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2020-03-04 AEA Agenda and docs
813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG REDUCING THE COST OF ENERGY IN ALASKA Alaska Energy Authority Board Meeting Wednesday, March 4, 2020 10:00 a.m. AGENDA To participate via teleconference dial 1-888-585-9008 and when prompted, enter code 676-392-603# 1. CALL TO ORDER 2. ROLL CALL BOARD MEMBERS 3. ROLL CALL STAFF, PUBLIC 4. AGENDA APPROVAL 5. PUBLIC COMMENTS (3 minutes per person) see call in number above 6. PRIOR MINUTES – January 15, 2020 7. NEW BUSINESS – Presentation by Denali Commission on “Roadbelt Inter-tie” (Jason Hoke) 8. OLD BUSINESS A. Updated AEA Organization Chart B. Battle Creek Update 9. EXECUTIVE SESSION – Discuss confidential matters related to Bradley Lake, Battle Creek, and the SQ Line 10. DIRECTOR COMMENTS A. Hydro Update B. AEA Annual Report C. Rural Power Systems Inventory & Assessment D. Coast Guard Bulk Fuel Inspections E. 5.5 Mile Update F. Tuluksak Update G. PCE Report H. Community Outreach Schedule I. Dashboard & Loan Report J. Denali Commission Update K. VW Settlement Update L. Articles of Interest M. Legislative Presentations N. Next Regularly Scheduled AEA Board Meeting Wed. April 15, 2020 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG 11. BOARD COMMENTS 12. ADJOURNMENT ROAD BELT INTER-TIE EXPANDING ALASKA’S INFRASTRUCTURE AND DEVELOPMENT CHAD STOVALL, CHIEF OPERATING OFFICER TOM WOLF, ENERGY PROGRAM MANAGER DENALI COMMISSION AEA BOARD PRESENTATION MARCH 4, 2020 CURRENT CONCEPT •Route: Sutton-Glennallen-Tok-Delta •Purpose and Need: •Reduce power costs for rural communities •Support regional economic development opportunities •Increase Department of Defense facility resilience •Increase reliability throughout the road system CURRENT CONCEPT CURRENT COSTS AND CONSUMPTIONS INHIBITING REGIONAL DEVELOPMENT •Most communities in this project area are paying 300-500% more than the national average ($.13/kwh national average). •Communities are electrified by multiple micro-grids consuming approximately 4 million gallons of diesel per year. Emissions and other issues plague these small grids. •PCE does not cover commercial electricity which is ~60% all electrical consumption in these communities. •Electrical costs directly correlate to business/ resident closure and relocation. ECONOMIC AND NATURAL RESOURCE DEVELOPMENT •Cheaper electrical power opens the door for BRE (Business Retention and Expansion), allows business plans to pencil out •Necessary Infrastructure for Economic Development. •Timber and Lumber Industry (e.g. OSB manufacturing, lumber mills, biomass pellet and brick plants) •Mining operations/prospects that could benefit: Ft. Knox, Pogo, Stellar, Ahtell Creek, Peak Gold (Tetlin), 4th of July Creek Placer •Agriculture: Food Hubs, Value-Added Processing, Hydroponics, Extending the Growing Seasonal Capacity. •Tourism, Outdoor recreation, Fishing benefits MILITARY BENEFITS AND BUILD UP •Energy IS National Security! •Military Bases that would benefit from the proposed intertie: Donnelly Dome Range, Ft. Greeley, Eielson AFB, Ft. Wainwright, and Clear AFS, JBER. •REDUNDANT, RESILIENT, AND RELIABLE ENERGY NECESSARY! The proposed intertie offers a redundant loop. •Reduced cost for military with cheaper energy and resiliency. •Signs of continued defense build up and growth. •25% Renewable needed and can be supplemented with RBIT PREVIOUS PUBLIC PLANNING AND VETTING PROCESSES •Copper Valley Regional Energy Plan with AEA Number 1 Priority •Statewide Energy Planning with AEA Top Priorities •Copper Valley Regional CEDS (Comprehensive Economic Development Strategy-US EDA) Top Priority •Statewide CEDS Top Priority (with US EDA and AK DED of DCCED) •Ahtna Tribal Energy Plan Number 1 Priority (US DoE-OIE) •Tanana Chiefs Conference Energy Planning Priority (US DoE-OIE) •Tanana Chiefs Conference CEDS Top Priority •FBNS Borough CEDS Top Priority SUPPORT AND RESOLUTIONS •AFNs Only Energy Resolution 2017 was RBIT! •Native Organizations impacted and supportive of this project effort are approximately 12 Tribal Governments, 12 Village Corporations, 4 ANSCA Corporations (Ahtna, CIRI, Doyon, Chitina), Ahtna Inter-Tribal Resource Commission, Tanana Chiefs Conference, Copper River Native Association, , NV Chickaloon and many more. •CVEA, AP&T, MEA, Golden Valley, APA (Alaska Power Association) •Copper Valley Development Association (ARDOR) •Copper Valley Chamber of Commerce •Senate/House Joint Resolution 10 passed in 2019 supporting the Road belt Intertie and urging the Congressional Delegation pursue it’s development RECENT DEVELOPMENTS/CURRENT STATUS •Senator Sullivan requested detailed project develop cost information in advance of FY2021 budget making •Denali Commission contracted with Ahtna Engineering/Electric Power Systems to prepare the Roadbelt Intertie Reconnaissance Report to be completed by mid-June 2020. The report will address: •Possible line corridors •Mitigation Areas/Solutions •Transmission Planning (design parameters required for system technical feasibility & reliability) •Renderings of typical installations •Design and construction estimates •Descriptions of anticipated environmental permit requirements •Qualitative cost/benefit analyses WHAT’S NEXT? •Commission/AIDEA/AEA will draft a MOU for approval at the April 15 board meeting •The MOU will address the types of support AIDEA and AEA can bring to the project as it moves forward including: •Technical Assistance/Reviews •Economic Analyses •Financing and Ownership Plan. ROAD BELT INTER-TIE •Questions? •Thank you Curtis ThayerExecutive Director - AEAPCN 08-0208VacantCOOPCN 08-0206Bryan CareyOwned Assets/Hydro Group MgrPCN 08-X071Keith DivollPCE TechnicianPCN 08-X075Ashton DoyleExecutive AsstPCN 08-0219VacantAdmin AsstPCN 08-0410Kirk WarrenDir Engineering & Energy DevelopmentPCN 08-0491Neil McMahonPlanning ManagerPCN 21-7014Josephine HartleyProject Manager Program MangerPCN 08-0443 Vacant Safety/Whs Support TechPCN 08-0440Curtis HansonRural Electric Utility WorkerPCN 21-7010Kyler KillmerCircuit Rider TechnicianPCN 08-X003Justin TuomiRural Electric Utility WorkerPCN 21-7012Tim SandstromDir Rural ProgramsPCN 08-0466Alan FettersRural Assist MgrPCN 08-0231TW PatchDirector Planning PCN 08-0230VacantAEEE Program ManagerPCN 08-X007Phillip ChandonnetCircuit Rider TechPCN 08-X029Rebecca GarrettProject ManagerPCN 08-0403Brandy Dixon Public Engagement Officer PCN 08-X034Brandi WhiteSr AccountantPCN 08-0457Vacant IFD AmblerPCN 08-0233Justin CrowtherSystems ProgrammerPCN 08-X076Robert HawkinsMIS AdministratorPCN 08-0227Vacant Analyst ProgrammerPCN 08-X037William PriceProject ManagerPCN 08-0222Tomas BoutinExecutive Director - AIDEAPCN 08-0200Mark Davis Chief Infrastructure Dev OfficerPCN 08-0224Chris AndersonCommercial Fin DirPCN 08-0201Brenda ApplegateCFOPCN 08-0203Amy AdlerAsst CFO/ControllerPCN 08-0453Jennifer BrideFinancial Systems AnalystPCN 08-X038Jocelyn GarnerAsst ControllerPCN 08-X074Jessica HoustonAccounting TechPCN 08-0214Owen BerklundAccountantPCN 08-0438Jodie MackFinancial Reporting AnalystPCN 21-7015Amy GreenAccounting TechPCN 08-0468Beazit RedzepiSr Project Acct/ Budget AnalystPCN 08-0507Linda SennHR Director PCN 08-0455Lex SargentoCPCOPCN 08-0220Michele HopeSr. Contracting OfficerPCN 08-0495Lois LemusContracting OfficerPCN 08-X019VacantContract AdminPCN 08-0469Sherrie SiversonExecutive AsstPCN 08-0213Krin KemppainenAdmin AsstPCN 08-X036Aimee SudbeckAdmin AsstPCN 21-7013VacantSr Investment Offcr Project FinancePCN 08-0402Leona HakalaLoan Officer IIPCN 08-0204William PhelanLoan Officer IIPCN 08-0205Kara MabryCredit AdministratorPCN 08-0215Rebecca LawsLoan Srvcs SupvPCN 08-0207Emily EngrischLoan Servicing/ATPCN 08-0210 VacantProject ManagerPCN 08-0490Jesse PetersonSr. Manager PFAMPCN 08-0228Ryan GarnerProject Manager Program ManagerPCN 08-X033Rob JordanProgram Manager - Energy Data PCN 08-0425VacantEconomistPCN 08-X098VacantEnergy IFD OfficerPCN 08-X095Jeff WilliamsPCE Program Mgr/ Cmnty Assist AdvPCN 08-0411Angelica SamudioPCE TechnicianPCN 08-0217Jeff San JuanSr Fin OfficerPCN 08-X109 Terence CatoIT DirectorPCN 08-0401 82 EX: Exempt 0 NP: Non Perm 82 Total PositionsDepartment of Commerce, Community and Economic DevelopmentAIDEA/AEAFY2020 Org Chart as of 2/14/2020VacantIFD AmblerPCN 08-0412Sam TappenIFD OfficerPCN 08-0498 Alan WeitznerChief Investment OfficerPCN 08-0229VacantBusiness Systems AnalystPCN 08-X141Thomas BenkertEnergy Funding Res SpecialistPCN 08-X077Taylor AsherAsst Project Mgr - RenewablesPCN 08-X1062/14/2020Betsy McGregorPrelim Design & Envir MgrPCN 08-X073Geoffrey JohnsInvestment Offcr PF PCN 08-X072Karin St. ClairProject Control SpecialistPCN 08-X127VacantHR TechnicianPCN 08-0473Nicole DavisFront Desk Admin PCN 08-0216UpdatedKarsten RodvikExternal Affairs OfficerPCN 08-0223VacantDebt Finance OffcrPCN 08-0202SHARED SERVICESAIDEAAEAKevin BucklandAsst CFO/ControllerPCN 08-0209Shawn CalfaSr AccountantPCN 08-0423Carmen NobleAccountantPCN 08-0493Rita NiemannAccounting TechPCN 08-0211Jennifer BrownAsst ControllerPCN 08-X117Fiorella Isla GalvezAccounting TechPCN 08-0221David LockardInfrastructure EngineerPCN 08-X123 Page 1 of 5 AEA Board Update – West Fork Upper Battle Creek March 4, 2020 Events The HDPE pipe and fusing machine arrived onsite during multiple barge trips in September, October, and November. The contractor has been building the diversion dam this fall/winter and construction has taken longer than expected. While December weather was mild, the temperatures dropped substantially in January requiring a change in cement mix, heating, and insulation. During each pour a concrete tester is on site taking samples and concrete has been meeting specifications. Schedule Last contractor schedule (data date January 5, 2020) has the diversion dam construction proceeding forward through mid-February 2020. Two more concrete pours, drilling several foundation drains, placing drain rock and rip rap, and removal of super sack diversion dam will complete the diversion structure and the season. Orion plans to remobilize to the site in early April and start HDPE fusing May 1, 2020. Schedule shows substantial completion July 2020 (same as contract). Schedule is achievable. Budget Little change in budget. Increases in rock excavation quantities (expected) balance out with reductions in the MSE walls. Contract amount is within 1% of initial. Page 2 of 5 Photo 1: Diversion Dam Stage 2 (November) Photo 2: Diversion Dam Stage 3 (December) Page 3 of 5 Photo 3: Heating Aggregate Photo 4: Spillway & Left Abutment Page 4 of 5 Photo 5: Spillway & Right Abutment Photo 6: Talon Fusion Machine Page 5 of 5 Photo 7: HDPE Pipe Page 1 of 2 AEA Board Update – Hydroelectric Projects Involvement March 4, 2020 Bradley Lake Hydroelectric Project Location: ~20 miles Northeast of Homer Capacity: 120 MW Funding: This is an AEA owned asset. Original construction funding was split between utilities and the State of Alaska. Status: Bradley Lake’s elevation is 15 – 20 feet above “normal” for this time of year. This is due to transmission lines being out of service in 2019, so less water was being drawn from the lake. With the restoration of the transmission line north of the Kenai Peninsula, utilities are being urged to use as much Bradley energy as they can to draw the lake down prior to spring in flows. Bradley could see a spill in 2020 if the lake not sufficiently drawn down. Original Bradley bonds are scheduled to be paid off July 1, 2021. Once the original bonds are paid off, utilities will start excess payments to the State of Alaska anticipated to be approximately $12.5M a year, subject to the terms of the Power Sales Agreement. Battle Creek Location: ~20 miles Northeast of Homer Capacity: 0 MW Funding: This is an AEA owned asset funded by participating utilities and $41,239,000 in bonds issued by Alaska Energy Authority. An additional $5,761,000 in bonds were issued and are available if needed for project financing. Status: Construction is proceeding toward the scheduled substantial completion date of July 22, 2020. The construction contract value is within 1% of the initial contract amount. The project is a zero capacity amendment to the Bradley Lake FERC license but will enable Bradley to provide an average annual energy increase of 37,300 MWh to the Railbelt. Hiilangaay Location: Southwest side of Prince of Wales Island Capacity: 5 MW Funding: This is a Haida Energy owned asset funded by $20M in a Power Project Fund loan, $4M in AEA grants, and Haida Energy financing. Page 2 of 2 Status: Construction is currently shut down for winter conditions. Once construction restarts, it will proceed toward the scheduled completion date of November 2020 and Haida Energy will start making quarterly payments of $108,696 on April 1, 2020. Gunnuk Creek Location: Kake, Alaska Capacity: 500 kW Funding: This is an Inside Passage Electric Cooperative (IPEC) owned asset funded by a $3,920,000 direct AEA grant and $80,000 REF grant along with approximately $4.5M in IPEC financing and other grants. Status: Construction is still on-going and proceeding toward the scheduled completion date of April 2020. Thayer Creek Location: Six miles North of Angoon, Alaska Capacity: 850 kW (approximately) Funding: This is a Kootznoowoo Inc. (KI) owned asset that is operated by IPEC. This project will be funded by $2, 345,168 REF grants, $1,142,856 KI match, and $100,000 IPEC financing. Status: Final design is occurring and KI is working on project construction financing not covered by AEA grants. Construction could start in 2021 if financing is obtained. Five Mile Creek Location: Chitina, Alaska Capacity: 250 kW (approximately) Funding: This is a Chitina Electric Inc. (CEI) owned asset. This project is funded through $3,980,000 in REF grants, $500,000 in Chitina Native Corporation match, and a $2,850,000 AEA grant (USDA RUS through Denali Commission). Status: The revised 35-65% design, updated cost estimate, and economic analysis is expected to be completed by June 2020 using REF funds. CEI has been granted $3.4M in REF funds and $2.85M in USDA RUS funds through the Denali Commission. The projects final design, permitting, and construction will be funded through AEA. Project construction is expected to begin summer of 2021 and be completed by fall 2022. Page 1 of 2 AEA Board Update – Rural Program Coordination Efforts with the U.S. Coast Guard March 4, 2020 This is an update and general information on AEA efforts to coordinate our rural programs with the U.S. Coast Guard, Anchorage Sector, Marine Safety Task Force (CG) and other State agencies including the Division of Community and Regional Affairs (DCRA) and Department of Environmental Conservation (DEC). Current Situation The CG has begun inspections on bulk fuel facilities throughout rural Alaska. This increased inspection effort and enforcement action will impact a large number of communities serviced by AEA’s Bulk Fuel Upgrade (BFU) program. Facts There are about 400 CG regulated rural bulk fuel facilities (excluding Southeast Alaska). CG staff inspected 200 facilities during 2019 at a cost of about $700,000. The CG plans to inspect the remaining facilities in 2020 at a similar cost. They issued over 200 Form 835 (deficiency or fix-it ticket) to facility owners. The facilities that do not show progress, or have a plan for moving forward, will receive Notice of Violations (NOA) and monetary fines will follow. This level of inspection is expected to continue into the foreseeable future. AEA intends to use the Coast Guard’s effort to leverage funding and resources to maximize the impact of the Bulk Fuel Upgrade Program and associate Maintenance and Improvement projects. This represents a program cost savings of approximately 1.4M which can now be used for projects. Follow Up An advisory subcommittee for rural Alaska bulk fuel facilities has been formed under the Arctic and Western Alaska Area Committee. Agencies on the subcommittee currently include AEA, CG, DEC, and DCRA. The CG and DEC are both regulatory agencies without the resources or responsibility to provide assistance while AEA and DCRA have programs that are aimed at providing assistance. Page 2 of 2 It is AEA and DCRA’s intent to coordinate with the CG and focus their available training and technical resources on the eligible facilities that need assistance. The CG inspections provide a good data point on the condition and the administration of rural bulk fuel facilities. This data will be used to assist with the ranking and prioritization of AEA’s assistance programs as required by 3 AAC 108.110. The goal is compliance with the regulations. This will help ensure personnel and environmental safety by preventing spills. Cooperation between agencies will pool resources and information to assist the eligible rural facility owners with compliance, training, and in some cases deferred maintenance. Page 1 of 2 AEA Board Update – Tuluksak Status Report February 21, 2020 Current Status The power plant has two operable diesel engine generator sets and the plant is in good order. They have some spare parts in stock; E.G. filters, oil, water pumps, injectors. They have acquired some necessary minor maintenance tools and PPE. One of the two gensets has a manageable oil leak. The switch gear requires an upgrade to correctly parallel the two gensets. One radiator requires repair of a failed motor controller. The diesel fuel day tank’s automatic fill pump requires replacement. They only have one operator, Harry. There does not appear to be a backup for him. The enclosed genset use for electrical emergency is still on site but disconnected from the local grid. The plan is to backhaul it to Bethel once barge service is available. Coordinating with School regarding recent problems with their power system – initiating interconnection. Utility Management Assistance AEA will provide assistance to Tuluksak Traditional Utility thru February 2021. This assistance will involve in person training, technical assistance, email based assistance, and phone based training/assistance. AEA staff will coordinate with DCRA to leverage resources that speed up the project schedule and reduce resource allocation. Tuluksak Cost Summary Utility Training _______________________________________ $89,000 Maintenance and Improvement (M&I) Project. Replace one genset and appurtenances Diesel Emission Reduction Act Project (DERA) Project. Replace one genset and upgrade switchgear Page 2 of 2 Emergency Response (Completed June 12, 2019). Flying a self-contained emergency standalone generator and connection to electrical distribution.____________________________________ $348,425 Previous Six Emergency Reponses & Thirty-three Circuit Rider Contacts___________________ $134,000 Responses 2004 - 2017 ______________________________________ $306,007 Previous Energy Projects 2004 - Present ____________________________________ $2,929,356 Total ____________________________________ $3,806,788 Page 1 of 2 2019/2020 AEA Community Outreach Schedule Last modified on February 19, 2020 # Status Date Organization AEA Staff 1. Past November 18, 2019 Alaska Municipal League Annual Conference Tom Benkert 2. Past November 21, 2019 Alaska Municipal League Annual Conference Jeff Williams 3. Past December 5, 2019 BIA Tribal Providers Conference Curtis W. Thayer 4. Past December 9, 2019 Anchorage Chamber of Commerce Curtis W. Thayer 5. Past December 18, 2019 Chugiak-Eagle River Chamber of Commerce Curtis W. Thayer 6. Past January 10, 2020 Commonwealth North’s Energy Action Coalition Curtis W. Thayer 7. Past January 29, 2020 Alaska Power Association’s Legislative Conference Curtis W. Thayer 8. Past January 29, 2020 Senate Special Committee on the Railbelt Electric System Curtis W. Thayer 9. Past January 30, 2020 House Subcommittee Curtis W. Thayer 10. Past January 30, 2020 Senate Community & Regional Affairs Committee Curtis W. Thayer 11. Past February 4, 2020 Southeast Conference Mid-Session Summit Curtis W. Thayer 12. Past February 5-7, 2020 National Association of State Energy Officials Curtis W. Thayer 13. Past February 10-14, 2020 Alaska Forum on the Environment AEA Team Members: “ a. Welcome Remarks during Keynote Event: Alaska Beyond Oil Panel T.W. Patch “ b. Renewable Energy & Rural Alaska Powerhouse Panel Bill Price “ c. Bulk Fuel Tank Farm Updates: Construction, Training, & Regulations Panel Bill Price “ d. The Shines in Alaska: Solar Power Projects on the Railbelt Panel Tom Benkert “ e. Harvesting Energy from Wood & Waste: Biomass & Landfill Gas Fuels in Alaska Panel Taylor Asher “ f. Electric Vehicles Panel Betsy McGregor “ g. Solar Power in Rural Alaska Panel David Lockard “ h. The Low-Hanging Fruit of Energy Savings Panel Rob Jordan “ i. New Hydropower Energy for Alaska Panel Bryan Carey “ j. Rooftop Solar in your Alaskan Community Tom Benkert “ k. Capturing the Wind Across Alaska: Large Scale Wind Projects Panel Kirk Warren “ l. Clean Energy Financing Panel Tom Benkert Page 2 of 2 14. Past February, 11, 2020 Community & Regional Affairs Committee Curtis W. Thayer 15. Upcoming February 20, 2020 Greater Wasilla Chamber of Commerce Curtis W. Thayer 16. Upcoming March 10, 2020 Greater Fairbanks Chamber of Commerce Curtis W. Thayer 17. Upcoming April, 21, 2020 (Tentative) Homer Chamber of Commerce Curtis W. Thayer 18. Upcoming To Be Determined, 2020 Greater Palmer Chamber of Commerce Curtis W. Thayer 19. Upcoming To Be Determined, 2020 Bethel Chamber of Commerce Curtis W. Thayer 20. Upcoming To Be Determined, 2020 Kenai/Soldotna Chamber of Commerce Curtis W. Thayer AEA LOAN DASHBOARD REPORT AEA POWER PROJECT LOAN FUND YEAR TO DATE 07/01/2019 LOAN ACTIVITY EARNINGS START DATE LOAN CATEGORY STARTING BALANCE FUNDS DISBURSED PAYMENTS RECEIVED ENDING BALANCE INTEREST RECEIVED LATE FEES RECEIVED INTEREST + LATE FEES 20 AEA POWER PROJECT FUND LOANS 23,690,152 4,514,324 (230,703) 27,973,773 211,367 199 211,566 TOTAL # OF PPF LOANS 1 # OF DELINQUENT PPF LOANS Outstanding Loans per Trial Balance 27,973,773$ $3,703 Uncommitted Cash Balance 10,358,508$ LOANS DELINQUENT AMOUNT ($)Loan Commitments 58,569$ 0.012%Total Loan Program 38,390,850$ % OF DELINQUENT LOANS TO PORTFOLIO BALANCE 01/31/2020 END DATE FISCAL YEAR-TO-DATE LOAN PORTFOLIO ACTIVITY (07/01/2019 - 01/31/2020 ) Waterfall Creek Hydro - King Cove, Alaska Print Date: 2/7/2020 Page 1 of 2 AEA POWER PROJECT FUND LOANS BY ENERGY REGION & PROJECT TYPE OUTSTANDING BALANCES & NEW ACTIVITY ENERGY REGION AEA PPF LOAN BALANCE REMAINING LOAN COMMITMENTS NEW APPLICATIONS IN PROCESS # OF AEA PPF LOANS TOTAL ALEUTIANS 2,583,460 - 65,000 4 2,648,460 BERING STRAITS - - - 0 - BRISTOL BAY 470,506 - 514,500 2 985,006 COPPER RIVER/ CHUGACH - - - 0 - KODIAK 86,104 - - 2 86,104 LOWER YUKON- KUSKOKWIM 399,117 - - 2 399,117 NORTH SLOPE - - - 0 - NORTHWEST ARCTIC - - - 0 - RAILBELT 4,179,600 - - 3 4,179,600 SOUTHEAST 20,059,615 293 924,153 3 20,984,061 YUKON-KOYUKUK/ UPPER TANANA 195,371 58,276 2,258,829 4 2,512,476 27,973,773 58,569 3,762,482 20 31,794,824 TOTAL BIOMASS $107,592 CONSERVATION $13,104DIESEL $1,015,678 HYDRO $24,910,185 SOLAR $801,112 TANK FARM $2,258,829 WIND $2,688,324 AEA PPF LOANS BY PROJECT TYPE -NEW & OUTSTANDING BALANCE BIOMASS 1 CONSERVATION 1 DIESEL 5 HYDRO 7 SOLAR 1 TANK FARM 1 WIND 4 AEA PPF LOANS BY PROJECT TYPE Print Date: 2/7/2020 Page 2 of 2 PPF Loan #Borrower Principal Amount Date Committed Remaining Payment Obligation Line of Credit Maturity Date Payment Start Date Loan Maturity Date Payment Schedule Scheduled Payment Amount Payment Per Year Comments 40901033 City of Larsen Bay $ 528,584 7/1/89 $ 73,000 6/30/07 7/1/21 annual $ 35,000 $ 35,000 40901099 Aleutian Wind $ 815,575 12/21/06 $ 616,892 7/1/13 1/1/33 semi-annual $ 32,517 $ 65,034 40901101 City of Atka $ 705,818 2/6/08 $ 543,764 1/1/14 7/1/33 semi-annual $ 27,295 $ 54,590 40901112 Southfork Hydro $ 2,070,000 7/30/12 $ 1,886,556 7/1/14 1/1/44 semi-annual $ 68,755 $ 137,510.40 40901115 Haida Energy $ 20,000,000 7/9/14 $ 20,000,000 4/1/20 3/17/66 quarterly $ 108,696 $ 434,783 40901118 AK Enviro Power $ 1,906,285 7/10/12 $ 1,491,931 1/1/15 4/14/32 semi-annual $ 82,002 $ 164,005 40901127 Kwigillingok $ 400,000 12/10/14 $ 188,620 7/1/17 4/1/22 quarterly $ 21,718 $ 86,871 40901128 Arctic Village $ 100,000 2/16/15 $ 45,255 1/1/17 9/1/24 quarterly $ 2,886 $ 11,546 40901132 King Cove $ 1,422,803 11/6/15 $ 1,422,803 10/1/19 10/1/57 semi-annual $ 30,790 $ 61,580 40901133 Newtok $ 235,139 11/18/15 $ 210,497 11/1/17 12/31/31 monthly $ 1,852 $ 22,219 40901134 Akhiok $ 37,800 8/5/16 $ 13,104 1/1/17 10/1/21 quarterly $ 2,083 $ 8,330 40901137 Tanacross $ 117,000 3/19/18 $ 107,592 2/1/19 1/1/29 monthly $ 1,179 $ 14,151 40901139 Tanalian $ 500,000 5/22/18 $ 470,506 10/1/18 7/1/38 quarterly $ 9,014 $ 36,057 40901140 Takotna* $ 100,800 11/19/18 $ 42,524 6/30/20 8/1/20 8/1/30 monthly $ 973 $ 11,680 *Estimated, not yet termed, in LOC draw period 40901142 City of Pelican- Controls* $ 59,908 4/2/19 $ 59,615 3/19/20 4/1/20 4/1/22 monthly $ 1,771 $ 21,247 *Estimated, not yet termed, in LOC draw period 40901143 AK REP-Willow Solar $ 814,234 6/25/19 $ 801,112 1/1/20 7/1/49 semi-annual $ 22,972 $ 45,945 TOTALS 29,813,945$ 27,973,773$ TOTAL CASH IN 1,210,547$ SUMMARY Uncommitted Cash Balance 10,358,508$ Less Pending Applications (3,762,482)$ Cash Available for New Applications 6,596,026$ 1,210,547$ Cash Available 6,596,026$ Cash Forecast FY 2020 7,806,573$ PPF Cash Flow Forecast for FY2020 (as of 1/31/20) Cash In/Loan Pyts Page 1 of 3 $0 $200,000 $400,000 $600,000 $800,000 $1,000,000 $1,200,000 $1,400,000 $1,600,000 $1,800,000 $2,000,000 2020202120222023202420252026202720282029203020312032203320342035203620372038203920402041204220432044204520462047204820492050205120522053205420552056205720582059206020612062206320642065206620672068206920702071Fiscal Year PPF Loan Payment Chart 1/31/2020 City of Larsen Bay Aleutian Wind City of Atka Southfork Hydro AK Enviro Power Kwigillingok Arctic Village King Cove Newtok Akhiok Tanacross Tanalian Takotna*City of Pelican- Controls*AK REP-Willow Solar Haida Energy Total Page 2 of 3 PPF Loan #Borrower Principal Amount Date Committed Payment Start Date Loan Maturity Date Payment Schedule Scheduled Payment Amount Payment Per Year Comments 40901144 St. George* $ 65,000 7/9/19 1/1/21 1/1/31 monthly $ 651 $ 7,808 *Estimated. Pending - Incomplete application 40901145 Pilot Point* $ 514,500 6/3/19 1/1/21 1/1/31 semi-annual $ 30,966 $ 61,933 *Estimated. Pending - Incomplete application 40901146 Nunapitchuk Ltd - Tank Farm* $ 2,258,829 10/16/19 1/1/21 1/1/51 semi-annual $ 61,033 $ 122,065 *Estimated. Pending - Incomplete application 40901147 Baxter Senior Living (CHP) $ 924,153 1/31/20 3/1/20 3/1/40 monthly $ 5,218 $ 62,616 *Estimated. Pending TOTALS 3,762,482$ TOTAL CASH IN 254,422$ PPF Pending Applications for FY2020 (as of 1/31/20) Page 3 of 3 Award No Project Name DC Funding Perf. Period Beg Perf. Period Thru 01349-09 RPSU - Togiak-Twin Hills Intertie 4,187,221.45$ 2/15/2011 9/30/2021 01432-08 BFU - Tatitlek 1,472,000.00 6/1/2013 12/31/2020 01473-06 RPSU - Clark's Point 2,819,700.00 6/16/2015 6/30/2020 01474-06 BFU - Chalkytsik 517,500.00 6/16/2015 12/31/2020 01485-04 START Communities Tech Asst 375,000.00 11/1/2015 6/30/2022 01492-07 BFU - Beaver 608,000.00 7/6/2016 12/31/2020 01500-05 Bulk Fuel Operator Training 750,000.00 9/1/2016 12/31/2020 01515-06 Circuit Rider Program 600,000.00 1/1/2017 12/31/2020 01516-06 RPSU - Maintenance & Improvement 748,776.00 10/1/2016 12/31/2020 01523-05 Miscellaneious Small M&I Projects 520,000.00 6/1/2017 12/31/2020 01524-03 RPSU - Port Heiden 1,250,000.00 7/1/2017 6/30/2020 01525-04 Power Plant Operator Training 467,514.00 8/15/2017 9/30/2020 01544-03 Itinerant Utility Training 500,000.00 3/1/2018 6/30/2021 01548-05*RPSU M&I - Statewide 2,550,000.00 5/1/2018 12/31/2020 *Amendment in progress 01549-03 RPSU Inventory & Assessment - Statewide 300,000.00 4/18/2018 9/30/2020 01550-02 RPSU - Akhiok 1,500,000.00 5/1/2018 12/31/2020 01551-04*RPSU - Venetie 250,000.00 5/1/2018 *12/31/2019 *Amendment in progress 01557-02 Barge Headers and Fill Lines 3,976,820.00 10/1/2018 12/31/2022 01571-00 BFU - Nunapitchuk 1,852,546.00 8/15/2019 12/31/2021 01573-00 BFO In Community Training 40,000.00 8/15/2019 3/31/2020 01574-00 RPSU - Nikolai 351,050.00 8/1/2019 12/31/2020 01575-00 RPSU - Nelson Lagoon 135,455.00 8/1/2019 3/31/2020 01576-00 RPSU - Rampart 351,050.00 8/1/2019 12/31/2020 01577-00 RPSU - Napaskiak 135,455.00 8/1/2019 3/31/2020 01589-00 2020 Rural Energy Track 10,000.00 1/1/2020 3/31/2020 XXXXX-00*BFU - Scammon Bay 300,000.00 2/17/2020 3/31/2021 *Application in progress Total Funding for Active DC Awards:26,568,087.45$ Less Total Spending on Active DC Awards:(7,294,057.66) Total Funding Remaining on Active DC Awards:19,274,029.79$ Active Denali Commission Awards As of 02/10/2020 Alaska Energy Authority Page 1 of 1 Page 1 of 2 AEA Board Update – VW Settlement February 24, 2020 Status of Alaska’s administration of VW State Environmental Mitigation Trust The State of Alaska is a Beneficiary of the State Environmental Mitigation Trust (Trust) established under the VW Settlement. The Alaska Energy Authority (AEA) is the Lead Agency administering the $8.1 million awarded for funding eligible mitigation actions that result in a total lifetime reduction of NOx emissions by 10.5 short tons. The projects that have been selected thus far will reduce NOx emissions by more than 2.5 times Alaska’s mitigation goal. Below is a summary of the disbursement of funds to date. Replacement of Diesel Engines used for Prime Power (Approximately $813K+match funds) AEA has set aside Trust funds as voluntary match for AEA’s Diesel Emission Reduction Act (DERA) program to fully leverage the federal funds allocated to the state by the EPA. By contributing the voluntary match, the state is able to receive 50% more EPA DERA funds to replace diesel engines or gensets in rural powerhouses. Communities that will replace engines/gensets are: Circle - 2 Takotna - 2 Tuluksak - 1 Chignik Lake – 2 Anvik – 1 Arctic Village – 3 Chenega Bay – 2 Public Transit Bus Replacement (Approximately $234K) AEA’s solicitation for public transit bus upgrade/replacement closed June 2019. AEA received one application from the City and Borough of Juneau, Capital Transit. Capital Transit will purchase an all-electric transit bus and associated charging infrastructure. School Bus Replacement (Approximately $4.3M) Two requests for applications (RFA) were released in 2019 for the upgrade/replacement of eligible diesel school buses. A total of 33 applications were submitted. Given the public support for school bus replacement (>50%) and the amount of applications received, in January 2020 AEA reallocated the $800,000 of Trust funds that had been intended for marine engine upgrades to replace the school buses proposed in the oversubscribed applications. The following are school districts served: Page 2 of 2 Anchorage - 13 Matanuska-Susitna Borough - 4 Kenai Peninsula Borough - 7 Juneau - 1 Kake City - 2 Southeast Island (Prince of Wales Island) - 4 Kodiak Island - 1 Alaska Gateway (Tok) – 1 Electric Vehicle (EV) Charging Infrastructure (Approximately $1.2M + match funds) Alaska intends to allocate 15% of the Trust funds (~$1.2 million) to EV charging infrastructure over the next couple of years. AEA has been working with a variety of stakeholders on siting the charging stations to establish an EV charging corridor, reduce range anxiety, and facilitate EV adoption. AEA has submitted a grant application to DOE to fully leverage the state’s Trust funds with federal funding; a response is anticipated in the spring of 2020. Skagway close to plugging in first public electric vehicle charging station Feb 10, 2020 | Borough, Featured, Headlines, Local, News, Stories By Aly De Angelus Skagway is joining the growing list of communities to install electric vehicle charging stations. As an added incentive, Alaska Power & Telephone Co. (AP&T) gave the charging station to the municipality for free. Borough Manager Brad Ryan is looking at installation logistics and expects to have the outlet up and running by spring. There are a few questions that the borough still needs to settle. For starters, is one charging station enough to make a difference in the community? “It would be much better if we could get more than just a single car to drive around Whitehorse and plug Skagway Tours and Shore Excursions NEWS PHOTOS POLICE & FIRE BLOTTER COLUMNS PEOPLE CLASSIFIEDS SKAGUAY ALASKAN DINING GUIDE 2020 0 ITEMSInternship • Contact • Advertise • Subscribe • SEARCH Page 1 of 12 in,” Assemblymember Orion Hanson said. “That’s kind of the goal here, for human activity between here and Juneau, where it’s feasible for people to travel with an electric vehicle.” Juneau has more than 300 electric vehicles and about a dozen public charging stations. The Yukon Territory has about a dozen charging stations, too. And the territorial government released a draft proposal late last year to strive for 6,000 electric vehicles in use by 2030 — one of every six passenger vehicles in the territory. Ryan does not think it will be an issue to land three or four more charging units by July. Estimated cost for each station is $7,000 and a couple thousand per installation. The location has yet to be determined, though there is talk of settling near the waterfront so cars traveling by ferry can get a quick charge. Some stations have a payment feature, but Ryan said the municipality will not charge for the power unless the bill becomes insurmountable. “It seems like a fairly easy project so we just thought we would slap this one in the spring to see how it goes and budget for another,” Ryan said. Electric vehicles are considered an environmentally friendly alternative to gas-powered vehicles. Charging stations in the state received a boost last year when the Alaska Energy Authority set aside $1.2 million for new installations, of which it allocated $125,000 for Southeast. It was part of Alaska’s $8.1 million share of a $2.95 billion penalty paid to the federal government by German automaker Volkswagen, which was caught installing software in cars that cheated government emissions tests. One requirement of the company’s 2015 settlement was to invest $2 billion in zero-emissions vehicle initiatives over a 10-year term. Page 2 of 12 By ALAN BAILEY For Petroleum News On Jan. 29 several stakeholders in the Alaska Railbelt electrical system testified to a joint meeting of the Senate Railbelt Electric System Committee and the House Special Committee on Energy regarding two bills being considered dur- ing the current Alaska legislative session. The bills, Senate Bill 123 and House Bill 151, would give the Regulatory Commission of Alaska regulatory author- ity over an electric reliability organization for the Railbelt, and would also give the commission authority to review and pre- approve changes and additions to major generation and transmission facilities. In a previous joint meeting of the com- mittees the Railbelt electric utilities pre- sented their testimony on the two bills. The Jan. 29 meeting gathered testimony from other system stakeholders: the Renewable Energy Alaska Project, the Alaska Energy Authority, the Alaska Independent Power Producers Association and the Alaska Public Interest Research Group. Overall, the organizations expressed support for the legislation. Purpose of legislation The Railbelt electricity system, extend- ing from the southern Kenai Peninsula north through Southcentral Alaska to the Fairbanks region, is owned and operated by six independent electric utilities and the State of Alaska. The purpose of imple- menting an electric reliability organiza- tion, or ERO, regulated by the RCA and with RCA oversight of major changes to the electrical system, is to achieve a more coordinated and efficient approach to the operation of the system. In December all the utilities signed a memorandum of understanding for the formation of the Railbelt Reliability Council, or RRC, an organization that would constitute an ERO for the Railbelt. Formation of the RRC is moving ahead. However, the intent is to establish RCA regulation of the organization before the organization goes into operation: hence a primary purpose of enacting legislation as expressed in SB 123 and HB 151. The RCA is concerned that current statutes do not give it clear regulatory authority over an organization such as the RRC. The RRC would maintain and mandate reliability standards; administer rules for open access to the grid; conduct Railbelt- wide system planning; and investigate the economic value of security constrained economic dispatch for all or part of the system. Economic dispatch involves the continuous use of the most cost-effective power generation that is securely avail- able. REAP’s perspective Chris Rose, executive director of Renewable Energy Alaska Project, expressed his organization’s support for the legislation as proposed, including RCA oversight of the RRC or, should the RRC not be implemented, the authority of the RCA to mandate the formation of a similar organization. Rose commented on the evolving nature of the electricity industry, includ- ing the growth in the use of renewable energy sources and the dramatic fall in the cost of energy sources such as wind and solar power. Concerns about climate change and the carbon impact of electric- ity supplies are also impacting business decisions about where electricity consum- ing businesses will locate their operations, he said. REAP thinks that reform of the Railbelt electrical system would create a more level playing field for renewable energy producers, stabilize electricity prices, decrease greenhouse gas emis- sions, attract new investment and help diversify the economy, Rose said. However, Rose did express some con- cern about the governance structure of the RRC — questions over governance revolve around the need to balance the interests of the utilities with the interests of a broader spectrum of stakeholders in the electrical system. The governance board of the organization would have 12 members, plus the organization’s CEO, who would have a tie-breaking vote on board decisions. Six board members would represent the six Railbelt utilities and six members would represent other stakeholders. But one of those other stake- holders would be the Alaska Energy Authority, a state entity that owns genera- tion and transmission assets and, thus, acts in effect as a seventh utility, Rose suggest- ed. That would give utility interests a majority on the board, he said. REAP would also like to see a require- ment that any minority views expressed during RRC integrated resource planning for the electrical system must be reported to the RCA, Rose said. However, he also commented that meetings with the utili- ties over the last year and a half have been very productive, and he criticized a recent effort to completely rewrite SB 123. AEA support Curtis Thayer, executive director of Alaska Energy Authority, commented on AEA’s perspective, especially given the agency’s ownership of the Bradley Lake hydropower facility in the southern Kenai Peninsula and of the transmission intertie between Southcentral Alaska and the more northerly sector of the transmission grid. He said the proposed legislation would not impact the state’s rights and responsibilities for budgeting improve- ments to the state-owned facilities, and that the utilities manage the facilities through the Bradley Project Management Committee and the Intertie Management Committee. Thayer said that that the manner in which SB 123 expresses legislative intent, ensuring appropriate RCA oversight, rather than being over prescriptive, is appropriate. SB 123 is the right vehicle at the right time to address long-sought insti- tutional reform, he said. Independent power producers Duff Mitchell, executive director of Alaska Independent Power Producers Association, said that his organization has been working with the utilities and the RCA to promote the use of more compet- itive power generation in the state. Whereas in the United States as a whole 42% of power comes from independent producers, in Alaska only 4% of power is independently generated, he commented. Mitchell said that, while SB 123 and HB 151 are not perfect, his organization does support them. Key issues for his organization are the need for an open access tariff for use of the transmission grid, the need for an independent board of directors for the ERO and the need for RCA authority over the ERO. He empha- sized the growing importance of dealing with cybersecurity, as part of security oversight of the electrical system, and the importance of regional integrated resource planning, with RCA pre- approval needed for major projects. He also said his organization would like to see stronger language in the legis- lation for ensuring open access to the elec- trical grid. However, Mitchell said that his organ- ization sees the proposed legislation and the formation of an ERO for the Railbelt as foundational to achieving lower elec- tricity costs in the region. Public interest group Veri Di Suvero, executive director of Alaska Public Interest Research Group, commented that electricity costs in the Railbelt are among the highest in the nation and that the two bills form a critical step towards improved efficiency in the electrical system. She said that her organ- ization is nonpartisan and nonprofit, rep- resenting the interests of the public and consumers, including advocating for ratepayers. She emphasized the impor- tance of regional planning in achieving efficiencies. AKPIRG would like to see a mandate for public participation as well as public comment in planning processes and ensure that the RCA has full regulatory oversight of the RRC. However, the prior- ity at this point needs to be passage of the legislation, without that passage being slowed by major changes, Di Suvero sug- gested. The bills, as written, substantially serve the interests of consumers and the public, she said.l l UTILITIES More support for electric system bills Stakeholders in the Railbelt electrical system provide testimony to joint Senate and House committees over SB 123 and HB 151 PETROLEUM NEWS • WEEK OF FEBRUARY 16, 2020 3 Real Alaskan go.gns. Real car . 7 ere delivou need, wer yve umberLr.. Siding. Insulation. Whatevve yo we ver.. CONNECT WITH US /800.727..2141 /w .nac.aerwwww.roo / of the overlying K-3 Basal Siltstone away from existing well control.” AOGCC has tentatively scheduled a hearing on the request for March 17 at 10 a.m. at its Anchorage offices but said in its Feb. 10 notice that if a timely request for a hearing is not filed, it may consider issuance of an order without a hearing. The commission will accept written comments through March 14 at 4:30 p.m., unless a hearing is held, in which case written comments will be accepted through the end of the hearing.l continued from page 2 QANNIK POOL The RCA is concerned that current statutes do not give it clear regulatory authority over an organization such as the RRC. Page 3 of 12 Page 4 of 12 https://www.frontiersman.com/news/governor-keen-on-expanding-renewable-energy-resuming-work-on- susitna/article_b3696f30-5223-11ea-86ae-bb70d471d3e2.html FEATURED Governor keen on expanding renewable energy; resuming work on Susitna hydro seen as way to do it By Tim Bradner For the Frontiersman Feb 17, 2020 Gov. Mike Dunleavy Courtesy of Austin McDaniel/Alaska Governor’s O ce/ Gov. Mike Dunleavy is keen to expand renewable energy in the state. Page 5 of 12 Resuming work on the large Susitna hydroelectric project seems a good way to do it, promoters of Susitna are telling the governor. About $192 million has been spent by the state on the project since 2010. It was halted by former Gov. Bill Walker In 2014. Dunleavy cited the state’s goal of having renewable power meeting 50 percent of the state’s electricity needs by 2025 in his State of the State speech in January. The policy was adopted in state law in 2010. The governor is interested in what it would cost to complete the needed Federal Energy and Regulatory Commission license for the project. About 27 percent of Alaska’s electrical generation now comes from hydro, and that’s up from 21 percent in 2011, the state’s Alaska Energy Authority, or AEA, told the Senate Community and Regional A airs Committee Feb. 11. Building Susitna would bring the total over 50 percent. The Legislature authorized work to begin again on a Susitna project in 2011 but Walker stopped the work in 2014 when oil prices collapsed. However, two thirds of the work toward the has already been done, AEA told the House committee. Of 58 studies needed to support the Federal Energy and Regulatory Commission, 19 are completed and signi cant progress has been made on 39 others with the initial study reports led with the federal commission. A signi cant state investment has been made in the Susitna studies so far and costs to complete the work is estimated at about $50 million to $65 million. Until recently the Susitna project was looked on as a major source of new power for the state’s Interior and Southcentral “railbelt” communities. The project can supply about 50 percent of the power requirements in Interior and Southcentral Alaska. However, when a natural gas pipeline from the North Slope was planned, and which would make the large gas reserves on the slope available for power generation and space heating, there seemed to be less need for electricity from Susitna, which would be costly to build. But the gas pipeline now seems unlikely, at least for a while, due to the glut of natural gas on the world market. Also, the long-term outlook for natural gas reserves in Cook Inlet, which now fuels most power generation for the railbelt, seems uncertain.Page 6 of 12 While its initial capital costs would be large, once it is built Susitna could be a large source of power at stable prices for a hundred years or more, its backers say. About $11.2 billion in energy savings relative to natural gas are estimated over 50 years, AEA said in its presentation to the committee. Construction costs were estimated at $2.65 billion in 2014 with $627.3 million of this spent on labor. Susitna hydro has a long history. The rst studies of the region’s hydro potential were conducted by the U.S. Bureau of Reclamation in the 1950s. A large project planned in the 1970s would have involved two dams, one at Watana and one at Devil’s Canyon, but was cancelled by former Gov. Bill She eld in 1982. The project appeared to be uneconomic because of large capital costs and the relatively small populations of the “railbelt” communities at the time. Analysts told She eld then that the only was Susitna could be nanced would be if the Alaska Permanent Fund were to underwrite the project, the governor said later. She eld was unwilling to do that. The current Susitna project has been scaled back to one dam and with a lower construction cost. The regional population, and power demand, have also grown. It would still be a large project with a dam height of 705 feet and reservoir 42 miles long and 1.25 miles wide, the AEA told the House committees. In other energy-related legislation in Juneau the House Energy Committee took up HB 232 last week, which would reauthorize an air quality property tax credit for municipalities, like Fairbanks, that fail to meet federal air quality standards. The tax credit authorization, which would be against municipal tax obligations, lapsed in 2015. The tax credits would help Fairbanks area property owners nance energy conversions, Fairbanks Borough Mayor Bryce Ward told the committee. The bill would also establish a new construction energy credit which would be modeled on the Alaska Housing Finance Corp.’s energy compliance code. “This would help communities incentivize quality construction with a focus on energy e ciency, resulting in reduced community energy demand,” Ward told the committee in a letter. Page 7 of 12 Page 8 of 12 Post date: Wed, 02/19/2020 - 9:59am State dusts o look at Susitna-Watana hydro project Alaska Journal of Commerce Proponents of the massive Susitna-Watana hydro project contend it is the linchpin to making a large- scale shift to renewable energy in Alaska, but it’s unclear exactly what it would take for the state to dust o the shelved dam proposal. Former Gov. Bill Walker suspended the mega project through an administrative order in 2015 when the state was mired in a string of multibillion-dollar annual budget de cits. While the state’s scal situation has improved somewhat but is far from cured — the scal year 2021 de cit is pegged at roughly $1.5 billion — Gov. Mike Dunleavy lifted Walker’s freeze in 2019 as part of his overarching goal for the state to explore the gamut of economic development prospects available By: Elwood Brehmer (/authors/elwood-brehmer), Researchers walk along the Susitna River in this 2012 Alaska Energy Authority photo. The shelved Susitna-Watana dam was the subject of a Feb. 11 Senate hearing on whether e orts should resume on the massive hydropower project. (Photo/Frank Flavin/Alaska Energy Authority) (/) Page 9 of 12 Advertisement to Alaska. To that end, lawmakers heard from Alaska Energy Authority o cials what it would take to restart Susitna-Watana during a Feb. 11 Senate Community and Regional A airs Committee hearing. Alaska Energy Authority o cials who would lead the restarted project told legislators that they are about two-thirds done with the pre-licensing study work required by the Federal Energy Regulatory Commission before the state-owned authority could apply for the FERC license that would trigger a wholesale environmental and socioeconomic review of the plan. AEA estimated the 705-foot dam in the upper reaches of the Susitna River valley would cost roughly $5.6 billion in 2014 dollars. The hydro project would generate up to 619 megawatts of electricity — meeting about 60 percent of the Railbelt’s electricity demand — and would form a reservoir about 42 miles long and 1.25 miles wide, according to the authority. AEA Executive Director Curtis Thayer said AEA couldn’t resume work on Susitna-Watana without explicit direction from the Legislature and the governor, which would also have to include signi cant state funding to nish the environmental studies for the project. The hefty construction cost would be paid up front through bonds that would be repaid once the dam started producing power. Thayer told legislators he didn’t know speci cally how much it would cost to get through FERC licensing, but AEA o cials said when the project was suspended they needed about $100 million over four years to obtain the key federal construction license. “If it is greenlighted, obviously determining the licensing status would be the next step and then updating the cost estimate to obtain the license; updating the cost-bene t and economic analyses and then reviewing the data to make sure it remains re ective of the current conditions,” Thayer said. He added that AEA estimates power from the dam would cost about 6.5 cents per kilowatt before transmission costs are factored in, which is about 20 percent less than current costs for natural gas- red electricity in the Railbelt and about 40 percent more than existing hydropower in the region. According to AEA Hydro Group Manager Bryan Carey, power would likely start owing from the project after eight years of construction, though it wouldn’t be completely done for a couple years afterwards. Carey said AEA completed 19 studies and made “signi cant progress” on another 39 of the 58 total studies FERC approved for the project starting in 2012. However, dam opponents, led by the Susitna River Coalition point to a lengthy June 2017 determination report from FERC o cials on study requirements for the project as indication that advancing Susitna-Watana would require much more work than advocates claim. That report states that the agency partially approved changes recommended by third parties to 17 AEA studies covering baseline water quality data, the dam’s impact to ice formation, in-river sediment, sh passage and other issues.Page 10 of 12 Updated: 02/19/2020 - 10:05am It notes that AEA has conducted a signi cant amount of water quality data, but it’s di cult to tell if that data represents current conditions because it has not been fully vetted. “Consequently, we nd that in its current state, the (water quality) data are largely unusable, and we are also unable to determine the adequacy of the data to characterize baseline water chemistry, water quality, water temperature and groundwater of the Susitna River,” the 2017 FERC determination report states. The project was essentially frozen at that point. The report authors additionally state that it would be “premature to require AEA to essentially redo the study as requested by the commenters” until the authority has the chance to support its conclusions. AEA o cials emphasize that while the dam would restrict water ow in one of the state’s largest salmon-bearing drainages, it would be upriver of nearly all salmon habitat. That’s because Devil’s Canyon — about 20 miles downstream of the proposed dam site — acts as a natural sh barrier for all but a few chinook salmon. However, members of the Talkeetna-based Susitna River Coalition counter that operating the dam to meet energy demand would mean more stable year-round ows in the river that are counter to what juvenile salmon rearing in the river and its back channels have adapted to. The coalition further disputes claims that the dam would provide decades of clean power by displacing natural gas-generated electricity because the reservoir would inundate many thousands of acres predominantly spruce forests that would release carbon gasses as they decay. ^ Elwood Brehmer can be reached at elwood.brehmer@alaskajournal.com (mailto:elwood.brehmer@alaskajournal.com). Comments 0 Comments Sort by Facebook Comments Plugin Oldest Add a comment... Page 11 of 12 Alaska Journal of Commerce 300 W. 31st Avenue Anchorage, AK 99503 Phone: 907-257-4200 Outside Anchorage, toll-free: 800-478-4200 Copyright © Binkley Co. All rights reserved. Contact Us (/contact) Page 12 of 12 REDUCING THE COST OF ENERGY IN ALASKA Alaska Energy Authority Curtis W. Thayer Executive Director Alaska Energy Authority House Finance Subcommittee January 30, 2020 Who We Are Created in 1976 by the Alaska Legislature, the Alaska Energy Authority (AEA) is a public corporation of the State of Alaska governed by a board of directors with the mission to “reduce the cost of energy in Alaska.” AEA is the state's energy office and lead agency for statewide energy policy and program development. Alaska Energy Authority 2 What We Do Energy Planning –In collaboration with local and regional partners, AEA provides critical economic and engineering analysis to plan the development of cost effective energy infrastructure. Grants and Loans –AEA provides loans to local utilities, local governments, and independent power producers for the construction or upgrade of power generation and other energy facilities. Railbelt Energy –AEA owns the Bradley Lake Hydroelectric Project and the Alaska Intertie. These assets benefit Railbelt consumers by reducing the cost of power. Renewable Energy –AEA provides renewable energy and energy efficiency grants, analysis, and expertise to benefit Alaskans. These include hydro, biomass, wind, solar, and others. Power Cost Equalization –The Power Cost Equalization Program reduces the cost of electricity in rural Alaska for residential customers and community facilities. Rural Energy –AEA constructs bulk fuel tank farms, diesel powerhouses, and electrical distribution grids in rural villages. AEA supports the operation of these facilities through circuit rider and emergency response programs. Alaska Energy Authority 3 Our Projects AEA works with its Alaska partners and stakeholders to provide reliable and affordable energy solutions. Alaska Energy Authority 4 Bradley Lake Hydroelectric Project Alaska Intertie Bulk Fuel Upgrades Rural Power System Upgrades Rural Utility Assistance Power Cost Equalization Renewable Energy Fund Grants Power Project Fund Loans Alaska C-PACE Alternative Energy Energy Efficiency Energy Project Development Programs and Projects Alaska Energy Authority 5 Bradley Lake Hydroelectric Project Produces ~10% of Railbelt electricity, 4.5 cents/kWh Benefits members of: Chugach Electric Association City of Seward Golden Valley Electric Association Homer Electric Association Matanuska Electric Association Municipal Light & Power Battle Creek Diversion Project:$47 million, will add ~10% energy Alaska Energy Authority 6 Alaska Intertie 7 170 miles from Willow to Healy Allows Golden Valley Electric Association (GVEA) to connect to and benefit from lower cost power Improves reliability within Railbelt system Operated by AEA and Railbelt utilities $40 million savings for GVEA in Fiscal Year 2019 Alaska Energy Authority 7 Bulk Fuel TankFarm Upgrades Code compliant fuel storage facilities Prevention of spills and contamination Reduction of fuel cost by allowing the community to purchase bulk quantities 118 projects completed since 2000 Alaska Energy Authority 8 Rural PowerSystem Upgrades 9 Alaska Energy Authority 9 Improving power system efficiency, safety, and reliability Building code compliant facilities to provide stable and reliable power ~10% to 20% efficiency improvement in diesel generation 86 projects completed since 2000 Rural Utility Assistance 103 Communities received circuit rider and rural utility worker assistance in Fiscal Year 2018 38 Communities received training in Fiscal Year 2018 6 Communities assisted with electrical emergencies in Fiscal Year 2018 Alaska Energy Authority 10 110History –Established in 1985, the Power Cost Equalization (PCE) Program provides electric power to rural residential customers and community facilities at costs similar those in Anchorage, Fairbanks, and Juneau PCE Endowment Fund –Created and capitalized in Fiscal Year 2001, the $1.1 billion PCE Endowment Fund is managed by the Department of Revenue Calculation of PCE Rate –The Regulatory Commission of Alaska determines the effective rate based on rural utility expenses and power sales Power Cost Equalization Program Alaska Energy Authority 11 PCE Impact 194 Communities Served $27 Million Disbursed in Fiscal Year 2018 Supported by AEA Rural Utility Assistance Web Portal to Increase Accuracy $ Renewable Energy Fund $268 million invested in the Renewable Energy Fund (REF) by the State Boosted renewable energy market in Alaska Leveraged hundreds of millions of federal and private dollars 90 operational projects, 30 in development Displacing ~30 million diesel equivalent gallons annually ~$74 million in fuel savings in 2017 Power Project FundLoan Program $27.5 million committed or disbursed for 20 loans $10.7 million uncommitted Flexible loan program Covers all aspects of supply side system Relies on unique, in-house technical expertise for evaluation of loan viability and regulatory compliance Loan applications are vetted for economic and finance viability Critical resource in shift from grant funded to debt financed energy projects Alaska Energy Authority 14 Alaska C-PACE Adopted by over 20 states, Commercial Property Assessed Clean Energy (C-PACE) is an effective financing program tool to attract private capital for energy upgrades In 2017, legislation was passed to develop a C-PACE program in Alaska AEA is leading an ad hoc group of stakeholders to initiate programs in municipalities and boroughs statewide Under the C-PACE model, debt associated with doing the improvements is repaid via a line item on local tax assessments Alaska Energy Authority 15 Alternative Energy and Energy Efficiency Biomass AEA’s biomass program supports the construction of wood-fired boilers using local fuels that provide heat for public facilities. Energy Efficiency AEA focuses its energy efficiency programs on commercial buildings, public buildings, industrial facilities, and electrical efficiency. Hydroelectric In addition to Bradley Lake, AEA continues to analyze, develop, construct, and fund hydroelectric projects throughout Alaska. Wind AEA supports the development and construction of wind projects across Alaska – from the Railbelt Grid to rural villages. Alaska Energy Authority 16 AEA Org Chart Alaska Energy Authority 17 AEA FY2021 Budget (thousands) Alaska Energy Authority 18 AEA FY2021 Capital Budget (thousands) Alaska Energy Authority 19 Unaudited Financial Highlights (thousands) Alaska Energy Authority 20 Unaudited Financial Highlights (thousands) Alaska Energy Authority 21 PCE Endowment History (thousands) Alaska Energy Authority 22 AEA provides energy solutions to meet the unique needs and opportunities of Alaska’s rural and urban communities. REDUCING THE COST OF ENERGY IN ALASKA SAFE, RELIABLE, & AFFORDABLE ENERGY SOLUTIONS ALASKA ENERGY AUTHORITY 813 West Northern Lights Blvd. Anchorage, Alaska 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Toll Free (888) 300-8534 akenergyauthority.org For more information, please contact AEA Executive Director Curtis W. Thayer REDUCING THE COST OF ENERGY IN ALASKA REDUCING THE COST OF ENERGY IN ALASKA Alaska Hydropower Curtis W. Thayer Executive Director Alaska Energy Authority Community and Regional Affairs Committee January 30, 2020 Who We Are Created in 1976 by the Alaska Legislature, the Alaska Energy Authority (AEA) is a public corporation of the State of Alaska governed by a board of directors with the mission to “reduce the cost of energy in Alaska.” AEA is the state's energy office and lead agency for statewide energy policy and program development. Alaska Energy Authority 2 What We Do Energy Planning –In collaboration with local and regional partners, AEA provides critical economic and engineering analysis to plan the development of cost effective energy infrastructure. Grants and Loans –AEA provides loans to local utilities, local governments, and independent power producers for the construction or upgrade of power generation and other energy facilities. Railbelt Energy –AEA owns the Bradley Lake Hydroelectric Project and the Alaska Intertie. These assets benefit Railbelt consumers by reducing the cost of power. Renewable Energy –AEA provides renewable energy and energy efficiency grants, analysis, and expertise to benefit Alaskans. These include hydro, biomass, wind, solar, and others. Power Cost Equalization –The Power Cost Equalization Program reduces the cost of electricity in rural Alaska for residential customers and community facilities. Rural Energy –AEA constructs bulk fuel tank farms, diesel powerhouses, and electrical distribution grids in rural villages. AEA supports the operation of these facilities through circuit rider and emergency response programs. Alaska Energy Authority 3 Our Projects AEA works with its Alaska partners and stakeholders to provide reliable and affordable energy solutions. Alaska Energy Authority 4 Bradley Lake Hydroelectric Project Alaska Intertie Bulk Fuel Upgrades Rural Power System Upgrades Rural Utility Assistance Power Cost Equalization Renewable Energy Fund Grants Power Project Fund Loans Alaska C-PACE Alternative Energy Energy Efficiency Energy Project Development Programs and Projects Alaska Energy Authority 5 Hydropower Projects in Alaska Alaska Energy Authority 6 3 Projects in Construction 6 Projects in Design 51 Projects in Operation Alaska Electric Energy Generation (2017) Alaska Energy Authority 7 0% 25% 50% 75% 100% 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 Coal Natural gas Oil Wind Hydro18% 27% Two Types of Hydropower Projects Alaska Energy Authority 9 Traditional Storage projects tend to be more expensive, require terrain chokepoints, and require more time for permitting and construction. Bradley Lake Snettisham Susitna-Watana Swan Lake Sweetheart Lake Terror Lake Traditional Storage Alaska Energy Authority 10 Run of River projects are lower cost and tend to be permitted and constructed quicker. Delta Creek Five Mile Creek Gartina Falls Humpback Creek Knutson Creek Nuyakuk River Thayer Creek Run of River Important Terms Capacity of a generator is measured in megawatts (MW) or kilowatts (kW) at a single point in time. Project Energy is power over time. Commonly measured as Megawatt -hours (MWh) or kilowatt-hours (kWh). House on the Alaska Railbelt may use 500-600 kWh per month energy. Alaska Hydropower Projects in Operation Alaska Energy Authority 13 Alaska Hydropower Projects in Operation 51 operational hydropower projects in Alaska Three projects under construction to increase Statewide capacity by 5.5 MW to be completed in 2020 Projects in design/funding to increase capacity by nearly 491 MW 14 Alaska Energy Authority 14 State Involvement in Hydropower Projects State of Alaska owns over 40% of Statewide hydropower capacity Bradley Lake (AEA) Snettisham (AIDEA) State of Alaska through AEA/AIDEA has supported the development of more than two thirds of Statewide hydropower capacity Alaska Energy Authority 15 Bradley Lake Located 25 miles northeast of Homer and serves Railbelt Capacity of 120 MW Completed in 1991 Funding by State of Alaska and Railbelt utilities Owned by AEA and managed to maximum extent by Railbelt utilities Alaska Energy Authority 16 Located 30 miles southeast of Juneau and serves Juneau Capacity of 78 MW Initial completion of 1973 Funded by Federal Government Owned by AIDEA, managed by AEA, and operated by Alaska Electric Light & Power Snettisham Alaska Energy Authority 17 Four Dam PoolPower Authority AEA sold to local utilities in 2002 Solomon Gulch Swan Lake Terror Lake Tyee Lake Proceeds helped establish Power Cost Equalization Program Endowment Alaska Hydropower Projects in Construction Alaska Hydropower Projects in Construction Four projects under construction to increase Statewide energy by 5.5 MW to be completed in 2020. Gunnuk Creek Hidden Basin Hiilangaay West Fork Upper Battle Creek Alaska Energy Authority 19 Alaska Energy Authority 20 Gunnuk Creek Located in Kake, Alaska Capacity 0.5 MW Completion 2020 Funded by AEA grant and Inside Passage Electric Cooperative financing Owned by Inside Passage Electric Coop Located 22 miles southeast of Kodiak, and serves City of Kodiak and surrounding communities Capacity zero Completed December 2019 Financed and owned by Kodiak Electric Association Alaska Energy Authority 21 Hidden Basin Alaska Energy Authority 22 Located 8 miles East of Hydaburg and serve Prince of Wales Island Capacity 5 MW Completion 2020 Funded by AEA ,grants, loans and Alaska Power & Telephone Owned by Haida Energy Hiilangaay West Fork UpperBattle Creek Located 2 miles southwest of Bradley Lake dam Capacity zero Completion 2020 Funded by AEA grant and Railbelt utilities Owned by AEA Alaska Energy Authority 23 Alaska Hydropower Projects in Design Alaska Energy Authority 25 Alaska Hydropower Projects in Design Projects in design/funding to increase Statewide energy by greater than 491 MW hours Nuyakuk River Susitna-Watana Sweetheart Lake Thayer Creek Alaska Energy Authority 26 Located 50 miles north of Dillingham and would serve regional communities Capacity ~12 MW Completion date: TBD Funding: TBD Owned by Nushagak Electric & Telephone Cooperative 2019 Senate Bill 91 passed and allows for the development and operation of a hydro facility in the State Park Nuyakuk River Located ~125 miles northeast of Anchorage and serve Railbelt Average capacity 459 MW Average annual energy 2,800,000 MWh Completion Date: TBD Funding: TBD Owned by: TBD Alaska Energy Authority 27 Susitna-Watana 28 Alaska Energy Authority 28 Located 33 miles southeast of Juneau and serve region Capacity 19.9 MW Completion Date: TBD Funding: TBD Juneau Hydropower Inc. Sweetheart Lake Located 6 miles north of Angoon and serve Angoon Capacity 0.85 MW Completion Date: TBD Funding by AEA, Kootznoowoo Inc. and Inside Passage Electric Cooperative Owned by Kootznoowoo Inc. Alaska Energy Authority 29 Thayer Creek AEA provides energy solutions to meet the unique needs and opportunities of Alaska’s rural and urban communities. REDUCING THE COST OF ENERGY IN ALASKA SAFE, RELIABLE, & AFFORDABLE ENERGY SOLUTIONS ALASKA ENERGY AUTHORITY 813 West Northern Lights Blvd. Anchorage, Alaska 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Toll Free (888) 300-8534 akenergyauthority.org For more information, please contact AEA Executive Director Curtis W. Thayer REDUCING THE COST OF ENERGY IN ALASKA REDUCING THE COST OF ENERGY IN ALASKA Alaska Energy Authority Curtis W. Thayer, Executive Director Bryan Carey, Owned Assets/Hydro Group Manager Senate Community & Regional Affairs Committee February 11, 2020 Current Status Alaska Energy Authority 3 In 2014, Administrative Order (AO) 271 placed the Susitna-Watana Hydroelectric Project into abeyance In 2019, AO 306 rescinded AO 271 No state funds were spent in Fiscal Year 2019 State Energy Policy Alaska Energy Authority 4 In 2010, House Bill 306 was passed and set an aspirational goal to generate 50% of the state’s electricity from renewable and alternative energy sources by 2025 Why Large Hydro? Alaska Energy Authority 5 Oil & Gas 70% Coal 9% 21%Hydro 2011 Oil & Gas 65% Coal 6% 27%Hydro 2019 Why Susitna-Watana? 50% Railbelt energy demand Greater winter storage capacity Lower overall cost to develop Less complex project Fewer long-term operational uncertainties Stable, reliable, clean energy 100+ years AS 44.83.080 Powers of the Authority Alaska Energy Authority 7 (18) to acquire a Susitna River power project, whether by construction, purchase, gift, or lease, including the acquisition of property rights and interests by eminent domain under AS 09; (19) to perform feasibility studies and engineering and design with respect to power projects. Project History Alaska Energy Authority 8 2017 Licensing Abeyance Alaska Energy Authority 10 Dam Height: 705 feet Dam Elevation: 2,065 Feet MSL Reservoir Length: ~42 miles Reservoir Width: ~1.25 miles Installed Capacity: 459-619 MW Annual Energy: 2,800,000 MWh Cost: ~$5.655 billion (2014$) Project At a Glance Size and generation optimized Design reviewed by International Board of Consultants Designed to withstand: 10,000-year flood Maximum credible earthquake of a magnitude 8.0 2014 Engineering Feasibility Report Engineering Alaska Energy Authority 11 Economics Alaska Energy Authority 12 Benefit-Cost and Economic Impact Analyses completed in 2015 Based on 2014 projection of natural gas prices: Benefit-cost ratio of 2.39 from energy savings alone $11.2 billion (2014$) in energy savings over first 50 years $4.7 billion (2014$) in capital and O&M costs over first 50 years Employment Opportunities Alaska Energy Authority 13 Direct jobs: 5,000 preconstruction and non-construction direct jobs (2010-2028) 12,000 direct overall construction workforce Local spending and statewide multiplier effects (2014$): Alaska Energy Authority 14 Licensing Status Integrated Licensing Process 2/3 of the way done 58 FERC-approved studies: Implemented 2012-2017 19 studies completed 39 significant progress made Initial Study Report filed with FERC FERC Study Plan Determination Outcome Alaska Energy Authority 15 Confirmed adequacy of environmental studies Validated quality of work completed to date Rejected nearly all study modification requests Rejected requests for additional years of study Confirmed data gathered thus far is representative of baselines Rejected requests for additional studies Licensing activity currently in abeyance Alaska Energy Authority 16 Project Timeline Governor and Legislature Determine Next Steps If greenlighted… Determine licensing status Update cost estimate to obtain license Update benefit-cost and economic impact analyses Review data to assure it remains reflective of current conditions Consult with FERC, landowners, and other stakeholders REDUCING THE COST OF ENERGY IN ALASKA SAFE, RELIABLE, & AFFORDABLE ENERGY SOLUTIONS ALASKA ENERGY AUTHORITY 813 West Northern Lights Blvd. Anchorage, Alaska 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Toll Free (888) 300-8534 akenergyauthority.org For more information, please contact AEA Executive Director Curtis W. Thayer REDUCING THE COST OF ENERGY IN ALASKA 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG REDUCING THE COST OF ENERGY IN ALASKA February 10, 2020 Senator John Coghill Alaska State Legislature State Capitol Room 103 Juneau, Alaska 99801 Dear Chairman Coghill and Chairman Hopkins, I am writing in response to a question raised during my January 29, 2020, AEA testimony before the Joint Senate Railbelt Electric System Special Committee and House Special Committee on Energy. A summary of this question and AEA’s follow up is provided below: Q: Senator Giessel – Can you explain why Bradley Lake is not regulated by the RCA? A: Currently Bradley Lake is not regulated by the RCA as it has outstanding Bond’s that were issued during construction of the facility. There are differing legal interpretations as to whether or not that relief from RCA regulation will continue once the bonds issued for construction are paid off or if the current bonds that have been issued for the Battle Creek Diversion project which is currently under construction, will extend the exemption from RCA regulation. AEA is investigating this matter with the Department of Law. If you have any further questions, please contact me at (907) 771-3009. Sincerely, Curtis W. Thayer Executive Director Cc: Senator Cathy Giessel Senator Elvi Gray-Jackson Senator Peter Micciche Senator Mike Shower Representative Zack Fields Representative John Lincoln Representative George Rauscher Representative Ivy Spohnholz Representative Tiffany Zulkosky Representative Grier Hopkins Alaska State Legislature State Capitol Room 409 Juneau, Alaska 99801 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG REDUCING THE COST OF ENERGY IN ALASKA February 10, 2020 Senator Click Bishop Alaska State Legislature State Capitol Room 121 Juneau, Alaska 99801 Dear Chairman Bishop and Vice Chairman Micciche, I am writing in response to questions raised during the January 30, 2020, AEA Hydroelectric Projects in Alaska Presentation to the Senate Community and Regional Affairs Committee. A summary of these questions and AEA’s follow up are provided below: Akutan Hydroelectric Project Q: Senator Gray-Jackson – Inquired if there are any projects in Akutan A: Our research suggests that the Akutan Hydroelectric Project has not operated since August 2018. Angoon Q: Senator Bishop – Will Thayer Lake make Angoon 100% renewable? A: Yes. Thayer Hydroelectric Project is anticipated to be able to supply all the electric energy for Angoon. Excess energy will be available for heating or other needs. Statewide Energy Generation Q: Senator Micciche – Inquired if the kilowatt demand (statewide) increased and did renewables supply energy for the increase. Additional information on how energy generation has changed was requested of AEA. A: Generation in 2017 is less than 2008. Absolute and percentage of renewables generation has increased while absolute and percentage of oil, natural gas, and coal have decreased. Senator Peter Micciche Alaska State Legislature State Capitol Room 504 Juneau, Alaska 99801 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG Statewide generation by type from 2008 through 2017 (preliminary) A copy of the Alaska Hydropower Projects Summary is enclosed. If you have any further questions, please contact me at (907) 771-3009. Sincerely, Curtis W. Thayer Executive Director Cc: Senator Elvi Gray-Jackson Senator Lyman Hoffman Senator Mike Shower Encl. PhaseYear of Operation or Development Phase Project Name Name Utility/Owner Capacity (kW)Average Expected Annual Generation Potential (MWh) State ParticpationAverage Expected New Annual Generation Utilized at Time of Developement, MWh Type Service AreaOperational 2000 10 Mile Creek 10 Mile Creek IPEC 550 1000 run‐of‐riverHaines/SkagwayOperational 2016 Allison Creek Allison Creek CVEA 6500 23000 AEA 15000 run‐of‐riverGlennallen‐ValdezOperational1915 Annex CreekAnnex CreekAELP400026000lake tapJuneauOperational1988 AWWU ConduitAWWU ConduitAWWU750conduitRailbeltOperational1947 Beaver FallsBeaver FallsKPU520044676run‐of‐river/lake tap Wrangell/Petersburg/KetchikanOperational1995 Black Bear LakeBlack Bear LakeAP&T450020600storagePrince of WalesOperational1925 Blind Slough (Crystal Lake)Blind Slough (Crystal Lake)Petersburg Municipal Power & Light (PMP&L240011310storageWrangell/Petersburg/KetchikanOperational1958 Blue LakeBlue LakeSitka754054800lake tap/storage SitkaOperational2014 Blue LakeBlue Lake RetirementCity and Borough of Sitka (CBS)‐7540‐54800 AEAlake tap/storage SitkaOperational2014 Blue LakeBlue Lake ExpansionCity and Borough of Sitka (CBS)1856792500 AEA1000 lake tap/storage SitkaOperational2014 Blue LakeBlue Lake Fish Valve UnitCity and Borough of Sitka (CBS)13707700 AEAlake tap/storage SitkaOperational1991 Bradley LakeBradley LakeAlaska Energy Authority (AEA)120000380000 AEAlake tapRailbeltOperationalBurnett River HatcheryBurnett River HatcherySSRAA80Burnett Inlet HatcheryOperational1987 Chester LakeChester LakeMetlakatla11004961lake tapMetlakatlaOperational1949 ChignikChignikChignik Bay60300storageChignik BayOperational2012 Chuniisax CreekChuniisax CreekAtka284443 AEArun‐of‐riverAtkaOperational1960 Cooper LakeCooper LakeCEA1920048500lake tapRailbeltOperational2015 Cooper LakeCooper Lake, Stetson Creek Diversion CEA06020 AEA6020 diversionRailbeltOperational1995 Delta CreekDelta CreekKing Cove8001998 ??run‐of‐riverKing CoveOperational early 1900's Dewey LakesDewey LakesAP&T9433138run‐of‐riverHaines/SkagwayOperationalDry Spruce Bay (Creek)Dry Spruce Bay (Creek)PB Energy, Inc75300Port Bailey Cannery (Kodiak)Operational1955 EklutnaEklutnaCEA/MEA/MLP40000172077storageRailbeltOperational2009 Falls CreekFalls CreekAP&T8001939 AEA?run‐of‐riverGustavusOperational2015 Gartina FallsGartina FallsIPEC4501810 AEA1810 run‐of‐riverHoonahOperational1997 Goat LakeGoat LakeAP&T400015617storageHaines/SkagwayOperational1914 Gold CreekGold CreekAELP16004500run‐of‐riverJuneauOperational1979 Green LakeGreen LakeCity and Borough of Sitka (CBS)1860063800storageSitkaOperational2010 Humpback CreekHumpback CreekCordova Electric Cooperative (CEC)12503554 AEArun‐of‐riverCordovaOperationalJetty Lake (West Side Hydro) Jetty Lake (West Side Hydro)Armstrong‐Keta Inc.249Port Armstrong HatcheryOperational2008 Kasidaya CreekKasidaya CreekAP&T30007446run‐of‐riverHaines/SkagwayOperational1903 Ketchikan LakesKetchikan LakesKPU420023025lake tapWrangell/Petersburg/KetchikanOperational2010 Lake DorothyPhase I ‐ Bart LakeAELP1430075000lake tapJuneauOperational1991 Larsen BayLarsen BayLarsen Bay475773run‐of‐riverLarsen BayOperational purch. 2002 LutakLutakAP&T250164run‐of‐riverHaines/SkagwayOperational1987 Mahoona LakeMahoona LakeOuzinkie125167storageOuzinkieOperational Nonoperational Marathon HydroMarathon HydroCity of Seward160876run‐of‐riverRailbeltOperational1991 McRoberts CreekMcRoberts CreekEnerdyne125387run‐of‐riverRailbeltOperational2015 Packers CreekPackers CreekChignik Lagoon167521 AEA521 run‐of‐riverChignik LagoonOperational1988 PelicanPelicanPelican650799 AEArun‐of‐riverPelicanOperational1997 Power CreekPower CreekCEC600015929run‐of‐riverCordovaOperational1955 Purple LakePurple LakeMetlakatla390016076lake tapMetlakatlaOperational1914 Salmon CreekSalmon CreekAELP850029500storageJuneauOperational1975 Silvis LakesSilvis LakesKPU210012462lake tapWrangell/Petersburg/KetchikanOperational 1973/1990SnettishamSnettishamAELP78200295000 AIDEAlake tapJuneauOperational1981 Solomon GulchSolomon GulchCVEA1200045000 AEAstorageGlennallen‐ValdezOperational2005 South Fork Black BearSouth Fork Black BearAP&T20005740run‐of‐riverPrince of WalesOperational2013 South Fork Hydro (Eagle River) South Fork Hydro (Eagle River)South Fork Hydro, LLC12003725run‐of‐riverRailbeltOperational1984 Swan LakeSwan LakeSEAPA2250076000 AEAstorageWrangell/Petersburg/KetchikanOperational2016 Swan LakeSwan Lake ExpansionSEAPA07500storageWrangell/Petersburg/KetchikanOperational1998 TaziminaTaziminaINNEC8244048 ??run‐of‐riverIliamnaOperational1985 Terror LakeTerror LakeKEA20000135000 AEAlake tapKodiakOperational2014 Terror LakeTerror Lake, Third UnitKEA140000 AEA12000 lake tapKodiakOperational1993 Town CreekTown CreekAkutan105300 AEArun‐of‐riverAkutanOperational1984 Tyee LakeTyee LakeSEAPA22500125000 AEAlake tapWrangell/Petersburg/KetchikanOperational2017 Waterfall CreekWaterfall CreekKing Cove4001167 AEA1167 run‐of‐riverKing CoveOperational2014 Whitman LakeWhitman LakeKPU460016000 AEA2500 storageWrangell/Petersburg/Ketchikan4‐ConstructionHíilangaay (Reynolds Creek) Hydro Híilangaay (Reynolds Creek) Hydro AP&T477525250 AEAstoragePrince of Wales Island4‐ConstructionIndian RiverIndian RiverTenakee Springs1801169 AEArun‐of‐riverTenakee Springs4‐ConstructionBradley LakeBradley Lake, Battle Creek Diversion AEA037000 AEAdiversionRailbelt4‐ConstructionGunnuk CreekGunnuk CreekIPEC5001620 AEAstorageKake4‐ConstructionJuniper Creek (Upper Eagle River)Brailey3001700run‐of‐riverRailbeltOperational2019 Terror LakeTerror Lake, Hidden BasinKEA033000run‐of‐riverKodiakDesignNuyakuk RiverNE&TC1200058200run‐of‐riverDillingham RegionDesignSweetheart LakeJHI19800116000storageJuneau RegionDesignThayer CreekKootznoo8505500 AEArun‐of‐riverAngoonDesignSusitna‐WatanaAEA4590002800000 AEAStorageRailbeltDesignFivemile CreekChitina Electric6000 AEArun‐of‐riverChitinaDesignKnutson CreekPedro Bay2001504 AEArun‐of‐riverPedro BayALASKA HYDROELECTRIC PROJECTSAEA Hydro Inventory Summary Page 1 DesignCrooked Creek/Jim's LakeElfin Cove Utility Commission160673 ??run‐of‐river/storage Elfin CoveDesignChenega Bay (Anderson Creek) Chenega Corporation61370run‐of‐riverChenegaDesignChignikChignik Bay‐60‐300Chignik BayDesignChignikChignik Bay3852140storeageChignik BayDesignCrater LakeCEC5002250storageCordovaDesignFishhookFishhook Renewable Energy LLC20007429run‐of‐riverRailbeltDesignGrant Lake/Falls CreekKenai Hydro, LLC500019700run‐of‐riverRailbeltDesignOld HarborAVEC2622300run‐of‐riverOld HarborDesignYerrick CreekNative Village of Tanacross15003440run‐of‐riverGlennallen‐Valdez2‐FeasibilityChikuminuk LakeAVEC2200078100storageBethel/Dillingham2‐FeasibilityConnelly Lake800043200storageHaines/Skagway2‐FeasibilityFourth of July CreekChugach Electric1270055000run‐of‐riverSeward2‐FeasibilityKogoluktuk RiverAVEC6905410run‐of‐riverAmbler, Shungnak, Kobuk, and Kiana2‐FeasibilityMahoney LakeCity of Saxman960046000storageWrangell/Petersburg/Ketchikan2‐FeasibilityScammon Bay Scammon Bay188756run‐of‐riverScammon Bay2‐FeasibilityTakatz LakeSitka27600106900storageSitka2‐FeasibilityTiekel RiverCVEA50000204000storageGlennallen‐Valdez2‐FeasibilityTriangle LakeMetlakatla400017324storageMetlakatla1‐ReconChignik Lake100788run‐of‐river1‐ReconChignik Lake83545run‐of‐river1‐ReconClearwater CreekNative Village of Tanacross10003400run‐of‐riverGlennallen‐Valdez1‐ReconExcursion InletExcursion Inlet1‐ReconFalse Pass125936run‐of‐riverFalse Pass1‐ReconLake Bonnie RoseCity of Adak4403200storageAdak1‐ReconLoud CreekAkutan1‐ReconMoffet CreekCity of Adak450run‐of‐riverAdak1‐ReconNeck Lake1‐ReconRaging Creek Hydro500023230run‐of‐riverCordova1‐ReconSnow RiverChugach Electric75000341500341500storageRailbeltAEA Hydro Inventory Summary Page 2 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG REDUCING THE COST OF ENERGY IN ALASKA February 10, 2020 Representative Adam Wool Alaska State Legislature State Capitol Room 501 Juneau, Alaska 99801 Dear Chairman Wool, I am writing in response to questions raised during the January 30, 2020, AEA Overview Presentation to the House Commerce, Community & Economic Development Finance Subcommittee. A summary of these questions and AEA’s follow up are provided below: Bradley Lake Hydroelectric Project Q: Chair Wool – When is the Bradley Lake project paid off? A: The Bradley Lake bonds for original construction have a scheduled maturity date of July 1, 2021. The State financed the Bradley Project construction using an approximate split of 50/50 of bonds issued by AEA and State appropriations. The participating Utilities pay the debt service on the bonds through the Power Sales Agreement (PSA). After the retirement of all bonds issued to pay for the original project construction, the PSA requires that the Utilities make “Excess Payments.” These payments are in an amount equivalent to what the average bond debt service had been. AEA estimates this will be approximately $12.5 million per year. Excess payments to AEA will be deposited into the Railbelt Energy Fund. The payments continue until the PSA expires or is terminated. In December 2017, the Authority issued, as a private placement, $47 million bonds for long term financing of the construction costs of the Battle Creek Diversion Project, an improvement to the Bradley Lake Hydroelectric Project. The outstanding bonds for the Battle Creek financing mature annually each July 1 starting in 2021 and running through 2050. Bulk Fuel Tank Farm Upgrades Q: Representative Hannan – What is the scheduled completion date of the Coast Guard’s assessments of the bulk fuel tanks? A: The Coast Guard has indicated to its partners that the inspections and follow-ups are not scheduled to end but will be the new program methodology for the foreseeable 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG future, funding dependent. Every facility in their purview, fewer than 400, will be inspected every other summer. Approximately 200 were inspected last summer. The initial round should be completed in about a year. The information gathered during the Coast Guard inspections will inform and focus the AEA Bulk Fuel Upgrade priority list as well as the Bulk Fuel Maintenance & Improvement and Training programs. Power Cost Equalization (PCE) Program Q: Representative Lincoln – Which PCE community is not in compliance with the PCE program requirements? A: There are currently 196 communities eligible to receive PCE. AEA’s PCE staff works with those communities not currently receiving PCE to bring them into compliance so they can receive PCE payments. The community of Platinum has fallen behind in its reporting to the RCA. In accordance with 3 AAC 52.680(c) and 3 AAC 52.680(e), reimbursements have been suspended. The number of communities eligible for PCE payments is 195. Renewable Energy Fund (REF) Q: Representative Fields – Are there any eligible projects for which a relatively small incremental amount of money might be helpful (in reference to the uncommitted balance of approximately $7 million in the Renewable Energy Fund)? A: AEA is preparing the Request for Applications and supporting materials for a solicitation in March 2020. Applications are expected to be received in July 2020 with analysis and recommendations to the legislature in January 2021. As of June 30, 2019, there were $6.2 million in uncommitted funds in the Renewable Energy Fund. The uncommitted balance will change throughout the year as grants are closed and funds are committed for FY20 and FY21 administrative costs (estimated to be $1.4 million per year). On December 3, 2019, AEA met with the Renewable Energy Fund Advisory Committee (REFAC), a nine-member committee that assists AEA by offering valuable guidance and policy direction including final funding recommendations. Because AEA has not solicited renewable energy applications since 2015, the REFAC advised AEA that projects should not be recommended for funding until a current solicitation for applications is complete. 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG Although not anticipated, any REF fund capitalizations in FY21 would increase the available balance to fund projects selected through the current solicitation process for appropriation to projects in the FY22 budget year. Q: Representative Hannan – When was the last time the REF had any capital investments from the legislature given to it? A: In fiscal year 2019, $14 million was appropriated from the power cost equalization endowment fund to the renewable energy grant fund. This was a result of the calculation of excess power cost equalization earnings available for appropriation in accordance with AS 42.45.085 (d). See below: Q: Representative Fields – With approximately 74 million in annual fuel savings in 2017, would it be possible to get back with the savings since we (the State) started making these investments ($268 million invested)? A: Through 2017, REF operational projects had saved approximately $292 million of fuel costs and 123 million gallons of diesel equivalent (this includes diesel, natural gas, and coal converted into equivalent amounts of diesel). Over the expected life of projects that were operational in 2017, the present value of the fuel savings is estimated to be $1.5 billion. Power Project Fund Loan Program As it relates to the solar project in Willow, AK funded partially by power project funds - $112,330,514 AEA – Rural Energy Assistance $381,800 AEA – Power Cost Equalization $32,355,000 Revenue – Treasury $359,000 $33,095,800 $79,234,714 $55,000,000 Community Assistance Program (AS 42.45.085(d)(2)(A))$30,000,000 Renewable Energy Grant Fund (AS 42.45.085(d)(2)(B))$14,000,000 Rural Power Systems Upgrades (AS 42.45.085(d)(2)(B))$11,000,000 $55,000,000 $0 FY2019 Additional Appropriations per AS 42.45.085 (d)(2) Less: FY2019 Additional Appropriations Remaining Balance Calculation of Excess Power Cost Equalization Earnings Available for Appropriation FY2017 Earnings (AS 42.45.050(c)(2)) FY2019 Planned Appropriations – Based on Prior Year Less: Total FY2019 Appropriations Unobligated FY2017 Earnings 70% of Unobligated FY2017 Earnings per AS 42.45.085(d) (max $55 million per AS 42.45.085(d)(2)) 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG Q: Representative Fields – Do you have a sense of what the installed cost of (solar) PV is in Alaska now? It may be as low as 2 ½ cents per kWh for projects in the Lower 48 but what about up here for projects of this scale? A: The installed cost of the Willow Solar Farm is $1.39 per Watt. This may not represent all costs associated with the project. The power is sold to MEA for 8.8 cents/kWh. Costs can vary greatly throughout the state depending on capacity, year, location, design, etc. For example, the installed cost of the 2015 solar project in Eagle works out to $8.83 per Watt. If you have any further questions, please contact me at (907) 771-3009. Sincerely, Curtis W. Thayer Executive Director Cc: Representative Zack Fields Representative Mel Gillis Representative Sara Hannan Representative Jonathan Kreiss-Tomkins Representative John Lincoln Representative Sara Rasmussen Representative Chris Tuck 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG REDUCING THE COST OF ENERGY IN ALASKA February 20, 2020 Senator Click Bishop Senate C&RA Committee Alaska State Legislature State Capitol Room 121 Juneau, Alaska 99801 Dear Chairman Bishop and Vice Chairman Micciche, I am writing in response to a follow up question raised by Senator Micciche during the February 11, 2020, AEA Susitna-Watana Hydroelectric Project presentation to the Senate Community & Regional Affairs Committee. A summary of this question and AEA’s follow up are provided below: Susitna-Watana Hydroelectric Project Q: Senator Micciche – How much of the project area is in private ownership? A: Depending on final transmission corridor selection of Denali East or Denali West, the project area ownership consists of: Land Ownership Denali East Denali West Federal Land BLM – State Selected or Top-filed 30% 28% State Land State – DNR, Alaska Railroad 26% 30% Private Land ANCSA Corporations 43% 41% Private (Non-ANCSA) <1% <1% I would like to provide clarification on Slide 13 – Employment Opportunities: Pre-construction employment (18 year period) o Approximately 5,000 direct jobs o Approximately 3,870 indirect jobs Construction employment (10 year period) o Approximately 12,000 direct jobs o Approximately 11,305 indirect jobs Operations employment (life of Project) o Approximately 24-28 direct jobs Senator Peter Micciche Senate C&RA Committee Alaska State Legislature State Capitol Room 504 Juneau, Alaska 99801 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG o Approximately 105 indirect jobs Following the committee meeting, an additional question was asked: Q: Senator Bishop – What type of analysis was completed comparing Susitna River to the Chakachamna hydro projects? A: See attachment. If you have any further questions, please contact me at (907) 771-3009. Sincerely, Curtis W. Thayer Executive Director Cc: Senator Elvi Gray-Jackson Senator Lyman Hoffman Senator Mike Shower Encl. 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG REDUCING THE COST OF ENERGY IN ALASKA February 12, 2020 Representative Adam Wool House DCCED Finance Subcommittee Alaska State Legislature State Capitol Room 501 Juneau, Alaska 99801 Dear Chairman Wool, I am writing in response to a follow up question raised by both Representatives Lincoln and Rasmussen during the February 11, 2020, House Commerce, Community & Economic Development Finance Subcommittee: Budget Action Items & Amendments. The question was regarding the proposed federal receipts decrement of $300,000 for the Rural Energy Assistance component. This reduction does not reduce services, it reduces the budget authorization to better align with anticipated expenditures. Our Rural Energy Assistance programs include the circuit rider, technical assistance, and several rural energy infrastructure operator training programs. While these programs received general fund reductions during previous budget cycles our federal partnerships, largely with the Denali Commission, provided funding to offset this loss. The federal funding required minimal, if any, state matching funds. Federal authorization increased in FY2019 by $750,000 to accommodate the anticipated growth in receipts for a total of $1,502,000 in authorization. AEA continues to partner with the Denali Commission to increase circuit rider funding and rural energy program support, particularly in training program opportunities. If you have any further questions, please contact me at (907) 771-3009. Sincerely, Curtis W. Thayer Executive Director Cc: Representative Zack Fields Representative Mel Gillis Representative Sara Hannan Representative Jonathan Kreiss-Tomkins 813 West Northern Lights Boulevard, Anchorage, Alaska 99503 | P 907.771.3000 | Toll Free 888.300.8534 | F 907.771.3044 | WWW.AKENERGYAUTHORITY.ORG Representative John Lincoln Representative Sara Rasmussen Representative Chris Tuck 1 | P a g e Senate Finance Budget Subcommittee FY20/FY21 Key Issues Department of Commerce, Community, & Economic Development ALASKA ENERGY AUTHORITY RESPONSE – February 14, 2020 10. Alaska Energy Authority Owned Facilities a. -$200.0 AEA Receipts: Q. Describe what reimbursements were derived from the Railbelt Utilities for administration of AEA assets? AEA owns the Bradley Lake Hydro and the Alaska Intertie projects. The cost of administering the projects is shared by the Railbelt Utilities who reimburse AEA for costs. The proposed decrement reduces the budget authorization to align with expected actuals and does not affect the delivery of these services. Q. Is AEA still administering the AEA assets? Yes, AEA continues to administer the assets. Q. What activities have changed? The costs of administering the Bradley Lake Hydro project have increased with the construction of the Battle Creek Diversion project, an improvement to the Bradley Lake Hydro project. In December 2017, the Authority issued, as a private placement, $47 million bonds for long term financing of the construction costs of the Battle Creek Diversion Project increasing project management, as well as compliance and reporting requirements. Q. How does this impact AEA and Alaskans? What impact to staff development will this have? Is there in-house training available as a replacement? There is no impact of this decrement to AEA, Alaskans or on staff development. Administration of AEA assets is provided by our in-house technical project management and finance staff. The Railbelt Utilities reimburse for costs. 11. Alaska Energy Authority Rural Energy Assistance a. -$50.0 GF/Program receipts: Q. What conferences will be eliminated and where? In terms of hosting conferences, there will be no significant elimination of conferences. This is because such conferences are often in collaboration with others such as the UAF Center for Energy and Power (ACEP.) ACEP has been a conference partner in the recent past assisting with the Rural Energy 2 | P a g e Conference. That conference provides useful information to Alaskan’s attending and as their attendance is at a cost, the expenses of the conference are largely or completely born by those attending and benefitting. The same is true for the AEA hosted Energy Efficiency Finance Seminar. General Fund receipts cover the costs of the hosted conference. The AEA staff that participate in hosted conferences varies depending upon the scope or area of specialization of the conference. AEA will despite the reduction, continue to seek out opportunities to engage with others to educate and promote state energy projects and programs that have a positive benefit for Alaska. Over the past year our key partners have included The Denali Commission, The Alaska Federation of Natives, The Alaska Forum on the Environment, and The Bureau of Indian Affairs Tribal Providers Conference, to name only a few. Q. Who attends the conferences? AEA’s participation in the conferences it participates in is typically limited to key personnel. Depending on the given conference, AEA team members may be asked to serve on a planning committee, moderate or speak on a panel, and/or staff an exhibitor booth for the duration of the conference. Primary factors that determine staff participation include conference location, theme/topics, and audience. Q. What impact to rural Alaskans will this have, if any? We do not anticipate that this decrement will reduce conference participation by AEA. b. -$300.0 Federal Receipts: Q. Has the rural energy program activities been reduced or what impact does this have in training residents and their ability to sustain their energy and infrastructure projects? This reduction does not reduce services, but reduces budget authorization to better align with the expected or anticipated expenditures. Q. What impacts to rural Alaska do you expect with a reduction in funding? The rural energy assistance programs include the circuit rider program, technical assistance, and several rural energy infrastructure operator training programs. While these programs received reductions of general funds during previous budget cycles, federal partnerships, largely with the Denali Commission, provided funding to offset the loss of general funds. The federal funding required minimal or no state matching funds. Federal authorization increased in FY2019 by $750,000 to accommodate the anticipated growth in receipts for a total of $1,502,000 in authorization. Q. Describe why the federal receipts have been reduced? Prior year increment(s), while needed to meet increased federal funds, were greater than actuals. This is a reduction in excess receipt authority. Q. Is the funding no longer available? Federal funding is available for the circuit rider program, technical assistance, and rural training programs. The Denali Commission has been instrumental in the continuation of these services. In FY20, AEA was able to add one new circuit rider position through its partnership with the Denali Commission. 3 | P a g e The Alaska Energy Authority’s Circuit Rider program provides eligible utilities with technical assistance to improve the efficiency, safety, and reliability of their energy infrastructure and helps reduce the risk and severity of emergency conditions. During FY19, in accordance with 3 AAC 108.220, the Circuit Rider and Rural Electric Utility Workers provided real time remote assistance and training via phone and SCADA to 80 rural Alaska communities. AEA continues to provide training opportunities to local residents for their energy projects and infrastructure. The intent of this training is to ensure that community personnel have the best opportunity to acquire the necessary skills which enable them to timely & properly maintain their energy infrastructure. With proper training, operators will keep their facilities code-compliant. The following training classes were provided in FY19: o Advanced Power Plant Operator training. Communities: Kasigluk, Kipnuk, Kokhanok, New Stuyahok, Ruby, Tuntutuliak, and White Mountain. o Bulk Fuel Operator training . Communities: Ambler, Brevig Mission, Buckland, Chenega Bay, Diomede, Emmonak, Holy Cross, Hughes, Kaktovik, Kalskag, Kongiganak, Kwigillingok, Mountain Village, Pilot Station, Port Heiden, Ruby, Wales, and White Mountain. o Power Plant Operator training. Communities: Emmonak, Kokhanok, Kwigillingok, Saint Paul, Tuntutuliak, Sleetmute, Stony River, Sitka, Egegik, Ambler, Kwethluk, Atmautluak, and Twin Hills. o Itinerant Bulk Fuel Operator Training: Alakanuk, Chalkyitsik, Chignik Lagoon, Eek, Goodnews Bay, Hoonah, Kake, Kasigluk, Kipnuk, Kwigillingok, Larsen Bay, Napaskiak, Newtok, Nunapitchuk, Old Harbor, Port Lions, Quinhagak, Saint Mary’s, Togiak, Tuluksak, Tuntutuliak, and Venetie. o Training Manual Development: In FY19, AEA began testing the first draft of the “Financial and Operational Management Guide for PCE-eligible Utilities.” Tests included on-site and remote training to five communities (Arctic Village, Venetie, Tuluksak, Metlakatla, and Kwigillingok). AEA provided training to utility managers, utility boards, operators, and clerks. We learned valuable lessons in working with the communities that have been incorporated into the guidebook. In April 2019, AEA hired a contractor to do a final edit of the guidebook. The contractor, who has written similar guides for water & wastewater utilities for DCRA, has added valuable practical financial management tools and tips. The guidebook has been simplified and improved for the target audience. As new sections have been completed, we have had the opportunity to work with utilities and monitor their effectiveness. Q. How will this impact the training available going forward, will there be less training? This reduction does not reduce services, but reduces budget authorization to better align with the expected or anticipated expenditures. Q. Can you provide the training schedule for FY21/FY22? AEA anticipates completing the following training and assistance to rural communities for their energy infrastructure on an annual basis: Bulk Fuel Tank Farm Operators training – train 20 Operators at AVTEC in Seward 4 | P a g e Power Plant Operators training – train 15 Operators at AVTEC Advanced Power Plant Operators training – train 8 Operators at AVTEC Itinerant Onsite Bulk Fuel training – 35 Communities, on-site Circuit Rider training – 30 Communities, on-site Circuit Rider remote technical assistance – 200+ Remote technical responses Regional and Onsite Utility Trainings – 10 training sessions (regional & on-site) Q. How will the training schedule be impacted? The proposed decrement does not impact the training schedule because it aligns authorization with anticipated expenditures. 12. Alaska Energy Authority Power Cost Equalization Q. Describe how the Power Cost Equalization Endowment Fund Program works? The Power Cost Equalization (PCE) Program provides economic assistance to communities and residents of rural electric utilities where the cost of electricity can be three to five times higher than for customers in more urban areas of the state. The program’s purpose is to equalize power costs to near the average cost of power in Anchorage, Fairbanks, and Juneau. Residential and community facility buildings in nearly 200 communities are eligible for the reduced rate. The Regulatory Commission of Alaska (RCA) determines if a utility is eligible to participate in the program and annually calculates the rate at which the PCE program reimburses each eligible utility. AEA determines the eligibility of community facilities and residential customers and reimburses costs the electric utility incurs for the PCE credits extended to customers. The PCE Program is funded by earnings of the PCE Endowment Fund. AS 42.45.085 provides that five percent of the PCE Endowment Fund’s three-year monthly average market value may be appropriated to the PCE Program. It has only been in recent years that the five percent draw on the endowment has been sufficient to fully fund PCE payments. Q. What programs receive funding from the endowment earnings? AS 45.45.085 defines the use of the power cost equalization endowment fund. Earnings are used to fund the PCE program and costs of administering the fund. Excess earnings of the fund can, by statute, be appropriated to community revenue sharing or the community assistance fund; then to the renewable energy grant fund (REF), to the bulk fuel revolving loan fund or for rural power systems upgrades. The amount available is dependent on market conditions. For example, in fiscal year 2019, $14 million was appropriated from the power cost equalization endowment fund. However, in FY20 the excess earnings calculation resulted in only $454,000 being available for REF projects. The FY20 amount was vetoed by the Governor and retained by the PCE Endowment fund. See below FY19 and FY20 excess earnings calculations: 5 | P a g e Q. How does this benefit Alaskans? The PCE program, as well at other energy programs that AEA administers, including the AEA owned assets, reduce the cost of energy for Alaskans. Q. Describe how the Regulatory Commission of Alaska (RCA) calculates the “PCE Floor.” The RCA is required by AS42.45.110(c)) to calculate a base amount for PCE. The amount calculated by the RCA by Order U-19-028(1), effective for bills rendered on or after July 1, 2019 was determined to be 19.1 cents for each kilowatt-hour. That rate will remain in effect until changed by the RCA. $112,330,514 AEA – Rural Energy Assistance $381,800 AEA – Power Cost Equalization $32,355,000 Revenue – Treasury $359,000 $33,095,800 $79,234,714 $55,000,000 Community Assistance Program (AS 42.45.085(d)(2)(A))$30,000,000 Renewable Energy Grant Fund (AS 42.45.085(d)(2)(B))$14,000,000 Rural Power Systems Upgrades (AS 42.45.085(d)(2)(B))$11,000,000 $55,000,000 $0 FY2019 Additional Appropriations per AS 42.45.085 (d)(2) Less: FY2019 Additional Appropriations Remaining Balance FY2019 Appropriations (SLA2018) Calculation of Excess Power Cost Equalization Earnings Available for Appropriation FY2017 Earnings (AS 42.45.050(c)(2)) FY2019 Planned Appropriations – Based on Prior Year Less: Total FY2019 Appropriations Unobligated FY2017 Earnings 70% of Unobligated FY2017 Earnings per AS 42.45.085(d) (max $55 million per AS 42.45.085(d)(2)) $76,602,411 AEA – Rural Energy Assistance $381,800 AEA – Power Cost Equalization (AEA updated estimate?)$32,355,000 Revenue – Treasury $359,700 $33,096,500 $43,505,911 $30,454,138 Community Assistance Program (AS 42.45.085(d)(2)(A))$30,000,000 Renewable Energy Grant Fund (AS 42.45.085(d)(2)(B)) Rural Power Systems Upgrades (AS 42.45.085(d)(2)(B)) $30,000,000 $454,138 70% of Unobligated FY2018 Earnings per AS 42.45.085(d) (max $55 million per AS 42.45.085(d)(2)) FY2020 Additional Appropriations per AS 42.45.085 (d)(2) Less: FY2020 Additional Appropriations Remaining Balance FY2020 Appropriations (SLA2019) Calculation of Excess Power Cost Equalization Earnings Available for Appropriation FY2018 Earnings (AS 42.45.050(c)(2)) FY2019 Appropriations Less: Total FY2020 Appropriations Unobligated FY2018 Earnings 6 | P a g e The calculation of the amount for PCE is based upon residential sales in the electricity markets of Anchorage Fairbanks and Juneau. An excerpt from the RCA’s most recent order setting the amount is below (RCA U-19-028(1), Appendix A): APPENDIX A FY2020 Power Cost Equalization Base Rate Calculation TOTAL RESIDENTIAL SALES Total Residential Sales Kilowatt-hour (kW h) ($) ($/kW h) AEL&P 148,071,000 18,952,881 $ 0.1280 Chugach 479,353,000 93,972,829 $ 0.1960 GVEA 269,185,000 68,513,747 $ 0.2545 MEA 428,354,000 91,596,989 $ 0.2138 ML&P 120,098,000 24,180,864 $ 0.2013 Sources: Utilities' 2019 Annual Reports to Commission - FERC Form No. 1 ************** ************************ **************** *********** ************* ************* ************* ************ RESIDENTIAL SALES W ITHIN FAIRBANKS, ANCHORAGE, & JUNEAU (% Total Residential W eighted (kW h) ($) ($/kW h) kW h) Average AEL&P 148,071,000 18,952,881 $ 0.1280 16.709% $ 0.0214 Chugach 465,739,375 91,304,001 $ 0.1960 52.556% $ 0.1030 GVEA 53,834,308 13,702,064 $ 0.2545 6.075% $ 0.0155 MEA 98,435,749 21,048,988 $ 0.2138 11.108% $ 0.0238 ML&P 120,098,000 24,180,864 $ 0.2013 13.552% $ 0.0273 Total 886,178,432 169,188,798 100.000% $ 0.1910 $/kW h Q. What changes effect the “floor” in calculating how much funding is available for other programs? Other than changes to the statute that establishes how the RCA is to calculate the PCE rate to be paid it is impossible to know or reasonably estimate the funding that may be required for PCE payments. It is certainly possible that if the populations of Anchorage, Fairbanks and Juneau change drastically, or if fuel prices for electric utilities in those same cities are altered significantly that the base rate for PCE would vary from the present calculation. Q. Provide a listing of communities, how much they receive in FY20 and are projected to receive in FY21? See attached list of communities and the projected disbursements for FY20. PCE estimates for FY21 are dependent on a variety of factors including fuel costs, weather, usage, and eligibility. 13. Statewide Project Development, Alternative Energy & Efficiency a. -$600.0 Renewable Energy: 7 | P a g e Q. Describe how the program benefits Alaskans? The Alaska Renewable Energy Fund (REF) provides benefits to Alaskans by reducing and stabilizing the cost of energy by encouraging & funding the development of renewable energy projects. The program is designed to produce cost-effective renewable energy for heat and power to benefit Alaskans statewide. The program creates jobs, uses local energy resources, and keeps money in local economies. THE REF was established by Alaska State Legislature in 2008, and in 2012 was extended 10 years to June 30, 2023. The REF is managed by the Alaska Energy Authority in coordination with a 9- member Renewable Energy Fund Advisory Committee (REFAC). The Program provides public grant funding for the development of qualifying and competitively selected renewable energy project in Alaska. From 2008 to 2019, appropriations totaling $268 million were made for expenditures to REF projects. State funding has been matched with hundreds of millions of dollars from other sources to develop renewable energy projects designed to reduce and stabilize the cost of energy in Alaska. Q. What impact will the reduction in funding have on energy grants? The proposed decrement of $600.0 reduces authorization to align with anticipated expenditures. This reduction is to the costs of administering the program and does not impact projects. The costs of administering the REF program has declined over the past several years from a high of $2.1 million to an average of $1.4 million over the past 4 years. This is a primarily a result of less funding being allocated for new projects and grants being closed as projects are completed. Operational and staffing efficiencies also contribute to lower costs. Q. How many grants were issued in FY20 and FY21? After several years of no funding for new projects, in FY2019, $11 million in excess earnings from the PCE Endowment fund went to fund eight projects which had previously been recommended for funding through the REF application process. Seven of those grants were issued in FY2019. One grant remains in negotiation. Q. Is funding sufficient to complete the projects that are in progress? During application review and selection, the projects’ scopes, schedules, and budgets are analyzed by AEA staff to ensure that the “project”, as defined in the grant agreement, can be completed and deliverables are realistic. Grantees are required to cover cost overruns. If additional capital is needed, most REF projects and grantees would be eligible for AEA’s Power Project Loan Fund. Project monitoring and reporting requirements ensures that project deliverables are met. Q. Have any applications been submitted in FY20 yet? No, on December 3, 2019, AEA met with the REFAC. Because AEA has not solicited renewable energy applications since 2015, the REFAC advised AEA that no projects should be recommended for funding until a next solicitation for applications is complete. AEA expects a new solicitation for renewable projects to be released to the public in March 2020. Proposals will be evaluated in 2020, with AEA providing recommendation to the Legislature for funding consideration in fiscal years 2022 and 2023. While the authorization of the REF grant program expires on June 30, 2023, if the program is extended a solicitation would be released in March 2022, and every two years thereafter. 8 | P a g e Q. Describe some of the completed projects and the impacts on Alaskans and their communities? Operational projects have an estimated return of more than two dollars for every dollar invested. Contributions from REF projects, including Pillar Mountain wind and Terror Lake hydropower expansion, have helped Kodiak Electric generate nearly 100% of its power from renewable sources. Atka’s Chuniixsax hydro project has displaced over 80% of the community’s diesel generation. Locally harvested biomass from the Galena biomass project displaced over $600,000 in heating oil (113,000 gallons) over the 2017/2018 heating season, saving $233,000, creating jobs and keeping money in the community. Heat recovery projects account for 24 percent of operational projects. In 2017, 17 operational heat recovery projects captured heat from diesel powerhouse engines to displace over 200,000 gallons of heating oil in public buildings and water systems. The Hiilangaay hydro project funded by both the REF and Power Project loan fund will be operational in 2020. ALASKA ENERGY AUTHORITY FY2020 Estimated PCE Disbursements by Community Prepared 02/13/2020 Community Name Utility Name Estimated FY20 Disbursement Adak PCE TDX ADAK GENERATING LLC 262,133 Akhiok PCE AKHIOK/KAGUYAK ELECTRIC 29,565 Akiachak PCE AKIACHAK NATIVE COMMUNITY 190,005 Akiak PCE AKIAK CITY COUNCIL 101,565 Akutan PCE CITY OF AKUTAN 218,715 Allakaket; Alatna PCE ALASKA POWER COMPANY 175,775 Bettles; Evansville PCE ALASKA POWER COMPANY 38,123 Chistochina PCE ALASKA POWER COMPANY 48,197 Coffman Cove PCE ALASKA POWER COMPANY 13,827 Craig PCE ALASKA POWER COMPANY 80,103 Dot Lake; Dot Lake Village PCE ALASKA POWER COMPANY 24,173 Eagle; Eagle Village PCE ALASKA POWER COMPANY 124,908 Haines; Covenant Life PCE ALASKA POWER COMPANY 70,575 Healy Lake PCE ALASKA POWER COMPANY 17,981 Hollis PCE ALASKA POWER COMPANY 9,993 Hydaburg PCE ALASKA POWER COMPANY 15,905 Klawock PCE ALASKA POWER COMPANY 49,254 Mentasta PCE ALASKA POWER COMPANY 42,502 Naukati PCE ALASKA POWER COMPANY 7,001 Northway; Northway Village PCE ALASKA POWER COMPANY 114,206 Skagway PCE ALASKA POWER COMPANY 40,036 Slana PCE ALASKA POWER COMPANY 69,598 Tetlin PCE ALASKA POWER COMPANY 50,335 Thorne Bay; Kasaan PCE ALASKA POWER COMPANY 33,714 Tok; Tanacross PCE ALASKA POWER COMPANY 667,729 Whale Pass PCE ALASKA POWER COMPANY 4,720 Alakanuk PCE ALASKA VILLAGE ELECTRIC COOP 246,900 Ambler PCE ALASKA VILLAGE ELECTRIC COOP 185,382 Anvik PCE ALASKA VILLAGE ELECTRIC COOP 58,409 Brevig Mission PCE ALASKA VILLAGE ELECTRIC COOP 166,687 Chevak PCE ALASKA VILLAGE ELECTRIC COOP 285,811 Eek PCE ALASKA VILLAGE ELECTRIC COOP 158,204 Elim PCE ALASKA VILLAGE ELECTRIC COOP 183,093 Emmonak PCE ALASKA VILLAGE ELECTRIC COOP 386,459 Gambell PCE ALASKA VILLAGE ELECTRIC COOP 228,524 Goodnews Bay PCE ALASKA VILLAGE ELECTRIC COOP 120,345 Grayling PCE ALASKA VILLAGE ELECTRIC COOP 110,941 Holy Cross PCE ALASKA VILLAGE ELECTRIC COOP 98,411 Hooper Bay PCE ALASKA VILLAGE ELECTRIC COOP 367,375 Huslia PCE ALASKA VILLAGE ELECTRIC COOP 170,770 1 FY2020 Estimated PCE Disbursements by Community Prepared 02/13/2020 Community Name Utility Name Estimated FY20 Disbursement Kaltag PCE ALASKA VILLAGE ELECTRIC COOP 92,688 Kasigluk PCE ALASKA VILLAGE ELECTRIC COOP 213,922 Kiana PCE ALASKA VILLAGE ELECTRIC COOP 263,792 Kivalina PCE ALASKA VILLAGE ELECTRIC COOP 176,411 Kotlik PCE ALASKA VILLAGE ELECTRIC COOP 231,881 Koyuk PCE ALASKA VILLAGE ELECTRIC COOP 174,170 Lower Kalskag PCE ALASKA VILLAGE ELECTRIC COOP 105,654 Marshall PCE ALASKA VILLAGE ELECTRIC COOP 192,196 Mekoryuk PCE ALASKA VILLAGE ELECTRIC COOP 111,240 Minto PCE ALASKA VILLAGE ELECTRIC COOP 105,782 Mt. Village PCE ALASKA VILLAGE ELECTRIC COOP 328,428 New Stuyahok PCE ALASKA VILLAGE ELECTRIC COOP 195,977 Nightmute PCE ALASKA VILLAGE ELECTRIC COOP 79,659 Noatak PCE ALASKA VILLAGE ELECTRIC COOP 438,386 Noorvik PCE ALASKA VILLAGE ELECTRIC COOP 291,851 Nulato PCE ALASKA VILLAGE ELECTRIC COOP 196,859 Nunapitchuk PCE ALASKA VILLAGE ELECTRIC COOP 171,151 Old Harbor PCE ALASKA VILLAGE ELECTRIC COOP 146,682 Pilot Station PCE ALASKA VILLAGE ELECTRIC COOP 249,835 Pitkas Point PCE ALASKA VILLAGE ELECTRIC COOP 67,055 Quinhagak PCE ALASKA VILLAGE ELECTRIC COOP 277,436 Russian Mission PCE ALASKA VILLAGE ELECTRIC COOP 127,398 Savoonga PCE ALASKA VILLAGE ELECTRIC COOP 262,970 Scammon Bay PCE ALASKA VILLAGE ELECTRIC COOP 219,690 Selawik PCE ALASKA VILLAGE ELECTRIC COOP 382,710 Shageluk PCE ALASKA VILLAGE ELECTRIC COOP 57,892 Shaktoolik PCE ALASKA VILLAGE ELECTRIC COOP 98,094 Shishmaref PCE ALASKA VILLAGE ELECTRIC COOP 265,386 Shungnak PCE ALASKA VILLAGE ELECTRIC COOP 143,666 St. Mary's; Andreafsky PCE ALASKA VILLAGE ELECTRIC COOP 339,423 St. Michael PCE ALASKA VILLAGE ELECTRIC COOP 201,580 Stebbins PCE ALASKA VILLAGE ELECTRIC COOP 209,668 Teller PCE ALASKA VILLAGE ELECTRIC COOP 89,449 Togiak PCE ALASKA VILLAGE ELECTRIC COOP 385,021 Toksook Bay PCE ALASKA VILLAGE ELECTRIC COOP 238,081 Tununak PCE ALASKA VILLAGE ELECTRIC COOP 112,527 Upper Kalskag PCE ALASKA VILLAGE ELECTRIC COOP 80,115 Wales PCE ALASKA VILLAGE ELECTRIC COOP 71,453 Karluk PCE KARLUK IRA TRIBAL COUNCIL 27,376 Atka PCE CITY OF ATKA 26,618 Aniak PCE ANIAK LIGHT & POWER 233,380 Arctic Village PCE ARCTIC VILLAGE COUNCIL 179,602 2 FY2020 Estimated PCE Disbursements by Community Prepared 02/13/2020 Community Name Utility Name Estimated FY20 Disbursement Atmautluak PCE ATMAUTLUAK TRIBAL UTILITIES 151,492 Beaver PCE BEAVER JOINT UTILITIES 83,026 Bethel; Oscarville PCE ALASKA VILLAGE ELECTRIC COOP 1,545,030 Birch Creek PCE BIRCH CREEK ELECTRIC COMPANY 26,304 Buckland PCE CITY OF BUCKLAND 67,294 Central PCE GOLD COUNTRY ENERGY 76,935 Chalkyitsik PCE CHALKYITSIK VILLAGE COUNCIL 48,559 Chenega Bay PCE NATIVE VILLAGE OF CHENEGA 48,715 Chignik PCE CITY OF CHIGNIK 50,396 Chignik Lagoon PCE CHIGNIK LAGOON POWER UTILITY 52,085 Chignik Lake PCE CHIGNIK LAKE ELECTRIC UTILITY 47,347 Chitina PCE CHITINA ELECTRIC INC.32,157 Circle PCE CIRCLE ELECTRIC LLC 88,982 Clark's Point PCE CLARKS POINT VILLAGE COUNCIL 75,627 Cordova PCE CORDOVA ELECTRIC 410,510 Egegik PCE CITY OF EGEGIK 95,194 Ekwok PCE ALASKA VILLAGE ELECTRIC COOP 64,681 Ekwok PCE ALASKA VILLAGE ELECTRIC COOP 1,267 Elfin Cove PCE ELFIN COVE UTILITY COMMISSION 29,946 False Pass PCE CITY OF FALSE PASS 22,881 Cold Bay PCE G & K INC.47,895 Galena PCE CITY OF GALENA 240,353 Golovin PCE GOLOVIN POWER UTILITIES 53,708 Gustavus PCE ALASKA POWER COMPANY 101,071 Fort Yukon PCE GWITCHYAA ZHEE UTILITY COMPANY 378,622 Hughes PCE HUGHES POWER & LIGHT 115,355 Igiugig PCE IGIUGIG ELECTRIC COMPANY 80,036 Iliamna Newhalen Nondalton PCE ILIAMNA NEWHALEN NONDALTON 348,423 Angoon PCE INSIDE PASSAGE ELECTRIC 277,883 Chilkat Valley PCE INSIDE PASSAGE ELECTRIC 195,007 Hoonah PCE INSIDE PASSAGE ELECTRIC 707,410 Kake PCE INSIDE PASSAGE ELECTRIC 328,199 Klukwan PCE INSIDE PASSAGE ELECTRIC 89,469 Deering PCE IPNATCHIAQ ELECTRIC COMPANY 73,872 Kipnuk PCE KIPNUK LIGHT PLANT 350,495 Kobuk PCE ALASKA VILLAGE ELECTRIC COOP 92,361 Kokhanok PCE KOKHANOK VILLAGE COUNCIL 158,071 Koliganek PCE NEW KOLIGANEK VILLAGE COUNCIL 82,667 Kotzebue PCE KOTZEBUE ELECTRIC ASSOCIATION 917,006 Kwethluk PCE KWETHLUK INCORPORATED 178,108 Kwigillingok PCE KWIGILLINGOK IRA COUNCIL 213,006 Larsen Bay PCE LARSEN BAY UTILITY COMPANY 16 3 FY2020 Estimated PCE Disbursements by Community Prepared 02/13/2020 Community Name Utility Name Estimated FY20 Disbursement Levelock PCE LEVELOCK ELECTRICAL COOP 61,758 Lime Village PCE LIME VILLAGE ELECTRIC UTILITY 13,135 Manley Hot Springs PCE TDX MANLEY GENERATING LLC 132,501 Manokotak PCE MANOKOTAK POWER COMPANY 101,191 McGrath PCE MCGRATH LIGHT & POWER 234,806 Chuathbaluk PCE MIDDLE KUSKOKWIM ELECTRIC COOPERATIVE INC 83,905 Crooked Creek PCE MIDDLE KUSKOKWIM ELECTRIC COOPERATIVE INC 80,435 Red Devil PCE MIDDLE KUSKOKWIM ELECTRIC COOPERATIVE INC 21,852 Sleetmute PCE MIDDLE KUSKOKWIM ELECTRIC COOPERATIVE INC 87,357 Stony River PCE MIDDLE KUSKOKWIM ELECTRIC COOPERATIVE INC 32,839 Naknek;S.Naknek;Kng Slmn PCE NAKNEK ELECTRIC 720,477 Napakiak PCE NAPAKIAK IRCINRAQ 132,285 Napaskiak PCE NAPASKIAK ELECTRIC UTILITY 83,394 Chefornak PCE NATERKAQ LIGHT PLANT 126,482 Nelson Lagoon PCE NELSON LAGOON ELECTRICAL COOP 46,107 Nikolai PCE CITY OF NIKOLAI 63,273 Nome PCE NOME JOINT UTILITY SYSTEM 980,858 Anaktuvuk Pass PCE NORTH SLOPE BOROUGH 3,462 Atqasuk PCE NORTH SLOPE BOROUGH 5,327 Kaktovik PCE NORTH SLOPE BOROUGH 6,605 Nuiqsut PCE NORTH SLOPE BOROUGH 7,116 Point Hope PCE NORTH SLOPE BOROUGH 2,205 Point Lay PCE NORTH SLOPE BOROUGH 1,635 Wainwright PCE NORTH SLOPE BOROUGH 5,707 Nunam Iqua PCE NUNAM IQUA ELECTRIC COMPANY 63,959 Dillingham; Aleknagik PCE NUSHAGAK ELECTRIC AND 823,513 Ouzinkie PCE CITY OF OUZINKIE 43,812 Pedro Bay PCE PEDRO BAY VILLAGE COUNCIL 17,299 Perryville PCE NATIVE VILLAGE OF PERRYVILLE 22,219 Pilot Point PCE PILOT POINT ELECTRIC UTILITY 65,898 Port Heiden PCE PORT HEIDEN UTILITIES 66,755 Kongiganak PCE PUVURNAQ POWER COMPANY 164,826 Rampart PCE RAMPART VILLAGE COUNCIL 51,412 Ruby PCE CITY OF RUBY 118,232 Sand Point PCE TDX CORPORATION 503,087 St. George PCE CITY OF ST. GEORGE 110,681 St. Paul PCE ST. PAUL MUNICIPAL ELECTRIC 218,838 Stevens Village PCE STEVENS VILLAGE IRA COUNCIL 10,556 Takotna PCE TAKOTNA COMMUNITY ASSOC 28,912 Port Alsworth PCE TANALIAN ELECTRIC COOPERATIVE 107,382 Tanana PCE TANANA POWER COMPANY INC.154,492 Tatitlek PCE TATITLEK VILLAGE IRA COUNCIL 86,566 4 FY2020 Estimated PCE Disbursements by Community Prepared 02/13/2020 Community Name Utility Name Estimated FY20 Disbursement Tenakee Springs PCE CITY OF TENAKEE SPRINGS 81,001 Tuluksak PCE TULUKSAK TRADITIONAL 92,954 Tuntutuliak PCE TUNTUTULIAK COMMUNITY 198,058 Twin Hills PCE TWIN HILLS VILLAGE COUNCIL 36,047 Nikolski PCE UMNAK POWER COMPANY 32,532 Unalakleet PCE UNALAKLEET VALLEY ELECTRIC 211,359 Unalaska PCE CITY OF UNALASKA 648,551 Newtok PCE UNGUSRAQ POWER COMPANY 108,562 Venetie PCE VENETIE VILLAGE ELECTRIC 115,333 White Mountain PCE CITY OF WHITE MOUNTAIN 90,890 Yakutat PCE ALASKA VILLAGE ELECTRIC COOP 401,804 FY2020 Estimated disbursements 28,888,804 Rounded Estimate 29,000,000 AEA costs of administering (includes RCA RSA)355,000 Total Estimated Costs 29,355,000.00$ 5