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HomeMy WebLinkAboutAPPLICATION - REF Round 15 Application - Augustine Island Geothermal FinalRenewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 1 of 32 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) Alaska Electric & Energy Cooperative, Inc. Tax ID # 92-0177236 Date of last financial statement audit: December 31, 2021 Mailing Address: Physical Address: 3977 Lake Street, Homer, AK 99603 Same Telephone: Fax: Email: 907-283-2375 msalzetti@homerelectric.com 1.1 Applicant Point of Contact / Grants Coordinator Name: Mike Salzetti Title: Manager of Renewable Energy Development Mailing Address: 3977 Lake Street, Homer, AK 99603 Telephone: Fax: Email: 907-283-2375 msalzetti@homerelectric.com 1.1.1 Applicant Signatory Authority Contact Information Name: Bradley P. Janorschke Title: General Manager Mailing Address: 3977 Lake Street, Homer, AK 99603 Telephone: Fax: Email: 907-283-2312 907-283-7122 bjanorschke@homerelectric.com 1.1.2 Applicant Alternate Points of Contact Name Telephone: Fax: Email: David Thomas 907-283-2364 dthomas@homerelectric.com Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 2 of 32 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 # 640 , or ☐ An independent power producer in accordance with 3 AAC 107.695 (a) (1) CPCN #______, or ☐ 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) Beneficiaries will be the Homer Electric Association’s member-owners, however the ownership model of a project (AEEC, GeoAlaska, or another IPP) will be determined in a future phase, based on available of federal tax incentives, grants, financing costs, project economics, and operations & maintenance considerations. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 3 of 32 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. Augustine Island Geothermal 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 59.342333 Longitude -153.433333 This phase of the proposed project is a feasibility effort to develop economic costs of interconnecting a new geothermal power generation plant to the Railbelt transmission grid. 2.2.2 Community benefiting – Name(s) of the community or communities that will be the beneficiaries of the project. The member-owners of Homer Electric Association will benefit from these grant funds. Homer Electric’s certificated territory encompasses a vast majority of the population and communities on the Kenai Peninsula and essentially all the populated portions of the central and western Kenai Peninsula including the incorporated cities of Kenai, Soldotna, and Homer and the villages/communities of Nikiski, Salamatof, Sterling, Kasilof, Clam Gulch, Ninilchik, Anchor Point, Kachemak City, Halibut Cove, Seldovia, Port Graham and Nanwalek. Depending on the eventual size of the final geothermal project, other entities, such as other Railbelt Electric Cooperatives might also opt to receive energy from the project. 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) Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 4 of 32 10/04/2022 Pre-Construction Construction ☐ Reconnaissance ☐ Final Design and Permitting ☒ Feasibility and Conceptual Design ☐ Construction 2.4 Project Description Provide a brief, one-paragraph description of the proposed project. Homer Electric Association, Inc. (HEA) through its generation subsidiary Alaska Electric & Energy Cooperative, Inc. (AEEC), plans to study the interconnection of approximately 70-MWs of geothermal energy generation located on Augustine Island. The proposed effort will evaluate the preferred method of bringing power onshore to AEEC’s existing 115,000-volt transmission lines along the western shore of the Kenai Peninsula in the vicinity of Anchor Point, Alaska. The proposed project is a feasibility level effort to develop costs of sufficient accuracy to assess project economics. 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. This funding request is for a feasibility-level effort to assess the interconnection of a proposed geothermal prospect currently being pursued by GeoAlaska, LLC but would be applicable to any similar such project on Augustine Island. The Scope of Work will include: Phase 2 – Feasibility Scope of Work: 1. Preliminary Engineering Analysis a. Electrical engineering consultants with experience on the Railbelt grid or the ability to analyze the grid, will be retained to assess the most economic method of bringing power ashore. b. Approximately routing of an undersea cable will be developed as an input to cable specifications, depths, installation costs and permitting requirements. c. DC conversion stations on each end (or reactive elements to correct capacitance effects) will be specified, and costs estimates developed for their acquisition, installation and commissioning. d. A conceptual-level design will be developed e. The result of the engineering analysis will be compiled and presented in the Feasibility Report. 2. Project Costs and Economic Evaluation a. Budgetary quotes for appropriately sized grid interconnections, step-up/step-down transformers and/or AC/DC conversion stations will be obtained. b. A projected project cost estimate will be completed. c. An investigation of possible financial incentives such as Investment Tax Credits, Production Tax Credits, grants or loan programs will be completed. d. Evaluation of financing options and available interest rates. e. Analysis of possible ownership scenarios. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 5 of 32 10/04/2022 f. The results of the cost and economic analyses will be provided in the final Feasibility Report along with an overall simple economic analysis of the project. 3. Energy System Modeling a. The proposed geothermal generation will be added to HEA’s existing power production model(s). b. Several model iterations will be run at anticipated capacity factors and power levels at various costs to assist in establishing project economic thresholds. c. The modeling results will be incorporated into the final Feasibility Report. d. The model will predict natural gas fuel displacement associated with the proposed project. e. The model will optimize existing HEA generation, optimally dispatch HEA’s Battery Energy Storage System (BESS) to establish system project economic thresholds and impacts to the balance of the system. 4. Permitting and Licensing Evaluation a. Investigate land leasing requirements for the route of the proposed undersea cable. b. Interface with government agencies such as the U.S. Coast Guard, NOAA and others to establish a preliminary list of permitting requirements. c. The final Feasibility Report will present the findings of this evaluation. 5. Environmental Screening a. A screening will be conducted to identify potential environmental impacts that the proposed project may have as a result of installing undersea cables. b. The results of the screening and any environmental barriers will be compiled and presented in the Feasibility Report. 6. Analysis and Recommendations a. As noted previously, the information, analysis, and modeling results from this scope of work will be compiled and presented in the Feasibility Report. b. The final Report will include a recommendation on whether to continue the pursuit of this project and if so, what the recommended next steps should be. 2.6 Previous REF Applications for the Project See Section 1.15 of the RFA for the maximum per project cumulative grant award amount Round Submitted Title of application Application #, if known Did you receive a grant? Y/N Amount of REF grant awarded ($) NA Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 6 of 32 10/04/2022 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 P2-all Contractor Solicitation Develop and issue RFPs for consulting services and award contracts 9/23 12/23 Contracts Awarded P2-1 Preliminary Engineering Analysis Gather data and develop conceptual design. 1/24 2/24 Conceptual Design portion of Feasibility Report P2-2 Project Costs and Economics Develop project costs and assessing project financing and tax incentives. 2/24 4/24 Economic Analysis portion of Feasibility Report P2-3 Energy System Modeling Energy System Modeling per Scope of Work 2/24 5/24 Model Results P2-4 Permitting and Licensing Evaluation Permitting and Licensing Evaluation per Scope of Work 1/24 5/24 Permitting and Licensing Evaluation P2-5 Environmental Screening Environmental Screening per Scope of Work 1/24 4/24 Preliminary Screening Results P2-6 Final Reconnaissance Report Final Reconnaissance Report per Scope of Work 5/24 7/24 Final Feasibility Report 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 $68,000 Cash match to be provideda $15,200 In-kind match to be provideda $26,940 Energy efficiency match provided $0 Total costs for project phase(s) covered in application (sum of above) $110,140 Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 7 of 32 10/04/2022 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. HEA’s generation subsidiary’s (AEEC’s) Board of Directors has passed Resolution 01.2022.13, “Grant Funding Authorization for a Geothermal Project located on the West Side of Cook Inlet.” which is attached. Also attached is a certification by the AEEC General Manager, Bradley P. Janorschke, that the Cooperative will honor the match amounts and is in a financial condition to do so. Both documents are included as Attachment C. an 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. HEA/AEEC would cover any cost overruns required to complete the Scope of Work described in Section 2.5 of this grant application. 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] $0 Feasibility and Conceptual Design [Actual/Estimated] $110,140 Final Design and Permitting [Actual/Estimated] $9,600,000 Construction [Actual/Estimated] $167,500,000 Total Project Costs (sum of above) Estimated $177,210,140 Metering/Tracking Equipment [not included in project cost] Estimated $ Note that AEEC estimates the construction cost to be $335,000,000. With the passage of the Inflation Reduction Act (IRA), that provides for direct pay of Investment Tax Credits (ITC) to non- profit entities such as AEEC, we believe that the project qualifies for a 50% ITC. We therefore estimate our construction costs for this project to be $167,500,000 and have entered that value as the Construction 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) Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 8 of 32 10/04/2022 Ownership of the electrical interconnection from any geothermal project to the existing transmission grid has not been determined. Should HEA/AEEC determine AEEC ownership is to HEA’s members’ advantage, the following funding sources would be sought for the Balance of the Design phase AEEC would seek future grant opportunities, explore partnership potentials and / or self fund this phase of the work. For design and construction phases, AEEC would seek applicable state or federal grant and funding opportunities. HEA/AEEC is working with McAllister & Quinn and Strategies 360 to identify and pursue federal funding opportunities to implement all of HEA’s renewable energy goals. HEA/AEEC is also working with McAllister & Quinn and Strategies 360 on gaining an understanding of the direct pay ITCs made possible by the IRA. As noted above AEEC believes that it will qualify for a 50% ITC for this project. HEA/AEEC would examine current interest rates and loan terms from its two primary lenders National Rural Utilities Cooperative Finance Corporation (CFC) – a not-for-profit lender set up by its member electrical utilities and the USDA Rural Utilities Service (RUS). AEEC would also contact the Alaska Industrial Development and Export Authority (AIDEA) to explore other financing options and opportunities through that organization. Renewable Energy Certificates would be obtained for all energy eventually put onto the grid (as CEA already does with Fire Island wind energy) and monetized, although that has historically yielded less than $1/MWh. Should a mandatory Renewable Portfolio Standard (RPS) be enacted in Alaska, HEA would diligently monetize any excess RECs (beyond HEA’s own statutory requirements) for resale to other utilities at rates of potentially $10-20/MWh which is a significant portion of the energy cost. HEA/AEEC has been successful in the past in obtaining grant funding and securing attractive financing terms for its capital projects and anticipates it will continue to do so for future projects. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 9 of 32 10/04/2022 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. 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 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) $ $ $ Contractor Solicitation 12/23 $0 $2,500 In-Kind $2500 Preliminary Engineering Analysis 2/24 $22,300 $5,900 Cash&In-Kind $28,200 Project Cost and Economic Evaluation 4/24 $32,500 $9,550 Cash&In-Kind $42,050 Energy System Modeling 5/24 $0 $7,240 In-Kind $7,240 Permitting and Licensing Evaluation 5/24 $6,800 $5,225 Cash&In-Kind $12,025 Environmental Screening 4/24 $3,400 $3,700 Cash&In-Kind $7,100 Final Reconnaissance Report 7/24 $3,000 $8,025 Cash&In-Kind $11,025 TOTALS $68,000 $50,565 $110,140 Budget Categories: Direct Labor & Benefits $0 $26,940 In-Kind $26,940 Travel & Per Diem $0 $0 $0 Equipment $0 $0 $0 Materials & Supplies $0 $0 $0 Contractual Services $68,000 $15,200 Cash $83,200 Construction Services $0 $0 $0 Other $0 $0 $0 TOTALS $68,000 $42,140 $110,140 Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 10 of 32 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. This is a Feasibility Study proposed to develop more refined costs, so the cost estimates are preliminary at this point. Part of the proposed work scope is the development of a high-level project cost estimate. The cost estimates do incorporate verbal estimates from potential consultants as well as the team’s experience in project development and knowledge of prudent industry practices. Costs for the generation assets themselves come from GeoAlaska materials prepared for their investors. 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? The Project Manager will conduct regularly scheduled meetings with the contractors providing the feasibility work for this Project to track progress, schedule, and budget. Project management and financial control will issue reports to AEA on a mutually agreeable schedule throughout the life of the grant. These reports can be customized to meet AEA needs. 3.3.2 Financial Reporting 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. HEA has a dedicated financial controller. Ms. Clymer, HEA’s Controller has acted as financial control for several other AEA awarded grants. HEA uses Southeastern Data Corporation (SEDC) for our financial services software to assist with accounting and financial control systems. Every year, HEA’s and AEEC’s financial statements and accounting procedures are audited by an outside firm (which in recent years has been BDO USA, Inc). Financial control of the project will be done at no cost to the project, and it is not included or claimed in any of the in-kind matching labor funds outlined in this grant application. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 11 of 32 10/04/2022 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. HEA’s Manager of Renewable Energy Development, Mike Salzetti, will be the Project Manager for this Project. He has 32 years of engineering experience with 22 of those years including Project Management responsibilities. Mr. Salzetti’s contact information in shown in Section 1.1 of this application and his professional qualifications are included in Attachment A. 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. Katheryn Parke, HEA’s Plant Accounting Supervisor will be performing the accounting for this Project. Accounting work for the project will be done at no cost to the project, and it is not included or claimed in any of the in-kind matching labor funds outlined in this grant application. 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 in 3.1 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. HEA’s Manager of Renewable Energy Development, Mike Salzetti, will be the Project Manager for this Project. Mike has over 32 years of engineering experience with 22 of those years including Project Management responsibilities. Mr. Salzetti played an integral role in the design of Homer Electric’s new generation facilities and successfully shepherded the Grant Lake Hydroelectric Project through an original FERC licensing process. Mr. Salzetti has the guidance, support, staffing, and resources of Homer Electric Association to support him in all phases of this project. The professional biographies of HEA’s Executive Management Team are included as part of Attachment A to this application. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 12 of 32 10/04/2022 HEA is working with GeoAlaska on this project who has obtained permits for the geothermal resource on Augustine Island associated with this Project study. GeoAlaska’s experience in assessing such prospects have provided a basis for the preliminary estimates of project size and cost. 4.2 Local Workforce Describe how the project will use local labor or train a local labor workforce. HEA Management Directives governing contracting and procurement include considerations for such things as material procurement from pre-qualified businesses operating on the Kenai Peninsula, possession of an Alaska Business license, maintenance of an office and staff within Alaska and advertisements in general circulation publications as defined by Alaska State Statutes that promote local contracting and procurement. Pursuit to Board Policy 401 – Contracting and Purchasing, Section II, part H, HEA and AEEC give a 5% preference to vendors maintaining an office or place of business in the cooperative’s service area (unless prohibited by statute, regulation or grant). Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 13 of 32 10/04/2022 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. AEEC plans to assess the interconnection of approximately 70-MWs of geothermal energy generation located on Augustine Island. The proposed project would consist of two modular plants of 35 MW each located on the southern end of Augustine Island and electrically interconnected to the HEA/AEEC’s transmission system near Anchor Point, Alaska. This grant application is to develop refined costs for the interconnection of this geothermal prospect to HEA’s system and the Railbelt. The resulting public Feasibility Report can be used by any party – IPPs or energy off-takers such as Railbelt Electric Cooperatives to more quickly and accurate assess the economics of this project and similar such projects, but also related work such as off-shore wind, or redundant transmission off the Kenai Peninsula across Cook Inlet through a DC transmission line. We believe that these conceptual designs and cost estimates would meaningfully add to the State’s body of knowledge for future renewable energy projects. 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. Homer Electric Association’s Board of Directors has developed a Board Policy (505 - Renewable Portfolio Goal) that states, “It is the policy of the Cooperative to use best efforts to meet a renewable portfolio goal of 50% of its annual energy needs by the end of 2025.” HEA staff is in the Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 14 of 32 10/04/2022 process of analyzing and developing a suite of firm and non-firm renewable energy projects to meet this goal. It is anticipated that a mix of renewable energy projects will be needed to cost effectively achieve this goal. HEA is evaluating and in some cases actively pursuing additional hydro, wind, solar, landfill gas, tidal, and geothermal resources. Augustine Island Geothermal Project Pros: 1. It is forecast to provide an excellent capacity factor in excess of 90% and as such can be used as base-loaded energy. 2. Compared to non-firm renewables wind and solar with much lower capacity factors, the integration costs of base-loaded power are much lower (and will be assessed further in Phase 2-3). 3. An anticipated cost of energy comparable to the cost of avoided gas consumption. 4. There exist in Cook Inlet significant industrial support for the offshore oil & gas industry which may reduce the “Alaska factor” involved in many energy projects. 5. AEEC already possesses a BESS which can and already does function as spinning reserves for other generation assets with no additional fuel use or cost. 6. The project is likely to qualify for a 50% ITC 7. As a not-for-profit entity, should HEA opt to build any portions of the interconnection, HEA has the following advantages over an IPP executing a similar project: a. No profit margin required b. Access to lower financing rates c. No property taxes d. Access to an existing work force and remote dispatch system This project would be beneficial for HEA owner-members, citizens of the Kenai Peninsula Borough, and the environment. Augustine Island Geothermal Project Cons: 1. While above-grade geothermal equipment is an increasingly known technology, used throughout the world, the particulars of the underground resources is unique to its location and requires careful study, design and robust construction. 2. Any remote, offshore work is more expensive than onshore. 3. The project will connect to generation in an active volcanic area that is potentially subject to volcanic ash, fumes, debris or lava flows. 4. AEECs generation assets will have to be realigned to accept a significant fraction of its energy from this new source. To the extent that a geothermal project is base-loaded, AEEC’s other assets will have to be varied, as a percentage of their output, more than currently to meet load. For AEEC’s thermal generation, more variable operation will increase operating and maintenance costs. 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 Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 15 of 32 10/04/2022 Permit Name Permit Trigger Unknown Unknown For this scope of work – a engineering feasibility study, no permitting will be required. Part of the feasibility study will be to identify future permitting requirements and their impact on project costs. This proposed work scope includes developing and reporting on a preliminary list of permitting requirements. 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 owner of existing geothermal permits, GeoAlaska, LLC is highly supportive of this study effort and is cooperating and assisting with the study. This particular scope involves no field work so we see no issue with the availability of the site. 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. The largest unknowns at this time are 1) the depth and temperature of the geothermal resource and 2) the cost to interconnect any generation project to the existing electrical transmission grid. This scope of work will define the later. While another possible sequence would be to assess the geothermal resource itself first, that is a much more costly endeavor with all the financial, environmental and human risks of any remote field work. We believe that firmer costs for a conceptual design of the electrical interconnection may either rule out such a project of this size should it be very high or, if a reasonable interconnection design and cost be developed, empower the permit holder or others pursuing similar projects to proceed with more confidence regarding the total costs of such a project. This scope of work is straight forward and without technical risks – it is office-based work by experienced electrical engineering consultants assisted by HEA’s technical and financial staff. Likewise, there are not environmental risks to this proposed scope of work. Looking ahead to development of a geothermal resource; the subsurface temperatures, permeability, depth of production wells, water chemistry, steam quality, and geologic stability are all risks to be identified, measured, and minimized. Should the proposed project progress through futures development phases, HEA will include contingency planning for critical milestones throughout the design and construction phases of the project. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 16 of 32 10/04/2022 We are not aware of any opposition to the proposed project. Considering public advocacy in favor of renewable resources voiced at several HEA Board meetings and during public forums we anticipate public support for the project. 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 Species Name Scientific Name Status Presence Eskimo Curlew Numenius borealis Endangered May Occur Short-Tailed Albatross Phoebastria albatrus Endangered May Occur Steller Sea Lion Eumetopias jubatus Endangered May Occur Beluga Whale Delphinapterus leucas Endangered May Occur Green Sturgeon Acipenser medirostris Threatened May Occur Steller's Eider Polysticta stelleri Threatened Not Likely to Occur Habitat issues The species identified above may occur within or around the project footprint. However the below water infrastructure currently exists, there should be no new impact to the marine mammals listed above. Wetlands and other protected areas Being an offshore project there should be no wetlands impact. Archaeological and historical resources The project site is an uninhabited island so no archaeological and historical impacts are anticipated. Land development constraints The owner of the geothermal permits from the State of Alaska is highly supportive of this study effort and is cooperating and assisting with the study. This scope requires no access, but in the future, we see no issue with the availability of the site. Telecommunications interference No telecommunication interference analysis has been conducted to-date. Aviation considerations No aviation analysis has been conducted to date, but none is expected. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 17 of 32 10/04/2022 Visual, aesthetics impacts No visual or aesthetic analysis has been conducted to-date. 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. AEEC owns and operates three plants that are fueled by natural gas. The Nikiski Plant is an 80 MW baseload generating plant fueled by natural gas and recovered heat. HEA has two backup generating plants: the Soldotna Plant, a 48 MW generating plant; and the Bernice Lake Plant, a 73 MW generating plant that are used for backup, peaking, and reserve capacity. Additionally, AEEC has access to 14 MW of purchased power capacity at the State’s Bradley Lake Hydroelectric facility. 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: Nikiski Combined Cycle Plant: Natural Gas/ Steam, CT GE Frame 6B Combustion Turbine, 40-MW ST GE SC2-22, HRSG Deltak Dino 4128 Heat Recovery Steam Generator, 40-MW, NCC design capacity 80 MW, NCC minimum operational load 20 MW, CT RPM 5105, ST RPM 3600, Emerson Ovation DCS Unit 2: Soldotna Combustion Turbine Plant: Natural Gas, GE LM6000 Combustion Turbine Generator, design capacity 48 MW, minimum operational load 3 MW, RPM 3600, Emerson Ovation DCS Unit 3: Bernice Lake Combustion Turbine Plant: Natural Gas, GE Frame 5 Combustion Turbine, design capacity 19 MW, design capacity 27 MW, design capacity 27 MW, minimum operational load 3 MW, minimum operational load 6 MW, minimum operational load 6 MW, RPM 3600, Emerson Ovation DCS Unit 4: Bradley Lake Hydroelectric Project (Hydro), Fuji generators, Andritz hydro runners, design capacity 64 MW per unit (HEA 14 MW share), no minimum operational load, RPM 300, Emerson Ovation DCS Unit 5: Unit 6: 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). Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 18 of 32 10/04/2022 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. The HEA system has a total of 2,499 miles of energized line that distributes power to 35,865 meters in a 3,166 square-mile service area on the Kenai Peninsula. At 70 MW, this project will need to tie into the transmission system at transmission voltages, not distribution lines and voltages, hence the proposal to bring power ashore in Anchor Point. Part of the conceptual design would be the details of that interconnection. 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 Nikiski Combined Cycle Plant Natural Gas/Steam CT 40 MW, ST 40 MW CT GE, ST GE HRSG Deltak CT frame 6B Combustion Turbine, ST SC2-22, HRSG Dino 4128 Heat Recovery Steam Generator CT 35- 42% NCC 60% CT 1986, HRSG 2001, ST 2014 CT 168,983 Hours (as Of EOY 2019) Soldotna Combustion Turbine Plant Natural Gas CT 48 MW CT GE CT LM6000 Combustion Turbine Generator Peak CT 2014 CT 13,326 Hours (as of EOY 2019) Bernice Lake Combustion Turbine Plant Natural Gas Soldotna Combustion Turbine Plant CT GE CT Frame 5 Combustion Turbine Peak CT 1971, CT 1978, CT 1981 Is there operational heat recovery? (Y/N) If yes estimated annual displaced heating fuel (gallons) 5.4.2.4 O&M and replacement costs for existing units Power Generation i. Annual O&M cost for labor AEEC does not track labor & non-labor separately so O&M cost are below. This excludes natural gas costs. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 19 of 32 10/04/2022 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 Nikiski Combined Cycle Plant (kWh) Generation Soldotna Combustion Turbine Plant (kWh) Generation Bernice Lake Combustion Plant (kWh) Fuel Consumption (Diesel- Gallons) Fuel Consumption Natural Gas (MCF) Peak Load MWh Minimum Load January 41,899,405 2,097 1,256 2306 368,042 1,553 1,319 February 37,527,357 109,052 1,526 415 334,878 1,563 1,351 March 39,406,815 1,000,229 203,136 2601 365,365 1,572 1,323 April 35,481,301 2,767 151,421 16 319,225 1,456 1,201 May 17,186,990 13,800,750 344,021 9 305,346 1,303 1,182 June 26,701,127 4,402,566 200,985 1036 292,899 1,288 1,071 July 32,859,596 0 3 1182 298,043 1,386 1,209 August 32,356,522 14,203 1,764 44 296,783 1,388 1,044 September 20,007,288 10,537,928 321,433 453 286,838 1,443 1,182 October 39,997,133 2,714,565 10,067 15 392,830 1,437 1,277 November 42,267,368 18,194 2,385 1974 380,941 1,683 1,348 December 41,720,850 685,731 1,376 8904 380,057 1,810 1,479 Total 407,501,750 33,288,083 1,239373 18955 4,021,248 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 February March April May June July August September October November December Total ii. Annual O&M cost for non-labor $7,975,397 iii. Replacement schedule and cost for existing units NCC retirement 2043, SCT retirement 2054, BCT retirement 2034 Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 20 of 32 10/04/2022 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. HEA has 25,077 member-owners and provides power to 35,865 meters located throughout the Kenai Peninsula. HEA sold 452 million kilowatt-hours of electricity in 2020. HEA’S latest published Equity Management Plan indicates a 1% per year growth rate over the next 15 years but actual results indicate flat to a slight decline in load due to member efficiency and conservation efforts. A significant portion of that decline was the shuttering of the LNG and fertilizer-production facilities on our systems after the rising price of natural gas made them uneconomic. Predicting the future is difficult but HEA is hopeful that the adoption of electric vehicles along with other beneficial electrification technologies will result in a return to a 1% per year load growth for the life of this project. Additionally, HEA is interconnected to a regional Alaskan grid known as the “Railbelt” via a three phase, 115 kV transmission line. The Railbelt is generally defined as the service areas of five regulated public utilities: Chugach Electric Association (Chugach), Golden Valley Electric Association (GVEA), HEA, Matanuska Electric Association (MEA), and the City of Seward Electric System (SES). This region grid covers a significant area of the state and contains the majority of the state’s population and economic activity; it extends from Homer to Fairbanks and includes areas such as Anchorage, Fairbanks, and the Matanuska-Susitna Valley. HEA can and has regularly provided power to Alaskan residents from Anchorage to Fairbanks via wholesale and economy energy sales to the other four interconnected electric utilities. 5.4.4 Proposed System Design Provide the following information for the proposed renewable energy system: • 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. This scope of work is to develop costs for interconnection to a potential geothermal generation and not to study the resource itself. However, the generation project itself is envisioned as two 35-MW modular geothermal generation plants either using geothermal steam directly, depending on its temperature and chemical characteristics, or a secondary fluid after heat exchange with geothermal fluids which would, in either case, be reinjected. The energy modeling effort associated with scope of work described in Section 2.5 of this grant application will model the effects of both 35 MW and 70 MW onto the HEA system. The project will be integrated to the regional electric grid through the existing Western Segment, owned by HEA. This will permit delivery of electricity to the bulk power system. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 21 of 32 10/04/2022 The geothermal generation will be backed up by HEA’s other generation assets and our BESS. 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 2 Geothermal 35,000 100 30 95% 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 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. • 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. HEA would most likely by itself or in conjunction with other Railbelt utilities, enter into a Power Purchase Agreement with an Independent Power Producer such as GeoAlaska. Because geothermal is a base-loaded resource, the generation would be operated near peak capacity and coordinate any scheduled outages for maintenance with HEA and other Railbelt utilities as is already done for combustion turbines and Bradley Lake. Unscheduled outages would also be addressed as they are for combustion units currently with all interconnected utilities providing sufficient spinning reserves to maintain grid stability should any one unit trip off. If project economics allow for 70 MWs, it would be a very large fraction of HEAs current load, at times in excess of local demand. During short periods when HEA’s load was less than 70 MW, our existing BESS would be utilized to store excess energy and short- or longer-term contractual arrangements made with other Railbelt utilities for off-system sales. Sized at 46.5 MW, the BESS Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 22 of 32 10/04/2022 has the ability to inject into (or absorb from) the system more than any projected excess or shortfall while HEA’s combustion turbines can be started within 15 minutes to make up multi-hour shortfalls. Part of the scope of this effort is to model such a large baseload generation and refine the economics of such operations. * All HEA load and energy figures presented are for HEA’s current customer/member base, but should HEA’s offer to purchase Seward’s electrical system come to fruition, then an additional 4-9 MW of demand would be needed in HEA’s annual energy production. 5.4.3.1 Expected Capacity Factor 100% A geothermal plant is expected to operate continuously at its rated output with an availability in the order of 95%. For cost estimating purposes, the 5% downtime has been assumed to occur in one of HEA’s shoulder-season month, specifically May, in the chart in Section 5.4.5.2, below. 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) January 52,080,000 February 52,080,000 March 52,080,000 April 50,400,000 May 21,420,000 June 50,400,000 July 52,080,000 August 52,080,000 September 50,400,000 October 52,080,000 November 50,400,000 December 52,080,000 Total 587,580,000 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 February March April May June Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 23 of 32 10/04/2022 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: 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. $ 2. Hour’s diesel OFF/year: 3.$13,4000,000 annual estimate (Includes projected, ongoing well refurbishment) 5.4.7 Fuel Costs Estimate annual costs for all applicable fuel(s) needed to run the proposed system (Year 1 of operation) Diesel (Gallons) Electricity Propane (Gallons) Coal (Tons) Wood Other Unit cost ($) Annual Units Total Annual cost ($) 5.5 Performance and O&M Reporting For construction projects only Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 24 of 32 10/04/2022 5.5.1 Metering Equipment Please provide a short narrative, and cost estimate, identifying the metering equipment that will be used to comply with the operations reporting requirement identified in Section 3.15 of the Request for Applications. N/A 5.5.2 O&M reporting Please provide a short narrative about the methods that will be used to gather and store reliable operations and maintenance data, including costs, to comply with the operations reporting requirement identified in Section 3.15 of the Request for Applications N/A SECTION 6 – ECONOMIC FEASIBILITY AND BENEFITS 6.1 Economic Feasibility 6.1.1 Economic Benefit Annual Lifetime Anticipated Diesel Fuel Displaced for Power Generation (gallons) Anticipated Fuel Displaced for Heat (gallons) Total Fuel displaced (gallons) Anticipated Diesel Fuel Displaced for Power Generation ($) Anticipated Fuel Displaced for Heat ($) Anticipated Power Generation O&M Cost Savings Anticipated Thermal Generation O&M Cost Savings Total Other costs savings (taxes, insurance, etc.) Total Fuel, O&M, and Other Cost Savings $54,421,660 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 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. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 25 of 32 10/04/2022 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. To approximate costs savings, HEA has used its small-facility power producer rate, as approved by the RCA for the current quarter of $0.09262/kWh. This is primarily the amount of natural gas saved in our average use of our combustion-turbine fleet without considering integration costs and comes to an amount more than HEA’s current natural gas costs. As stated elsewhere, if the project is sized at 70 MW generation plant, HEA would have to 1) be providing power to the City of Seward, 2) serving increased load possibly due to increase EV penetration and/or 3) have off- system sales of energy to other Railbelt utilities. Additional savings would be realized should AEEC’s combined cycle plant no longer be needed, and the labor costs at that facility were reduced or eliminated. 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. In addition to a lower cost of energy arising from HEA’s avoided cost for natural gas, this project allows HEA to diversify their energy sources and be far less sensitive to increasing natural-gas prices and less vulnerable to gas availability issues. To the extent that HEA reduces their gas consumption, the life of finite gas resources in Cook Inlet is extended for all users in the region and seasonal gas availability issues are diminished. If financed by HEA, the debt service and depreciation costs would be nearly constant in 2026/2027 dollars and therefore decreasing, in real dollars, throughout the project projected 30-year life meaning that in addition to an initial downward pressure on consumer rates, the project’s output would continue to resist the inflationary pressure of HEA’s combustion assets. 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 Note that this scope for office-based with very low risk of disruptions. However, should the project proceed, the following logistical, supply-chain and tax policy risks are detailed in the table below: Risk Importance Mitigation Strategy Unexpected increase in generation component or delivery costs High Early coordination with turbine vendors to protect against price volatility Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 26 of 32 10/04/2022 Labor shortages for construction or operations phases Medium Establish a labor resource plan in advance of construction activities Foreign exchange risk with European or Asian based manufacturers Low Explore domestic content options Lack of federal tax incentive extension Low Vigilant monitoring of developments in Washington Availability of Jones Act compliant heavy lift and transportation vessels Medium Proactive and early discussions with vessel contractors Availability of appropriate cable- laying ship and tenders Low Proactive and early discussions with vessel contractors 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 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 This project will refine critical costs involved and any off-shore renewable energy development and inform all IPPs and Load-Serving Entities of the interconnection costs early in their evaluation of this and other off-shore projects. The project could also act as a model for repurposing other oil platforms in the Cook Inlet and elsewhere. The project could help sustain the offshore oil & gas support industry in the area since it is likely that some of the same services will be needed. The project could provide offshore infrastructure for other renewable energy opportunities such as tidal power development or off-shore wind The interconnections costs developed in this Feasibility project would meaningfully add to the State’s body of knowledge for future wind projects. SECTION 7 – SUSTAINABILITY Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 27 of 32 10/04/2022 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 • Describe the system will be used to ensure that scheduled maintenance is performed Should this generation facility be built, it would be remotely operated and monitored utilizing HEA’s existing SCADA infrastructure from the existing HEA Dispatch Center, which is staffed 24 hours a day, 7 days a week, 365 days a year. Any onsite operations and maintenance activities will be cooperatively facilitated by HEA and the IPP that develops the project. HEA operates the Bradley Lake Hydro Facility for the State of Alaska and is experienced at operating and maintaining equipment in remote areas. Should HEA operate the generation facility, HEA would use its existing maintenance scheduling, inventory control, outage scheduling, warehousing, and accounting procedures to coordinate and track scheduled and unscheduled maintenance on these new assets. HEA’s existing staff would supply support services such as accounting, HR, IT, engineering support, payroll, etc. 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. It is anticipated that this transmission asset will be owned and operated by AEEC / HEA which will use established and existing utility accounting practices, procedures, financial systems, accounting personnel, and outside independent audits to account for operational and capital costs. HEA rates are set by the member-elected Board of Directors on an annual basis (and modified each mid-year). HEA develops its annual budget to cover all its operational expenses, debt service, fuel costs, and margins required to comply with lender’s loan covenants, HEA’s own capital-credits policy, and provide sufficient funds for system maintenance and upgrades. Those rates (tariffs) are then reviewed and approved by the Regulatory Commission of Alaska. As an AEEC / HEA asset, revenues would be collected through HEA’s existing monthly billing process and systems. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 28 of 32 10/04/2022 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) HEA / AEEC hopes to add this environmentally friendly, beneficial, renewable-energy project to AEEC’s generation portfolio without negatively impacting rates. This will depend on the final actual cost of the project, any grants, direct pay tax incentives, legislative appropriations, power- production-incentives, greenhouse-gas, and / or renewable-energy credits received and the capital financing terms of the project. Operational and capital costs or purchased power through a PPA will be covered through revenues received from the sale of power to HEA’s members. The purchased-power rates are set by HEA’s member elected Board of Directors and reviewed and approved by the Regulatory Commission of Alaska. Since HEA is a not-for-profit entity, no rate of return is incorporated into the rates that HEA charges its members. HEA provides power at cost plus an allowed RCA specified operational margin. As mentioned above it is HEA’s hope that this project will not increase HEA’s current rates (https://www.homerelectric.com/member-services/my-bill/rates/) but will provide a downward pressure on rates upon commissioning and into the future. 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) 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. It is anticipated that this transmission asset will be owned and operated by AEEC / HEA. It is anticipated that HEA would enter into a PPA with a IPP who develops the generation facility itself. Such a PPA would be approved by the RCA and then the generation incorporated into AEEC’s existing generation portfolio that provides power to HEA members. Since HEA is a not-for-profit entity, no rate of return is incorporated into the rates that HEA charges its members. HEA provides power at cost plus an allowed, RCA-specified operational margin. Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 29 of 32 10/04/2022 As noted in Section 2.5, part of the scope of work is to analyze possible ownership scenarios. If it is more advantageous and economically beneficial for AEEC to own and operate the generation facility, HEA/AEEC would work with the appropriate IPP to develop power purchase / power sales agreements which include an option to purchase the generation asset at a reduced price at 5 or 10 years into the project life after the developers have realized the majority of their ITC, PTC and depreciation benefits. 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. HEA/AEEC has existing RFPs for similar work that can be used as templates to quickly and efficiently specify and solicit the consultants required to compete this Feasibility Study. AEEC will work to select the engineering consultant soon after a grant is awarded. 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. HEA/AEEC has installed the largest Battery Energy Storage System (BESS) in Alaska. It has been tested, found able to exceed the maximum discharge rates specified in procurement contracts, and will allow more flexible, efficient operation of our current thermal and future renewable assets. With capacities of 46.5 MW and 93 MWh, this $41M project was untaken to give HEA the ability to bring large intermittent projects online without incurring the costs of rapidly cycling thermal units and without adversely affecting the Railbelt grid. 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 Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 30 of 32 10/04/2022 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. Included as Attachment B are letters of support from the following: Erin McKittrick, the Board President, Alaska Electric and Energy Cooperative. Paul Craig, PhD, Manager, GeoAlaska, LLC. Brentwood Higman, Ground Truth Alaska. Tim Dillion, Executive Director, Kenai Peninsula Economic Development District. 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. Homer Electric Association through its wholly own subsidiary Kenai Hydro, completed some Phase I Reconnaissance studies, which were completed in January 2009 and were partially funded by a $100,000 AEA grant. Kenai Hydro received partial funding for Phase II activities in the amount of $2,000,000 through two separate awards of $816,000 and of $1,184,400 through AEA Renewable Energy Grants. Kenai Hydro complied with all terms of the grant agreements from previously award grants, which included timely quarterly progress reports, delivery of agreed upon deliverables, and closeout of the grants. HEA/AEEC was the recipient of four Phase II wind resource assessment feasibility grants and a Phase III final design grant for a landfill gas project in the AEA REF Round 14 solicitation. The finalized AEA grant agreements for the wind projects were received on 10/31/2022 and the finalized landfill gas grant agreement was received on 11/14/2022 so we are just getting started on the administration and compliance requirements of those grants but AEEC has the processes in place to ensure compliance with these grants. 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. NA SECTION 12 – LIST OF ADDITIONAL DOCUMENTATION SUBMITTED FOR CONSIDERATION In the space below, please provide a list of additional information submitted for consideration. Attachment A: Resumes, submitted as a separate file Attachment B: Letters of Support Attachment C: Board Resolution & Authorization SECTION 13 – AUTHORIZED SIGNERS FORM Community/Grantee Name: Regular Election is held: Date: Authorized Grant Signer(s): Alaska Electric & Energy Cooperative, Inc. Annually June Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 31 of 32 10/04/2022 Printed Name Title Term Signature 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 Grantee Contact Information: Mailing Address: Phone Number: Fax Number: Email Address: Federal Tax ID #: Please submit an updated form whenever there is a change to the above information. 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. Bradley P. Janorschke General Manager N/A Bradley P. Janorschke General Manager N/A 3977 Lake Street, Homer, AK 99603 907-235-8551 907-235-3323 bjanorschke@homerelectric.com 92-0177236 Renewable Energy Fund Round 15 Grant Application – Standard Form AEA 23046 Page 32 of 32 10/04/2022 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 Bradley P. Janorschke General Manager December 5, 2022 AEEC Augustine Island Geothermal Project REF Round 15 Application Attachment A: Resumes (attached as a separate file) AEEC Augustine Island Geothermal Project REF Round 15 Application Attachment B: Letters of Local Support To whom it may concern, Homer Electric Association (HEA) is a member-owned electric cooperative serving customers on the Kenai Peninsula, governed by a nine-member board. As a democratically elected body, our board represents the interests of HEA’s 25,000 members, and speaks on their behalf. In our commitment to providing affordable and reliable electricity, we regularly review the cooperative’s finances, analyzing cost drivers, risks, and opportunities. Natural gas costs are responsible for around a third of members’ bills. This gas is only available from a single source, and at the time of our last contract negotiation, only from a single provider. That provider has stated that there is a strong likelihood of gas shortages in the future, and encouraged its customers to reduce dependence on its natural gas. HEA’s gas contract will be the first to expire in the Railbelt, in early 2024, making the need to reduce gas dependence particularly urgent for our members. The board has determined that this reliance on a single energy source is a substantial risk to our members. We have created an ambitious renewable energy policy to address this issue, seeking 50% renewable energy by 2025. We have determined that incorporating diverse renewable sources of energy into our energy portfolio will benefit HEA members, reduce our vulnerability to price or supply shocks, and reduce upward pressure on electric rates. HEA considers all possible renewable energy projects with the potential to provide energy to our cooperative. We have increased hydro production through our portion of the Battle Creek Diversion and are proceeding on our Grant Lake Hydro and Landfill Gas projects. Meanwhile, we have been exploring opportunities in wind and solar. Our board is interested in assessing the economics of two geothermal prospects – Augustine Island and Mount Spurr. These are the most promising geothermal energy sources in the Cook Inlet region, and there is a project developer pursuing generation in each location. If either location proves viable, we need to know the interconnection costs to determine the project’s value to our members. The possibility of a large, base-loaded renewable like geothermal could, more than any other single project, allow HEA to diversify away from natural gas for the majority of our energy. I encourage AEA to fund this request to study interconnection costs at these two locations so that we can incorporate those economic findings into our strategic plans. Sincerely, Erin McKittrick Board President, Alaska Electric and Energy Cooperative (Alaska Electric and Energy Cooperative is a generation and transmission cooperative with HEA as its sole member, sharing a governing body. AEEC is responsible for generating and providing all the energy to HEA) GeoAlaska, LLC 2440 East Tudor Road, # 230 Phone +1-907- 830-1151 Anchorage, AK 99507 pcraig@geoalaska.com November 19, 2022 Homer Electric Association, Inc. 280 Airport Way Kenai, AK 99611 To whom it may concern: The Members and management of GeoAlaska, LLC (“GeoAlaska”) hereby declare GeoAlaska’s unanimous endorsement and support for Homer Electric Association’s (“HEA”) efforts to secure financial resources pertaining to the development and delivery of geothermal power to the benefit of Alaskans in general, and HEA’s customers in particular. GeoAlaska, LLC was established on May 1, 2000 for the purpose of identifying and developing sustainable geothermal power that could supply green energy for use by Alaskans. GeoAlaska was issued its first geothermal prospecting permit on Mt. Spurr effective September 1, 2021. On September 1, 2022, GeoAlaska was issued its second geothermal prospecting permit on Augustine Island. Both prospects are on the west side of the Cook Inlet and were strategically selected by GeoAlaska for geological, geographical, and geopolitical (e.g., State land reasonably proximate to existing infrastructure) reasons. GeoAlaska is actively negotiating with investors regarding the upstream development of geothermal resources in each location. HEA and GeoAlaska have entered into a letter agreement providing HEA with a first right of refusal pertaining to a power purchase agreement at each location. As a consideration for the first right of refusal, HEA has agreed to pursue funding to study grid interconnection, including the size of resource that must be developed to assure economic viability of geothermal power at Augustine Island and Mt. Spurr. GeoAlaska is delighted to be working collaboratively with HEA toward the goal of supplying Alaskans with sustainable geothermal power to help meet our State’s future energy needs in a climate-sensitive manner. GeoAlaska fully supports HEA’s efforts in this regard. Sincerely, Paul L. Craig, PhD Manager, GeoAlaska, LLC To Whom it may Concern: I am a resident of the Kenai Peninsula, a Homer Electric Association ratepayer, and executive director of Ground Truth Alaska, a local science education nonprofit. I'd like to express my support for HEA's proposed study of two possible renewable energy projects in Cook Inlet: Geothermal at Augustine Volcano, and wind generation on oil platforms in upper Cook Inlet. The need for diverse renewable energy on our electric grid is urgent. Currently we rely almost exclusively on natural gas, but we need to move away from this as quickly as possible. We need this transition first because we have no other choice - the natural gas supply in Cook Inlet is dwindling, and we are very likely to face increasingly dire shortages in the coming years and decades. Additionally, we have to do our part in the face of a climate emergency - both the CO2 emissions from combustion, and fugitive methane that escapes from our aged and thinly spread gas lines and distribution. Wind generators atop abandoned platforms seems worth studying - available estimates of wind energy show upper Cook Inlet as having excellent wind potential. The details of installation, maintenance, transmission, and generation variability will all bear on whether this is a practical source of electricity - exactly the analysis that the proposed study will attempt. Geothermal production at Augustine Volcano is in some ways more speculative - the transmission distances are long, and geologic hazards may doom a project here. However, this very active volcano could be a major source of electricity, providing baseload or even balancing generation to complement variable renewables such as wind and solar. The devil is in the details, but I strongly support a careful study of the potential before we rule out this potentially beneficial development. I would suggest that some consideration be given to combining geothermal energy production at Augustine with offshore wind near Anchor Point, since they might benefit from the same transmission infrastructure, and the geography appears favorable for offshore wind in this area. Thank you for your consideration, Bretwood Higman, Executive Director AEEC Augustine Island Geothermal Project REF Round 15 Application Attachment C: Board Resolution & Authorizations Alaska Electric and Energy Cooperative, Inc. 3977 Lake Street  Homer, Alaska 99603  (907) 235-8551 RESOLUTION 01.2022.13 GRANT FUNDING AUTHORIZATION FOR A GEOTHERMAL PROJECT LOCATED ON THE WEST SIDE OF COOK INLET BE IT RESOLVED that Alaska Electric & Energy Cooperative, Inc. (AEEC) hereby authorizes the General Manager to proceed with the Alaska Energy Authority (AEA) application process to seek grant funding for a geothermal project located on the west side of Cook Inlet. CERTIFICATION I, Jim Duffield, do hereby certify that I am the Secretary/Treasurer of Alaska Electric & Energy Cooperative, Inc., and that the foregoing resolution was adopted at a meeting of the Directors of Alaska Electric & Energy Cooperative, Inc., held on November 15, 2022, at which meeting a quorum was present. Jim Duffield, Secretary/Treasurer Alaska Electric and Energy Cooperative, Inc. 3977 Lake Street  Homer, Alaska 99603  (907) 235-8551 CERTIFICATE OF GENERAL MANAGER OF ALASKA ELECTRIC AND ENERGY COOPERATIVE, INC. (AEEC) IN SUPPORT OF A GEOTHERMAL PROJECT LOCATED ON THE WEST SIDE OF COOK INLET GRANT APPLICATION I am the General Manager of Alaska Electric and Energy Cooperative, Inc. (the “Cooperative”). I am authorized by the Board of Directors of the Cooperative pursuant to Board Policy 203, and by formal action of the Board of Directors of the Cooperative at a meeting held on November 15, 2022 to certify as follows: 1. The Board of Directors of the Cooperative has authorized the application for project funding and agrees that the Cooperative will honor the match amounts contained in the application to which this certificate is attached. 2. The Cooperative is in good standing with respect to any existing credit and federal tax obligations. Signed and dated in Homer, Alaska, on November 15, 2022. ____________________________________ Bradley P. Janorschke General Manager