to provide a complete and accurate view of the actual maintenance costs associated with the system. Monthly O&M costs will be tracked using the existing AVEC accounting procedures that are used to report to the PCE program. The IPP will establish cost tracking procedures for O&M costs within the TCC accounting system. TCC has significant experience tracking spending on capital projects and operational departments, so tracking spending from an IPP will not be anything unusual. SECTION 6 – ECONOMIC FEASIBILITY AND BENEFITS 6.1 Economic Feasibility 6.1.1 Economic Benefit – The fuel cost in the B/C ratio Calculator was updated with the latest 2022 AVEC Huslia weighted average fuel cost from the 8/31/22 report to the RCA - $4.6534/gallon Annual Lifetime Anticipated Diesel Fuel Displaced for Power Generation (gallons) 32,243 806,075 Anticipated Fuel Displaced for Heat (gallons) Total Fuel displaced (gallons) 32,243 806,075 Anticipated Diesel Fuel Displaced for Power Generation ($) 1st year - $134,437 $ 3,943,572 Anticipated Fuel Displaced for Heat ($) Anticipated Power Generation O&M Cost Savings $31,152 $778,800 Anticipated Thermal Generation O&M Cost Savings Total Other costs savings (taxes, insurance, etc.) Total Fuel, O&M, and Other Cost Savings $165,589 $4,722,370 6.1.2 Economic Benefit Explain the economic benefits of your project. Include direct cost savings and other economic benefits, and how the people of Alaska will benefit from the project. Note that additional revenue Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 32 of 43 10/04/2022 sources (such as tax credits or green tags) to pay for operations and/or financing, will not be included as economic benefits of the project. Where appropriate, describe the anticipated energy cost in the community, or whatever will be affected by the project, over the life of the project. Explain how the forecast was developed and provide year-by-year forecasts The economic model used by AEA is available at https://www.akenergyauthority.org/What-We- Do/Grants-Loans/Renewable-Energy-Fund/2022-REF-Application. This economic model may be used by applicants but is not required. The final benefit/cost ratio used will be derived from the AEA model to ensure a level playing field for all applicants. If used, please submit the model with the application. The economic modeling used for this application was the AEA B/C ratio model. Because the most recent AVEC Huslia weighted fuel cost that was submitted to the RCA on 8/31/22 was higher than the estimated fuel costs in the AEA B/C ration model, the fuel cost were updated in this applicant analysis. The current fuel cost of $4.6534/gallon was escalated using the same yearly inflation rate in the diesel cost tab in the AEA B/C ratio model. In this applicant model, the 2022 starting point for the fuel cost was about $.30 higher than the ACEP developed costs. Potential annual fuel displacement (gallons and dollars) over the lifetime of the evaluated renewable energy project: In total, the project will displace the equivalent of 32,243 gallons of diesel fuel for electrical generation annually. Based on the output of the B/C ratio model, over the 25-year lifetime of the project, the project will displace 806,075 gallons of diesel, with a lifetime cost savings of $ 3,943,572. As stated above, this project will result in TCC acting as the IPP in Huslia selling kWh from the solar PV array to AVEC. AVEC has agreed in principle to purchase all kWh that are generated from the system. Using the current avoided fuel cost (PPA rate) from AVEC Huslia of $.2929, the IPP will have an annual revenue of $105,403. This revenue will be used for the O&M of the renewable energy system, will fund a repair and replacement account, and excess revenue will be reinvested in the Huslia energy infrastructure to include future expansion of the system to increase diesel offset further. AVEC will save $32,243 in fuel costs annually. This arrangement is a win/win for both parties. The B/C ratio for this project is 1.31. The installation of battery energy storage system is expected to have positive impacts on the operation of the diesel power plants, regardless of the renewable energy system. These benefits include utilizing battery charge and discharge to maximize the fuel efficiency of the diesel engines and reducing or eliminating brown-outs and black-outs. A recent potential power outage in Shungnak was avoided due to the battery providing time for the powerplant operators to troubleshoot a diesel engine problem and restarting the system before an outage could occur. Unfortunately, the economic benefits of these other diesel engine benefits have not yet been quantified. The assumptions used in the B/C ratio analysis are: • Annual solar production– values calculated in the NREL HOMER modeling with an additional 12% increase in output conservatively estimated from improved performance of bifacial solar panels. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 33 of 43 10/04/2022 • Annual diesels off hours – values calculated in the NREL HOMER modeling. This estimate is likely low and does not take into account the bifacial panels. This diesels off hours estimate will be updated during the first phase of the engineering design. • Annual Renewable Energy O&M costs – The project team has lowered AEA’s recommendation for 2% of the capital costs to 1% of the capital cost for the renewable energy annual O&M costs. This is based on experience from the Northwest Arctic Borough projects in Deering, Buckland, and Shungnak. 2% of the capital cost is a realistic estimate for wind power system, but solar battery systems are proving to be extremely low maintenance. The 1% estimate includes the replacement of batteries at 12 to 15 years. • Diesel Generator O&M is based on the size of the generator from AEA’s B/C ratio model. • Because Huslia’s diesel engines are newly rebuilt or replaced, there was no savings calculated related to reduced replacement costs. • Project life of 25 years By selling power to AVEC as an IPP, TCC will be able to use the revenue from the Solar PV system to reinvest in the energy systems of Huslia. This could be additional renewable energy systems to reduce the dependence on diesel or support for efficiency improvements in the power plant. While the community will not see immediate reductions in electric rates, as TCC invests in more renewable energy and energy efficiency projects, the cost of electricity should steadily decrease in the future. Additionally, Huslia and AVEC will be less dependent on the volatile international oil markets, providing better predictability of energy costs. The IPP model will create a part-time job in the community of Huslia to monitor and maintain the renewable energy system. The person hired will, most likely, be part of the local labor used to construct the system and will be receive training on the operation and maintenance of the system. 6.1.3 Economic Risks Discuss potential issues that could make the project uneconomic to operate and how the project team will address the issues. Factors may include: • Low prices for diesel and/or heating oil • Other projects developed in community • Reductions in expected energy demand: Is there a risk of an insufficient market for energy produced over the life of the project. • Deferred and/or inadequate facility maintenance • Other factors In the last two years of the Covid pandemic we are seeing high levels of inflation on the costs of fuel delivery and other operating supplies. Since this project will be significantly reducing the amount of diesel fuel required for our operation and the diesels-off time will reduce our maintenance costs, we do not see a major economic risk related to this work. Solar is a free fuel source that is very easy to operate and maintain. Of all the energy technology used in Alaska, Solar PV is the easiest and least expensive for O&M. 6.1.4 Public Benefit for Projects with Direct Private Sector Sales For projects that include direct sales of power to private sector businesses (sawmills, cruise ships, mines, etc.), please provide a brief description of the direct and indirect public benefits derived from the project as well as the private sector benefits and complete the table below. See Section 1.6 in the Request for Applications for more information. N/A Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 34 of 43 10/04/2022 Renewable energy resource availability (kWh per month) Estimated direct sales to private sector businesses (kWh) Revenue for displacing diesel generation for use at private sector businesses ($) Estimated sales for use by the Alaskan public (kWh) Revenue for displacing diesel generation for use by the Alaskan public ($) 6.2 Other Public Benefit Describe the non-economic public benefits to Alaskans over the lifetime of the project. For the purpose of evaluating this criterion, public benefits are those benefits that would be considered unique to a given project and not generic to any renewable resource. For example, decreased greenhouse gas emission, stable pricing of fuel source, won’t be considered under this category. Some examples of other public benefits include: • The project will result in developing infrastructure (roads, trails, pipes, power lines, etc.) that can be used for other purposes • The project will result in a direct long-term increase in jobs (operating, supplying fuel, etc.) • The project will solve other problems for the community (waste disposal, food security, etc.) • The project will generate useful information that could be used by the public in other parts of the state • The project will promote or sustain long-term commercial economic development for the community The primary goals of this project are economic and include reduced diesel fuel consumption by about 35% over baseline for electricity production and achieve diesels-off operation in our powerhouse at least 36% of the time on an annual basis (based on HOMER modeling by NREL). Because TCC will be operating this project as an IPP, at least one part-time job will be created in the community of Huslia. Local jobs, especially jobs that develop technical skills are limited in rural communities, so even a part-time job can be transformational for a local community member. While commercially available and technologically mature, this Bifacial Solar PV and battery project would be an important demonstration in Alaska and across high latitude communities of an improved technology for achieving the long-sought goal of High Penetration Solar-Battery-Diesel Hybrid System for Huslia, AK, capturing the northern midnight sun for months at a time. Bifacial panels are expected to increase the PV panel output by a conservative estimate of 12%. Running a village electric microgrid on only solar and batteries for much of the Alaskan summer will be another example of how villages can and will operate in the future. Renewable Energy construction projects in remote Alaska are extremely expensive and engineering firms tend to “over engineer” to reduce the risk of construction costs overruns. We are proposing to demonstration the ability to manage these costs through a Design/Procure contract where the mush of the engineering is provided by the equipment suppliers. This could demonstrate a procurement method that will help minimize engineering costs. Demonstrating this concept with a renewable project would help reduce project development costs on many future installations. Power plants in remote Alaska are notorious for regular brown-outs and black-outs that have a high cost on electronics equipment in the communities. However, this cost has not been quantified. Batteries, like the ones that will be installed in Huslia, are showing great success in reducing these Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 35 of 43 10/04/2022 power interruptions. The batteries have the ability to carry the load of the community for a significant amount of time, sometimes up to an hour or more. This gives the power plant operations the time to troubleshoot and address the issues with the generators and restart the generating systems. Recently in Shungnak, in two months of operation, the battery system prevented 2 blackouts from diesel powerplant trips. We hope to help quantify this benefit so that it can be used in future economic justifications. Additionally, batteries are replacing the need for spinning reserves in the diesel powerplants, and as a result, most demand charges. By eliminating this need, powerhouses will be operating more efficiently and virtually eliminate the need for no load diesel engine operation. We have not yet been able to quantify this benefit, but work is currently taking place to access this significant economic value. Eliminating demand charges could have major benefits in reduced electric costs to the large loads in remote communities, such as the school and water treatment plants. Energy resilience and energy security is a priority from the Huslia long term energy plan. This was one of the drivers in prioritizing this project for the City of Huslia. Alternative energy systems, especially systems that do not require an imported fuel, offer a secure energy source during catastrophic events when the community is cut off from the supply chains. TCC will be demonstrating a non-profit organization operating an IPP with a power sales agreement to a utility where all of the benefits will be passed through to the rate payers through increased investment in renewable energy systems. This is an innovative business arrangement that has potential to be replicated in other regions of Alaska for public benefit. Other public benefits include: • Reduced environmental risk for oil spills and other petroleum storage risks due to less usage of diesel. • Long term, reduced electric rates for commercial customers that could be passed to community members through lower prices. • Long term, reduced electric rates for commercial customers could lead to economic development such as opening a restaurant. • Businesses currently operating in the community of Huslia will be able to claim the environmental benefits of purchasing low carbon electricity from the Huslia solar farm. • Reduced carbon emissions from diesel generators. SECTION 7 – SUSTAINABILITY Describe your plan for operating the completed project so that it will be sustainable throughout its economic life. At a minimum for construction projects, a business and operations plan should be attached and the applicant should describe how it will be implemented. See Section 11. 7.1.1 Operation and Maintenance Demonstrate the capacity to provide for the long-term operation and maintenance of the proposed project for its expected life • Provide examples of success with similar or related long-term operations • Describe the key personnel that will be available for operating and maintaining the infrastructure. • Describe the training plan for existing and future employees to become proficient at operating and maintaining the proposed system. • Describe the systems that will be used to track necessary supplies Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 36 of 43 10/04/2022 • Describe the system will be used to ensure that scheduled maintenance is performed When the new solar PV and battery system is added to the Huslia energy system, AVEC’s operators and mechanics will participate in the design and construction of the project, along with the selected solar PV operator. By participating in the construction and commissioning of the system, they will have more in-depth understanding of the entire installation. Both organizations, AVEC and the IPP will work closely with the vendor representatives to support the commissioning of the system, and formal operations and maintenance training will be a deliverable of the system suppliers. Recommended spare parts for the new installations will be in-house before the commissioning of the system. The IPP operator will be selected from the local construction crew and will be trained on the daily inspection rounds, and the weekly and monthly maintenance tasks. O&M on a solar PV system is very simple and is the perfect training ground for new local technicians. The IPP operator will have monthly meetings with the IPP manager to discuss safety, current operational statistics, maintenance issues, spending, and prioritization of required tasks. AVEC’s power plant/electric utility local team will work closely with the design team to ensure the battery-inverter-control system is safely and properly integrated into the diesel powerhouse. This may include modifying the location of some system components to accommodate inverter and battery cabinets and overlaying systems controls for more automated powerhouse operation. This is ultimately expected to produce significant savings in both diesel engine O&M and reduced labor demands as the powerhouse becomes automated. AVEC will continue to use their successful maintenance management systems that includes maintenance inspections, scheduled maintenance, and management of spare parts inventory. TCC will purchase required critical spare parts for the solar PV and battery system and will designate secure storage for the parts on the project site. Any usage of spare parts will be discussed at the monthly IPP meeting, and replacement parts will be ordered. This O&M management plan has been used successfully in the recent Shungnak Solar PV/Battery system in collaboration with AVEC. Community outreach will be conducted during the project so that community members understand the value of the solar panels and will work together with the IPP to protect the investment from damage. 7.1.2 Financial Sustainability • Describe the process used (or propose to use) to account for operational and capital costs. • Describe how rates are determined (or will be determined). What process is required to set rates? • Describe how you ensure that revenue is collected. • If you will not be selling energy, explain how you will ensure that the completed project will be financially sustainable for its useful life. AVEC has a long history of successful operations in remote Alaska and is the leader in compliance of revenue collection. AVEC will use their current accounting system to track the operational costs related to the IPP power sales agreement and will use their existing avoided cost process for rate setting. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 37 of 43 10/04/2022 TCC is a non-profit with $246 million/yr. in revenue that is owned by the 37 federally recognized tribes that it serves, Huslia Tribal Council included. TCC was established prior to ANCSA to assist our tribes with self governance and has grown substantially as a Tribal Health Organization (THO) which manages the health needs of our region’s tribes. Approximately $60 million/yr. is spent on self-governance and tribal assistance and spread across a number of programs that include energy, tribal realty, forestry, archaeology, transportation, tribal courts, Village Public Safety Officers (VPSO) and many more. TCC has a long history of providing successful project management for our communities and the TCC energy program has assisted with or managed eight powerplant generator replacement projects in the last six years. Many of these projects involved EPA funds and a number of them utilized AEA funding as cost share. Both our project management and financial bookkeeping have sufficient expertise to make this project a success. TCC will invoice AVEC on a monthly basis for the power produced by the solar PV system per the draft power sales agreement included in the appendices of this application. TCC will maintain the IPP revenue in a separate account that will be used for the O&M costs of the IPP, including equipment insurance and a repair and replacement account. The revenue projected through the Power Sales Agreement is more than enough to cover the costs of the O&M of the IPP and insuring the equipment. Excess revenue will be re-invested in Huslia renewable energy programs. 7.1.2.1 Revenue Sources Briefly explain what if any effect your project will have on electrical rates in the proposed benefit area over the life of the project. If there is expected to be multiple rates for electricity, such as a separate rate for intermittent heat, explain what the rates will be and how they will be determined Collect sufficient revenue to cover operational and capital costs • What is the expected cost-based rate (as consistent with RFA requirements) • If you expect to have multiple rate classes, such as excess electricity for heat, explain what those rates are expected to be and how those rates account for the costs of delivering the energy (see AEA’s white paper on excess electricity for heat). • Annual customer revenue sufficient to cover costs • Additional incentives (i.e. tax credits) • Additional revenue streams (i.e. green tag sales or other renewable energy subsidies or programs that might be available) AVEC has a standard process for developing the cost-based rate for power sales agreements with the IPP. This avoided fuel cost rate takes into account the cost of fuel and diesel operations, maintenance, and replacement costs. For Huslia, the current avoided fuel cost is $.2929/kWh based on a diesel fuel cost of $4.6534 per gallon – the latest weighted fuel cost reported to the RCA. The power purchase rate is updated with each new fuel price report to the RCA. AVEC rate payers will not see significant costs savings related to this project. The benefit for the projects comes from the IPP and the development of a local part-time O&M job and the reinvestment of excess revenue after IPP O&M costs. This excess revenue will be invested in additional renewable energy and energy efficiency projects that will reduce electric rates long-term. The revenue projected through the Power Sales Agreement is more than enough to cover the costs of the O&M of the IPP and insuring the equipment. 7.1.2.2 Power Purchase/Sale The power purchase/sale information should include the following: • Identification of potential power buyer(s)/customer(s) • Potential power purchase/sales price - at a minimum indicate a price range (consistent with the Section 3.16 of the RFA) Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 38 of 43 10/04/2022 Identify the potential power buyer(s)/customer(s) and anticipated power purchase/sales price range. Indicate the proposed rate of return from the grant-funded project. Include letters of support or power purchase agreement from identified customers. AVEC is an active partner in this project and will buy the electricity production from the IPP. This project is being replicated from the successful IPP owned by the Native Village of Shungnak that is selling power generated by Solar PV to AVEC. AVEC will buy the power from TCC at the avoided fuel cost rate. This rate is currently $.2929/kWh. This rate will be adjusted each time AVEC submits a fuel cost adjustment to the RCA. SECTION 8 – PROJECT READINESS 8.1 Project Preparation Describe what you have done to prepare for this award and how quickly you intend to proceed with work once your grant is approved. Specifically address your progress towards or readiness to begin, at a minimum, the following: • The phase(s) that must be completed prior to beginning the phase(s) proposed in this application • The phase(s) proposed in this application • Obtaining all necessary permits • Securing land access and use for the project • Procuring all necessary equipment and materials Refer to the RFA and/or the pre-requisite checklists for the required activities and deliverables for each project phase. Please describe below and attach any required documentation. In 2016, NREL conducted a solar resource assessment across Alaska that quantified the solar potential by month. This study has been the building block for most feasibility work in the state. For Huslia and other similarly sized projects in the TCC region, NREL performed HOMER modeling to quantify the solar energy projection based on various sizes of solar PV and battery systems. For Huslia, a 350 kW solar PV with a 500 kWh battery and 500 kW converter maximized the diesels off potential for the community. This project application is for the design, permitting, and construction of the solar PV and battery storage system. Alaska communities have developed more than 5 Solar PV and battery storage systems, and 7 additional systems are in the design/build stage. This type of project has become very low risk, and design/procure followed by construction contracts are proving to be the most cost effective project management approach. All permit requirements have been identified and initial consultations with the permitting agencies did not identify any major concerns. The project site is owned by the City of Huslia and is located to the northeast of the AVEC powerhouse. It is identified on DCRA maps as Birchgrove Subdivision Plant No. 2005-2 Tract H. The City of Huslia has submitted a resolution committing the land and authorizing the City Manager to negotiate and enter into a minimum of a 25-year lease agreement for the project site. This lease agreement will be completed during the design phase of this project. TCC will serve as the Project Manager and IPP. It is our hope that recent supply chain issues are resolving, so no equipment availability issues are anticipated. We are currently observing improvements in the supply chain of most system components and with sufficient planning and early ordering of long-lead time items, we do not expect significant delays because of equipment availability. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 39 of 43 10/04/2022 8.2 Demand- or Supply-Side Efficiency Upgrades If you have invested in energy efficiency projects that will have a positive impact on the proposed project, and have chosen to not include them in the economic analysis, applicants should provide as much documentation as possible including: 1. Explain how it will improve the success of the RE project 2. Energy efficiency pre and post audit reports, or other appropriate analysis, 3. Invoices for work completed, 4. Photos of the work performed, and/or 5. Any other available verification such as scopes of work, technical drawings, and payroll for work completed internally. Huslia has completed a number of energy efficiency upgrades, but project documentation is not readily available. These projects include: With support from the Round 15 REF grant, a project managed by ANTHC was installed at the Huslia Water Treatment Plant and Clinic to meet the heating needs using local wood in a cordwood heating system. This project is displacing about 8500 gallons of imported heating oil with local wood supplied by local harvesters. Huslia has also participated in the 2010 Village End Use Energy Efficiencies Measures Program and NREL’s START program, focusing on LED light bulb installations, including all of the community’s streetlights. The VEUEM report is included in the attachments. Huslia has recently completed a replacement of an inefficient gen-set with a new Detroit Diesels Series 60unit through a US EPA Diesel Emission Reduction Act grant. SECTION 9 – LOCAL SUPPORT AND OPPOSITION Describe local support and opposition, known or anticipated, for the project. Include letters, resolutions, or other documentation of local support from the community that would benefit from this project. Provide letters of support, memorandum of understandings, cooperative agreements between the applicant, the utility, local government and project partners. The documentation of support must be dated within one year of the RFA date of October 4, 2022. Please note that letters of support from legislators will not count toward this criterion. A resolution was provided by TCC, committing match, supporting the submittal of this application, and committing to forming an IPP with a negotiated PPA with AVEC. The City of Huslia submitted a resolution in support of this project and committing to negotiating the lease agreement for the solar panel site. Letters of Support have been provided by Doyon, Interior Regional Housing Authority, Native Village of Huslia, City of Huslia, and the ANSCA Village Corporation. AVEC has submitted a letter supporting the draft power purchase agreement and providing in-kind match for this project. SECTION 10 – COMPLIANCE WITH OTHER AWARDS Identify other grants that may have been previously awarded to the Applicant by AEA for this or any other project. Describe the degree you have been able to meet the requirements of previous grants including project deadlines, reporting, and information requests. Although TCC has not been a previous grant awardee from the Renewable Energy Fund, we have a strong history of successful grants management on the Federal Level. As stated in section 3.3.2, the Finance and Accounting department processes all fiscal transactions that flow through TCC. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 40 of 43 10/04/2022 The department verifies all expenses, ensuring that they follow state and federal procurement regulations and internal TCC policies, and that they are compliant with granting agencies overseeing all financial transactions on over 300 grants and 700 individual programs. TCC’s FY20 revenue totaled $246 million, up $37.8 million from the previous year. A companywide grant management tool tracks all TCC grants, and Oracle Software is used for our accounting program. Tanana Chiefs Conference has exemplary financial accounting and over the last 6 years has received only one audit finding from our annual audits. SECTION 11 – LIST OF SUPPORTING DOCUMENTATION FOR PRIOR PHASES In the space below, please provide a list of additional documents attached to support completion of prior phases. NREL Solar PV and Battery HOMER Feasibility Study Titan Solar Racking Quote Maddox Transformer Quote EPC Power Quote CED Greentech PV panel quote CED Greentech Highpower 125 kVA quote SECTION 12 – LIST OF ADDITIONAL DOCUMENTATION SUBMITTED FOR CONSIDERATION In the space below, please provide a list of additional information submitted for consideration. Draft PPA TCC Resolution City of Huslia Resolution Detailed Capital Budget Team Resumes B/C Ratio Model Letters of Support Siting Map Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 41 of 43 10/04/2022 SECTION 13 – AUTHORIZED SIGNERS FORM Community/Grantee Name: Tanana Chiefs Conference Regular Election is held: Every 3rd year the 3rd week in March 2023 then 2026 Date: 12/1/22 Authorized Grant Signer(s): Printed Name Title Term Signature Ben Shilling Acting Chief Financial Officer staff Brian Ridley Chief/Chairman Present- 23 Dave Messier Infrastructure Division Director staff I authorize the above person(s) to sign Grant Documents: (Must be authorized by the highest ranking organization/community/municipal official) Printed Name Title Term Signature Brian Ridley Chief/Chairman Present-23 Grantee Contact Information: Mailing Address: 122 1st Ave Suite 600 Phone Number: 907-452-8251 Fax Number: Email Address: Dave.pm@tananachiefs.org Federal Tax ID #: 92-0040308 Please submit an updated form whenever there is a change to the above information. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 42 of 43 10/04/2022 SECTION 14 – ADDITIONAL DOCUMENTATION AND CERTIFICATION SUBMIT THE FOLLOWING DOCUMENTS WITH YOUR APPLICATION: A.Contact information and resumes of Applicant’s Project Manager, Project Accountant(s), key staff, partners, consultants, and suppliers per application form Section 3.1, 3.4 and 3.6. Applicants are asked to provide resumes submitted with applications in separate electronic documents if the individuals do not want their resumes posted to the project web site. B.Letters or resolutions demonstrating local support per application form Section 9. C.For projects involving heat: Most recent invoice demonstrating the cost of heating fuel for the building(s) impacted by the project. D.Governing Body Resolution or other formal action taken by the applicant’s governing body or management per RFA Section 1.4 that: •Commits the organization to provide the matching resources for project at the match amounts indicated in the application. •Authorizes the individual who signs the application has the authority to commit the organization to the obligations under the grant. •Provides as point of contact to represent the applicant for purposes of this application. •Certifies the applicant is in compliance with applicable federal, state, and local, laws including existing credit and federal tax obligations. E.An electronic version of the entire application on CD or other electronic media, per RFA Section 1.7. F.CERTIFICATION The undersigned certifies that this application for a renewable energy grant is truthful and correct, and that the applicant is in compliance with, and will continue to comply with, all federal and state laws including existing credit and federal tax obligations and that they can indeed commit the entity to these obligations. Print Name Signature Title Date Brian Ridley 12/2/22 Chief/Chairman Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 43 of 43 10/04/2022 TCC – Huslia Community-Scale Solar PV and Battery Project Summary of Appendices Resolutions and Letters of Support and Other Documentation - Appendices 1 1. Draft Power Purchase Agreement 2. Resolutions a. TCC Resolution b. City of Huslia Resolution 3. AVEC Letter of Commitment 4. Letters of Support a. Doyon b. Interior Regional Housing Authority c. Native Village of Huslia d. City of Huslia e. K’oyitl’ots’ina ANSCA Village Corporation 5. Siting Map 6. Detailed Capital Budget 7. Team Resumes Technical Information - Appendices 2 8. End Use Efficiency Report 9. Technical Backup a. NREL Solar PV and Battery HOMER Feasibility Study and Summary b. Titan Solar Racking Quote c. Maddox Transformer Quote d. EPC Power Quote e. CED Greentech Quote f. CED Greentech Highpower 125 kVA quote g. AGETO Cut Sheet for Microcontrollers 10. B/C Ratio Model File Draft Power Purchase Agreement INTERCONNECTION AND POWER PURCHASE AGREEMENT BETWEEN ALASKA VILLAGE ELECTRIC COOPERATIVE, INC. AND TANANA CHIEFS CONFERENCE FOR HUSLIA SOLAR PV AND BATTERY PROJECT INDEX 1. Parties .................................................................................................................................................1 2. Term .....................................................................................................................................................1 3. Project Output ...................................................................................................................................2 4. Equipment and Inspection .............................................................................................................2 5. Liability and Indemnification .........................................................................................................2 6. Insurance ............................................................................................................................................3 7. Technical Standards ........................................................................................................................3 8. Operation ............................................................................................................................................3 9. Pricing .................................................................................................................................................4 10. Billing & Payment .............................................................................................................................4 11. Billing Disputes.................................................................................................................................5 12. Interconnection and Integration Cost .........................................................................................5 13. Station Service ..................................................................................................................................5 14. Disconnection ...................................................................................................................................6 15. Termination ........................................................................................................................................6 16. Notice ..................................................................................................................................................6 17. Entire Agreement..............................................................................................................................7 18. Covenant Not to Compete ..............................................................................................................7 19. No Wheeling Rights .........................................................................................................................7 20. Renewable Energy Credits.............................................................................................................7 21. Amendment........................................................................................................................................8 22. Assignment ........................................................................................................................................8 23. Governing Law ..................................................................................................................................8 24. Relationship of the Parties.............................................................................................................8 25. Disputes ..............................................................................................................................................8 26. Signatures ........................................................................................................................................10 APPENDIX A:Technical Requirements (5 Pages) APPENDIX B:Interconnection Drawings, (6Page) APPENDIX C:Description of Project, (1 Pages) APPENDIX D:Operating Agreement, (4 Pages) Page 1 of9 INTERCONNECTION AND POWER PURCHASE AGREEMENT BETWEEN ALASKA VILLAGE ELECTRIC COOPERATIVE, INC. AND TANANA CHIEFS CONFERENCE (IPP) WHEREAS, Tanana Chiefs Conference (hereinafter “TCC” or “Producer”) is constructing a solar-battery generation facility with an alternating current (AC) nameplate capacity of approximately 350 kilowatts (“kW”) solar and 100kW/500kWh battery, to be located at Block 9 Lot 1 Shungnak Townsite Subdivision, Shungnak Alaska, 99773 (hereinafter the “Project”); and WHEREAS, Producer wishes to interconnect the Project with the electric distribution system owned by Alaska Village Electric Cooperative, Inc. (hereinafter “AVEC”); and WHEREAS, Producer desires to sell the entire electric energy output of the Project to AVEC pursuant to a long-term power purchase agreement (hereinafter the “Agreement”); and WHEREAS, AVEC wishes to interconnect with Producer’ Project, and to the extent possible, purchase the entire electric energy output of the Project, in a manner not detrimental to its members. NOWTHEREFOREITISHEREBYAGREED: 1. Parties. The parties to this Agreement are Producer and AVEC. Within this Agreement, the term “Party” means TCC or AVEC, and the term “Parties” means both Producer and AVEC. 2. Term. This Agreement does not become effective until it has been signed by authorized representatives of both Parties. This Agreement will expire three (3) years from its effective date if Producer has not commenced delivery of electric energy generated from the Project to AVEC prior to such expiration date. If Producer commences delivery of electric energy from the Project to AVEC prior to the expiration date identified above, this Agreement will expire twenty (20) years from its effective date. Unless there is notification from either party to the contrary, at the end of twenty (20) years, this Agreement will be automatically extended to the next end of the calendar year on an annual basis. Page 2 of9 3. Project Output. Producer commits to sell all (100%) of the Project’s output, as metered at the interconnection point, to AVEC. AVEC commits, subject to Section 15 (Disconnection) of this Agreement, to purchase as much of the Project’s output as the electric system can take, as determined in AVEC’s commercially reasonable discretion for the safe and effective operation of the electric system, at any point in time. Due to the relative capacity of the Project’s output compared to historical loads in Huslia, it is expected that the Project output will be curtailed at times. 4. Equipment and Inspection. Producer warrants that the Project equipment is as described in the Project Description in Appendix C. In the event Producer seek to modify the Project equipment (replacement in kind excluded), Producer will provide AVEC sixty (60) days’ notice prior to performing such modifications so that AVEC may determine whether the modifications meet Tariff, safety, and operational requirements, or require modifications to the interconnection equipment. Producer authorizes AVEC to inspect Project equipment at any time, at AVEC’s expense, with a twenty-four (24) hour notice. Regarding this right of inspection, the Parties hereby agree that AVEC is not undertaking any responsibility for the design, operation, or maintenance of the Project. 5. Liability and Indemnification. Producer shall defend, indemnify and hold harmless AVEC from and against any and all claims, liability, damages and expenses, including reasonable attorneys’ fees and court costs, arising out of or related to any personal injury, death or damage to any person or property, including loss of use thereof, which arises out of or results from any act or omission by Producer, their employees, agents, contractors, representatives, successors or assigns during or after construction, ownership, operation or maintenance of Producer’ facilities used in connection with this Agreement, except to the extent caused by the negligence of AVEC, its employees, agents, or representatives. Producer agrees to compensate AVEC for any damage to AVEC’s equipment caused by Producer’ operations or resulting from Producer’ interconnection with the Project. Upon the written request of AVEC seeking indemnification under this provision Producer shall defend any suit which asserts a claim covered by this provision. If AVEC is required to file an action or proceeding to enforce its indemnification rights under this provision and said indemnification rights are upheld by a court or arbitrator having valid jurisdiction, Producer shall reimburse AVEC for all expenses, including actual attorneys’ fees and court costs, incurred in connection with such action. Producer further agrees to defend and indemnify and hold AVEC harmless against any penalty or remediation ordered by any government agency, caused by or resulting from operation, construction, removal or failure to remove the Project, or Producer’s failure to properly maintain the Project. Producer further agree that AVEC has no responsibility for the design, operation, or maintenance of the Project, except as identified in the Operating Agreement, included as Appendix D, and agrees to indemnify AVEC against any claims related to such matters. Page 3 of9 AVEC agrees to defend, indemnify, and hold harmless Producer from any personal injury, death, or property damage to any third party resulting from negligent acts or omissions of AVEC employees,agents, contractors, or representatives. AVEC shall have no liability to Producer for outages or disturbances on the AVEC system that may impact Producer’ operations. Producer is responsible for all protections or safeguards necessary to protect Producer’ operations and equipment while interconnected to AVEC. Upon the written request of Producer seeking indemnification under this provision, AVEC shall defend any suit which asserts a claim covered by this provision. If Producer are required to file an action or proceeding to enforce its indemnification rights under this provision and said indemnification rights are upheld by a court or arbitrator having valid jurisdiction, AVEC shall reimburse Producer for all expenses, including actual attorneys’ fees and court costs, incurred in connection with such action. 6. Insurance. For the duration of this Agreement, and at all times the Project is interconnected with AVEC’s distribution system, Producer agree to continuously maintain commercial general liability insurance, with carrier(s) permitted to issue insurance policies in the State of Alaska, of not less than $1,000,000 combined single limit for bodily injury and property damage that may originate from the Project. Producer will list AVEC as an additional insured Party on the general liability insurance policy(ies) for the Project. To the extent required by law, Producer will also maintain Workers Compensation and Employer’s Liability insurance for the Project during all times the Project is interconnected with AVEC’s distribution system and Producer or their employees or contractors are working on Producer’ facilities. To the extent insurance is required by this Agreement, Producer will provide AVEC with Certificates of Insurance documenting their compliance with such requirements. Any failure to comply with the requirements of this paragraph constitutes cause for AVEC to immediately disconnect the Project from AVEC’s system. In the event the Project is disconnected from AVEC’s system due to Producer’ failure to maintain the required insurance, AVEC’s obligation to purchase electric energy from the Project shall be suspended until such time as Producer provide proof that they are in compliance with their insurance requirements. During such suspension, Producer shall be prohibited from selling Project energy to any individual or entity other than AVEC. 7. Technical Standards. Electric energy produced by the Project shall be delivered in accordance with IEEE Standard 1547, Standard for Interconnecting Distributed Resources with Electric Power Systems, as well as AVEC Interconnection standards specified in this Agreement in Appendix-A: Technical Requirements. 8. Operation. Producer shall always operate the Project in a manner consistent with prudent utility practice during which the Project is electrically interconnected with AVEC’s system. The Project shall be built and maintained in a manner that it is able to meet the required electrical standards contained in Appendix A: Technical Requirements. The operating responsibilities and operation protocol are included in the Operating Agreement shown in Appendix-D Page 4 of9 Prior to the time Producer commences producing electric energy with the Project, and after the interconnection equipment has been installed, Producer and AVEC shall review and mutually understand the protocol for disconnection of the Project from AVEC’s system due to scheduled maintenance and/or unplanned outages and restoration to normal operations. 9. Pricing AVEC shall pay its Tariff, Non-firm Power Rate, (Rate Schedule “SC”) for the net energy received by AVEC from the Project for the life of this Agreement. This rate will be adjusted with each of AVEC’s approved power cost equalization (“PCE”) rate filings with the Regulatory Commission of Alaska. The net energy received shall be defined as the difference between the total energy received by AVEC from the Project and the total energy delivered from AVEC to the Project over a given time period. AVEC will deduct from this payment any amounts that are due to AVEC for payment from Producer under this Agreement, including for maintenance under Section 13. 10. Billing & Payment. AVEC shall meter the electric energy received by AVEC from the Project and the electric energy delivered to the Project from AVEC and shall read such meter for billing purposes on or about the last day of each calendar month. AVEC shall electronically provide Producer with these meter readings and, to the extent readily available, any intermediate meter readings that Producer may reasonably request. Meter testing shall be done pursuant to the terms set forth in AVEC’s Tariff. AVEC will compensate Producer for only energy transmitted; a demand or kW capacity payment will not be applicable or paid by AVEC for the life of the project. Producer shall render an invoice to AVEC based upon billing readings and the net energy received by AVEC not more frequently than once per calendar month, and AVEC shall pay such invoices, less any other charges attributable to the Producer per this agreement, within thirty (30) days of receipt. AVEC may administer charges for Power Factor (PF) correction should the Project fail to perform within agreed technical boundaries included in Appendix A for acceptable PF requirements. Producer will submit their billing invoice to AVEC’s Accounts Payable Department based on the net energy received by AVEC the previous month. Billing invoices must be mailed to the following address: Alaska Village Electric Cooperative, Inc. Attn: Accounts Payable Dept. 4831 Eagle Street, Anchorage, AK 99503 Alternatively, billing invoices may also be sent electronically to AVEC’s Accounts Payable Department by emailing them to: accountspayable@AVEC.org. Page 5 of9 11. Billing Disputes. In the event AVEC disputes the amount invoiced by Producer, AVEC shall pay the undisputed amount, less any charges attributable to the Producer per this Agreement, within thirty (30) days of receiving the disputed invoice and shall notify Producer in writing of the basis for disputing the remainder at the same time as the partial payment is made. In the event Producer disputes the cost of charges AVEC attributes to the Producer, which is deducted from AVEC’s payment, the Producer shall have thirty (30) days from receiving payment to dispute the charges. Representatives of Producer and AVEC shall attempt to resolve the dispute within sixty (60) days of the date AVEC received the disputed invoice, or the Producer received the disputed payment. If resolution is not achieved within such 60-day period, either Party may submit the dispute in accordance with dispute resolution as outlined below. 12. Interconnection and Integration Cost. AVEC will operate and maintain an electrical connection to the Project from its facilities up to the point of common coupling (PCC) as defined in Appendix D. Producer is not under any obligation to supply electric energy to AVEC but may do so if and when Producer choose. AVEC may disconnect the Project at any time for safety, or operational, or other such reasons, at its commercially reasonable discretion, without any guarantee of restoration time other than complying with prudent utility practices. Service can also be interrupted in case of material breach as stipulated in Section 16 of this Agreement. Any time AVEC disconnects the Project for more than 12 hours, AVEC shall generate and distribute to Producer a report explaining the reason for such disconnection and an estimate of time when connection shall be restored. Producer agrees to provide or pay AVEC for all studies and improvements to the AVEC system that AVEC determines, in its commercially reasonable discretion, are required to interconnect and integrate any modifications that the producer plans to implement to the configuration of the project. AVEC must receive payment for the estimated cost to perform the studies prior to commencing work. AVEC must receive payment of the estimated cost to install the required improvements prior to performing any work related to the installation of those improvements. The payment method outlined above shall be in full force and effect throughout the term of this contract, including any additions or modifications to Producer’s facility, unless other mutually acceptable terms for payment are reached, and documented in writing. 13. Billing for Requested Maintenance In the event that AVEC is requested by the Producer to maintain the Producer’s equipment, AVEC will track its costs associated with the work and will issue an invoice to the Producer for reimbursement with an explanation of the charges. After thirty (30) days from invoicing if payment is not received AVEC shall deduct the invoice amount from any payment(s) due to the Producer until the balance is paid. 14. Station Service. AVEC will supply separate electric utility service(s) to Producer pursuant to AVEC’s Tariff if such service is requested by Producer. Producer shall be responsible for all member obligations related to maintenance and payment for such service(s) as provided in AVEC’s Tariff. In the event Producer has accrued fees and charges due AVEC for Page 6 of9 separate utility service(s), such fees and charges may be deducted from payments due to Producer by AVEC. 15. Disconnection. AVEC may disconnect the Project from its system without notice if a hazardous condition exists and disconnection is necessary to protect persons, utility facilities, or consumer property from damage, or to restore service on AVEC’s distribution system in the event of an unplanned outage. In the event of such, AVEC shall notify Producer as soon as possible of the reason for disconnection and its expected duration. AVEC shall provide Producer with at least 24 hours advance notice of a scheduled disconnection required to maintain or upgrade AVEC’s facilities. If Producer disputes AVEC’s decision to disconnect the Project pursuant to this paragraph, Producer shall notify AVEC of the basis for their dispute in writing within ten (10) days of the date of disconnection. If the Parties cannot resolve such dispute within ten (10) days of the date AVEC receives this notice, any Party is free to submit the dispute for resolution. In no event shall AVEC be liable to Producer for revenue lost during a disconnection pursuant to this paragraph. 16. Termination. Any Party may terminate this Agreement upon a material breach by another Party, but only if notice of the breach has been given to the other Parties, and no cure of the breach has been made prior to expiration of sixty (60) days from date of notice. Disputes submitted for resolution pursuant to this Agreement shall not be considered a material breach of this Agreement for purposes of termination until such time as the dispute resolution process has been finally concluded and there has been a failure of one or both Parties to comply with such final resolution. 17. Notice. NoticeshallbegiveninwritingtothePartiesatthefollowingaddresses: When to AVEC: Alaska Village Electric Cooperative, Inc. Attn. William Stamm, President and CEO 4831 Eagle Street Anchorage AK 99503 Email: Bill Stamm (bstamm@avec.org) When to TCC: Name: Tanana Chiefs Conference Attn. Dave Messier, Infrastructure Division Director 122 1st Ave, Fairbanks, AK 99701 Email: Dave.PM@tananachiefs.org Page 7 of9 18. Entire Agreement. The entire agreement between Producer and AVEC with regard to the Project is as set forth in this Agreement and those portions of AVEC’s Tariff, as such may be amended from time to time, which do not directly conflict with the specific terms of this Agreement. 19. Covenant Not to Compete. Producer agrees that they will not sell, barter, donate or otherwise attempt to deliver Project energy to any individual or entity other than AVEC during the life of this Agreement. 20. No Wheeling Rights. Producer acknowledges and agrees that nothing contained herein shall be interpreted or argued to give Producer any right to use AVEC facilities for any purpose other than delivering Project energy to AVEC under this Agreement, including but not limited to the wheeling of electrical energy. 21. Renewable Energy Credits. The Parties acknowledge and agree that the Project relies on AVEC’s willingness to enter into a long-term power purchase agreement, under which AVEC takes the entire output of the Project. The Parties further acknowledge that the Project may be eligible, or become eligible, for Renewable Energy Credits (herein after “RECs”) or similar federal, state, or local government incentive programs, and that such RECs may have a monetary value that is independent of the energy produced. a. Economic Benefits to be Shared Equally. The Parties agree that, for the duration of this Agreement, they will share equally in the benefit of any and all RECs attributable to the Project. Producer shall act as the agent for sale of any available RECs until such time that AVEC requests Producer to cease such activity on AVEC’s behalf. b. Duty of Disclosure and Access to Records. Producer shall have a duty to make available documentation as is reasonably required to verify the terms and value of the RECs. AVEC and Producer shall execute and deliver such documents and assurances and take such further actions as may be reasonably required to obtain any and all available and applicable RECs. c. Right of Offset. Page 8 of9 AVEC reserves the right to collect its share of the payments to Producer from any RECs received by Producer from payments that may otherwise be due to Producer under this Agreement. 22. Amendment. The terms of this Agreement shall only be amended by written agreement signed by both Producer and AVEC. 23. Assignment. Neither this Agreement, nor any interest therein, shall be transferred or assigned to any other person or entity by any Party unless the other Parties have consented to such assignment in writing. Producer may assign its right to receive payments under this Agreement so long as AVEC is held harmless under such assignment for payments that might be misdirected. 24. Governing Law. The validity, interpretation, and performance of this Agreement shall be governed by the laws of the State of Alaska, without giving effect to Alaska choice of law principles. 25. Relationship of the Parties. Under the terms of this Agreement, Producer are a seller of electric energy and AVEC is a purchaser of electric energy. This Agreement shall not be interpreted as creating any sort of partnership, joint venture, or agency relationship between AVEC and Producer. 26. Disputes. In the event of a dispute arising as to the meaning of this Agreement or in which a party requests enforcement of this Agreement or damages for breach of this Agreement, the Parties agree that the laws of the State of Alaska shall apply, and the matter shall be decided in the courts of applicable jurisdiction of the Third Judicial District of the State of Alaska at Anchorage. The Parties further agree to be subject to and bound by the laws of the state of Alaska and waive any immunity thereto. 27.Force Majeure. In the event any Party, by reason of a Force Majeure Event, is rendered unable, wholly or in part, to perform its obligations under this Agreement (other than its obligations to pay money), then upon said Party giving written notice and particulars of such Force Majeure Event to the other Parties, its obligation to perform shall be suspended or correspondingly reduced during the continuance of any inability so caused, but in no greater amount than required by the Force Majeure Event and for no longer period, and the effects of such cause shall, so far as possible, be remedied with all reasonable and prompt dispatch. For purposes of this Agreement, “Force Majeure Event” means any cause beyond the control of a Party and which, by the exercise of due diligence, that Party is unable to prevent or overcome, including but not limited to an act of God, fire, flood, volcano, earthquake, explosion, sabotage, and an act of the public enemy, an act of civil or military authority (including court orders, injunctions and orders of governmental agencies of competent jurisdiction (including delay or denial of necessary permits)), insurrection or riot, an act of the elements, failure of equipment, of the inability to obtain or transport equipment or materials because of the effects of similar causes on carriers or shippers. Strikes, lockouts, and other labor disturbances may be considered Force Majeure Events, and nothing in this Agreement shall require any Party to settle a labor dispute against its best judgment. Signatures: _________________________________ Name: Title: Alaska Village Electric Cooperative Date: _________________________________ Name: Title: Tanana Chiefs Conference Date: nak -- positioned - - r Appendices Electrical Design Package Project Description Project Location Operating Agreement MajorProduct Specifications PV Modules - - Inverters - - Optimizers - - Batteries: - – Blue Planet Grid Forming Inverter System Controller TechnicalDescriptionof Shungnak PV Project: - - 1 Alaska Village Electric Cooperative PPAHuslia TCCIPP Appendix D: Operating Agreement APPENDIX-D OPERATING AGREEMENT A.Overview 1 B.ProjectDefinition 1 C.Points of Common Coupling 2 D.Point ofIsolation 2 E.Ownership and Maintenance 2 F.Official Contacts 2 G.Operation of the Project 3 H.Operating Protocol 3 I.Operation of the Point of Isolation 4 J.Planned Outages for Schedule Maintenance 4 K.Unplannedoutages 4 L.NotificationofDisconnection 4 A. Overview: The intent of Appendix D of this agreement is to outline the responsibilities of the Producer and AVEC for operation and maintenance of the Project and the interconnected facilities of AVEC. It defines points of interconnection, isolation, operating protocols, and notification. B. Project Definition a. The Project is a solar-battery generation facility with an alternating current (AC) nameplate capacity of approximately 350 kilowatts (“kW”)solarand a 100kW/500kWh battery plus inverter, to be located at Block 9 Lot 1 Shungnak Townsite Subdivision, Shungnak Alaska, 99773, further described in Appendix C of this agreement. b. The Project includes a system control panel that will be installed at the AVEC power plant to allow monitoring and control of the Project. c. The Project connections to the AVEC system include a metered, 480V, three-phase power connection to the power plant bus for bi-directional delivery ofbulk power; an 2 Alaska Village Electric Cooperative PPAHuslia TCCIPP Appendix D: Operating Agreement ethernet communications connection to the AVEC communications network; and a separate, metered, commercial service from AVEC to the Project to provide station service to the Project. C. Points of Common Coupling a. The Point of Common Coupling (PCC) shall be the point in any connection between the Project and AVEC where the ownership and maintenance of facilities transfers from the Producer to AVEC. b. For the bulk power connection, the PCC shall be at the spliced cable connections at the weatherhead, on the service riser on the utility side of the “600A Main DISC SW” at the Project’s battery/inverter building. c. For the communications and controls the PCC shall be at the ethernet port on the AVEC router or network device where the Project’s system controller communication cable is plugged in, at the AVEC power plant. d. For the Project station service connection, the PCC shall be at the spliced cable connections at the weatherhead, on the service riser on the utility side of the Project’s service entrance, at the Project’s battery/inverter building. D. Point of Isolation a. The Point of Isolation (POI)shall be the pointwhere the Producer’s power generation system and AVEC’s power generation system can be separated electrically, with a lockable, visible open. b. The POI for this project is designated as the manually operated switch “600AMAIN DISC SW” on the Project’s battery/inverter building. E. Ownership and Maintenance a. Producer shall own and maintain all facilities installed under the Project up to the point of common coupling (PCC) as defined above. b. AVEC shall own and maintain all facilities on the utility side ofthe PCC as definedabove including and cable splices at the PCC. c. The Producer shall contact AVEC Operations Department (1-800-478-1818) to request and shall receive approval prior to entering AVEC facilities to inspect, maintain, or repair any of Producer’s equipment installed on AVEC property. Permission for Producer to access Producer’s equipment at AVEC facilities will not be unreasonably withheld by AVEC. d. In the event that AVEC is requested by the Producer to maintain or repair the Producer’s facilities, AVEC will be reimbursed by the Producer for all reasonable cost for such, including but not limited to labor, materials, freight, travel, overhead and administrative costs. F. Official Contacts 3 Alaska Village Electric Cooperative PPAHuslia TCCIPP Appendix D: Operating Agreement a. The Producer shall provide 24-hour telephone contact(s). This contact will be used by AVEC to arrange for repairs, inspection, or emergencies. AVEC will make such arrangements (except for emergencies) during normal business hours. b. AVEC monitors utility power to the Cooperative’s customers year-roundandon24-hour basis from AVEC’s main office in Anchorage, Alaska. AVEC can be reached 24 hours a day, 7 days a week for communicating any system disturbances and planned or unplanned service outage. c. The primary contacts and phone numbersofthe representatives designatedto respond on behalf of both Parties (AVEC and Producer) on operational matters are as named below: i. Producer:Huslia TCC IPP Name/Title: Contact Phone: ii. AVEC: ManagerofOperationsorEngineering, 1-800-478-1818 or (907) 561-1818 G. Operation of the Project a. The Project’s system control panel, installed at the AVEC power plant, will be the interface that allows control and monitoring of the Project’s electrical output to the AVEC system. AVEC will be allowed direct and remote access to this panel at all times. The control programing theory of operation and network security provisions shall be submitted to and approved by AVEC prior to connections to the AVEC system. Any alterations by the Producer of the system operating controls or security must be approved by AVEC Engineering (1-800-478-1818) prior to implementation. b. The Producer shall operate the Project facilities and controlits ability to provide power to the AVEC system. c. AVEC shall operate its facilities and control the dispatch of generation resources, including from the Project, and manage utility loads at its sole discretion to provide safe reliable utility power. d. AVEC shall control the dispatch of generation resources from the Project in such a manner asto reasonably maximize the lifespan of the Projectequipment and minimize unreasonable wear and tear. H. OperatingProtocol a. Prior to connecting the Project to the AVEC system the Producer shall inspect, test and otherwise verify that all components of its system are operating properly and verify all protection devices are properly adjusted and functioning. b. The Producer and AVEC shall collaborate and agree to the automated dispatch logic used by the Project system controller to determine when the Project will provide power to the AVEC system. Until agreement is reached on the dispatch logic the Project will remain isolated from the AVEC system. 4 Alaska Village Electric Cooperative PPAHuslia TCCIPP Appendix D: Operating Agreement Operation of the Point of Isolation The Point of Isolation (POI) is a manually operated switch. Prior to either party closing the POIswitch, both parties shall be informed and both parties shallapprove the closing of the switch. In the event that one or more parties cannot be contacted or a Party’s contact cannot provide approval, the switch will remain open. AVEC may open the POI switch at any time for the following reasons: To eliminate conditions that constitute a potential hazard to AVEC personnel or the general public. The Producer’s equipment interferes with AVEC’s equipment or equipment belonging to other AVEC members. The Producer’s system isfound to haveanadverse impact onthe quality of power provided to AVEC members. The POI switch may be used by either party as Lock-out Tag-out device for employee safety. Neither party shall remove the other party’s locks nor bypass a locked switch. Planned Outages forSchedule Maintenance Producer shall notifyAVEC and AVEC shall notify Producer at least 24 hoursin advance of the time that the interconnection line needs to be taken out of service due to a scheduled maintenance. The Parties will jointly review the disconnection details at the time such notice is given. Unless the POI is opened it will be assumed that power restoration can happen at any time without notification. Unplanned outages At any time the AVEC system and or the Producer’s system may experience a fault, oran emergency action creating a power outage. Unless the POI is opened it will be assumed that power restoration can happen at any time without notification. Notification of Disconnection In the event that AVEC disconnects the Project from the AVEC system for other than a planned outage, it will contact the Producer as soon as reasonably possible to notify them of the disconnection. Inthe eventthat AVEC disconnectsthe project from the AVECsystem formorethan consecutive hours, AVEC shall provide an explanation for the disconnection to the Producer in writing. In the event that the Producer disconnects the Project from the AVEC system for other than a planned outage, it will contact AVEC as soon as reasonably possible to notify them of the disconnection. End of Appendix D 7&&5HVROXWLRQ $JUZPG)VTMJB3FTPMVUJPO - land lease commitment "7&$-FUUFSPG$PNNJUNFOU -FUUFSTPG4VQQPSU November 16, 2022 Tanana Chiefs Conference 122 1st Ave Fairbanks, AK 99701 To Whom It May Concern, Please accept this letter of support for the proposal by Tanana Chiefs Conference for the project to install a photovoltaic (PV) power system and battery energy storage in one of our region’s communities under the Alaska Energy Authority (AEA) Renewable Energy Fund (REF) Project FY23. TCC’s proposed project would benefit the community of Huslia by reducing diesel generator usage with a more efficient, less polluting energy system of a PV system, and battery storage. Doyon, Limited is the regional ANCSA Corporation for Interior Alaskan Villages. Our mission is to continually enhance our position as a financially strong Native corporation in order to promote the economic and social well-being of our shareholders and future shareholders, to strengthen our Native way of life, and to protect and enhance our land and resources. Huslia is an excellent choice to fund a renewable energy project. Like many of our Alaskan villages, Huslia is utilizing outdated and oversized energy sources that burn far too much fuel and release too many emissions. Funding this project would deliver several benefits to the village such as cleaner air, reduced fuel usage, cost savings, and reduced diesel emissions while still meeting local energy demand. Doyon fully supports the efforts of Tanana Chiefs Conference and Huslia to create a more sustainable energy future. The high cost of fuel within our village communities, especially those smaller communities that are not connected to the road system, is an immense burden that this project would help reduce. We greatly appreciate the programs that AEA manages which help our villages reach their energy goals and preserve the environment. If I can answer any questions, please contact Doyon at (907) 459-2000 or by email at communications@doyon.com. Thank you for your consideration. Sincerely, Aaron M. Schutt President and Chief Executive Officer Doyon, Limited 4JUJOH.BQ %FUBJMFE$BQJUBM#VEHFU Item Cost Shipping Cost Ground Screws 65,400$ 24,525$ APA Racking 104,319$ 29,025$ Solar Mods 217,620$ 46,649$ Inverters 30,842$ 1,000$ EPC Inverter 74,450$ 2,500$ BESS 425,000$ 20,000$ Transformer 25,000$ 2,500$ Misc Wiring 104,910$ 20,000$ fencing 42,174$ 21,087$ AVEC Integration Work Orde 75,000$ Installation Contractor 750,000$ Subtotal 1,914,714$ 167,286$ Total 2,082,000$ Huslia Detailed Equipment and Installation Budget Major Budget Components Huslia 5FBN3FTVNFT • • AVEC staff and their role on this project includes: • William R. Stamm, President and Chief Executive Officer, would act as Project Executive and will maintain ultimate program and financial authority. Forest Button, Manager, Community Development and Key Accounts, would lead the project management team consisting of AVEC staff, consultants, and contractors. Together with the Assistant Project Manager, Forest would provide coordination of solar data analysis, conceptual design, and permitting. The group’s resources include a project coordinator, accountant, project/construction manager (PM/CM), and a community liaison. Mr. Button will be responsible for managing all the project milestones listed in Section 3.1. He will also be responsible for reporting directly to AEA on the status of the project. Onya Stein, Assistant Project Manager, will assist on all milestones of the project. In particular, she will be responsible for managing the consultant team. Onya would ensure that all milestones and tasks are completed. Specifically, she would be responsible for selecting, coordinating, and managing the solar resource specialist, engineers, and permitting consultants and ensuring that their deliverables are on time and within budget. Daniel Allis, Manager of Operations, would provide oversight and input in planning for construction, distribution, and solar energy generation components of the project. Specifically, he would provide input on analysis of current cost (milestone 5); the assessment of alternatives (milestone 6); the CDR (milestone 7); and the final report (milestone 10). Darren Westby, Manager of Engineering, would provide technical assistance and information on the existing power system and possible issues and project study needs. Specifically, Darren would provide input on the detailed resource analysis (milestone 2); analysis of current cost (milestone 5); the assessment of alternatives (milestone 6); the CDR (milestone 7); and the final report (milestone 10). Rebecca Lopez, Chief Financial Officer, would assist with questions arising out of the economic and financial analysis (milestone 8) and the business and operations plan (milestone 9). In addition, related to grant management, she would provide support in accounting, payables, financial reporting, and capitalization of assets in accordance with AEA guidelines. Anna Sattler, Community Liaison, would communicate directly with Huslia residents to ensure that the community is informed. Specifically, Anna would assist by working with the community on identification of land issues (milestone 3); assessment of alternatives (milestone 6); and relaying information and recommendations from the CDR (milestone 7 and 10) VEEP (Efficiency Report) Village End Use Energy Efficiency Measures Program AEA Grant # 2195294 Administered by Alaska Building Science Network Huslia Final Report Community Summary 14 community buildings and 5 teacher housing units received energy efficiency upgrades. City Office / VPSO, Community Hall, Gas & Oil Office, Huslia Head Start Building, Tribal Office & Elder Center, Armory, Old Clinic / Old Tribal Office, TFYS, Elementary School, High School, Maintenance Shop, Wood Shop, School Gym, Community Church, Episcopal Church Retrofits Completed: March 2010 Village-Wide Lighting Retrofit Summary: • Retrofitted 274 light fixtures with electronic ballasts & T8 lamps • Retrofitted 19 existing electronic ballasts with T8 lamps • Installed 71 compact fluorescent light bulbs • Pre-retrofit energy use for all lighting: 44.597 Kilowatts • Post-retrofit energy use for all lighting: 23.378 Kilowatts • Energy savings projection: 21.219 Kilowatts • Pre-retrofit to post retrofit energy reduction: 48% • Estimated Annual Savings: kWh Rate (FY 2009 AVE): $0.65 Fuel Cost (FY 2009 Ave): $4.43 Comparative Comparative Hours Per Day/ 250 Electrical Avoided Diesel Avoided Diesel Days Per Year Savings Use (gal) Costs Locally Estimated Use $23,026.21 2639.74 $11,694.0 4 Hours/day $13,730.81 1574.11 $6,973.31 7 Hours/day $24,028.93 2754.69 $12,203.2 10 Hours/day $34,327.04 3935.27 $17,433.2 • Total project cost for all measures: 48,000 • Simple Payback (lighting measures only, using 7 hours/day lighting use run-time): 2 years • Total village wide in-kind contribution: $5,798.00 Additional Energy Efficiency Measures: One programmable thermostat installed in City office. 2 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia City of Huslia Owned Buildings Fluorescent light ballasts retrofit. Lighting retrofit training for maintenance workers. Programmable thermostat installed in City office. 4 buildings owned by the City of Huslia received energy efficient lighting upgrades as follows: City Office / VPSO, Community Hall, Gas & Oil Office, Head Start Building • Lighting upgrades completed in March 2010 • Retrofitted 44 light fixtures with electronic ballasts & T8 lamps • Installed 11 compact fluorescent light bulbs • Pre-retrofit energy use for all lighting: 6.772 Kilowatts • Post-retrofit energy use for all lighting: 3.037 Kilowatts • Energy savings projection: 3.735 Kilowatts • Pre-retrofit to post retrofit energy reduction: 55% • Estimated Annual Savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided 250 Days Per Year Savings Use (gal) Diesel Costs Locally Estimated $4,966.05 569.31 $2,522.05 4 Hours/day $2,416.92 277.08 $1,227.45 7 Hours/day $4,229.61 484.89 $2,148.04 10 Hours/day $6,042.30 692.69 $3,068.63 3 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia City Office / VPSO Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 11 CFL-20 W 1 • Pre-retrofit energy use: 904 watts • Post-retrofit energy use: 526 watts • Energy savings projection: 378 watts • Pre-retrofit to post retrofit energy reduction: 42% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $244.60 28.04 $124.22 7 Hours/day $428.06 49.07 $217.39 10 Hours/day $611.51 70.10 $310.56 2080 Hours/year (Est.) $508.78 58.33 $258.39 Note: Five high output T-5 2-lamp fluorescent fixtures taken offline for additional savings. Community Hall Materials Installed Quantity 3-lamp electronic ballast, (2) 25 watt T8 lamps 7 4-lamp electronic ballast, (4) 25 watt T8 lamps 2 CFL-23 W 9 • Pre-retrofit energy use: 1824 watts • Post-retrofit energy use: 751 watts • Energy savings projection: 1073 watts • Pre-retrofit to post retrofit energy reduction: 59% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $694.34 79.60 $352.63 7 Hours/day $1,215.09 139.30 $617.09 10 Hours/day $1,735.85 199.00 $881.56 2000 Hours/year (Est.) $1,388.68 159.20 $705.25 4 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Gas & Oil Office Materials Installed Quantity 4-lamp electronic ballast, (4) 25 watt T8 lamps 2 • Pre-retrofit energy use: 288 watts • Post-retrofit energy use: 180 watts • Energy savings projection: 108 watts • Pre-retrofit to post retrofit energy reduction: 38% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $69.89 8.01 $35.49 7 Hours/day $122.30 14.02 $62.11 10 Hours/day $174.72 20.03 $88.73 2000 Hours/year (Est.) $139.77 16.02 $70.99 Head Start Building Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 3 3-lamp electronic ballast, (3) 25 watt T8 lamps 18 4-lamp electronic ballast, (4) 25 watt T8 lamps 1 CFL-20 W 1 • Pre-retrofit energy use: 3756 watts • Post-retrofit energy use: 1580 watts • Energy savings projection: 2176 watts • Pre-retrofit to post retrofit energy reduction: 58% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $1,408.09 161.42 $715.11 7 Hours/day $2,464.16 282.49 $1,251.44 10 Hours/day $3,520.22 403.56 $1,787.77 2080 Hours/year (Est.) $2,928.83 335.76 $1,487.43 Note: Three fixtures reduced from 4-lamp to 2-lamp and eighteen fixtures from 3-lamp to 2-lamp fixtures for additional savings. Additional Energy Efficiency Measures: One programmable thermostat installed in City office. 5 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Huslia Tribal Council Owned Buildings 4 buildings owned by the Huslia Tribal Council received energy efficient lighting upgrades as follows: Tribal Office & Elder Center, Armory, Old Clinic / Old Tribal Office, TFYS • Lighting upgrades completed in March 2010 • Retrofitted 46 light fixtures with electronic ballasts & T8 lamps • Installed 16 compact fluorescent light bulbs • Pre-retrofit energy use for all lighting: 5.652 Kilowatts • Post-retrofit energy use for all lighting: 2.507 Kilowatts • Energy savings projection: 3.145 Kilowatts • Pre-retrofit to post retrofit energy reduction: 56% • Estimated Annual Savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided 250 Days Per Year Savings Use (gal) Diesel Costs Locally Estimated $3,351.09 384.17 $1,701.88 4 Hours/day $2,035.13 233.31 $1,033.56 7 Hours/day $3,561.48 408.29 $1,808.72 10 Hours/day $5,087.82 583.27 $2,583.89 6 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Tribal Office & Elder Center Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 18 3-lamp electronic ballast, (2) 25 watt T8 lamps 2 CFL-23 W 8 CFL-27 W 1 CFL-9 W 1 • Pre-retrofit energy use: 2740 watts • Post-retrofit energy use: 1152 watts • Energy savings projection: 1588 watts • Pre-retrofit to post retrofit energy reduction: 58% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $1,027.59 117.80 $521.87 7 Hours/day $1,798.29 206.16 $913.28 10 Hours/day $2,568.99 294.51 $1,304.68 2000 Hours/year (Est.) $2,055.19 235.61 $1,043.74 Note: Five fixtures reduced from 4-lamp to 2-lamp fixtures, for additional savings. Armory Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 12 3-lamp electronic ballast, (3) 25 watt T8 lamps 2 • Pre-retrofit energy use: 1344 watts • Post-retrofit energy use: 700 watts • Energy savings projection: 644 watts • Pre-retrofit to post retrofit energy reduction: 48% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $416.73 47.77 $211.64 7 Hours/day $729.28 83.61 $370.37 10 Hours/day $1,041.83 119.44 $529.10 1500 Hours/year (Est.) $625.10 71.66 $317.46 Note: Two fixtures reduced from 4-lamp to 3-lamp fixtures for additional savings. 7 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Old Clinic, Old Tribal Office Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 10 CFL-20 W 1 CFL-27 W 1 • Pre-retrofit energy use: 1160 watts • Post-retrofit energy use: 507 watts • Energy savings projection: 653 watts • Pre-retrofit to post retrofit energy reduction: 56% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $422.56 48.44 $214.60 7 Hours/day $739.47 84.77 $375.55 10 Hours/day $1,056.39 121.11 $536.50 1040 Hours/year (Est.) $439.46 50.38 $223.18 Note: Two fixtures reduced from 4-lamp to 2-lamp fixtures, for additional savings. TFYS Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 2 CFL-14 W 4 • Pre-retrofit energy use: 408 watts • Post-retrofit energy use: 148 watts • Energy savings projection: 260 watts • Pre-retrofit to post retrofit energy reduction: 64% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $168.25 19.29 $85.45 7 Hours/day $294.43 33.75 $149.53 10 Hours/day $420.62 48.22 $213.61 1375 Hours/year (Est.) $231.34 26.52 $117.49 8 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Yukon - Koyukuk School District Owned Buildings 4 buildings and 5 teacher housing units owned by the Yukon - Koyukuk School District received energy efficient lighting upgrades as follows: Jimmy Huntington School Elementary School, High School, Maintenance Shop, Wood Shop, School Gym, Teacher Housing 1, Teacher Housing 2, Teacher Housing 3, Teacher Housing Duplex • Lighting upgrades completed in March 2010 • Retrofitted 176 light fixtures with electronic ballasts & T8 lamps • Retrofitted 19 existing electronic ballasts with T8 lamps • Installed 41 compact fluorescent light bulbs • Retrofitted 32 light fixtures w HO electronic ballasts & T8 lamps • Pre-retrofit energy use for all lighting: 31.033 Kilowatts • Post-retrofit energy use for all lighting: 17.397 Kilowatts • Energy savings projection: 13.636 Kilowatts • Pre-retrofit to post retrofit energy reduction: 44% • Estimated Annual Savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided 250 Days Per Year Savings Use (gal) Diesel Costs Locally Estimated $14,345.10 1644.54 $7,285.30 4 Hours/day $8,823.86 1011.57 $4,481.27 7 Hours/day $15,441.70 1770.25 $7,842.22 10 Hours/day $22,059.60 2528.93 $11,203.10 ABSN Project Coordinator gives a few pointers to the school lighting crew. 9 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Elementary School Materials Installed Quantity 2-lamp existing electronic ballast, re-lamped with (2) 1 3-lamp existing electronic ballast, re-lamped with (3) 7 2-lamp electronic ballast, (2) 25 watt T8 lamps 8 4-lamp fixture (2) 2-lamp ballasts (4) 25 watt T8 13 • Pre-retrofit energy use: 3354 watts • Post-retrofit energy use: 2128 watts • Energy savings projection: 1226 watts • Pre-retrofit to post retrofit energy reduction: 37% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $793.34 90.95 $402.91 7 Hours/day $1,388.35 159.16 $705.09 10 Hours/day $1,983.36 227.37 $1,007.27 1800 Hours/year (Est.) $1,428.02 163.71 $725.23 Note: Reduced two 4-lamp fixtures to 2-lamp fixtures for additional savings. High School Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 40 3-lamp electronic ballast, (3) 25 watt T8 lamps 6 3-lamp fixture, (2) 2-lamp electronic ballasts (3) 25 44 4-lamp electronic ballast, (3) 25 watt T8 lamps 36 CFL-20 W 1 • Pre-retrofit energy use: 13028 watts • Post-retrofit energy use: 8172 watts • Energy savings projection: 4856 watts • Pre-retrofit to post retrofit energy reduction: 37% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $3,142.32 360.24 $1,595.85 7 Hours/day $5,499.06 630.42 $2,792.74 10 Hours/day $7,855.79 900.59 $3,989.63 1800 Hours/year (Est.) $5,656.17 648.43 $2,872.53 Note: Reduced three fixtures from 3-lamp to 2-lamp fixtures and one fixture from a 4-lamp to a 2-lamp fixture while de-lamping thirty-six 4-lamp fixtures to operate three lamps each for additional savings. 10 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Maintenance Shop / Generator Shed Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 4 • Pre-retrofit energy use: 336 watts • Post-retrofit energy use: 184 watts • Energy savings projection: 152 watts • Pre-retrofit to post retrofit energy reduction: 45% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $98.36 11.28 $49.95 7 Hours/day $172.13 19.73 $87.42 10 Hours/day $245.90 28.19 $124.88 500 Hours/year (Est.) $49.18 5.64 $24.98 Wood Shop Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 20 • Pre-retrofit energy use: 1680 watts • Post-retrofit energy use: 920 watts • Energy savings projection: 760 watts • Pre-retrofit to post retrofit energy reduction: 45% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $491.80 56.38 $249.76 7 Hours/day $860.64 98.66 $437.08 10 Hours/day $1,229.49 140.95 $624.41 500 Hours/year (Est.) $245.90 28.19 $124.88 11 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Teacher Housing 1 Materials Installed Quantity 2-lamp existing electronic ballast, re-lamped with (2) 7 • Pre-retrofit energy use: 420 watts • Post-retrofit energy use: 322 watts • Energy savings projection: 98 watts • Pre-retrofit to post retrofit energy reduction: 23% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $63.42 7.27 $32.21 7 Hours/day $110.98 12.72 $56.36 10 Hours/day $158.54 18.18 $80.52 1375 Hours/year (Est.) $87.20 10.00 $44.28 Teacher Housing 2 Materials Installed Quantity 4-lamp electronic ballast, (4) 25 watt T8 lamps 1 CFL-20 W 6 CFL-9 W 3 • Pre-retrofit energy use: 859 watts • Post-retrofit energy use: 237 watts • Energy savings projection: 622 watts • Pre-retrofit to post retrofit energy reduction: 72% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $402.50 46.14 $204.41 7 Hours/day $704.37 80.75 $357.72 10 Hours/day $1,006.24 115.36 $511.03 1375 Hours/year (Est.) $553.43 63.45 $281.07 Teacher Housing 3 Materials Installed Quantity 2-lamp existing electronic ballast, re-lamped with (2) T8s 1 CFL-20 W 8 • Pre-retrofit energy use: 540 watts • Post-retrofit energy use: 206 watts • Energy savings projection: 334 watts • Pre-retrofit to post retrofit energy reduction: 62% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $216.13 24.78 $109.76 7 Hours/day $378.23 43.36 $192.09 10 Hours/day $540.33 61.94 $274.41 1375 Hours/year (Est.) $297.18 34.07 $150.93 12 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Teacher Housing Duplex Materials Installed Quantity 2-lamp existing electronic ballast, re-lamped with (2) T8 lamps 3 2-lamp electronic ballast, (2) 25 watt T8 lamps 4 CFL-14 W 6 CFL-20 W 1 CFL-27 W 1 CFL-9 W 15 • Pre-retrofit energy use: 2336 watts • Post-retrofit energy use: 588 watts • Energy savings projection: 1748 watts • Pre-retrofit to post retrofit energy reduction: 75% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $1,131.13 129.67 $574.45 7 Hours/day $1,979.48 226.93 $1,005.29 10 Hours/day $2,827.83 324.18 $1,436.14 1375 Hours/year (Est.) $1,555.30 178.30 $789.87 School Gym Materials Installed Quantity 8 FT, 2 lamp HO electronic ballast, T8 (145w 32 • Pre-retrofit energy use: 8480 watts • Post-retrofit energy use: 4640 watts • Energy savings projection: 3840 watts • Pre-retrofit to post retrofit energy reduction: 45% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $2,484.86 284.87 $1,261.96 7 Hours/day $4,348.51 498.52 $2,208.43 10 Hours/day $6,212.16 712.17 $3,154.90 1800 Hours/year (Est.) $4,472.76 512.76 $2,271.53 13 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Community Owned Church Buildings 2 buildings owned by the Community Churches received energy efficient lighting upgrades as follows: Community Church, Episcopal Church • Lighting upgrades completed in March 2010 • Retrofitted 8 light fixtures with electronic ballasts & T8 lamps • Installed 3 compact fluorescent light bulbs • Pre-retrofit energy use for all lighting: 1.14 Kilowatts • Post-retrofit energy use for all lighting: 0.437 Kilowatts • Energy savings projection: 0.703 Kilowatts • Pre-retrofit to post retrofit energy reduction: 62% • Estimated Annual Savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided 250 Days Per Year Savings Use (gal) Diesel Costs Locally Estimated $363.93 41.72 $184.82 4 Hours/day $454.91 52.15 $231.03 7 Hours/day $796.09 91.26 $404.30 10 Hours/day $1,137.28 130.38 $577.58 Community Church Materials Installed Quantity 2-lamp electronic ballast, (2) 25 watt T8 lamps 8 CFL-23 W 1 • Pre-retrofit energy use: 940 watts • Post-retrofit energy use: 391 watts • Energy savings projection: 549 watts • Pre-retrofit to post retrofit energy reduction: 58% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $355.26 40.73 $180.42 7 Hours/day $621.70 71.27 $315.74 10 Hours/day $888.14 101.82 $451.05 800 Hours/year (Est.) $284.21 32.58 $144.34 Note: Two fixtures reduced from 4-lamp to 2-lamp fixtures, for additional savings. 14 Alaska Building Science Network – Village End Use Energy Efficiency Program – ’08-’10 Final Report Interior Region - Huslia Episcopal Church Materials Installed Quantity CFL-23 W 2 • Pre-retrofit energy use: 200 watts • Post-retrofit energy use: 46 watts • Energy savings projection: 154 watts • Pre-retrofit to post retrofit energy reduction: 77% • Estimated annual savings: Comparative Comparative Hours Per Day / Electrical Avoided Diesel Avoided Diesel 250 Days Per Year Savings Use (gal) Costs 4 Hours/day $99.65 11.42 $50.61 7 Hours/day $174.39 19.99 $88.57 10 Hours/day $249.13 28.56 $126.52 800 Hours/year (Est.) $79.72 9.14 $40.49 All waste electrical lighting ballasts and fluorescent lamps back hauled for recycling. Huslia In-Kind Contribution Tracking Record - ABSN Energy Efficiency Projects: In-Kind Item Dates Hours Contri -buted Hourly Wage Value / Amount Notes Staff time for project contact & review of intro materials (# of entities x 1 hour) 3 $ 20.00 $ 60.00 Staff time for Attending teleconference 1 $ 20.00 $ 20.00 (TC/IRA) Staff time for Attending teleconference 1 $ 20.00 $ 20.00 (City) Staff time for Attending teleconference 2 $ 20.00 $ 40.00 (School) Maint. Staff time with Field Manager on building assessments - 1st site visit 2/24/200 9 3 $ 15.00 $ 37.50 Phillip Roberts-YKSD Maintenance Conservative village office administrative percentage of total project cost less ABSN Admin %. Total project cost = $48,000/village - (our admin percentage , (around 12%) Approx: $5,760) = $42,240 x 5.5% = $2,323 (this 5.5% village admin cost estimate is spread across all entities we work with for the course of the grant for completing all energy efficiency measures. These are primarily for cumulative, otherwise unaccounted time expense for village- based project support. Feb, '07 through $2,323.00 Each time we call, email, or fax a village entity, someone has to receive the communication, review and/or forward the information, follow-up on requests, etc. Whether it is to set-up a teleconference, verify maintenance staff participation in lighting or boiler trainings, set-up in-kind lodging and transportation, lighting trainings, track a shipment, verify completion of lighting in a given building, ship lamps and ballasts out of the village, request a labor reimbursement agreement, or invoice etc. Village expenses for phone charges, copying and fax costs, office supplies, etc. are part of this amount. Lodging - 1st assessment site visit 3/23- 24/2010 3 25 $ 75.00 3 nights at the school for Field Manager Dan Lung ($25/night) Transportation and fuel costs 1st assessment site-visit Lodging for ABSN Field Managers - 2nd site visit 3/15- 20/2010 11 25 $ 275.00 5 nights for Dan Lung, 2 nights for Geoff Butler and 4 nights for Anna Hilbruner-($25 ea. Per night) Transportation and fuel costs 2nd Visit 3/15- 20/2010 3 50 $ 150.00 Use of YKSD School truck to transport materials & staff $50/day Employer share of payroll contributions School Work on Lighting Upgrades 3/15- 20/2010 186.5 0 $15 $2,797.50 Byron Peters, Whitney Sam, Tanya Yatlin, Samatha Sam, Russell David, Elizabeth Peters TOTAL $5,798.00 The capacity of ABSN’s scope of work was greatly increased by the response of local communities to work in partnership with ABSN and provide in-kind services of project coordination, paid labor for lighting retrofits, transportation and lodging for ABSN field staff, and other valuable contributions. This allowed ABSN and the community of Huslia to deliver 12% more energy savings measures beyond the original grant funding. NREL Solar PV and Battery HOMER Feasibility Study and Summary Page 1 of 14 System Simulation Report Generated 11/25/2 System Simulation Report File: Nulato 02.homer Author: Tony Jimenez Location: PV9W+QQ Nulato, AK, USA (64°43.2'N, 158°6.2'W) Total Net Present Cost: $7,789,961.00 Levelized Cost of Energy ($/kWh): $0.490 Notes: Nulato (Applicable to Huslia) Fuel: $0.75/L ($2.84/Gal) & $1.10/L ($4.13/gal) PV Capacity: 350 kW Battery Capacity: 500 kWh Converter Capacity: 250 kW (Not the economic optimum, but covers the load for most hours) Sensitivity variable values for this simulation Variable Value Unit Diesel Fuel Price 1.10 $/L Page 2 of 14 System Simulation Report Generated 11/25/2 Table of Contents System Architecture .................................................................................................. 3 Cost Summary .......................................................................................................... 4 Cash Flow ................................................................................................................ 5 Electrical Summary .................................................................................................... 6 Generator: Generic-363 kW (Diesel) ............................................................................ 7 Generator: Generic-229 kW (Diesel) ............................................................................ 8 PV: Generic flat plate PV ............................................................................................ 9 Storage: Generic 100kWh Li-Ion ................................................................................. 10 Converter: System Converter ..................................................................................... 11 Fuel Summary ......................................................................................................... 12 Compare Economics .................................................................................................. 13 Page 3 of 14 System Simulation Report Generated 11/25/2 System Architecture Component Name Size Unit Generator #1 Generic-363 kW 363 kW Generator #2 Generic-229 kW 229 kW PV Generic flat plate PV 350 kW Storage Generic 100kWh Li-Ion 5 strings System converter System Converter 250 kW Dispatch strategy HOMER Cycle Charging Schematic Page 4 of 14 System Simulation Report Generated 11/25/2 Cost Summary Net Present Costs Name Capital Operating Replacement Salvage Resource Total Generic 100kWh Li-Ion $446,000 $140,511 $128,437 -$21,909 $0.00 $693,039 Generic flat plate PV $1.23M $110,267 $0.00 $0.00 $0.00 $1.34M Generic-229 kW $0.00 $354,618 $147,372 -$74,210 $3.48M $3.91M Generic-363 kW $0.00 $63.01 $0.00 -$114,650 $1,331 -$113,256 Other $0.00 $1.87M $0.00 $0.00 $0.00 $1.87M System Converter $55,000 $17,328 $23,165 -$5,256 $0.00 $90,237 System $1.73M $2.50M $298,975 -$216,025 $3.48M $7.79M Annualized Costs Name Capital Operating Replacement Salvage Resource Total Generic 100kWh Li-Ion $28,313 $8,920 $8,153 -$1,391 $0.00 $43,996 Generic flat plate PV $77,766 $7,000 $0.00 $0.00 $0.00 $84,766 Generic-229 kW $0.00 $22,512 $9,356 -$4,711 $221,068 $248,225 Generic-363 kW $0.00 $4.00 $0.00 -$7,278 $84.53 -$7,190 Other $0.00 $119,000 $0.00 $0.00 $0.00 $119,000 System Converter $3,492 $1,100 $1,471 -$333.67 $0.00 $5,728 System $109,571 $158,536 $18,980 -$13,714 $221,153 $494,525 -2,000,000 -1,000,000 0 1,000,000 2,000,000 3,000,000 4,000,000 System Converter Other Generic-363 kW Generic-229 kW Generic flat plate PV Generic 100kWh Li-Ion Page 5 of 14 System Simulation Report Generated 11/25/2 Cash Flow -2,400,000 -1,800,000 -1,200,000 -600,000 0 600,000 1,200,000 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Salvage Replacement Operating Fuel Capital -2,500,000 -2,000,000 -1,500,000 -1,000,000 -500,000 0 500,000 0 1 2 3 4 5 6 7 8 9 10111213141516171819202122232425 System Converter Other Generic-363 kW Generic-229 kW Generic flat plate PV Generic 100kWh Li-Ion Page 6 of 14 System Simulation Report Generated 11/25/2 Electrical Summary Excess and Unmet Quantity Value Units Excess Electricity 79,687 kWh/yr Unmet Electric Load 0 kWh/yr Capacity Shortage 0 kWh/yr Production Summary Component Production (kWh/yr) Percent Generic flat plate PV 359,859 32.4 Generic-363 kW 294 0.0265 Generic-229 kW 749,705 67.5 Total 1,109,857 100 Consumption Summary Component Consumption (kWh/yr) Percent AC Primary Load 1,008,385 100 DC Primary Load 0 0 Deferrable Load 0 0 Total 1,008,385 100 Page 7 of 14 System Simulation Report Generated 11/25/2 Generator: Generic-363 kW (Diesel) Generic-363 kW Electrical Summary Quantity Value Units Electrical Production 294 kWh/yr Mean Electrical Output 294 kW Minimum Electrical Output 294 kW Maximum Electrical Output 294 kW Generic-363 kW Fuel Summary Quantity Value Units Fuel Consumption 76.8 L Specific Fuel Consumption 0.261 L/kWh Fuel Energy Input 756 kWh/yr Mean Electrical Efficiency 38.9 % Generic-363 kW Statistics Quantity Value Units Hours of Operation 1.00 hrs/yr Number of Starts 1.00 starts/yr Operational Life 104,000 yr Capacity Factor 0.00925 % Fixed Generation Cost 12.5 $/hr Marginal Generation Cost 0.268 $/kWh Generic-363 kW Output (kW) 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hours Year 0 75 150 225 300 kW Page 8 of 14 System Simulation Report Generated 11/25/2 Generator: Generic-229 kW (Diesel) Generic-229 kW Electrical Summary Quantity Value Units Electrical Production 749,705 kWh/yr Mean Electrical Output 133 kW Minimum Electrical Output 60.4 kW Maximum Electrical Output 229 kW Generic-229 kW Fuel Summary Quantity Value Units Fuel Consumption 200,971 L Specific Fuel Consumption 0.268 L/kWh Fuel Energy Input 1,977,558 kWh/yr Mean Electrical Efficiency 37.9 % Generic-229 kW Statistics Quantity Value Units Hours of Operation 5,628 hrs/yr Number of Starts 610 starts/yr Operational Life 18.5 yr Capacity Factor 37.4 % Fixed Generation Cost 10.4 $/hr Marginal Generation Cost 0.268 $/kWh Generic-229 kW Output (kW) 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hours Year 0 62.5 125 187.5 250 kW Page 9 of 14 System Simulation Report Generated 11/25/2 PV: Generic flat plate PV Generic flat plate PV Electrical Summary Quantity Value Units Minimum Output 0 kW Maximum Output 362 kW PV Penetration 35.7 % Hours of Operation 4,380 hrs/yr Levelized Cost 0.236 $/kWh Generic flat plate PV Statistics Quantity Value Units Rated Capacity 350 kW Mean Output 41.1 kW Mean Output 986 kWh/d Capacity Factor 11.7 % Total Production 359,859 kWh/yr Generic flat plate PV Output (kW) 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hours Year 0 100 200 300 400 kW Page 10 of 14 System Simulation Report Generated 11/25/2 Storage: Generic 100kWh Li-Ion Generic 100kWh Li-Ion Properties Quantity Value Units Batteries 5.00 qty. String Size 1.00 batteries Strings in Parallel 5.00 strings Bus Voltage 600 V Generic 100kWh Li-Ion Result Data Quantity Value Units Average Energy Cost 0.238 $/kWh Energy In 110,236 kWh/yr Energy Out 99,212 kWh/yr Storage Depletion 0 kWh/yr Losses 11,024 kWh/yr Annual Throughput 104,579 kWh/yr Generic 100kWh Li-Ion Statistics Quantity Value Units Autonomy 3.47 hr Storage Wear Cost 0.157 $/kWh Nominal Capacity 500 kWh Usable Nominal Capacity 400 kWh Lifetime Throughput 1,500,000 kWh Expected Life 14.3 yr Generic 100kWh Li-Ion State of Charge (%) 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hours Year 20 40 60 80 100 % Page 11 of 14 System Simulation Report Generated 11/25/2 Converter: System Converter System Converter Electrical Summary Quantity Value Units Hours of Operation 1,833 hrs/yr Energy Out 94,251 kWh/yr Energy In 99,212 kWh/yr Losses 4,961 kWh/yr System Converter Statistics Quantity Value Units Capacity 250 kW Mean Output 10.8 kW Minimum Output 0 kW Maximum Output 149 kW Capacity Factor 4.30 % System Converter Inverter Output (kW) System Converter Rectifier Output (kW) 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hours Year 0 40 80 120 160 kW0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hours Year 0 62.5 125 187.5 250 kW Page 12 of 14 System Simulation Report Generated 11/25/2 Fuel Summary Diesel Consumption Statistics Quantity Value Units Total fuel consumed 201,048 L Avg fuel per day 551 L/day Avg fuel per hour 23.0 L/hour Diesel Consumption (L/hr) Emissions Pollutant Quantity Unit Carbon Dioxide 525,858 kg/yr Carbon Monoxide 3,577 kg/yr Unburned Hydrocarbons 145 kg/yr Particulate Matter 14.3 kg/yr Sulfur Dioxide 1,289 kg/yr Nitrogen Oxides 286 kg/yr 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hours Year 0 20 40 60 80 L/hr Page 13 of 14 System Simulation Report Generated 11/25/2 Compare Economics IRR (%):0.861 Discounted payback (yr):N/A Simple payback (yr):23.7 Base System Proposed System Net Present Cost $7.27M $7.79M CAPEX $0.00 $1.73M OPEX $461,510 $384,955 LCOE (per kWh) $0.458 $0.490 CO2 Emitted (kg/yr) 717,045 525,858 Fuel Consumption (L/yr) 274,144 201,048 Page 14 of 14 System Simulation Report Generated 11/25/2 Proposed Annual Nominal Cash Flows Base System Annual Nominal Cash Flows Cumulative Discounted Cash Flows -2,500,000 -2,000,000 -1,500,000 -1,000,000 -500,000 0 500,000 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Proposed System -1,500,000 -1,200,000 -900,000 -600,000 -300,000 0 300,000 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Base System -8100000-6750000-5400000-4050000-2700000-13500000 0 5 10 15 20 25 Cash Flow ($)year Base System Proposed System PREPARED BY: Tony Jimenez NREL Page 1 of 11 Microgrid Proposal PREPARED FOR: Tanana Chiefs Conference Nulato (Applicable to Huslia) PREPARED BY: Tony Jimenez NREL This proposal was generated using HOMER Pro, a dynamic software engine that runs complex simulations of your hybrid electrical system’s energy data and system components to determine the least-cost solution and most effective risk-mitigation strategies. Originally developed at the US Department of Energy’s National Renewable Energy Laboratory (NREL), HOMER software set the global standard for optimizing microgrid design. More than 200,000 HOMER Pro users worldwide have produced economic feasibility studies, system design, engineering insight, and energy cost savings. Table of Contents PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 2 of 11 Project Summary ..................................................................................... 3 About Your Company Name ................................................................... 4 Consumption Summary .......................................................................... 5 Engineering Details ................................................................................. 6 Cashflow Section .................................................................................... 9 Glossary and Abbreviations ................................................................. 10 HOMER Energy Section ........................................................................ 11 Project Summary PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 3 of 11 CURRENT SYSTEM The electric needs of Nulato (Applicable to Huslia) are met with 592 kW of generator capacity. Your operating costs for energy are currently $461,510 per year. PROPOSED SYSTEM We propose adding 350 kW of PV and 500 kWh of battery capacity. This would reduce your operating costs to $384,955/yr. Your investment has a payback of 23.7 years and an IRR of 0.861%. Simple payback: 23.7 yr Net Present Value: -$520,081 Return on Investment: 0.474 % Capital Investment: $1.73M Internal Rate of Return: 0.861 % Annualized Savings: $76,555 0 1350000 2700000 4050000 5400000 6750000 8100000 0 5 10 15 20 25Cash Flow ($)year Cumulative Cash Flow over Project Lifetime Current System Proposed System Your Company Name PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 4 of 11 ABOUT YOUR COMPANY NAME Use this section to introduce your company name and explain what your business does, where you operate (or the markets you serve), and how long you’ve been doing it for. About Us page is the ideal place to accommodate several objectives: • Communicate the story of your business and why you started it. • Describe the customers or the cause that your business serves. • Explain your business model or how your products are made Customer Testimonials Use this space to provide statements made about your company by satisfied customers. Quotes and positive comments are valuable to prospective clients as they evaluate their options and decide whether your company’s services provide the best solution to fit their needs. Testimonial statements demonstrate how others have benefited from your company’s services, making them a powerful tool for establishing trust and encouraging potential clients to take action. —John J. Client, CEO - Your Happy Client, Inc. Consumption Summary PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 5 of 11 Electric Consumption This microgrid requires 2766 kWh/day and has a peak of 294 kW. In the proposed system, the following generation sources serve the electrical load. 0 20 40 60 80 100 120 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov DecProduction (MWh)PV Gen363 Gen229 Engineering Details PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 6 of 11 PV: Generic flat plate PV The Generic PV system has a nominal capacity of 350 kW. The annual production is 359,859 kWh/yr. Rated Capacity 350 kW Total Production 359,859 kW Capital Cost $1.23M Maintenance Cost 7,000 $/yr Specific Yield 1,028 kWh/kW LCOE 0.236 $/kWh PV Penetration 35.7 % Generator: Generic-363 kW (Diesel) Power output from the Generic generator system, rated at 363 kW using Diesel as fuel, is 294 kWh/yr. Capacity 363 kW Generator Fuel Diesel Operational Life 104,000 yr Generator Fuel Price 0.750 $/L Maintenance Cost 4.00 $/yr Fuel Consumption 76.8 L Electrical Production 294 kWh/yr Hours of Operation 1.00 hrs/yr Marginal Generation Cost 0.268 $/kWh Fixed Generation Cost 12.5 $/hr 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hour of DayDay of Year 0 100 200 300 400 kW0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hour of DayDay of Year 0 75 150 225 300 kW Engineering Details PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 7 of 11 Generator: Generic-229 kW (Diesel) Power output from the Generic generator system, rated at 229 kW using Diesel as fuel, is 749,705 kWh/yr. Capacity 229 kW Generator Fuel Diesel Operational Life 18.5 yr Generator Fuel Price 0.750 $/L Maintenance Cost 22,512 $/yr Fuel Consumption 200,971 L Electrical Production 749,705 kWh/yr Hours of Operation 5,628 hrs/yr Marginal Generation Cost 0.268 $/kWh Fixed Generation Cost 10.4 $/hr Storage: Generic 100kWh Li-Ion The Generic storage system's nominal capacity is 500 kWh. The annual throughput is 104,579 kWh/yr. Rated Capacity 500 kWh Expected Life 14.3 yr Annual Throughput 104,579 kWh/yr Capital Costs $446,000 Maintenance Cost 8,920 $/yr Losses 11,024 kWh/yr Autonomy 3.47 hr Converter: System Converter 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hour of DayDay of Year 0 62.5 125 187.5 250 kW0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hour of DayDay of Year 20 40 60 80 100 % Engineering Details PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 8 of 11 Capacity 250 kW Hours of Operation 1,833 hrs/yr Mean Output 10.8 kW Energy Out 94,251 kWh/yr Minimum Output 0 kW Energy In 99,212 kWh/yr Maximum Output 149 kW Losses 4,961 kWh/yr Capacity Factor 4.30 % 0 6 12 18 24 0 30 60 90 120 150 180 210 240 270 300 330 360Hour of DayDay of Year 0 40 80 120 160 kW Cash Flows PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 9 of 11 Project Lifetime 25 years Expected Inflation Rate 2.0% Nominal Discount Rate 6.0% Real Interest Rate 3.9% Year 1 2 3 4 5 6 7 8 9 10 Generic 100kWh Li-Ion ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) Generic flat plate PV ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) Generic-229 kW ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) Generic-363 kW ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) Other ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) System Converter ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) Year 11 12 13 14 15 16 17 18 19 20 Generic 100kWh Li-Ion ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) Generic flat plate PV ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) Generic-229 kW ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) Generic-363 kW ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) Other ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) System Converter ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) Year 21 22 23 24 25 Generic 100kWh Li-Ion ($8,920) ($8,920) ($8,920) ($8,920) ($8,920) Generic flat plate PV ($7,000) ($7,000) ($7,000) ($7,000) ($7,000) Generic-229 kW ($22,512) ($22,512) ($22,512) ($22,512) ($22,512) Generic-363 kW ($4.00) ($4.00) ($4.00) ($4.00) ($4.00) Other ($119,000) ($119,000) ($119,000) ($119,000) ($119,000) System Converter ($1,100) ($1,100) ($1,100) ($1,100) ($1,100) Glossary and Abbreviations PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 10 of 11 Net Present Value The total net present cost (NPC) of a system is the present value of all the costs the system incurs over its lifetime, minus the present value of all the revenue it earns over its lifetime. Costs include capital costs, replacement costs, O & M costs, fuel costs, emissions penalties, and the costs of buying power from the grid. Revenues include salvage value and grid sales revenue. HOMER calculates the total NPC by summing the total discounted cash flows in each year of the project lifetime. Total Annualized Cost - is the annualized value of the total net present cost. The annualized cost of a component is the cost that, if it were to occur equally in every year of the project lifetime, would give the same net present cost as the actual cash flow sequence associated with that component. HOMER calculates annualized cost by first calculating the net present cost, then multiplying it by the capital recovery factor. Simple payback - is the number of years at which the cumulative cash flow of the difference between the current system and base case system switches from negative to positive. The payback is an indication of how long it would take to recover the difference in investment costs between the current system and the base case system. Return on Investment (ROI) - is the yearly cost savings relative to the initial investment. The ROI is the average yearly difference in nominal cash flows over the project lifetime, divided by the difference in capital cost. Internal rate of return (IRR) - is the discount rate at which the base case and current system have the same net present cost. HOMER calculates the IRR by determining the discount rate that makes the present value of the difference of the two cash flow sequences equal to zero. Refer to HOMER Pro Online Help Manual Abbreviations Gen363 Generic-363 kW Gen229 Generic-229 kW BESS 100 Generic 100kWh Li-Ion PV Generic flat plate PV Converter System Converter HOMER Energy PREPARED BY: Your Name, Your Title, Your Company Name, Your Email, Your Phone Number Page 11 of 11 About HOMER Pro HOMER® Pro simulates engineering and economic feasibility of microgrid or distributed energy systems that are off-grid or tied to an unreliable grid and enables the design of least- cost electrical systems and risk-mitigation strategies. The software provides insight into cost-effectively combining conventional and renewable energy, storage, grid resources (where available), and load management. In a single data run, HOMER Pro simulates the operation of a hybrid microgrid or distributed energy system for an entire year, evaluating and optimizing the electrical system design, load profiles, components, fuel costs, and environmental variables. The simulation produces key information on technical performance, risk-mitigation, and projected cost-savings to inform system design and optimization. Results are presented in a succinct Microgrid Proposal. For more information, visit HomerEnergy.com. About HOMER Energy by UL HOMER software is used by more than 200,000 users in 193 different countries. HOMER Energy by UL is the developer and distributor of HOMER software, a global standard for energy modeling tools that analyze solar-plus-storage, microgrids, and other distributed energy projects. HOMER software helps engineers and project developers navigate the complexities of designing cost-effective and reliable microgrids that combine traditional and renewable generation sources. The company makes two software platforms: HOMER Pro for the design of least-cost hybrid microgrid or distributed energy systems for use off-grid or when tied to an unreliable grid; and HOMER Grid, which helps design behind-the-meter solar- plus-storage systems to reduce costs and lower carbon footprints. Since its founding in Boulder, Colorado in 2009, HOMER Energy software has proven effective for analyzing complex distributed energy systems, including grid-tied hybrid renewable microgrids and situations where the grid is insufficiently reliable, such as islands and remote communities. In 2019, HOMER Energy was acquired by UL. More than 200,000 HOMER Pro users in over 190 countries have produced economic feasibility studies, system design, engineering insight, and energy cost savings. Learn more at www.homerenergy.com. Titan Solar Racking Quote # 20-345 County Road X, PO Box 224 Ridgeville Corners, OH 43555 Office: 419.267.5280 www.apasolar.com PROJECT SUMMARY Project Details Customer Quote Project Name: Huslia Solar PV Address:- Date: 11/10/2022 Number: 000000000 Company: TCC Attention: Dave Messier APA Contact:Cara Von Deylen Revision:7City: Huslia State: AK Phone:Cell:(937) 545-6707 Lead Time:Est. 12 Weeks Zip:-Email:carav@apasolar.com System Details Module:Canadian Solar Array Tilt:35°Quoted System:Titan Duo 4-Rail Wind Speed:136 mph Panel Orientation:2 High in Portrait Snow Load:79 psf Quoted Foundation:Ground Screw Front Lip Height:36'' Type:72 Cell (93.9" x 51.3") Module Quantity: Wattage:650 System Size (DC):,00 Wage Requirement:Non-prevailing Rows: Quoted Length:120'' Max Quoted Size:3'' Estimated Count: HARDWARE Price Price / Mod Price / Watt Foundation Hardware $13,110.25 $24.37 $0.0375 Required Racking Hardware $83,608.02 $155.40 $0.239 Required Subtotal $96,718.28 $179.77 $0.2765 SERVICES Packaging and Handling $2,252.07 $4.186 $0..00644 Optional Engineering Documents (AK) PE Stamp $5,388.88 $10.01 $0.0154 Optional Subtotal $7,640.945 $14.2 $0.02185 Total $104,359.2 $193.97 $0.2984 V1.771.21.251.330.382512266849818 Page:1 Ground Screws are not included in the quote. Option A Rate: $100 per normal obstruction Option B Rate: Provided by APA as a line item on your quote. Option C Rate: Time and Material Quote is based on APA's 4-rail TITAN Duo system. APA's project manager will communicate refusals with the contractor to determine the best method to mitigate costs Option B - Pre-Drill 100% of Site - Pre Drill all Foundation locations onsite. Option B is generally recommended for sites with high rock content - APA will confirm if this option is recommended during Foundation testing. Foundation Refusal Options - Options only if needed - APA will cover 1% of the normal obstructions already included in Foundation install pricing above Option A - Normal Obstructions - Remove Foundation Auger through obstruction, Install new Foundation. Normal obstructions are obstructions that can be remediated with standard equipment APA has onsite (Rock Auger). Option A is generally recommended on sites with low to medium rock content where we may hit up to 20% refusals. Option C - Abnormal refusals-Obstructions, such as large boulders, bedrock, commercial debris or rubble, as well as soft-spot conditions will be subject to time and material charges to the customer including a rock drill mobilization fee and will be remediated based on the engineering specified refusal method. Maddox Transformer Quote Prices valid for 10 days. Subject to prior sale. Payment terms offered on this quote are contingent on an established account in good standing. SALES TAXES, if applicable, may be added unless an exemption certificate is provided with purchase order. Enclosed photos may not represent finished product. Made-to-Order units are not refundable. Maddox Industrial Transformer’s Standard Terms & Conditions apply, see details at: www.maddoxtransformer.com/documents It is the buyer’s responsibility to verify conformity to any and all customer-provided specifications or bid documents. Exceptions and clarifications provided by MIT are not confirmations of conformity to any written, or verbally communicated specifications. #Description Count Price Amount 1 General Purpose Dry-Type Transformer New 500 kVA 3-Ph Dry-Type Transformer High Voltage: 480 D, 10 kV BIL Low Voltage: 480 Y 277, 10 kV BIL Frequency: 60 Hz Temperature Rise: 150℃ Cooling Class: AA Conductor: Al / Al Enclosure: Indoor NEMA 3R Dimensions: 64" x 49" x 39" (H x W x D), approx.. 2800 Lbs. Shipping: Freight allowed to Colorado Warranty: 5 Years Lead-time: 12 - 16 weeks until shipping 1 $20,678.00 $20,678.00 Additional Items #Description Amount 1 Freight $2,400.00 Quote Lines Additional Cost Total Quote Before Tax $20,678.00 Before Tax $2,400.00 Before Tax $23,078.00 Tax $1,060.78 Tax $119.64 Tax $1,180.42 Total $21,738.78 Total $2,519.64 Total $24,258.42 Notes: Pricing is based on the quantities above. Price to be reviewed if partial order is placed. Price Adjustment Clause: To accommodate potential material cost adjustments, Maddox may reprice the quoted units each (3) months after the order is released. In such price change event, Buyer shall have the option to either accept the price change, or cancel any portion of the order on which the price has changed. Quote # SO-75168 10/13/2022 Quote To: Tanana Chiefs Conference 122 1st Ave Fairbanks, AK 99701 United States Pay Terms: With order - credit card Contact Your Sales Rep Nikko Pliego Phone: 208-306-3691 Email: nikko@maddoxtransformer.com Ship To: 5735 Arapahoe Avenue unit c Boulder Colorado 80303 United States EPC Power Quote Quotation # SO001854 Bill To: Dave Messier Tanana Chiefs Conference 122 1st Ave Suite 600 Fairbanks, AK 99701 United States  +1 907-687-2296 Ship To: Kronus Engineering 5735 Arapahoe Ave Unit C Boulder CO 80030 United States Customer Contact: Dave Messier Salesperson: Ty Keefe ty.keefe@epcpower.com Quote Authorized By: Allan J Abela, COO & EVP Quote Date: 10/31/2022 Expiration Date: 30 Days Project Ref: TCC - PD250 10/31/2022 EPC Ref: TCC- PD250 10/31/2022 Payment Terms: 50% Dep. Bal. on Ready to Ship Ship Via: Best Way Shipping Terms: FCA - Poway Note: All lead times subject to ARO & deposit. Line Part Number Description Expctd Ship Date Quantity Unit Price Total Price Delivery Lead Time Products 1 50-100118 Power Drawer Cabinet (1600mm tall) Options: +AUXCB1, +UPS1, +COOLANT, +50-100195, +GND FAULT, +GFD FUSE 1.00 Unit 67,450.00 $ 67,450.00 2 50- 100115_06 [50-100115_06] Assy, PD Cooling System (REMOTE) Options: ARCTIC 1.00 Unit 5,500.00 $ 5,500.00 Subtotal $ 72,950.00 Shipping 3 FCA-Poway Shipping terms are FCA. Client takes delivery of all products at EPC dock in Poway, CA. Client arranges for shipping. 1.00 Unit 0.00 $ 0.00 Subtotal $ 0.00 Handling 4 H&C Handling & Crating 1.00 Unit 1,500.00 $ 1,500.00 Subtotal $ 1,500.00 Subtotal $ 74,450.00 Taxes $ 0.00 Total $ 74,450.00 EPC Power Corp. 13250 Gregg Street Suite A-2 Poway CA 92064 United States  +1 858-748-5590 orders@epcpower.com  http://www.epcpower.com  EIN: 27-2568879 Duns #: 96-257-0003 Cage Code: 6L8W6 BBB: Accredited (A+) ISO 9001:2015 Page 1 of 2 Important! All orders accepted by EPC Power Corp. are subject to our standard terms and conditions attached to this quote / order confirmation. If not attached, the standard terms and conditions are available at www.epcpower.com/terms. Any terms and conditions proposed by customer, whether in customer's purchase order or otherwise (whether additional or different, and whether or not such terms alter the above referenced terms and conditions) will be excluded from EPC's and customer's contract. EPC Power Corp. standard limited warranty is available at www.epcpower.com/warranty. NOTE: Prices are subject to change as determined by engineering requirements. INVOICE MILESTONES: 50% On Order 50% On Notification of Ready to Ship PAYMENT TERMS: Net 30 Days NOTE: All deposits are nonrefundable. All deposits are nonrefundable. EPC Power Corp. 13250 Gregg Street Suite A-2 Poway CA 92064 United States  +1 858-748-5590 orders@epcpower.com  http://www.epcpower.com  EIN: 27-2568879 Duns #: 96-257-0003 Cage Code: 6L8W6 BBB: Accredited (A+) ISO 9001:2015 Page 2 of 2 CED Greentech Quote DATE: TANANA CHIEFS CONFERENCE 201 1ST AVE SUITE 124 FAIRBANKS, AK 99701 TEL: (907) 452-8251 PAGE:SLS: INSLS: BY: FOB: FRT: CUS PO #: JOB NAME: QUOTE #: SHIPPING POINT PREPAID XS-66498 CED GREENTECH - PDX 5300 SE JOHNSON CREEK BLVD MILWAUKIE OR 97222 TEL: 971 444-0221 FAX: 971 386-1088 QUOTE FOR: QUOTE EXPIRES CONTACT: REV #: REV DATE: 000 ACCT #: 001 001OF TANANA CHIEFS CONFERENCE HUSLIA AL 5322 5302 1012362 10/25/22 10/25/22 ALEX LYNCH TANANA CHIEFS CONFERENCE CED GREENTECH - PDX QTY MFR CATALOG #/DESCRIPTION PRICE UOM EXT AMTLN 01 390.00558 CASOL CS7N-650MB-AG 217,620.00E650W BIFACIAL MONO COMMERICAL 217,620.00 MDSE: TAX: TOTAL: 0.00 217,620.00 CUSTOMER COPY PLEASE NOTE: THIS IS NOT AN OFFER TO CONTRACT, BUT MERELY A QUOTATION OF CURRENT PRICES FOR YOUR CONVENIENCE AND INFORMATION. ORDERS BASED ON THIS QUOTATION ARE SUBJECT TO YOUR ACCEPTANCE OF THE TERMS AND CONDITIONS LOCATED AT SALES.OUR-TERMS.COM, WHICH WE MAY CHANGE FROM TIME TO TIME WITHOUT PRIOR NOTICE. WE MAKE NO REPRESENTATION WITH RESPECT TO COMPLIANCE WITH JOB SPECIFICATIONS. DATE: Tanana Chiefs Conference 122 1st Ave Suite 600 Fairbanks, AK 99701 TEL: (907) 452-8251 PAGE:SLS: INSLS: BY: FOB: FRT: CUS PO #: JOB NAME: QUOTE #: SHIPPING POINT PREPAID XS-66498 CED GREENTECH - PDX 5300 SE JOHNSON CREEK BLVD MILWAUKIE OR 97222 TEL: 971 444-0221 FAX: 971 386-1088 QUOTE FOR: QUOTE EXPIRES CONTACT: REV #: REV DATE: 000 ACCT #: 001 001OF TANANA CHIEFS CONFERENCE AL 5322 5302 1012363 10/25/22 10/25/22 ALEX LYNCH TANANA CHIEFS CONFERENCE CED GREENTECH - PDX 11/24/2022 QTY MFR CATALOG #/DESCRIPTION PRICE UOM EXT AMTLN 01 10,271.553-125-1500-2-203 SMA 30,814.65EHIGHPOWER 125KVA SHP125-US-20 30,814.65 MDSE: TAX: TOTAL: 0.00 30,814.65 CUSTOMER COPY PLEASE NOTE: THIS IS NOT AN OFFER TO CONTRACT, BUT MERELY A QUOTATION OF CURRENT PRICES FOR YOUR CONVENIENCE AND INFORMATION. ORDERS BASED ON THIS QUOTATION ARE SUBJECT TO YOUR ACCEPTANCE OF THE TERMS AND CONDITIONS LOCATED AT SALES.OUR-TERMS.COM, WHICH WE MAY CHANGE FROM TIME TO TIME WITHOUT PRIOR NOTICE. WE MAKE NO REPRESENTATION WITH RESPECT TO COMPLIANCE WITH JOB SPECIFICATIONS. AGETO Cut Sheet for Microcontrollers turnkey control systems off-grid and behind-the-meter energy resource agnostic system sizing and analysis energy storage optimization making renewable energy simple www.agetoenergy.com +1 833 247 0365 sales@agetoenergy.com Ageto Renewable Controller (ARC) ●Energy Resource Agnostic ●Utility Rate Optimization ●Resilient Islanding ●Load Management ●Real-time Control ●User-level Authentication ●Web Dashboard ●Secure VPN Connection ●Historian and Trending ●Data Reporting ●Alarm Management ●SMS/Email Notifications ™ ARC is a simple, intuitive, and operator-focused microgrid control solution for both off-grid and behind-the-meter power systems. ARC maximizes clean, renewable energy by seamlessly integrating and optimizing the conventional and renewable energy resources in the microgrid. ARC performs under the most demanding conditions and applications where power reliability is critical. ARC provides real-time control to ensure system stability and resiliency, and is designed around the operator with an intuitive and straightforward user interface. In grid connected systems, ARC optimizes around utility tariffs and grid interconnect requirements. Project Reference Sandbar Solar's new office facility was built on an empty lot in Santa Cruz, CA as an entirely off-grid microgrid. Ageto performed system analysis to determine the optimal solar, battery, and generator size to minimize operating costs while meeting the generator run time limits specified by the city. ARC provides the primary user interface, real-time controls, and system monitoring to maximize the renewable energy usage while utilizing the backup generator as necessary. ARC has delivered over 93% renewable energy and has operated for over 45 days straight on 100% renewable power. The off-grid microgrid is providing cleaner, cheaper, and more reliable power than the local utility.