HomeMy WebLinkAbout2022-10-26 AEA Agenda and docs
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REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
Alaska Energy Authority Board Meeting
October 26, 2022, 8:30 AM
AGENDA - UPDATED
Dial 1 (888) 585-9008 and enter code 212-753-619# Public comment guidelines are below.
1. CALL TO ORDER
2. ROLL CALL BOARD MEMBERS
3. AGENDA APPROVAL
4. PRIOR MINUTES – August 3, 2022
5. PUBLIC COMMENTS (2 minutes per person) see call in number above
6. NEW BUSINESS
A. Resolution 2022-03 – Appointment of Tim Sandstrom as Assistant Secretary /Treasurer
B. Resolution 2022-04 – Castner Law Suit Settlement C. Resolution 2022-05 - Energy 49 PPF Loan
D. Resolution 2022-06 – Power Revenue Bonds for Required Project Work
i. Memo from Executive Director
ii. Resolution 2022-06 Power Revenue Bonds for Required Project Work
iii. Tenth Supplemental Resolution (substantially final form)
iv. Loan Agreement (substantially final form)
v. BPMC Resolution 22-08 Financing of the Proposed Transaction
vi. Utility Resolutions
vii. BPMC Resolution 22-04 Development of the Required Project Work
viii. Consultant Opinion of Required Project Work
ix. Department of Law Opinion of Required Project Work
x. Letter from BPMC to Department of Law – Required Project Work
xi. Power Sales Agreement
xii. Board Action and Media Coverage for Required Project Work Power Revenue Bonds
7. OLD BUSINESS
A. Rural Power House Assessment Demonstration
8. DIRECTOR COMMENTS
A. Budget Overview (Executive Session – To discuss to confidential financial matters, the immediate knowledge of which would have an adverse effect on Alaska Energy Authority)
B. Audit Update
C. Black Rapids Grant
D. IIJA 40101(D) Grid Resiliency Grant Program Update
E. Renewable Energy Grant Fund (REF) Program Update
F. Alaska Cargo and Cold Storage (ACCS) Update
G. Electric Vehicle (EV) Update – Plan Approved September 27, 2022
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H. Denali Commission Update
I. Juneau Hydro / Sweet Heart Lake Investment
J. Electric Utility Relief Program (EURP) Update
K. 2023 Proposed AEA Board Meeting Schedule
L. Community Outreach
M. Articles of Interest
N. Next Regularly Scheduled AEA Board Meeting Wednesday, December 7, 2022
9. BOARD COMMENTS
10. ADJOURNMENT
Public Comment Guidelines Members of the public who wish to provide written comments, please email your comments to
publiccomment@akenergyauthority.org by no later than 4 p.m. on the day before the meeting, so they can be shared with board members prior to the meeting.
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813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
Alaska Energy Authority BOARD MEETING MINUTES Wednesday, August 3, 2022 Anchorage, Alaska 1. CALL TO ORDER
Chair Pruhs called the meeting of the Alaska Energy Authority to order on August 3, 2022, at 8:31
am. A quorum was established. Chair Pruhs informed that Commissioner Sande will arrive late.
2. ROLL CALL BOARD MEMBERS
Members present: Chair Dana Pruhs (Public Member); Vice-Chair Bill Kendig (Public Member); Julie
Sande (Commissioner DCCED) (Arrived 9:43 a.m.); Albert Fogle (Public Member); Deven Mitchell
(SOA-DOR); Bill Vivlamore (Public Member); and Randy Eledge (Public Member).
3. AGENDA APPROVAL
Vice-Chair Kendig requested an amendment to the agenda, adding Executive Session as Item 8.
and renumbering the subsequent items.
Curtis Thayer, Executive Director, provided an update on the pending lawsuit in Homer Superior Court of Kenneth Castner versus AIDEA and AEA. The lawsuit alleges both AIDEA and AEA Board’s have continuously violated the Open Meetings Act since September of 2020. Counsel for AIDEA and AEA has discussed a settlement with Mr. Castner. As of Monday afternoon, the proposed settlement agreement has been determined and resolves the issue of the preliminary injunction hearing scheduled for Friday, August 5, in Homer. The agreement is only binding if AIDEA and AEA Board’s take action and approve the written settlement.
Mr. Thayer informed that Assistant Attorney General Gene Hickey, Department of Law, is available today to present to AIDEA and AEA Boards the proposed settlement agreement, to explain the legal requirements for the settlement agreement, and to provide legal advice concerning the ramifications. Mr. Thayer requested the Board enter into an Executive Session during the meeting to discuss the proposed settlement agreement with Mr. Hickey.
MOTION: A motion was made by Vice-Chair Kendig to amend the agenda, adding an Executive Session as Item 8. Motion seconded by Mr. Vivlamore.
The motion to amend the agenda, adding Executive Session as Item 8., passed without
objection.
MOTION: A motion was made by Vice-Chair Kendig to approve the amended agenda.
Motion seconded by Mr. Vivlamore.
The motion to approve the amended agenda passed without objection.
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4. PRIOR MINUTES – May 25, 2022 MOTION: A motion was made by Vice-Chair Kendig to approve the prior minutes of May 25, 2022, as presented. Motion seconded by Mr. Vivlamore.
The motion to approve the minutes of the May 25, 2022, passed without objection. 5. PUBLIC COMMENTS (2 minutes per person) - NONE
There were no members of the public online or in-person who requested to comment.
6. NEW BUSINESS - NONE
7. OLD BUSINESS
A. BPMC’s prepayment of certain debt obligations to the SSQ Line
Mr. Thayer discussed the notification included in the Board packet for the Bradley Lake Project
Management Committee’s (BPMC) prepayment of $11.5 million to the Power Revenue Bond, 10th Series. The prepayment includes interest of $293,000, principal of $10.9 million, and a prepayment
penalty of $266,000. The outstanding loan balance is $6,060,000, and the borrower is responsible
for revised principal and interest payments through July 2040 per the Loan Agreement.
Chair Pruhs asked if each utility paid their percentage of the BPMC prepayment. Mr. Thayer agreed, and explained that the approved funds were the remaining FY22 Bradley Lake excess payments. There were no other questions.
MOTION: A motion was made by Vice-Chair Kendig to enter into Executive Session to permit Assistant Attorney General (AAG) Hickey to present to the Board the proposed settlement agreement between Kenneth Castner and AIDEA and AEA, and for the purpose of Mr. Hickey to offer his analysis, to answer Board questions and concerns, and to provide legal advice concerning the proposed settlement agreement. This matter is protected by attorney/client privilege. Executive Session on this topic is permitted under AS 44.62.310(c)(1), which provides that an Executive Session is appropriate to discuss matters which by law are required to be confidential. Motion seconded by Mr. Vivlamore. A roll call was taken, and the motion to enter into Executive Session was approved unanimously, with Commissioner Sande absent.
8. EXECUTIVE SESSION: 8:40 am Discuss a possible settlement in Castner v. AIDEA and
AEA, Docket No. 3HO-20---265CI
The Board reconvened its regular meeting at 8:56 am. Chair Pruhs advised that during Executive
Session, Counsel presented the proposed settlement agreement between Mr. Castner and AIDEA
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and AEA, provided legal advice on the proposed settlement, and answered questions. The Board did not take any action on the proposed settlement agreement during Executive Session. Chair Pruhs requested Mr. Hickey provide additional information. Mr. Hickey discussed that a hearing is scheduled pertaining to Mr. Castner’s application for a preliminary injunction on August 5, 2022. The proposed settlement agreement resolved the application for preliminary injunction and resolved the case as a whole. Mr. Hickey recommended that the Board entertain a motion to approve the settlement agreement between Mr. Castner and AIDEA and AEA.
MOTION: A motion was made by Vice-Chair Kendig to approve the proposed settlement
agreement between Mr. Castner and AEA, and to give authority to Mr. Thayer to sign the
agreement. Motion seconded by Mr. Vivlamore.
A roll call vote was taken, and the motion to approve the proposed settlement agreement
between Mr. Castner and AEA, and to give authority to Mr. Thayer to sign the agreement
passed unanimously, with Commissioner Sande absent.
9. DIRECTOR COMMENTS
A. Response to Board Questions
Mr. Thayer discussed that Item 1., the demonstration of the Rural Power House Assessment is not available today due to a corrupt file that was found during the test yesterday. The information will be provided at the next meeting. Mr. Thayer noted that Items 2. and 3. are currently on hold. Item 4., the cost per kWh related to hydro, is attached in the Board packet. B. Letter from Dept. of Administration regarding AEA FY22 Audit Mr. Thayer discussed the included letter from Department of Administration regarding the AEA FY22 Audit. The letter requests notification if AEA cannot meet the audit schedule of audited financial statements by October 17. Mr. Thayer indicated that AEA is not going to meet the audit schedule due to challenges with the large amount of staff turnover. The closing of the books has been delayed by at least a month, which has caused further delay in the audit. Mr. Thayer reported that AEA currently has position vacancies for Comptroller and Assistant
Comptroller. There have been three different Comptrollers this year. Two of them were hired by
other utilities and the third one returned to the private sector. An RFP for accounting firm services
has been submitted and no replies have been received. Mr. Thayer believes the delay in the audit
will be 60 days to 90 days. He noted that resources will not be pulled from AIDEA because AIDEA
is on track with their schedule and AIDEA recently lost their Comptroller. AEA will continue to
look for outside auditors to assist in the preparation of the audit. Mr. Thayer discussed the
challenges in the industry that no auditors have responded to the RFP. He stated that updates
will be provided to the Board on a regular basis.
Chair Pruhs asked what the ramifications are for submitting a late audit. Mr. Thayer indicated that
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staff will make the requested notification of the delay to Department of Administration and will contact the Legislative Budget and Audit Committee to develop a plan going forward. Mr. Thayer noted that it is not uncommon for agencies to have problems. However, he does not have any specific information regarding other agencies. Chair Pruhs commented that his business’s annual audit this year was delayed by four months. He asked for an update on the replacement personnel. Mr. Thayer indicated that interviews for Comptroller and Assistant Comptroller are occurring. Previous personnel who are now retired
have returned by contract to assist in the training.
Mr. Mitchell asked if the RFP effort for the audit services was both in and out of state. Mr. Thayer
indicated that the RFP was both in and out of state. Mr. Mitchell commented that the Municipality
is also seeking a Comptroller. He noted the difficulty in finding qualified accounting staff. Mr.
Thayer discussed that AEA submits many federal filings for grants each year. He informed that
Tim Sandstrom, Chief Operating Officer, and his team have assisted in the submittal of all grant
reporting for this year.
Mr. Mitchell asked if staff will be able to provide draft financials to Department of Administration
in order for the State CAFR to be completed by their scheduled due date of December 15, 2022.
Mr. Mitchell indicated that an unidentified person was nodding in the affirmative. Chair Pruhs requested that Mr. Thayer let the Board know if there is anything they can do to help with the process. Mr. Thayer agreed. He reiterated that the struggle is in finding people to assist with the preparation. Mr. Fogle requested additional information on the process. He asked if the completed draft financials will be emailed to Board members for review prior to a Board meeting. Mr. Thayer agreed. C. Owned Assets Update Mr. Thayer discussed the Owned Assets Update included in the Board packet. AEA is working with Chugach Electric Association (CEA) to perform and procure the AEA-owned Sterling-Quartz (SSQ) section upgrade. A public meeting was held in June regarding the Dixon Diversion and was
followed by a site visit the next day. Media attended and the visit was well-received. The Intertie
and the Bradley Lake Hydroelectric Project are both running smoothly at this time. Mr. Thayer
noted that lake water levels are higher now than they were at this time last year.
D. Bradley Lake Required Project Work Update
Mr. Thayer advised that the included Bradley Lake Required Project Work information regards the
financing of the transmission upgrades. AEA has been working with the utilities on developing
the term sheet that is acceptable to all parties. The draft term sheet from the National Cooperative
Services Corporation is included in the Board packet for informational purposes. Mr. Thayer
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discussed the bond fund advisors and counsel AEA is currently utilizing. He reviewed the timeline of the process. Mr. Thayer noted the challenge of rising interest rates. When the financing ability process was announced, the anticipated amount was about $200 million. With the rise of interest rates, the amount is now closer to $170 million. The total cost of the projects was about $270 million. Mr. Thayer indicated the possibility that rates could increase again before the process is complete, which would further reduce the $170 million. The intent is for AEA and the utilities to improve the
scheduled timeline of final closing and funding before December 15 in order to receive the best
interest rates.
Chair Pruhs requested that a schedule is provided at the next Board meeting that includes each
of the required work projects with their anticipated start and finish dates. Mr. Thayer agreed. He
noted that those discussions are occurring with the utilities because the availability of the projects
decreases as the amount of funding decreases. Mr. Thayer discussed that Department of Law’s
memos allow for great flexibility in the projects. The primary focus with this tranche of funding is
on AEA’s Sterling to Quartz Creek project funding and other transmission upgrades.
E. State Energy Program (SEP) Update
Mr. Thayer discussed that the SEP is a federal program and additional lump-sum funding of approximately $4 million anticipated through the Infrastructure Investment and Jobs Act (IIJA). This will be shared with Alaska Housing Finance (AHFC). One of the IIJA requirements is for the State to develop a state energy plan (Energy Security Plan). AEA applied and received a grant for $200,000 to develop the state energy plan. The development and drafting of the plan will involve third-party participation, including Enstar, Department of Natural Resources (DNR), Department of Environmental Conservation (DEC), and others. The comprehensive plan is due in June of 2023. F. Power Cost Equalization (PCE) Memo Mr. Thayer discussed the PCE FY24 budget information from Department of Revenue. The average monthly market value of the fund for the previous three closed fiscal years is about $1.1 billion. The fund had losses of $143 million last year. The fund had earnings of approximately $150 million in the previous year and provided full funding of PCE, funding for community assistance, funding
for powerhouse, and funding for the Renewable Energy Program.
Mr. Thayer explained that the Legislature passed a bill that was signed by the Governor last month
that increased the payment of PCE in rural Alaska from the first 500 kWh to the first 750 kWh. This
increases the cost of the program from $30 million to about $45 million. The calculated amount
of funding this year is about $50 million, which will fully fund PCE, but will not provide funding for
other programs. He expressed concern that if the market returns for next year yield another loss,
there is a possibility that full funding for PCE at the 750 kWh level will not be available. Mr. Thayer
indicated this will be addressed as a broader conversation with the Governor’s Office and with the
Legislature. He does not believe that the potential loss of 10%, such as this, was anticipated.
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Chair Pruhs asked what choices are available if that scenario occurs. Mr. Thayer indicated that choices include withdrawing from the corpus of the fund, withdrawing from general funds, or adding funds to the corpus. Chair Pruhs asked if there a trigger clause if the returns on the fund do not meet the cost of the 750 kWh. Mr. Thayer commented that the endowment fund has never experienced being negative into the PCE. He noted the combination of the factors that the earnings are down and the payout has increased by 50%. Mr. Thayer explained that in the past, the PCE payment in rural Alaska was 750 kWh and then the State reduced it to 500 kWh, and it has now been increased back to 750 kWh.
Mr. Mitchell commented that there are many advocates for the fund. He believes it is important
to focus attention on the primary purpose of the fund. Mr. Mitchell reiterated the message of
potential concern should be conveyed to OMB, AML, and others that if there are additional
reductions to the corpus of the funds, then the 5% payout will not be able to fund the PCE
payment of 750 kWh. Mr. Thayer agreed and noted that he is meeting with AML later this month
regarding this issue.
Chair Pruhs asked if the statute includes a target return rate for the fund. Mr. Thayer indicated
that it does not. He noted that the language has a description of prudent investor returns. Chair
Pruhs asked if he is correct that the fund lost over 10% of its value in12 months. Mr. Mitchell
commented that the fund probably earned 20% last year. Mr. Thayer discussed that the operation of the fund and program were changed about eight years ago and this is the sharpest decline in return since that time. G. Renewable Energy Fund (REF) Update Mr. Thayer discussed the REF Update for Round 14. The information includes a summary of applications by energy region and by technology type. The Governor included $15 million in the budget and the Legislature approved the amount. There are 27 projects, totaling $14,972,000. The process is underway for the distribution of the grant monies. Chair Pruhs inquired if AEA is watching the events of the geothermal project in Unalaska, Dutch Harbor. Mr. Thayer agreed. Chair Pruhs requested an update. Mr. Thayer noted that conversations with the Governor’s Office have been ongoing regarding the project and there has not been a determination if State resources can be provided. Mr. Thayer discussed that the
change in Unalaska from a diesel fuel source to a geothermal fuel source does not change the
price to the community. He explained that because of the location and the limited number of
people, the USDA federal funding to refinance the project at 3% could be available only after the
project is built and operational. Mr. Thayer commented that discussions continue with legislators
and the Governor’s Office regarding the ultimate policy on the issue.
Chair Pruhs asked for the amount of grant funding needed for the project. Mr. Thayer noted that
the project would need in excess of $100 million in the form of a grant subsidy. Chair Pruhs asked
if the project has a rate of return. Mr. Thayer expressed his understanding that the most recent
rate of return on the project is 6%. Mr. Thayer noted that legislative approval is necessary for
either funding or AEA ownership of the project.
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Chair Pruhs discussed the possibility of utilizing $50 million or $100 million from the PCE Fund for two years and investing in the geothermal project in rural Alaska instead of the stock market. He noted that the PCE Fund would then receive the 6% rate of return for the next 30 to 40 years, with the guarantee of the Federal Government. Chair Pruhs asked Mr. Mitchell if that is a viable option or if the State has any mechanisms within Revenue that would address this option. Mr. Mitchell noted that the mechanism would have to be legislatively mandated. Chair Pruhs expressed understanding that the Legislature would have to mandate any agreement. Chair Pruhs asked Mr.
Mitchell if the option or mechanism is available.
Mr. Mitchell commented that the 6% rate of return is high for a short-term investment. He noted
that there are risks and other considerations associated with this investment. Mr. Mitchell
discussed the option would be similar to interim financing provided for the Yukon-Kuskokwim
Health Corporation’s hospital project in Bethel, in which the USDA guaranteed a loan upon
completion of the hospital. Mr. Mitchell commented that the City currently owns the electric utility
in Unalaska and any agreement would need to make them whole. Mr. Thayer explained that the
Village Corporation and the utility have a Power Sales Agreement with conditions. Chair Pruhs
agreed that there are a multitude of related details and his question was focused on the big
picture. He thanked Mr. Thayer for the update and requested additional information when
available. H. Power Project Fund - Southfork Hydro, LLC Mr. Thayer reviewed the informational page regarding the consideration of the Power Project Fund (PPF) Loan Committee’s refinance of Southfork Hydro’s loan. The borrower is located in the Eagle River Valley and sells power to Matanuska Electric Association (MEA). The refinance request was made in order to help finance an additional turbine in the powerhouse, which will increase the power sales to MEA. I. Alternative Energy & Energy Efficiency (AEEE) Update Mr. Thayer noted that included in the Board packet is a list of the ongoing projects within the AEEE Program led by Director Audrey Alstrom. Many of the projects are related to the REF funding.
J. Electric Vehicle Update
i. State of Alaska NEVI Plan
Mr. Thayer reviewed that the public comment period ended recently regarding the Electric Vehicle
Infrastructure Implementation Plan (The Plan) that was filed with the US Department of Energy
and Federal Highways, in conjunction with Department of Transportation (DOT). Mr. Thayer
highlighted for the record that the submitted Plan is a living document that can be changed and
updated. A notification will occur within 60 days if the Plan needs to have changes made this
year. If no changes are necessary, then the funding for this year will be approximately $7.8 million.
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There is $50 million available over the course of five years. AEA is the lead agency and the grant runs through DOT, who handles the accounting and reporting requirements. A press release is anticipated with Commissioner Ryan Anderson. Mr. Thayer discussed that an MOU is being developed between AEA and DOT regarding the split of the costs. The State budget did not allow for funding for AEA to apply for additional EV in rural Alaska. Rural Alaska is disqualified from this Plan because they are not part of the national highway corridor or the marine highway system.
Mr. Thayer complimented Ms. Alstrom and her team for completing the over 100-page Plan within
the 60-day timeframe. He requested that she review the included PowerPoint presentation. Ms.
Alstrom discussed that the AEEE is leading the EV effort for AEA through the IIJA’s National Electric
Vehicle Infrastructure (NEVI) Program. She reiterated that the Plan is slated to receive $7.8 million
in the first year, and a total of $50 million over the next five years. The funding is 80% Federal
and requires a 20% State or private match.
Ms. Alstrom reviewed the graphic showing the highway system within Alaska, including the
designated alternative fuel corridor (AFC) that was nominated by DOT in Round 4. One of the
NEVI requirements is that states must build out their designated alternative fuel corridors first.
This is the section between Anchorage and Fairbanks. The EV charging stations must meet certain NEVI requirements. Each station must be within 50 miles of each other. There is one section between communities in the AFC that is 80 miles apart and is without a power source. An application was submitted for a discretionary exception to the 50-mile rule. Stations must have at least four charging ports that are capable of charging 150 kW simultaneously. Once the AFC is built out, any excess funds can be used elsewhere. Ms. Alstrom reviewed the NEVI Program timeline and the overview of NEVI requirements. She noted that the Alaska Electric Vehicle Working Group discussed and developed the overall plan vision and goals listed within the presentation. Ms. Alstrom explained the outlook for the five-year program and build-out is divided into four phases. Phase 1 is the build out of Alaska AFC. Phase 2 is the build out of Alaska’s highway and marine highway systems. As funding allows, Phase 3 is the installation of charging stations in rural hub communities. Phase 4 is the installation of charging stations in urban and “destination” locations.
Ms. Alstrom discussed the contracting options and strategies for acquisition of the equipment,
installation, and operations and maintenance (O&M). The preferred option was determined to be
a competitive grant program. Ms. Alstrom noted that the Volkswagen Mitigation Trust is currently
installing nine stations between Homer and Healy at approximately every 100 miles. This is not
NEVI compliant. The NEVI effort requires the placement of the charging stations every 50 miles
within the stated corridor. Ms. Alstrom informed there are about 1,300 EVs in the state. She
discussed the growth scenarios over the next five years based on continued growth and
aggressive growth. Ms. Alstrom reviewed the graphic illustrating that the Railbelt has more than
enough grid capacity to meet the needs of the installation of the charging stations.
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Ms. Alstrom highlighted the evaluation of the risks and challenges of the plan and program. She discussed the lack of development in areas, climate challenges, barriers to consumer adoptions, energy sources and costs, and private investment challenges. The funding burden on the site host is expected to be approximately $200,000. This could limit participation. Ms. Alstrom reviewed the strategies for implementation of the plan, including O&M, identification of site hosts, data collection, snow removal, workforce development, and consideration of State fleet transition. A focus on cyber security will also be addressed in the Plan.
Ms. Alstrom informed that Federal programs include civil rights and equity considerations, which
are compliant with Title VI, Americans with Disabilities Act (ADA), Disadvantaged Communities
(DACs), and Justice40. These considerations ensure that infrastructure is inclusive and accessible
to all. The Justice40 Initiative is an effort that 40% of all the benefits of the program will go to a
disadvantaged community. Of the stakeholder list identified for Alaska’s Plan, about half of the
entities qualify as being located in a disadvantaged community. Other benefits include workforce
development opportunities and retention within the state. There are currently three EV IPP
certified contractors within the state. Ms. Alstrom advised that included in the Board packet is the
over 100-page Plan that was submitted.
Commissioner Sande asked if it is cost prohibitive to consider adding transmission in the 80-mile
area where there is currently no service. Ms. Alstrom noted that informal estimates that considered installation of a solar farm to support the compliant EV charging site were cost prohibitive. Commissioner Sande asked if there is a possibility that the funding may not be fully expended because of the Justice40 element. She noted that many of the disadvantaged communities may not have an interest or the ability for EV charging infrastructure. Ms. Alstrom commented that is not a high concern. She discussed that based on census data, a map was released of all of the disadvantaged communities and included most of Alaska. Vice-Chair Kendig asked what size of solar farm would be needed to be compliant for the four-stall EV charging station. Ms. Alstrom discussed that the estimates for the needs of the charging station is up to 600 kW at once and solar typically has a capacity factor of 20%, which would be approximately 4,800 kW or 5 MW. Mr. Eledge expressed appreciation and complimented Ms. Alstrom and the team on the comprehensive implementation plan. He asked if any agency has plans to address the end of life-
cycle ramifications of EVs. Ms. Alstrom noted that those discussions have not been considered
yet and believes they will occur at a later point, based on public feedback. Mr. Eledge expressed
particular concern regarding the rural communities that may be serviced by airplanes in the
summer.
K. EURP Update
Mr. Thayer noted the Electric Utility Relief Program (EURP) Update is included in the Board packet.
Round 1 of the program included 35 grantees and disbursed $2.9 million. Round 2 of the program
included five grantees and disbursed $37,000. Round 3 of the program included 10 grantees and
disbursed $435,000. There is currently $3.4 million available from the original designated amount
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of $6.8 million. Mr. Thayer will discuss with Department of Commerce to relieve AEA of this program. L. AEA/ GVEA Black Rapids Training Center Line Extension Grant Mr. Thayer discussed that the AEA / Golden Valley Electric Association (GVEA) Black Rapids Training Center Line Extension Grant is a necessary partnering project that is not within AEA’s normal day-to-day operations and is within the category of other duties, as assigned. The
opportunity utilizes infrastructure funds that can be applied for by a State agency. The application
for $12 million was submitted and is being reviewed. The application is included in the Board
packet. If the application is successful, GVEA would supply the match and AEA would administer
the funds as a pass-through.
M. AEA Whittier Chugach Electrification Project Grant
Mr. Thayer informed that the AEA Whittier Chugach Electrification Project Grant is through U.S.
DOT and the Port Infrastructure Development Program. The application for $10 million is to
electrify the dock in Whittier so that the ships can plug into shore power rather than running their
engines for power. Partners include CEA and City of Whittier. The application is included in the
Board packet. Mr. Thayer discussed that if the grant application is successful, it can be duplicated in Ketchikan, Juneau, Sitka, Seward and other ports. This project aligns with AEA’s mission. Commissioner Sande expressed her understanding that these efforts have to be completed because the cruise industry will have to respond to the new regulations. Mr. Thayer agreed. He noted that this is a $10 million project and if other projects occur that are $50 million or $70 million, then a discussion will need to occur regarding the effect of staffing levels and the administration of the program. Mr. Thayer discussed that there is currently a $5 per head tax on cruise ships for the first five ports of call. The State receives a portion of the head tax and the funds have to be used for projects that benefit the cruise industry. There is the opportunity for the State match to be funded by the head tax since the project directly benefits the cruise industry. Commissioner Sande asked if AEA is taking the lead in the conversations with the communities regarding the grant and application process. Mr. Thayer agreed it is appropriate for AEA to answer any questions from communities. He noted that this is the first application submitted and if it is
successful, then it can be modeled across the state. Mr. Thayer commented that CEA has the grid
to support electrification of the terminal and the project may be more challenging in other parts
of Southeast Alaska, depending on whether or not the local grid can support the additional power
needs. He believes that AEA’s role will be as a conduit. Partnership with the utilities, local
community, and the cruise ship industry will need to occur.
Commissioner Sande expressed appreciation for all of the ways the State has participated in this
process.
Chair Pruhs commented on the benefits for the cruise ships if they can plug in while docked and
not run their generators. He asked if it is the intent that a four-month business does not burden
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the residents of the area 12 months of the year. Mr. Thayer discussed that one of the conditions to be considered is to ensure that the community can support the additional power needs. He noted that this is not a major issue for CEA, for instance, but it would be more challenging in other communities, such as Juneau, who currently does not have enough hydro power capacity to support all of the opportunities. Mr. Mitchell informed that Juneau currently has an electrified dock with an interruptible power agreement and subsidized rate. He believes that Ketchikan is well-positioned to follow the same
model. He noted that some communities will have challenges.
Commissioner Sande believes that the communities that have capacity will be working and
planning with AEA. She believes that the communities that have capacity issues will focus on
building up their general power needs, as well as cruise ship shore power. There were no
additional questions.
Mr. Thayer commented on another topic that is not included in the Board packet. He discussed
there is funding of $60 million for transmission grid upgrades for grid resilience and reliability.
Staff was proactive during the legislative session and obtained the federal receipt authority and
at least two years’ of State match. The application period has been released and the application
is due September 30. Notification of an award will occur two months after the application is submitted. Staff is working to complete the application. This will benefit those on the Railbelt. The program will mirror the REF Program criteria and will include an application process, analysis, and technical feasibility. Staff will provide a presentation to the Board if the application is awarded. Mr. Thayer noted that new competitive programs are being announced daily regarding additional IIJA funds. He informed that Amy Adler, former AEA Comptroller and CFO, has been contracted back to be the IIJA Coordinator to assist in the internal management of the IIJA funding and applications. Commissioner Sande commented that Mr. Thayer has been a wonderful resource for the State. She noted that the Agency is clearly positioned and is forward-thinking in their efforts. Commissioner Sande expressed that she is thankful and proud of staff for their service. Mr. Thayer recognized that AEA has assembled a very good team. He noted that two new engineers have
been identified and will be hired to assist with owned assets. An Assistant Project Manager
vacancy has recently been filled to assist Ms. Alstrom and her team.
N. Community Outreach
Mr. Thayer informed that many community outreach opportunities have occurred recently. The
schedule is provided within the packet. Much attention has been received, especially nationally,
regarding Alaska’s EV efforts.
O. Articles of Interest – Included in packet.
Alaska Energy Authority Page 12 of 12
P. Next Regularly Scheduled AEA Board Meeting, Wednesday, September 14, 2022 Mr. Thayer noted that he will attend the next meeting on September 14 via MSTeams, as he will be at the final session of the National Renewable Energy Laboratory Executive Academy. Commissioner Sande advised that she will also attend the September 14 meeting via MSTeams, as the date coincides with the Southeast Conference.
10. BOARD COMMENTS
Mr. Eledge complimented and thanked Mr. Thayer for the recent AEA outreach presentation
provided at the Chamber of Commerce. Mr. Eledge commented that moose season is
approaching.
Mr. Fogle expressed appreciation for today’s presentations and information.
Chair Pruhs thanked Mr. Thayer and staff for their efforts.
11. ADJOURNMENT There being no further business of the Board, the AEA meeting adjourned at 10:13 am.
___________________________________________________ Curtis W. Thayer, Excutive Director / Secretary
AEA Resolution No. 2022-03
ALASK ENERGY AUTHORITY
RESOLUTION NO. 2022-03
RESOLUTION OF THE ALASKA ENERGY AUTHORITY
RELATING TO THE APPOINTMENT OF TIM SANDSTROM
AS CHIEF OPERATING OFFICER AND ASSISTANT
SECRETARY TREASURER OF THE AUTHORITY
WHEREAS, the Bylaws of the Alaska Energy Authority (“Authority”) provides inter
alia that the Authority may appoint persons as officers it considers advisable;
WHEREAS, the Bylaws of the Alaska Energy Authority (the “Bylaws”) provide that
the members of the Authority may employ such personnel as they deem necessary to exercise
the powers, duties and functions prescribed by AS 44.88 and all other applicable laws of the
State of Alaska;
WHEREAS, the Executive Director recommends that Timothy Sandstrom be
appointed to the position of Chief Operating Officer to provide executive management and
oversight over AEA programs in fulfillment of the Authority's statutory purposes; and
WHEREAS, the Executive Director additionally recommends that Timothy Sandstrom
be appointed Assistant Secretary-Treasurer.
NOW, THEREFORE, BE IT RESOLVED BY THE ALASKA ENERGY
AUTHORITY AS FOLLOWS:
Section 1. The appointment of Timothy Sandstrom as Chief Operating Officer is
hereby affirmed. The Chief Operating Officer shall report to the Executive Director and shall
provide management, oversight, and direction to the Authority. The Chief Operating Officer
shall also perform such other duties as the Board may assign to him from time to time, or as the
Executive Director may delegate to him from time to time.
Section 2. Timothy Sandstrom is hereby appointed Assistant Secretary-Treasurer to
perform all or part of the Secretary-Treasurer duties as may be delegated by the Executive
Director.
Section 3. Upon passage and approval, the actions authorized by this Resolution
shall be effective retroactive to ___________, 2022.
AEA Resolution No. 2022-03
DATED at Anchorage, Alaska, this 26th day of October, 2022.
Chairman
Secretary CORPORATE SEAL
AEA Resolution No. 2022-04 Castner Settlement Agreement
Page 1
ALASKA ENERGY AUTHORITY
RESOLUTION 2022-04
RATIFYING THE AUGUST 3, 2022 SETTLEMENT AGREEMENT
BETWEEN KENNETH W. CASTNER III, THE ALASKA ENERGY
AUTHORITY AND THE ALASKA INDUSTRIAL DEVELOPMENT
AND EXPORT AUTHORITY
WHEREAS, Kenneth W. Castner III (Castner) filed a lawsuit against the Alaska energy
Authority (AEA) and the Alaska Industrial Development and Export Authority (AIDEA)
alleging various violations of the Alaska Open Meetings Act, AS 44.62.310 et seq.;
WHEREAS, Castner, AEA and AIDEA have entered into a written settlement agreement
(Settlement) as of August 3, 2022;
WHEREAS, the AEA Board of Directors approved the Settlement by motion and roll
call vote at its August 3, 2022 meeting and it authorized its executive director to sign the
Settlement on behalf of AEA; and
WHEREAS, AEA desires to officially ratify the approval of the Settlement via
resolution.
NOW THEREFORE, BE IT RESOLVED, by the Board of Directors of the Alaska
Energy Authority that the August 3, 2022 Settlement is hereby ratified.
The Resolution was declared adopted on this 26th day of October, 2022.
ALASKA ENERGY AUTHOIRTY
______________________________
J. Dana Pruhs, Chair
_____________________________ [SEAL]
Curtis W. Thayer, Secretary
ALASKA ENERGY AUTHORITY
RESOLUTION NO. 2022-05
A RESOLUTION OF THE ALASKA ENERGY AUTHORITY
REGARDING A POWER PROJECT FUND LOAN BY THE
AUTHORITY TO ENERGY 49 LLC.
WHEREAS, Energy 49 LLC (“Applicant”) has applied to the Alaska Energy
Authority (“Authority”) for a loan in the amount up to $4,994,500, with a term of 25 years, under
the Authority’s power project fund program (AS 42.45.010), at the statutory prevailing rate of
interest per AS 42.45.010(f)(2)(A) as of May 27, 2022 (the “Loan Application”), and the PPF Loan
Committee has recommended approval of the loan under such terms;
WHEREAS, the nature, purpose and terms of the Loan Application are described
in the PPF Loan Committee Recommendation, attached as Exhibit “A.”;
WHEREAS, the Authority has determined that the Applicant is an eligible borrower
as per power project fund statute AS 42.45.010(b)(1);
WHEREAS, the Authority has determined that the Loan Application is for an
eligible project, as per power project fund statute AS 42.45.010(b)(1)(B);
WHEREAS, 3 AAC 106.110(d) requires that a loan from the power project fund be
approved by the Authority’s Board if the subject loan will exceed $2,000,000;
WHEREAS, 3 AAC 106.110(d) requires that the approval or disapproval of a power
project fund loan be in the form of a written determination that contains the findings required by 3
AAC 106.110;
WHEREAS, the PPF Loan Committee has recommended findings required by 3
AAC 106.110(d) in the PPF Loan Committee Recommendation, a copy of which is attached as
Exhibit A;
WHEREAS, the PPF Loan Committee has recommended that the Authority
approve the Loan, as described in the PPF Loan Committee Recommendation and in the Term
Sheet, a copy of which is attached as Exhibit B; and
WHEREAS, it is in the best interest of the Authority to approve the Loan.
NOW, THEREFORE, BE IT RESOLVED BY THE ALASKA ENERGY
AUTHORITY AS FOLLOWS:
AEA Resolution No. 2022-05 Page 2 of 2
Section 1. The written findings recommended by the PPF Loan Committee, as
required by 3 AAC 106.110(d), and contained in the PPF Loan Committee Recommendation,
attached as Exhibit A, are adopted and incorporated by reference as part of this Resolution.
Section 2. The Term Sheet attached as Exhibit B, is adopted and incorporated
by reference as part of this Resolution.
Section 3. The PPF Loan Committee’s recommendation to approve the Loan for
the Energy 49 LLC Houston solar project, as described in the Term Sheet attached as Exhibit B,
is accepted, adopted and approved.
Section 5. This Resolution is the final decision of the Authority regarding the Loan
Application for the Energy 49 LLC Houston solar project.
Section 6. The Executive Director of the Authority is authorized to take such
actions as may be necessary or convenient to consummate the Loan including, without limitation,
issuing a commitment with respect to the Loan. The Executive Director is further authorized to
approve other such changes in the terms and conditions of the Loan as the Executive Director, in
his discretion, determines appropriate, provided that such changes do not create a detrimental
material change to the Authority under the terms and conditions of the Loan.
DATED at Anchorage, Alaska on this 26th day of October, 2022.
J. Dana Pruhs, Chair
Curtis W. Thayer, Secretary
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
RGYAUTHORITY.ORG
MEMORANDUM
TO: Alaska Energy Authority Board
THRU: Curtis. W. Thayer, Executive Director
FROM: PPF Loan Committee
DATE: October 12, 2022
RE: AEA Resolution No. 2022-05 / Energy 49 LLC PPF Loan Application
Resolution No. 2022-05 would approve the Power Project Fund (“PPF”) loan application from
Energy 49 LLC (“Borrower”) for the proposed 6MW-AC Houston Solar Farm project (“Project”)
located in Houston, AK within the Matanuska-Susitna Borough (“MSB”), approximately 1.5 miles
west on Hawk Lane from the intersection with the Parks Highway. GPS coordinates for the site
are 61°35'15.03"N, 149°47'18.45"W.
Project Ownership
The solar farm facility will be owned by Energy 49, LLC, an Alaska limited liability company. At
the time of AEA’s receipt of the PPF loan application, Energy 49 was wholly-owned by
Renewable IPP, LLC (“RIPP”), an Alaska limited liability company. RIPP is the company
responsible for the development and operation of the Willow Solar Farm project, the largest
utility-scale solar farm in Alaska to-date. In July 2022, 100% of the ownership of Energy 49 was
transferred from RIPP to Glacier Bay Solar LLC c/o CleanCapital Holdings LLC (“CleanCapital”), a
Delaware limited liability. Such a transfer was made known to AEA within the loan application.
Glacier Bay Solar LLC is registered with the State of Alaska Dept. of Commerce, Community, and
Economic Development (“DCCED”) to conduct business in Alaska under license #2164971.
CleanCapital, a Delaware limited liability company, is providing the balance of capital for the
Project and is the owner of the Project. CleanCapital’s founding mission is to accelerate the flow
of institutional capital into clean energy. CleanCapital is owned by Manulife Infrastructure II AIV
Holdings B, L.P. and John Hancock Life Insurance Company (USA).
The land on which the project site is located is owned by MSB. The land has been secured via a
32-year land lease between RIPP and an approved sublease for Energy 49. The funds requested
in this application are to develop approximately 45 acres of 480 acres leased from MSB, with the
remaining available for future project expansion(s). A copy of the site plan is provided in the
attached Exhibit C - Site Plan & Site Photos.
Background and Purpose
The purpose of the Project is to expand renewable energy production in Southcentral Alaska.
This diversifies electrical power generation sources and reduces power production air quality
emissions. The project will also assist with conserving natural gas resources in the Cook Inlet.
Alaska Energy Authority
RIPP, the contracted developer and operator of the Project, are experienced, well-qualified
professionals with strong backgrounds in engineering, procurement, and construction that have
firsthand experience with developing and operating solar farms in Alaska. Within a year of
founding the company in 2017, RIPP completed the 140kW Willow Solar Farm Pilot Project,
about 13 miles north from the Project site. The Willow Pilot was Alaska’s first commercial solar
farm developed by private industry and was delivered 5% under budget. The four partners self-
funded and built the Willow Pilot project allowing the partners to optimize the design and
construction and to confirm the cost model for solar in Alaska. After successful completion of
the Pilot Project, RIPP took on a 1.2 MW expansion at the Willow site in 2019. Within a year,
Renewable IPP attracted private investment, received a PPF loan from AEA, acquired regulatory
approval of the Power Purchase Agreement (PPA) with MEA, became a licensed general
contractor to execute the Willow Expansion project, and successfully delivered the expansion
project under budget. Since the completion of both projects, Renewable IPP has gained
significant experience operating and maintaining solar farms in the Alaska environment.
The Loan Request
The Borrower has requested a loan from the Power Project Fund in the amount of $4,994,500.
The loan proceeds will provide supporting funds to develop the Project, including payment for
pre-construction engineering studies, engineering, material procurement, and construction. The
total cost of the Project is estimated to be $9,749,768. The balance of the project cost will be
funded with equity from CleanCapital in the amount of $4,799,768. The Borrower has stated that
CleanCapital may avail itself of third-party equity. The Borrower requests to secure these PPF
loan funds by the beginning of 2023 to ensure they are available when construction begins in
late winter/early spring. Per the Borrower’s submitted project timeline, the final commissioning
date is scheduled for July 2023.
Application History
AEA received the Borrower’s PPF loan application on May 27, 2022. On October 7, 2022, the PPF
Loan Committee unanimously approved the loan application subject to those terms as stated in
the term sheet, as provided in the attached Exhibit B – Loan Terms. Per PPF regulation 3 AAC
106.110, AEA now forwards the application to the Board for its approval for a $4,994,500 million
loan to construct the Project as described in this memo and per those recommendations stated
in the attached Exhibit A – PPF Loan Committee Recommendation.
Project Information
The Project is a 6 MW-AC utility-scale solar project located in Houston, AK at GPS coordinates
61°35'15.03"N, 149°47'18.45"W. The Borrower, an independent power producer (“IPP”), has an
executed Power Purchase Agreement (“PPA”) with Matanuska Electric Association, Inc. (“MEA”).
This agreement was approved by the Regulatory Commission of Alaska (“RCA”) on March 18,
2022. A copy of this agreement is provided in the attached Exhibit E - Energy 49 LLC – MEA –
Power Purchase Agreement. The Borrower also has in-place a fully-executed Operations and
Maintenance (“O&M”) agreement, and an Engineering, Procurement, and Construction (“EPC”)
agreement with RIPP, as of July 26, 2022. The topography and location of project site is well-
suited for a solar farm project, as evidenced by the continued success of the Willow solar
project, owned and operated by RIPP, located approximately 13 miles north from the Project
along the Parks Highway.
Alaska Energy Authority
Financial Feasibility
As required per 3 AAC 106.125(a) AEA examined the Borrower’s ability to repay the loan.
AEA has determined that the project has a positive net present value, in addition to a
satisfactory debt service coverage ratio, indicating the Borrower’s ability to repay the AEA Power
Project Fund Loan based on the projected sales as established in the PPA with MEA.
Additionally, the Project is determined to be able to raise revenue to cover PPF debt service
without undue burden on ratepayers. Solar-based federal Tax incentives available to the
Borrower will provide additional value, if used.
Economic Viability
The purpose of the Project is to expand renewable energy production in Southcentral Alaska.
The Project diversifies electrical power generation sources and reduces air quality emissions
associated with carbon-based power production. The project will also assist with conserving
natural gas resources in the Cook Inlet, providing an equivalent amount of energy to power
approximately 1,400 homes. This is an economically viable Project and provides a sufficient cash
flow to cover operating expenses and debt repayment. Additionally, The Project provides cost
competitive electricity and helps stabilize electricity prices with its 25 year PPA with MEA. The
Agreement's pricing methodology will provide long-term predictable, stable rates over the
length of the Agreement because the pricing is not based on any derivative of the SFPPR or tied
to existing or future gas contracts. Instead, the pricing was negotiated at a price of
$0.06700/kWh with annual escalations of 1.5%.
Technical Feasibility:
AEA staff member Daniel Miller, P.E., under supervision of Bill Price, P.E. conducted the technical
review of the application and stated in his review that “the Houston Solar Farm PPF application
is built upon a solid and generally conservative design. Pricing of plant design and construction
appears appropriate, with minimal project ambiguity. There are no major technical objections to
this application.” Mr. Miller’s assessment is that the project is technically feasible.
Findings:
As required by 3 AAC 106.110, the Alaska Energy Authority hereby makes the following
determinations:
1. Both the Project and the Borrower are eligible under the PPF loan program.
2. The project meets the needs of the area and the area will benefit from the project.
3. All necessary permits or certificates have been applied for or awarded.
4. The Borrower has sufficient revenue, from power sales to MEA via the PPA, to repay the
loan.
5. Sufficient funds are available in the Power Project Fund to make the loan.
6. The project is economically viable, technically feasible, and financially feasible.
7. No alternatives currently exist, to AEA’s knowledge, to the project at a different site, by a
different method, or by another applicant that could be expected to provide comparable
volumes of power at lower cost which meets the needs of the area, that could be built within
comparable timeframe, that is economically viable and financially feasible.
8. The project benefits the area by providing power from a renewable source at a stable
rate acceptable to MEA and its customers.
Alaska Energy Authority
Conclusion, Recommendation, and Conditions:
The PPF Loan Committee and AEA staff recommend the AEA Board of Directors approve and
adopt Resolution No. 2022-05 effectuating the approval of the loan terms as recommended and
approved by the PPF Loan Committee on October 7, 2022. Such recommended loan terms and
conditions are included in the attached Exhibit B – Loan Term Sheet.
Attachments:
Exhibit A – PPF Loan Committee Recommendation
Exhibit B – Loan Term Sheet
Exhibit C – Site Plan & Site Photos
Exhibit D – Financial Analysis
Exhibit E – Energy 49 LLC – MEA – Power Purchase Agreement
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
RGYAUTHORITY.ORG
Exhibit A:
PPF Loan Committee Recommendation
1 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
Energy 49 LLC PPF loan #40901151 Committee Packet
Prepared by:
Karen Bell kbell@akenergyauthority.org and Conner Erickson - cerickson@akenergyauthority.org
Presentation to the AEA Loan Committee: October 7, 2022
Summary
Energy 49, LLC (Energy 49 or Borrower), an Independent Power Producer (IPP), has applied for a loan in the
amount of $4,950,000. The Borrower has stated that upon the approval of the loan by AEA’s Board of
Directors, they would like to roll the 1% closing fee of $49,500, net of their $5,000 application fee, into the loan
amount resulting in a balance of $4,994,500, as allowed per 3 AAC 106.150(d). The Borrower requests to
secure these PPF loan funds by the beginning of 2023 to ensure they are available when construction begins in
late winter/early spring. Per the submitted project timeline, the final commissioning date is scheduled for July
2023.
The total cost of the Project is estimated to be $9,749,768. The balance of the project cost will be funded with
equity by CleanCapital Holdings, LLC (CleanCapital) in the amount of $4,799,768. The Borrower has stated that
CleanCapital may avail itself of third-party equity.
The loan proceeds will provide supporting funds to construct the Houston Solar Farm (Project), including
payment for pre-construction engineering studies, engineering, material procurement, and construction. The
Houston Solar Farm has a rated output of 6MW-AC and will interconnect with Matanuska Electric Association
(MEA). The Houston Solar Farm will be interconnected by way of the distribution lines located opposite the
site’s access road across Hawk Lane.
The PPF loan is anticipated to be serviced through revenue from the sale of electricity to MEA. Borrower has an
Interconnection and Power Purchase Agreement (Agreement) with MEA for the sale of the entire electric
energy output of the Project that was approved by the Regulatory Commission of Alaska (RCA) on March 18,
2022. The term of the Agreement is 25 years, equal to the term requested for the loan; however, there is a
provision that the Agreement will expire 3 years from the date of execution if the first delivery of electric
energy from the Project to MEA has not occurred. The Agreement offers MEA the option to purchase the
Project after Year 10 of the Agreement.
PPF loan request: $4,994,500
Applicant: Energy 49, LLC
Purpose: Construction of the Houston
Solar Farm, 6MW
Applicant request: 25 years, with a 3.05%
interest rate, the prevailing PPF rate at the
time of the application submittal (5/27/22)
2 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
The loan application for this proposed project is eligible under the PPF program.
Staff Recommendations to Loan Committee
The Borrower has requested the prevailing PPF interest rate at the time the application was submitted to AEA,
with a 25 year term, with quarterly payments. Staff recommends the terms below:
Loan amount: $4,994,500, inclusive of $49,500 closing fee net of the $5,000 application fee
Term: 25 years, with quarterly payments
o Fixed Line of Credit (FLOC) for 12 months from the execution date of the loan documents or the
date the project is complete, whichever is sooner, with quarterly interest only payments.
o Term loan on outstanding balance of FLOC amortized quarterly for 25 years.
Interest rate: 3.05%
Estimated annual payment: $284,732.84
Loan Draw/Disbursement Conditions: Borrower shall use equity funds prior to request of PPF loan
proceeds and shall provide documentation to support funds expended, including verified invoices and
progress documentation to the satisfaction of the Authority.
Source of repayment: Revenues from the sale of electricity to MEA.
Collateral: The term loan will be secured by Uniform Commercial Code (UCC) of all property, revenue,
assets, and equipment financed by the loan; in the event of default. AEA shall be in first position with
respect to the equipment and revenues financed by the Project.
Potential third party equity investor: The Authority shall be notified prior to the use of a third party
equity investor and reserves the right to review agreements with a third party prior to execution. AEA
shall remain first position with respect to the equipment and revenues financed by the Project.
Additional due diligence may be required to the satisfaction of AEA and the State of Alaska Department
of Law.
Conditions precedent to closing
o Operating Agreements for Glacier Bay Solar LLC, CleanCapital Holdings LLC, and Energy 49 LLC
must be provided to AEA before loan funds are disbursed.
o All due diligence information required by the State of Alaska Department of Law must be
provided to AEA before loan funds are disbursed.
o The loan agreement shall require AEA approval for the sale of the Project or the transfer of all
or a portion of its ownership.
o All required permits shall be obtained or applied for prior to closing.
o As part of the loan agreement, the Borrower shall maintain commercial general liability,
automobile, or personal property insurance on the equipment with AEA listed as the mortgage
loss payee. In addition, AEA is to be listed as an additional insured on the borrower’s public
liability insurance.
Borrower’s initial principal and interest payment will be due on the first day of the full monthly period that
follows disbursement of loan funds.
3 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
Collateral Conditions:
The term loan shall be secured by a Uniform Commercial Code (UCC) filing of all revenues from all of
Borrower's sales of electricity, including all receipts, revenue, income, rents, royalties, benefits, rates,
fees, charges and other monies received or derived from the services, facilities and commodities sold,
furnished or supplied through the facilities of the electric utility; property, assets, and equipment
financed by the loan; and,
Signed guarantee(s) by Energy 49 LLC and/or its related entities to the satisfaction of AEA and the State
of Alaska Department of Law, so as to secure the loan and guarantee repayment to the State in the
event of default.
Rationale:
Staff recommends approving Energy 49, LLC for a $4,994,500 loan at 3.05% fixed interest rate for a 25 year term
based on the following rationale:
1. The project and applicant are eligible for PPF financing pursuant to AS 42.45.010(b)(1) and AS
42.45.010(b)(1)(B).
2. Although the Borrower is a recently established IPP, the Borrower has entered into an Operations and
Maintenance Agreement and an Engineering, Procurement, Construction Agreement with Renewable
IPP LLC (RIPP). RIPP is comprised of seasoned engineering and planning professionals with experience
constructing and operating the Willow Solar Farm in Alaska.
3. CleanCapital, the owner of the borrowing entity, is experienced in sourcing debt and equity funding for
renewable energy projects and has acquired more than 200 projects to date.
4. Borrower has an RCA approved Interconnection and Power Purchase Agreement with MEA.
5. The Agreement’s pricing methodology will provide long-term predictable, stable rates over the term of
the Agreement. The pricing was negotiated at a price of $0.06700/kWh, which currently would be the
lowest cost of energy purchased from any of MEA's IPPs and is also materially less than the Small
Facility Power Purchase Rate (SFPPR) (currently $0.07267/kWh with the average since inception being
about $0.08100/kWh). With annual 1.5% inflationary adjustments applied, pricing under the
Agreement is expected to provide MEA customers benefits with pricing below the SFPPR, at least
through the end of MEA's gas supply agreement and potentially thereafter if gas prices increase beyond
2028 in the next contract. The risk of rate increases because of the project is de minimis.
6. The Project further diversifies Alaska’s energy supply with solar energy. The introduction of additional
solar energy helps to extend the existing Cook Inlet gas reserves. According to the 2018 State of Alaska
“Cook Inlet Gas Availability” report, Cook Inlet gas prices are expected to increase throughout this
decade as producers pay for development to access new resources. On May 17, 2022 the Anchorage
Daily News reported that “officials with several Alaska utilities say they’ve been informed by Hilcorp
that the company does not currently have enough natural gas reserves in Cook Inlet to provide for new
gas contracts.”
7. This is an important demonstration project for Alaska. Success of the Project would prove the cost
structure, revenues, and scalability of larger-scale solar projects on the Railbelt, and potentially create
new market opportunities for the start-up companies and serve to diversify Alaska’s energy generation
portfolio.
4 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
8. CleanCapital creditors provided good credit reference and nothing material was found or determined to
detrimental to development of the Project.
9. CleanCapital will provide equity funding for the Project in the amount of $4,799,768.
10. The Project benefits the local economy through the creation of construction and maintenance jobs.
11. There are no other PPF loan applications before the Authority at this time.
12. The Borrower has no outstanding debt.
Background
The Borrower is Energy 49 LLC, an Alaska limited liability company. 100% of the ownership of Energy 49 was
transferred from RIPP to Glacier Bay Solar LLC c/o CleanCapital Holdings LLC, a Delaware limited liability
company, in July of 2022. Glacier Bay Solar LLC is registered with AK DCEED to conduct business in Alaska
under license #2164971. CleanCapital, a Delaware limited liability company, is providing the balance of
capital for the Project and is the owner of the Project. CleanCapital’s founding mission is to accelerate the
flow of institutional capital into clean energy. CleanCapital is an industry-leading clean energy investment
platform. Since 2015, CleanCapital has worked to accelerate investment in distributed solar and storage
assets to address the urgent threat of climate change. To date, CleanCapital has invested more than $950
million in projects and companies that align with its mission. CleanCapital is owned by Manulife
Infrastructure II AIV Holdings B, L.P. and John Hancock Life Insurance Company (USA).
RIPP, an Alaska limited liability company, is contracted to construct and operate the Project. RIPP’s owners
are experienced, well-qualified professionals with strong backgrounds in engineering, procurement, and
construction that have firsthand experience with solar farms in Alaska. Within a year of founding the
company in 2017, RIPP completed the 140kW Willow Solar Farm Pilot Project, about 13 miles north from
the Houston site. The Willow Pilot was Alaska’s first commercial solar farm developed by private industry and
was delivered 5% under budget. The four partners self-funded and built the Willow Pilot project allowing
the partners to optimize the design and construction and to confirm the cost model for solar in Alaska. After
successful completion of the Pilot Project, RIPP took on a 1.2 MW expansion at the Willow site in 2019.
Within a year, Renewable IPP attracted private investment, received a PPF loan from AEA, acquired
regulatory approval of the Power Purchase Agreement (PPA) with MEA, became a licensed general
contractor to execute the Willow Expansion project, and successfully delivered the expansion project under
budget. Since the completion of both projects, Renewable IPP has gained significant experience operating
and maintaining solar farms in the Alaska environment.
Borrower Summary:
Energy 49, LLC (incorporated October 28, 2019)
Glacier Bay Solar, LLC (incorporated May 15, 2022)
CleanCapital Holdings, LLC (incorporated March 21, 2021)
Public Need Statement & Eligibility under AS 42.45.010
The Houston Solar Farm Project diversifies Southcentral Alaska’s energy supply with solar energy. The
introduction of additional solar energy will help to extend the existing Cook Inlet gas reserves. The project
is economic with pricing below MEA’s avoided cost (small facility purchase price) and will not increase
energy prices in the region. In addition to diversifying electricity generation for MEA members, the
5 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
Houston Solar Farm project provides cost competitive electricity and helps stabilize electricity prices with
its 25-year contract. The project also serves as an important demonstration of the viability of affordable,
utility-scale solar photovoltaics (PV) in Alaska. Finally, the project provides environmental benefit to
Alaska and MEA members. The State of Alaska has a non-binding goal of generating 50% of its electricity
from renewable energy sources by 2025. The project will help MEA meet its carbon reduction goal while
providing cost competitive energy to MEA members.
Project
Location
The project will be located within Section 3, Township 17 North, Range 3 West, Seward Meridian. The
parcel does not have an address but is located north of W Hawk Lane in Houston, AK 99694 and is to the
west of Houston Middle and Senior High schools. GPS coordinates for the site are 61°35'15.03"N,
149°47'18.45"W. A location map is provided below in Figure 1 for reference.
Figure 1: Location Map for Houston Solar Farm Project
Engineering Design & Equipment Information
The 6MW-AC Houston, Alaska solar farm is a grid-tied, utility scale solar farm that generates electricity which
will be conveyed to utility members through MEA’s electrical grid. The Project will produce energy to power
6 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
approximately 1,200 homes. The Project design relies on standardization to deliver a low-cost system and
uses RIPP’s Alaska experience to maximize production in Alaska weather conditions. The Project is
comprised of the following elements: substructure & racking, 14,400 solar panels, string inverters, AC
collection equipment and grid interconnection. The All components are commercially available equipment
with available replacement parts.
Substructure and Racking
The solar array substructure uses over 6,000 foundation piles, and the panels are fixed, facing South with a
40- degree tilt. The foundation is designed and tested to meet ASCE 7 and IBC wind and snow loads for
Houston, Alaska. This assumes a wind of 115 mph and a snow load of 70 psf. The design uses AP Alternatives
(APA) foundation and racking system. APA is a US company, and their foundation and racking systems are
used in various solar projects across Alaska and the company also has significant experience in the Lower 48.
APA’s Titan Duo racking system is designed specifically for bi-facial solar panels to minimize back-side shading
for optimized production.
The height of the solar arrays will be 12-15-feet above grade at their maximum height and 3-3.5-feet above
grade at their lowest point. The Project assumes a maximum height of 15 feet to account for ground
irregularities. Elevating the panels to 3-3.5-feet above grade allows for easier snow maintenance.
Bifacial Solar Panels
The Houston Solar Farm design employs bi-facial panels and a high DC/AC ratio to maximize production in
Alaska conditions. Bifacial panels produce energy both from the front side, which receives direct sun
exposure, and from reflective light which hits the back side. Bifacial panels are ideally suited for Alaska solar
farms which elevate arrays higher off the ground, place arrays further apart and at steeper angles than
Lower 48 designs. These design parameters increase the reflective light exposure for the back side of the
panels. Finally, the ground is covered by snow 4-5 months of the year, further increasing the reflective light
production. A recent study completed by the Alaska Center for Energy and Power (ACEP) estimated bifacial
panel gain to be as high as 20%; the Project assumes a conservative 10% bifacial gain. To further increase
solar production the design uses a high DC/AC ratio. A high DC/AC ratio means that there is excess panel
capacity compared to inverter rating. As Alaska has many overcast weather days compared to sunnier
locations, the high DC/AC ratio provides increased production during these “non-peak” production
conditions. As panels prices continue to fall, the losses associated with clipped production is outweighed by
the increased production during non-peak conditions. The Houston Solar Farm has a nominal DC/AC ratio
(front side only) of ~1.42. The solar farm will have a rated output of 6MW-AC.
The solar panels selected for the Houston Solar Farm project are the Risen 590W bifacial solar panels. The
selected panels are Tier 1 panels and will have a 30 year production warranty. The Borrower states in the
application that industry reports are now indicating that the solar panel useful life is 40 years and possibly
longer.
Inverters
Energy from solar panels is generated as direct current (DC) electricity and inverters convert this DC to
alternating current (AC). The Project uses commercially available, IEEE-1547 compliant string inverters. The
Houston Solar Farm uses SMA 150kW inverters which have a 20 year useful life. The expected operating life
7 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
of the SMA inverters is 20 years and the Project’s pro forma assumes that all inverters will be replaced once
in the 25 year project life.
Security
The project site will be bordered by an 8 foot fence and equipped with security cameras which alert upon
motion detection and motion detection security lights. These security measures are in place at the Willow
Solar Farm and have adequately deterred security threats.
Land
RIPP has a 32 year land lease in place and an approved sublease for Energy 49. Houston solar will be on
approximately 45 acres of 480 acres leased from the Matanuska Susitna Borough. The remaining acreage
may be used for future solar projects.
Technical Feasibility
The technical review was performed by Daniel Miller P.E. under the supervision of Bill Price P.E. Mr. Miller
provided the following summary:
“The Houston Solar Farm PPF application is built upon a solid and generally conservative design. Pricing
of plant design and construction appears appropriate, with minimal project ambiguity. There are no
major technical objections to this application.”
Economic and Financial Feasibility
The purpose of the project is to expand renewable energy production in Southcentral Alaska. This diversifies
electrical power generation sources and reduces power production air quality emissions. The project will also
assist with conserving natural gas resources in the Cook Inlet. This is an economically viable Project and
provides a sufficient cash flow to cover operating expenses and debt repayment. AEA calculations show an
average debt service ratio of 1.82 and a minimum of 1.59 using the potential production provided for the
Project. If actual production was only 80% of front-side panel production on a consistent basis, AEA calculations
show an average debt service ratio of 1.05 and a minimum of 0.83. The project also yields a positive net
present value. Tax incentives available to the Borrower will provide additional value, if used.
Cost Estimate for the Houston Solar Farm
The Borrower provided detailed cost tables. Material costs comprise 72% of the Project’s total installed cost
and most of these costs are based on quoted estimates and published price data as such there is a small
amount of uncertainty. The budget includes a contingency in the amount of $626,989, approximately 6.4% of
the total budget.
8 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
Power Production Summary Review
The monthly production forecast below was created using the industry standard software PVSYST and
incorporating detailed system layout, components, site specific shading, and AK satellite irradiance
information. Figure 2 shows the forecasted production by month.
Figure 2: Houston Solar Farm, 6MW-AC, Monthly Production Forecast
Figure 3 below provides the expected annual production over the 25 year Project life. The annual production
forecast assumes a 0.5% panel degradation based on the 2012 NREL Photovoltaic Degradation Rates— An
Analytical Review. The warranty for the bifacial panels chosen for the Project applies a .45% annual degradation
over 30 years.
9 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
Figure 3: Houston Solar Farm, 6MW-AC, Annual Production Forecast
The Project will use bifacial panels that produce energy using both sides of the solar panels. In the
Agreement between Energy 49 and MEA, Energy 49 guaranteed 80% of expected annual output from front-
side panel production over any consecutive 36 month period. The term "Front-side Panel Production" refers
to the estimated production from the front side of the bifacial solar panel, the expected annual output from
the Front-side Panel Production. In the event Energy 49 fails to satisfy its obligation to provide the contracted
output, MEA, in its sole discretion, may declare such failure a material breach the Agreement. As a point of
reference, RIPP submitted actual versus forecasted production for the 1.2MW Willow Solar Farm based on
the PVWatts modeling tool developed by NREL. The Willow Solar Farm has produced 93% to 99% of its
forecasted energy production over the past 3 years. At 80% of expected annual output from front-side panel
production only, AEA calculations show an average debt service ratio of 1.05 and a minimum of 0.83.
10 | Page PPF Loan Committee Packet: Houston Solar Farm #40901151
Statement of Net Position
Since CleanCapital and Glacier Bay Solar have been in business for less than two years, the financial statements
required by statute are not currently available. CleanCapital’s unaudited financial statements reflect a Net
Income of $6,124,727 for the year ending December 31, 2021. Consolidated Financial Statements for Manulife
are publicly available.
Additional Funding Sources
Source Amounts Percentages
Debt AEA PPF Loan $ 4,950,000 51%
Equity Energy 49 LLC $ 4,799,768 49%
Total Installed Cost $ 9,749,768
Financial Feasibility is defined to mean:
The Borrower will have sufficient funds to repay the loan; and,
Utility consumers will not unnecessarily incur major or unacceptable cost increases.
The Houston Solar Farm Project has the ability to raise revenue to cover PPF debt service without undue burden
on electric customers:
The Project will produce sufficient revenues for operations and maintenance over the next 25 years of
operation, based on the Agreement with MEA.
The Project provides cost competitive electricity and helps stabilize electricity prices with its 25 year
Agreement with MEA.
The Agreement's pricing methodology will provide long-term predictable, stable rates over the length of
the Agreement because the pricing is not based on any derivative of the SFPPR or tied to existing or
future gas contracts. Instead, the pricing was negotiated at a price of $0.06700/kWh with annual
increases of 1.5%.
Summary Conclusion:
Borrower has demonstrated sufficient and sophisticated technical and financial capacity, as well as,
commitment to assure the success of the project and ability to repay the loan. Staff recommends approving
Energy 49 LLC for a $4,994,500 loan at 3.05% fixed interest rate for a 25 year term based on the rationale
provided in this packet. Assistance will be required from the Department of Law in drafting the loan
agreements to ensure the loan is appropriately secured in the instances of default, third party equity
investment, or sale of Energy 49.
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
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Exhibit B:
Loan Term Sheet
813 W Northern Lights Blvd, Anchorage, AK 99503 x Phone: (907) 771-3000 x Fax:(907) 771-3044 x Email:info@akenergyauthority.org
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On October 7, 2022, the PPF Loan Committee convened to consider the loan application from
Energy 49 LLC (Loan #40901151). The committee voted to approve the loan subject to the
following terms:
x Loan amount (excl. closing fee): $4,950,000 (51%)
x Closing Fee:
o $44,500.00 due at closing (net of $5,000 application fee) - applicant has
requested to add this to the principal loan balance, as allowed per 3 AAC
160.150(d)
x Equity contribution:
o $4,799,768 (49%)
x Term:
o Fixed Line of Credit (FLOC) for 12 months from the execution date of the
loan documents or the date the project is complete, whichever is sooner,
with quarterly interest only payments.
o Term loan on outstanding balance of FLOC amortized quarterly for 25
years.
x Interest rate:
o Fixed rate of 3.05%, the prevailing PPF rate as of week of May 27, 2022.
x Estimated term payment on fully advance loan, inclusive of $44,500.00 closing fee, of
$4,994.500:
o $71,183 quarterly / $284,733 annually
x Loan Draw/Disbursement Conditions:
o Borrower shall use equity funds prior to request of PPF loan proceeds and
provide documentation to support funds expended based on supporting
invoices, current progress reports, and other supporting documentation as
deemed necessary by, and to the satisfaction of, the Alaska Energy Authority
(AEA).
o Operating Agreements for Glacier Bay Solar LLC, CleanCapital Holdings LLC, and
Energy 49 LLC must be provided to AEA before loan funds are disbursed.
o All due diligence information required by the Department of Law must be
provided to AEA before loan funds are disbursed.
Alaska Energy Authority Page 2 of 2
x Source of repayment:
o Revenue from power sales to the Matanuska Electric Association (MEA) via the
established, Regulatory Commission of Alaska approved, Power Purchase
Agreement between Energy 49 LLC and MEA.
x Collateral:
o The term loan will be secured by a Uniform Commercial Code (UCC) filing of all
revenues from all of Debtor's sales of electricity, including all receipts, revenue,
income, rents, royalties, benefits, rates, fees, charges and other monies received
or derived from the services, facilities and commodities sold, furnished or
supplied through the facilities of the electric utility; property, assets, and
equipment financed by the loan; and,
o Signed guarantee(s) by Energy 49 LLC and/or its related entities to the
satisfaction of AEA and the State of Alaska Department of Law, so as to secure
the loan and guarantee repayment to the State in the event of default.
x Conditions Precedent: The conditions precedent to closing, will include, but not be
limited to:
o Signed guarantee(s) by Energy 49 LLC and/or its related entities to the
satisfaction of AEA, and the State of Alaska Department of Law, so as to secure
the loan and guarantee repayment to the State in the event of Borrower default.
o The loan agreement shall require AEA approval for the sale of the Project or the
transfer of all or a portion of its ownership.
o All required permits shall be obtained or applied for prior to closing.
SIGNATURE PAGE
Curtis Thayer, Executive Director, Alaska Energy Authority Date
Timothy Sandstrom, Chief Operating Officer, Alaska Energy Authority Date
Morgan Neff, Chief Investment Officer, AIDEA Date
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Exhibit C:
Site Plan and Site Photos
Alaska Energy Authority
Figure 1: Site Plan
Alaska Energy Authority
Figure 2: Site Plan – Project Site with Expansion Areas Identified
Alaska Energy Authority
Figure 3: Site Photo – Looking South to Site Access via Hawk Ln
Figure 4: Site Photo – Looking NW from Hawk Ln Access - Solar Panel Pilings
Alaska Energy Authority
Figure 5: Site Photo – Piling row
Figure 6: Site Photo – Piling Installation with Pile Driver
Alaska Energy Authority
Figure 7: Site Photo – RIPP Staff – Chris Colbert (left) and Jenn Miller (right)
Figure 8: Site Photo – Pilings with Northern Intertie in background
Alaska Energy Authority
Figure 9: Site Photo – Facility Access Road (east side)
Figure 10: Site Photo – Groundbreaking Ceremony (9/14) –
Gov. Mike Dunleavy (left); Tony Izzo – MEA, CEO (middle); Jenn Miller – RIPP (right)
Alaska Energy Authority
Figure 11: Site Photo – Groundbreaking Ceremony (9/14) – Hawk Ln Access
Figure 12: Site Photo – Groundbreaking Ceremony (9/14) – From left with shovels:
Tony Izzo – MEA, CEO; Gov. Mike Dunleavy; Jenn Miller – RIPP; Chris Colbert - RIPP
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
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Exhibit D:
Financial Analysis
2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 2046 2047 2048 2049 2050 2051 2052 TotalRevenue191,742 668,404 675,073 681,757 688,483 695,319 702,236 709,190 716,249 723,383 730,550 737,789 745,085 752,517 759,976 767,526 775,140 782,803 790,591 798,425 806,379 814,350 822,425 830,615 838,842 947,131 956,602 966,168 975,830 985,588 23,036,165 O&M(24,060) (58,898) (60,076) (61,278) (62,503) (63,753) (65,029) (66,329) (67,656) (69,009) (70,389) (71,797) (73,233) (74,697) (76,191) (77,715) (79,269) (80,855) (82,472) (84,121) (85,804) (87,520) (89,270) (91,056) (92,877) (94,734) (96,629) (98,561) (100,532) (102,543) (2,308,857) Insurance(15,672) (15,829) (15,987) (16,147) (16,309) (16,472) (16,636) (16,803) (16,971) (17,140) (17,312) (17,485) (17,660) (17,836) (18,015) (18,195) (18,377) (18,561) (18,746) (18,934) (19,123) (19,314) (19,507) (19,702) (19,899) (20,098) (20,500) (20,910) (21,328) (21,755) (547,223) Property Tax(74,814) (72,570) (70,393) (68,281) (66,232) (64,245) (62,318) (60,449) (58,635) (56,876) (55,170) (53,515) (51,909) (50,352) (48,841) (47,376) (45,955) (44,576) (43,239) (41,942) (40,684) (39,463) (38,279) (37,131) (36,017) (34,936) (35,635) (36,347) (37,074) (37,816) (1,511,070) Other Opex(40,151) (54,741) (55,551) (56,208) (56,988) (60,554) (61,250) (40,848) (41,517) (42,255) (42,565) (43,223) (44,035) (44,809) (45,627) (48,514) (49,422) (50,350) (51,296) (52,372) (55,243) (56,416) (57,554) (58,770) (59,953) (65,262) (66,567) (67,899) (69,257) (70,642) (1,609,838) Total Opex(154,697) (202,038) (202,007) (201,914) (202,032) (205,024) (205,233) (184,429) (184,779) (185,280) (185,436) (186,020) (186,837) (187,694) (188,674) (191,800) (193,023) (194,342) (195,753) (197,369) (200,854) (202,713) (204,610) (206,659) (208,746) (215,030) (219,331) (223,717) (228,192) (232,755) (5,976,988) Inverter Reserve(46,728) (112,147) (112,147) (112,147) (112,147) (65,419) (46,728) (112,147) (112,147) (112,147) (112,147) (1,056,049) Cashflow37,045 466,366 473,066 479,843 486,451 490,295 497,003 524,761 531,470 538,103 545,114 551,769 511,520 452,676 459,155 463,579 469,970 523,042 594,838 601,056 605,525 564,909 505,668 511,809 517,949 619,954 737,272 742,451 747,638 752,833 16,003,124 DSC1.64 1.66 1.69 1.71 1.72 1.75 1.84 1.87 1.89 1.91 1.94 1.80 1.59 1.61 1.63 1.65 1.84 2.09 2.11 2.13 1.98 1.78 1.80 1.82 2.18 2.59 2.61 2.63 2.64 * Revenues and Expenses provided from appendix c of application through 2048. 2049‐2052 calculated with a 2% escalation for Expenses and 1% escalation for revenues. MEA PPA Ends in 2047‐2048 depending on plant commissioning allowing for the renegotiation of price.NPV Project Based on 30 Year Production Life of Panels1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30Capital Expense (9,461,201)$ (9,461,201)$ PV revenue 14,366,113$ 186,067 629,424 616,889 604,558 592,452 580,626 569,046 557,672 546,553 535,659 524,955 514,465 504,176 494,134 484,261 474,597 465,119 455,815 446,725 437,798 429,073 420,490 412,090 403,876 395,804 433,673 425,046 416,590 408,303 400,180 PV opex (3,833,297)$ (150,118) (190,255) (184,596) (179,050) (173,852) (171,205) (166,307) (145,026) (141,000) (137,198) (133,250) (129,713) (126,427) (123,248) (120,224) (118,599) (115,823) (113,163) (110,611) (108,223) (106,874) (104,671) (102,523) (100,485) (98,496) (98,458) (97,455) (96,462) (95,479) (94,506) PV Investment Tax Credit (ITC) 26% 2,387,106$ 2,387,106 NPV w/ITC 26% 3,458,720$ PV Investment Tax Credit (ITC) 6% 550,871$ NPV w/ITC 6% (minimum ITC)1,622,485$ NPV w/o ITC1,071,615$ Discount Rate (PPF Interest Rate for Loan) 3%Revenue Sensitivity based on PPA Schedule 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 2046 2047 204880% Frontside production 7116 7080 7045 7010 6975 6940 6905 6870 6836 6802 6768 6734 6700 6667 6634 6601 6568 6535 6502 6469 6437 6405 6373 6341 6309kwh price ($/kWh) 0.067 0.068005 0.069025075 0.070060451 0.071111358 0.072178028 0.073260699 0.074359609 0.075475003 0.076607128 0.077756235 0.078922579 0.080106417 0.081308014 0.082527634 0.083765548 0.085022032 0.086297362 0.087591823 0.0889057 0.090239285 0.091592875 0.092966768 0.094361269 0.095776688revenue ($)476,772 481,475 486,282 491,124 496,002 500,916 505,865 510,851 515,947 521,082 526,254 531,465 536,713 542,081 547,488 552,936 558,425 563,953 569,522 575,131 580,870 586,652 592,477 598,345 604,255 DSC0.96 0.98 1.00 1.02 1.02 1.04 1.13 1.15 1.16 1.18 1.19 1.05 0.83 0.85 0.86 0.87 1.05 1.29 1.31 1.31 1.16 0.95 0.96 0.97 1.30potential frontside production 8895 8851 8807 8763 8719 8675 8632 8589 8546 8503 8460 8418 8376 8334 8292 8251 8210 8169 8128 8087 8047 8007 7967 7927 7887kwh price ($/kWh) 0.067 0.068005 0.069025075 0.070060451 0.071111358 0.072178028 0.073260699 0.074359609 0.075475003 0.076607128 0.077756235 0.078922579 0.080106417 0.081308014 0.082527634 0.083765548 0.085022032 0.086297362 0.087591823 0.0889057 0.090239285 0.091592875 0.092966768 0.094361269 0.095776688revenue ($)595,965 601,912 607,904 613,940 620,020 626,144 632,386 638,675 645,009 651,390 657,818 664,370 670,971 677,621 684,319 691,150 698,031 704,963 711,946 718,980 726,156 733,384 740,666 748,002 755,391 DSC1.38 1.40 1.43 1.45 1.46 1.48 1.57 1.59 1.61 1.64 1.66 1.51 1.30 1.32 1.34 1.36 1.54 1.79 1.81 1.82 1.67 1.46 1.48 1.50 1.84potential production with 10% bifacial 9942 9892 9843 9794 9745 9696 9648 9600 9552 9504 9456 9409 9362 9315 9268 9222 9176 9130 9084 9039 8994 8949 8904 8859 8815kwh price ($/kWh) 0.067 0.068005 0.069025075 0.070060451 0.071111358 0.072178028 0.073260699 0.074359609 0.075475003 0.076607128 0.077756235 0.078922579 0.080106417 0.081308014 0.082527634 0.083765548 0.085022032 0.086297362 0.087591823 0.0889057 0.090239285 0.091592875 0.092966768 0.094361269 0.095776688revenue ($)666,114 672,705 679,414 686,172 692,980 699,838 706,819 713,852 720,937 728,074 735,263 742,583 749,956 757,384 764,866 772,486 780,162 787,895 795,684 803,619 811,612 819,665 827,776 835,946 844,272 DSC1.63 1.65 1.68 1.70 1.71 1.74 1.83 1.86 1.88 1.91 1.93 1.79 1.58 1.60 1.62 1.64 1.83 2.08 2.10 2.12 1.97 1.77 1.79 1.81 2.1580% potential production with 10% bifacial 7953.6 7914 7874 7835 7796 7757 7718 7679 7641 7603 7565 7527 7489 7452 7415 7378 7341 7304 7267 7231 7195 7159 7123 7087 7052kwh price ($/kWh) 0.067 0.068005 0.069025075 0.070060451 0.071111358 0.072178028 0.073260699 0.074359609 0.075475003 0.076607128 0.077756235 0.078922579 0.080106417 0.081308014 0.082527634 0.083765548 0.085022032 0.086297362 0.087591823 0.0889057 0.090239285 0.091592875 0.092966768 0.094361269 0.095776688revenue ($)532,891 538,192 543,503 548,924 554,384 559,885 565,426 571,007 576,705 582,444 588,226 594,050 599,917 605,907 611,942 618,022 624,147 630,316 636,530 642,877 649,272 655,713 662,202 668,738 675,417 DSC1.16 1.18 1.20 1.22 1.23 1.25 1.34 1.36 1.37 1.39 1.41 1.27 1.05 1.07 1.08 1.10 1.28 1.53 1.54 1.55 1.40 1.19 1.21 1.22 1.55
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Exhibit E:
Energy 49 LLC – MEA – Power Purchase Agreement
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
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MEMORANDUM
DATE: October 26, 2022 TO: AEA Board of Directors
FROM: Curtis W. Thayer, Executive Director
RE: Bradley Lake Hydroelectric Project Required Project Work
The purpose of this memo is to recommend that the Alaska Energy Authority (AEA) Board
approve Resolution 2022-06 – Providing for the Sale of Revenue Bonds for Bradley Lake
Hydroelectric Project Required Project Work.
RESOLUTION 2022-06
• Resolution of the Alaska Energy Authority providing for the sale of not to exceed
$270,000,000 of Alaska Energy Authority, Eleventh Series revenue bonds to allow for
maximum amount of borrowing in order to finance the proposed transaction described
below. At no time shall the bonds exceed annual debt service which can be covered by
the available Excess Payments; authorizing and adopting the Tenth Supplemental
Resolution of the Authority to secure said bonds; authorizing the execution of a loan
agreement between the Authority and purchaser of said bonds; delegating certain
authority to the Chair, Chair designee, the Executive Director, the Chief Financial Officer;
and providing for related matters.
• Supporting Documents
o Memo from Executive Director
o Resolution 2022-06 Power Revenue Bonds for Required Project Work
o Tenth Supplemental Resolution (substantially final form)
o Loan Agreement (substantially final form)
o BPMC Resolution 22-08 Financing of the Proposed Transaction
o Utility Resolutions
o BPMC Resolution 22-04 Development of the Required Project Work
o Consultant Opinion of Required Project Work
o Department of Law Opinion of Required Project Work
o Letter from BPMC to Department of Law – Required Project Work
o Power Sales Agreement
REQUIRED PROJECT WORK Bond proceeds will be used to (a) upgrade the Sterling to Quartz Line; (b) upgrade the Bradley to Soldotna Junction Line; (c) upgrade the Soldotna to Sterling Line; and acquire Battery Energy Storage Systems (BESS) for the three Load Balancing Areas of the Railbelt, all of which will
Alaska Energy Authority Page 2 of 4
become an integral part of the Bradley Lake Project. The upgrades and BESS’s are located on the attached BPMC REQUIRED PROJECT WORK 2022 – 1ST TRANCHE. BENEFITS TO CONSUMERS & RAILBELT ENERGY SYSTEM The upgrades of transmission lines and acquisition of BESS’s will require no AEA capital funding outlays, except for the issuance of general revenue bonds secured by payment by the utilities
under the terms of the Bradley Lake Project Power Sale Agreement (PSA). The benefits to
consumers are:
• Cost sharing – The Railbelt Utilities, through the BPMC, will split the cost of the upgrade
or purchase (debt service on the financing), operation and maintenance of the assets.
• Lower energy losses – Upgraded line and BESS will substantially reduce energy losses
from resistance and spinning reserves.
• Better Cost Alignment – Align the allocation of resources with traditional utility
methodology, i.e. cost causer/cost payer. From a financial perspective, there would be
greater resources available for use on this transmission segment, and the ongoing costs
would be spread more equitably to a wider group of ratepayers benefiting from Bradley
Lake power.
• Increased Reliability – Reduction in risk of outages from power quality or natural events
and related costs for power for ratepayers throughout the Railbelt.
• Future Benefits – Allows for un-constraining Bradley power, which would decrease line
lines, increase the capacity of power transmitted, increase the stability of transmission
system power, and allow for additional renewable energy projects to be constructed on
the Kenai Peninsula.
• New Renewable Energy projects and increased stability will benefit the Railbelt Energy
System. These improvements are required irrespective of the nature of fuel supply
diversity and decarbonization solutions
• Grid Stability - The construction and coordination of Battery Energy Storage Systems
(BESS) in the Southern, Central and Northern regions to reassert control over the Grid’s
operating point (Frequency) and mitigate the small-signal instability that occurs between
the Bradley Project and the grid.
OTHER PROVISIONS The benefits of consummating the transaction are significant and are designed to be long-term.
The transaction results in various transmission line upgrades and BESS’s being acquired or
constructed and becoming part of the Bradley Project under the oversight of the BPMC.
Upgrades to the transmission lines and BESS’s are needed to address significant issues with line
losses, capacity, and stability which have developed since the Bradley Project was constructed.
Alaska Energy Authority Page 3 of 4
This transmission build-out will take several years. However, as is sometimes said, “The longest journey begins with just one step.” From a “transmission line perspective,” the first steps in decongesting the Grid are:
1. The reconstruction of the Soldotna to Quartz Creek section of the Intertie between
Anchorage and Kenai.
2. The planning and permitting of the new line between Bradley and Soldotna, and;
3. The planning, engineering and purchase of the BESS’s three locations;
It is estimated that the available bond proceeds will fund 65% of the Transmission Upgrades
(Items 1 & 2) and 35% for the BESS(s). All proceeds from the sale of the Bonds will be generated
using best practices to provide competitive financing terms.
NEXT STEPS This bonding by AEA, in partnership with the Railbelt utilities, will be at no additional cost to ratepayers and with no burden on the State Treasury. The closing of the transaction is
scheduled for on or before December 2, 2022. AEA staff recommend approval of Resolution 2022-06.
Alaska Energy Authority Page 4 of 4
OH&S Draft 10/16/2022
4152-3049-5295.5
ALASKA ENERGY AUTHORITY
RESOLUTION NO. 2022-06
RESOLUTION OF THE ALASKA ENERGY AUTHORITY PROVIDING FOR
THE SALE OF NOT TO EXCEED $270,000,000 OF ALASKA ENERGY
AUTHORITY POWER REVENUE BONDS, ELEVENTH SERIES (BRADLEY
LAKE HYDROELECTRIC PROJECT); AUTHORIZING AND ADOPTING A
TENTH SUPPLEMENTAL RESOLUTION OF THE AUTHORITY TO SECURE
SAID BONDS; AUTHORIZING THE EXECUTION OF A LOAN AGREEMENT
BETWEEN THE AUTHORITY AND PURCHASER OF THE SAID BONDS;
DELEGATING CERTAIN AUTHORITY TO THE CHAIR, THE BOARD
MEMBER DESIGNEE OF THE CHAIR, THE EXECUTIVE DIRECTOR AND
THE CHIEF FINANCIAL OFFICER; AND PROVIDING FOR RELATED
MATTERS.
WHEREAS, the Alaska Energy Authority (“Authority”) is authorized by Title 44,
Chapter 83, of the Alaska Statutes, as amended, to issue bonds for the purpose of carrying out its
corporate purpose and power, including the establishment or increase of reserves to secure or to
pay for bonds; and
WHEREAS, the Authority has, pursuant to the Power Revenue Bond Resolution, adopted
by the Board on September 7, 1989, as amended and supplemented (“Master Bond Resolution”),
issued ten series of power revenue bonds subject to terms and conditions set forth in the Bradley
Lake Hydroelectric Project Agreement for the Sale and Purchase of Electric Power (the “Power
Sales Agreement”) dated as of December 8, 1987, by and among the Chugach Electric Association,
Inc., Golden Valley Electric Association, Inc., the City of Seward d/b/a Seward Electric System,
and Alaska Electric Generation & Transmission Cooperative, Inc., and as Additional Parties
Homer Electric Association, Inc. and Matanuska Electric Association, Inc. (collectively, “Power
Purchasers”) and the Authority; and
WHEREAS, the Master Bond Resolution authorizes the issuance of additional bonds for
purposes of financing costs and expenses of planning, designing, acquiring, constructing, installing
capital improvements in connection with the Bradley Lake Hydroelectric Project (“Bradley
Project”) subject to terms and conditions set forth therein and the Power Sales Agreement; and
WHEREAS, pursuant to the request of the Power Purchasers, the Authority has determined
to issue its Power Revenue Bonds, Eleventh Series (Bradley Lake Hydroelectric Project), in an
aggregate principal amount not to exceed $270,000,000 (“Bonds”) to provide funds which will be
used to (a) pay all or a portion of the costs of the acquisition, improvement and development of
the electric transmission line systems between the Bradley Junction and Soldotna Substation, the
electric transmission line systems between the Soldotna Substation and the Sterling Substation,
the electric transmission line systems between the Sterling Substation and the Quartz Creek
Substation, and of battery energy storage systems, in each case including associated rights-of-way
and permits, all of which will become an integral part of the Project; (b) fund a debt service reserve
account; and (c) pay costs incurred in connection with the issuance of the Bonds (collectively, the
“Project”); and DRAFT
Resolution No. 2022-06 Page 2
4152-3049-5295.5
WHEREAS, the Bonds will be issued under and pursuant to and are being secured by the
Master Bond Resolution and a Tenth Supplemental Resolution approved and adopted by the
Authority (“Supplemental Resolution,” and together with the Master Bond Resolution, the “Bond
Resolution”) which shall be in substantially the form presented to and made part of the records of
this meeting; and
WHEREAS, provisions shall be made for the sale of the Bonds pursuant to a Loan
Agreement entered into between the Authority and the National Cooperative Services Corporation
(“Purchaser”) which shall be in substantially the form presented to and made part of the records of
this meeting; and
WHEREAS, there has been presented to this meeting forms of the following documents,
which the Authority proposes to finalize in connection with the issuance of the Bonds in
substantially the form presented at this meeting:
1. Supplemental Resolution; and
2. Loan Agreement; and
WHEREAS, it appears that each of the instruments above referred to, which are now before
the members of the Authority, is in appropriate form and is an appropriate instrument for the
purposes intended; and
NOW, THEREFORE, BE IT RESOLVED BY THE ALASKA ENERGY AUTHORITY,
AS FOLLOWS:
That in order to provide funds to finance the Project, the Authority will issue the Bonds in
a principal amount not to exceed $270,000,000 maturing on the date or dates and bearing interest
at a fixed rate of interest described in the Supplemental Resolution now before this meeting, subject
to appropriate insertions and revisions, be and the same hereby is in all respects authorized,
approved and confirmed, and that the Chair, the Board member designee of the Chair, Executive
Director or Chief Financial Officer of the Authority (each, an “Authorized Officer”) be, and each
of them hereby is, authorized, empowered, and directed to execute the Bonds, whether by manual
or facsimile signature, to seal the Bonds with the official seal of the Authority (manually or by
facsimile), and to deliver, for and on behalf of the Authority, the Bonds to the Purchaser; and that
the provisions of the Supplemental Resolution with respect to the Bonds be and the same hereby
are authorized, approved and confirmed and are incorporated herein by reference.
The Bonds do not constitute an indebtedness or other liability of the State of Alaska, or any
political subdivision thereof, except the Authority. The Authority does not pledge the faith and
credit of the State of Alaska, or any political subdivision thereof (except the Authority) to the
payment of the Bonds, and the issuance of the Bonds does not obligate the State of Alaska or any
political subdivision thereof (except the Authority) to apply money, or levy or pledge any form of
taxation whatsoever to, payment of the Bonds. The Authority has no taxing power.
That the form and content of the Supplemental Resolution be and the same hereby are in
all respects authorized, approved, confirmed and adopted, and each Authorized Officer be and they
hereby are in all respects severally authorized, empowered, and directed to execute and deliver the DRAFT
Resolution No. 2022-06 Page 3
4152-3049-5295.5
final Supplemental Resolution for and on behalf of the Authority to U.S. Bank Trust Company,
National Association, as Trustee, for the security of the Bonds, including necessary counterparts,
in substantially the form now before this meeting, but with such changes, modifications, additions,
and deletions therein as shall to them seem necessary, desirable, or appropriate, the execution
thereof to constitute conclusive evidence of their approval of any and all changes, modifications,
additions, or deletions thereto from such form, and that the final Supplemental Resolution is hereby
authorized, approved, confirmed and adopted in accordance with the Master Bond Resolution and
is incorporated herein by reference. Following execution and delivery of the Supplemental
Resolution, each Authorized Officer be and they hereby are authorized, empowered, and directed
to do all such acts and things and to execute all such documents as may be necessary or convenient
to carry out and comply with the provisions of the Supplemental Resolution as executed.
That the form and content of the Loan Agreement be and the same hereby are in all respects
authorized, approved and confirmed and each Authorized Officer be and they hereby are
authorized, empowered and directed to execute and deliver the final Loan Agreement for and on
behalf of the Authority, in substantially the form and content now before this meeting but with
such changes, modifications, additions, and deletions therein as shall to them seem necessary,
desirable or appropriate, their execution of the Loan Agreement, to constitute conclusive evidence
of their approval of any and all changes, modifications, additions or deletions therein from the
form and content of the Loan Agreement now before this meeting, and that, from and after the
execution and delivery of the Loan Agreement, each Authorized Officer be and they hereby are
authorized, empowered, and directed to do all such acts and things and to execute all such
documents as may be necessary to carry out and comply with the provisions of the Loan Agreement
as executed.
That the sale of the Bonds to the Purchaser is hereby authorized and approved and the
Authority shall expend the proceeds of the Bonds related to the sale thereof in accordance with
State law governing contract procurement and applicable competitive bidding processes.
That the Board of the Authority acknowledges that the Bradley Lake Project Management
Committee desires to allocate approximately 65% of proceeds of the Bonds toward transmission
upgrades and approximately 35% of proceeds of the Bonds toward the battery energy storage
system serving the Kenai Peninsula, South Central, and Interior Alaska. The Authority will use
commercially reasonable efforts to effectuate such allocation; provided, however, that the
Authority in its discretion, may deviate from such allocation, in order to fulfill its purpose and
duties, as set forth in State law.
That the Authorized Officers be, and each of them hereby is, authorized to execute and
deliver for and on behalf of the Authority any and all additional certificates, documents, opinions
or other papers and perform all such other acts as they may deem necessary or appropriate in order
to implement and carry out the intent and purposes of this Resolution.
That this Resolution does hereby incorporate by reference, as though fully set out herein,
the provisions of the Act, the Master Bond Resolution, the final Supplemental Resolution, and the
documents presented to this meeting. DRAFT
Resolution No. 2022-06 Page 4
4152-3049-5295.5
That the recitals to this Resolution, including definition of terms, are incorporated into this
Resolution as if fully set forth herein.
That this Resolution shall become effectively immediately upon its passage and approval.
DATED at Anchorage, Alaska, this 26th day of October 2022.
Chair
ATTEST:
Secretary
DRAFT
OHS DRAFT 10/12/2022
4146-3513-2990.3
ALASKA ENERGY AUTHORITY
RESOLUTION NO. 2022-__
A SUPPLEMENTAL RESOLUTION
AUTHORIZING THE ISSUANCE, SALE AND
DELIVERY OF POWER REVENUE BONDS,
ELEVENTH SERIES (BRADLEY LAKE
HYDROELECTRIC PROJECT), IN AN
AGGREGATE PRINCIPAL AMOUNT NOT TO
EXCEED $________ AND DETERMINING
RELATED MATTERS
Adopted ________, 2022 DRAFT
TABLE OF CONTENTS
Page
i
4146-3513-2990.3
ARTICLE I
Definitions and Authority
Section 101. Short Title .............................................................................................................. 1
Section 102. Definitions.............................................................................................................. 1
Section 103. Authority for this Resolution ................................................................................. 2
ARTICLE II
Authorization; Terms and Issuance
Section 201. Authorization, Principal Amount, Interest Rate, Designation and Series.............. 2
Section 202. Purposes; Construction Fund; Reserve Fund ......................................................... 3
Section 203. Issue Date and Form, Book-Entry ......................................................................... 3
Section 204. Places and Manner of Payment .............................................................................. 4
Section 205. Maturities and Interest Rate ................................................................................... 5
Section 206. Numbers and Letters .............................................................................................. 5
Section 207. Redemption ............................................................................................................ 5
Section 208. No Redemption of Bonds from Construction Fund Moneys ................................. 5
ARTICLE III
Sale and Delivery of Bonds
Section 301. Sale of Bonds ......................................................................................................... 5
Section 302. Delivery of Bonds .................................................................................................. 6
ARTICLE IV
Paying Agent
Section 401. Appointment of Paving Agent ............................................................................... 7
ARTICLE V
Ratification
Section 501. Ratification, Confirmation and Approval .............................................................. 7
ARTICLE VI
Effective Date
Section 601. Tenth Supplemental Resolution Effective Date ..................................................... 7
Exhibit A Bond Terms DRAFT
Tenth Supplemental Resolution Page 1
4146-3513-2990.3
ALASKA ENERGY AUTHORITY
RESOLUTION NO. 2022-[__]
A SUPPLEMENTAL RESOLUTION
AUTHORIZING THE ISSUANCE, SALE AND
DELIVERY OF POWER REVENUE BONDS,
ELEVENTH SERIES (BRADLEY LAKE
HYDROELECTRIC PROJECT), IN AN
AGGREGATE PRINCIPAL AMOUNT NOT TO
EXCEED $_______ AND DETERMINING
RELATED MATTERS
Pursuant to the terms and conditions set forth in the Alaska Energy Authority Power
Revenue Bond Resolution, adopted on September 7, 1989 (as amended and supplemented, the
“Resolution”) and the Authority’s Resolution No. 2022-06, adopted on October 26, 2022, this
Supplemental Resolution is adopted as follows:
ARTICLE I
Definitions and Authority
Section 101. Short Title. This resolution may hereafter be cited by the Authority, and is
hereinafter sometimes referred to, as the “Tenth Supplemental Resolution.”
Section 102. Definitions.
(A) All defined terms contained in the Resolution shall have the same meanings in this
Tenth Supplemental Resolution as such defined terms are given in Section 102 of the Resolution.
(B) In addition, as used in this Tenth Supplemental Resolution, unless the context shall
otherwise require, the following terms shall have the following respective meanings:
Authorized Denomination means $25,000 and integral multiples of $1.00 in excess thereof
Beneficial Owner means the person in whose name a Bond is recorded as the beneficial
owner of such Bond by the respective systems of DTC and the DTC Participants or the registered
owner of the Bond if the Bond is not then held in book-entry form under Section 203.
Bonds means the Eleventh Series Bonds.
Code means the Internal Revenue Code of 1986, as amended.
Continuing Disclosure Agreement means the Continuing Disclosure Agreement, if any,
executed by the Authority and dated the date of the Bonds are issued and as it may be amended
from time to time in accordance with the terms thereof. DRAFT
Tenth Supplemental Resolution Page 2
4146-3513-2990.3
Designated Representative means the Authority’s Executive Director and Chief Financial
Officer.
DTC means The Depository Trust Company, a limited purpose trust company organized
under the laws of the State of New York, and its successors and assigns.
DTC Participant means a trust company, bank, broker, dealer, clearing corporation and
any other organization that is a participant of DTC.
Eleventh Series Bonds means the Bonds of the Authority authorized by this Tenth
Supplemental Resolution and herein designated “Power Revenue Bonds, Eleventh Series.”
Fixed Rate of Interest means ___.
Letter of Representations means the Blanket Issuer Letter of Representations dated
October 24, 1997, from the Authority to DTC.
Loan Agreement means that certain loan agreement, or similar type agreement, between
the Authority and the Purchaser relating to the sale of the Bonds.
Purchaser means National Cooperative Services Corporation.
Transmission Project means the acquisition, improvement and development of the electric
transmission line systems between the Bradley Junction and Soldotna Substation, the electric
transmission line systems between the Soldotna Substation and the Sterling Substation, the electric
transmission line systems between the Sterling Substation and the Quartz Creek Substation, and
of battery energy storage systems, in each case including associated rights-of-way and permits,
collectively approved by the Committee as Required Project Work.
Section 103. Authority for this Resolution. This Tenth Supplemental Resolution is
adopted pursuant to the provisions of the Act and the Resolution.
ARTICLE II
Authorization; Terms and Issuance
Section 201. Authorization, Principal Amount, Interest Rate, Designation and Series.
(A)
(1) In order to provide funds necessary for the purposes specified in
Section 204 of the Resolution, in accordance with and subject to the terms, conditions and
limitations established herein and in the Resolution, a Series of Power Revenue Bonds is hereby
authorized to be issued in an aggregate principal amount not to exceed $______. The Bonds are
being issued for the purpose of financing a portion of the costs of the Transmission Project. The
Bonds of such Series shall be designated and entitled “Power Revenue Bonds, Eleventh Series
(Bradley Lake Hydroelectric Project).” DRAFT
Tenth Supplemental Resolution Page 3
4146-3513-2990.3
(2) To make a deposit to the Capital Reserve Fund, sufficient to satisfy the
Capital Reserve Fund Requirement.
(3) To pay costs of issuance of the Bonds.
(B) The Bonds shall bear interest at the Fixed Rate of Interest.
(C) The Authority hereby finds and determines that the establishment in the Resolution
of the Capital Reserve Fund will enhance the marketability of the Bonds.
Section 202. Purposes; Construction Fund; Reserve Fund.
(A)
(1) The purpose for which the Bonds are being issued is to finance costs and
expenses of planning, designing, acquiring, and construction of the Transmission Project. The
Authority is of the opinion and hereby determines that the Transmission Project is necessary to
keep the Project in good and efficient operating condition, consistent with (i) sound economics for
the Project and Purchasers and (ii) national standards for the industry. The Committee has, by
resolution, deemed the Transmission Project as Required Project Work pursuant to the terms of
the Power Sales Agreement.
(2) To make a deposit to the Capital Reserve Fund, sufficient to satisfy the
Capital Reserve Fund Requirement.
(3) To pay costs of issuance of the Bonds.
(B) There is hereby established within the Construction Fund the Eleventh Series
Construction Account. The Trustee shall deposit proceeds of the Bonds, in the amount of $______
into the Eleventh Series Construction Account and shall hold such proceeds for the payment of
Costs of Acquisition and Construction of the Transmission Project in accordance with Section 503
of the Resolution; provided, however, that the Designated Representative may instruct the Trustee
to hold a portion of such proceeds or such other amounts for payment of Costs of Issuance in an
amount not to exceed $_______, and the Trustee shall apply such proceeds or such other amounts
to pay such costs as instructed by the Designated Representative.
(C) There is hereby established within the Capital Reserve Fund the Eleventh Series
Capital Reserve Account. The Trustee shall deposit proceeds of the Bonds in the amount of
$_______ into the Eleventh Series Capital Reserve Account and shall hold such amounts in
accordance with Section 508 of the Resolution.
Section 203. Issue Date and Form; Book-Entry.
(A) The Bonds shall be dated as of the date of delivery of the Bonds to the Purchaser.
(B) The Bonds shall be registered initially in the name of the Purchaser of the Bonds,
and shall be issued initially in the form of a single Bond with principal installments for each DRAFT
Tenth Supplemental Resolution Page 4
4146-3513-2990.3
maturity. Registered ownership of the Bonds, or any portions thereof, may not thereafter be
transferred except as provided in paragraph (D) below.
(C) The Authority confirms its appointment of the Trustee to serve as the Bond
Registrar under the terms of the Resolution.
(D) In the case of any transfer of ownership of the Bonds, the Trustee shall, upon receipt
of all Outstanding Bonds, together with a written request of an Authorized Officer and a supply of
new Bonds authenticate a single new Bond with principal installments for each maturity in the
amount of such maturity or new Bonds, in Authorized Denominations, for each maturity of Bonds
then Outstanding, registered in the name of a new person, entity or depository, or its nominee, as
the case may be, all as specified in such written request.
(E) If the Bonds are subsequently held in book-entry form under this Section, the
Authority and the Trustee may treat DTC (or its nominee) as the sole and exclusive registered
owner of the Bonds registered in its name for the purposes of payment of principal or Redemption
Price of and interest on such Bonds, selecting such Bonds or portions thereof to be redeemed,
giving any notice permitted or required to be given to Bondholders under the Resolution,
registering the transfer of such Bonds and obtaining any consent or other action to be taken by
Bondholders and for all other purposes whatsoever, and neither the Authority nor the Trustee shall
be affected by any notice to the contrary. Neither the Authority nor the Trustee shall have any
responsibility or obligation to any DTC Participant, any person claiming a beneficial ownership
interest in the Bonds under or through DTC or any DTC Participant, or any other person not shown
on the registration books of the Trustee as being a registered owner with respect to the accuracy
of any records maintained by DTC or any DTC Participant, the payment by DTC or any DTC
Participant of any amount in respect of the principal or Redemption Price of or interest on the
Bonds, any notice which is permitted or required to be given to Bondholders under the Resolution,
the selection by DTC or any DTC Participant of any person to receive payment in the event of a
partial redemption of the Bonds, or any consent given or other action taken by DTC as Bondholder.
The Trustee shall pay from monies available under the Resolution all principal and Redemption
Price of and interest on Bonds only to or upon the order of DTC, and all such payments shall be
valid and effective to fully satisfy and discharge the Authority’s obligations with respect to the
principal or Redemption Price of and interest on the Bonds to the extent of the sum or sums so
paid.
Section 204. Places and Manner of Payment. Payment of interest on the Bonds will be
made by check or draft mailed by first class mail to the registered owner at the address appearing
on the bond register of the Authority kept at the corporate trust office of the Trustee, or, upon the
written request of a registered owner of at least $1,000,000 in principal amount of Bonds received
at least 15 days prior to an interest payment date, by wire transfer in immediately available funds
to an account in the United States of America designated by such registered owner; principal of
the Bonds will be made by check or draft mailed by first class mail to the registered owner at the
address appearing on the bond register of the Authority kept at the corporate trust office of the
Trustee with the final installment of principal payable at the corporate trust office of the Trustee
upon surrender of the Bonds representing such principal. Both principal of and interest on the
Bonds are payable in any coin or currency of the United States of America which, on the respective
dates of payment thereof, shall be legal tender for the payment of public and private debts. If all DRAFT
Tenth Supplemental Resolution Page 5
4146-3513-2990.3
the Outstanding Bonds shall subsequently be registered in the name of “Cede & Co.,” or its
registered assigns, as nominee of DTC, payment of principal and interest thereon shall be made as
provided in the Letter of Representations and the operational arrangements referred to therein as
amended from time to time.
Section 205. Maturities and Interest Rate. The Bonds shall be issued in Authorized
Denominations, shall mature no later than July 1, 2052, and shall bear interest at the Fixed Rate of
Interest, all as further determined by the Designated Representative pursuant to Section 301 hereof.
Section 206. Numbers and Letters. Bonds shall be numbered and lettered in such manner
as the Designated Representative shall determine prior to delivery thereof.
Section 207. Redemption. The Bonds shall be subject to redemption (including
redemption by application of sinking fund payments) as determined by the Designated
Representative pursuant to Section 301 hereof.
Section 208. No Redemption of Bonds from Construction Fund Moneys. The Bonds
shall not be subject to redemption pursuant to subsection 503(8) of the Resolution.
ARTICLE III
Sale and Delivery of Bonds
Section 301. Sale of Bonds.
(A) The Bonds shall be sold at negotiated sale to the Purchaser pursuant to the terms of
the Loan Agreement. The Designated Representative is hereby authorized to negotiate terms for
the purchase of the Bonds, review, approve and execute the Loan Agreement, with such terms as
are approved by him or her pursuant to this Section and consistent with this Tenth Supplemental
Resolution. The Authority’s financial advisor has advised the Authority that market conditions
are fluctuating and, as a result, the most favorable market conditions may occur on a day other
than a scheduled meeting date of the Authority. The Authority has determined that it would be in
the best interest of the Authority to delegate to the Designated Representative for a limited time
(not to exceed 90 days following the date of adoption of this Tenth Supplemental Resolution) the
authority to approve the final interest rate or rates, interest payment dates, aggregate principal
amount, terms of redemption and redemption rights and principal amounts of each principal
installment/maturity date of the Bonds, subject in all events to the terms herein stated. The
Designated Representative is hereby authorized to approve the final interest rate or rates, interest
payment dates, principal installment/maturity date(s), principal installments/maturities, terms of
redemption and redemption rights for the Bonds in the manner provided hereafter so long as the
aggregate principal amount of the Bonds does not exceed $_______; provided, however, that
notwithstanding the foregoing the Designated Representative is not authorized, empowered, or
directed to execute or deliver the Loan Agreement until the Committee, or its designee for the
Transmission Project, shall have approved the final terms of the Loan Agreement and shall have
requested the Authority to execute and deliver the Loan Agreement.
In determining the final interest rate or rates, interest payment date or dates, aggregate
principal amount, principal installment/maturities dates, principal installments, terms of
redemption and redemption rights, the Designated Representative, in consultation with Authority DRAFT
Tenth Supplemental Resolution Page 6
4146-3513-2990.3
staff and the Authority’s financial advisor shall take into account those factors that, in his or her
judgment, will result in the most favorable terms for the Bonds, including, but not limited to current
financial market conditions and current interest rates for obligations comparable in tenor and
quality to the Bonds.
Subject to the terms and conditions set forth in this Section 301, the Designated
Representative is hereby authorized to execute the final form of the Loan Agreement, upon the
Designated Representative’s approval of the final interest rate or rates, interest payment dates,
aggregate principal amount, principal installments/maturities, terms of redemption and redemption
rights set forth therein. Such terms shall be set forth in Exhibit A to the Loan Agreement and an
exhibit setting forth such final terms of the Bonds shall be attached to this Tenth Supplemental
Resolution as Exhibit A, and thereby incorporated into this Tenth Supplemental Resolution. The
authority granted to the Designated Representative by this Section 301 shall expire 90 days after
the date of approval of this Tenth Supplemental Resolution. If a Loan Agreement for the Bonds
has not been executed within 90 days after the date of final approval of this Tenth Supplemental
Resolution, the authorization for the issuance of the Bonds shall be rescinded, and the Bonds shall
not be issued nor their sale approved unless such Bonds shall have been re-authorized by resolution
of the Authority. The resolution re-authorizing the issuance and sale of such Bonds may be in the
form of a new Supplemental Resolution repealing this Tenth Supplemental Resolution in whole or
in part or may be in the form of an amendatory resolution approving a Loan Agreement or
establishing terms and conditions for the authority delegated under this Section 301.
(B) Upon the passage and approval of this Tenth Supplemental Resolution, each
Designated Representative is authorized and directed to undertake all action necessary for the
prompt execution and delivery of the Bonds to the Purchaser and to execute the Loan Agreement
and all closing certificates and documents required to effect the closing and delivery of the Bonds
in accordance with the terms of the Loan Agreement.
Section 302. Delivery of Bonds. The Chair, the Board member designee of the Chair,
Executive Director, Chief Financial Officer and such other person or persons as may be designated
by the Executive Director are specifically designated as Authorized Officers as defined in the
Resolution, and they hereby are severally authorized, after execution of the Bonds, to deliver the
Bonds to the Trustee for authentication under the Resolution and, upon authentication and upon
receipt of the balance of the purchase price of the Bonds, to deliver to the Trustee a written order
in the name of the Authority directing the Trustee to deliver the Bonds to or upon the order of the
Purchaser and to receive the proceeds of sale of the Bonds and give a written receipt therefor on
behalf of the Authority, to apply said proceeds and the other moneys required to be transferred or
deposited in accordance with the terms of the Resolution and this Tenth Supplemental Resolution
and in such manner as is required to cause the conditions precedent to the issuance of the Bonds
to be complied with, and to do and perform or cause to be done and performed, for and on behalf
of the Authority, all acts and things that constitute conditions precedent to the authentication and
delivery of the Bonds or that are otherwise required or convenient to be done and performed by or
on behalf of the Authority prior to or simultaneously with the delivery of the Bonds. Such
Authorized Officers are hereby severally authorized for and on behalf of the Authority to do or
cause to be done all acts and things required or desirable to be done by the Authority under and
pursuant to the terms of the Resolution and in accordance with the terms and conditions of the
Loan Agreement. DRAFT
Tenth Supplemental Resolution Page 7
4146-3513-2990.3
ARTICLE IV
Paying Agent
Section 401. Appointment of Paving Agent. U.S. Bank Trust Company, National
Association is appointed Paying Agent for the Bonds pursuant to Section 902 of the Resolution.
ARTICLE V
Ratification
Section 501. Ratification, Confirmation and Approval. Pursuant to Section 713 of the
Resolution, the Authority has assigned, pledged and transferred its rights under the Power Sales
Agreement to the Trustee for the benefit of Bondholders and further agreed to enforce its terms.
This Board hereby ratifies, approves and confirms the Power Sales Agreement as a valid and
binding obligation of the Authority and further authorizes and directs that the Power Sales
Agreement, including all amendments thereto, certified by an Authorized Officer, be filed with the
Trustee.
ARTICLE VI
Effective Date
Section 601. Tenth Supplemental Resolution Effective Date. This Tenth Supplemental
Resolution shall take effect immediately.
Supplemental Resolution approved and adopted by the Alaska Energy Authority on
October 26, 2022.
ALASKA ENERGY AUTHORITY
CHAIR
[SEAL]
ATTEST:
SECRETARY
DRAFT
Tenth Supplemental Resolution Page A-1
4146-3513-2990.3
EXHIBIT A
BOND TERMS
1. Principal amount of Bonds: $_______
2. Fixed Rate: ______%
3. Principal payment dates: ______ 1 of each year, commencing _____ 1, 20__
4. Interest payment dates: ____1, 2023 and thereafter the first day of each _____ and ____
5. Redemption feature: ___________
DRAFT
OHS DRAFT 10/14/2022
4123-9575-7373.4
LOAN AGREEMENT
LOAN AGREEMENT (the “Agreement”) dated December [__], 2022, between the
ALASKA ENERGY AUTHORITY (the “Borrower”), a public corporation of the State of Alaska
in the Department of Commerce, Community and Economic Development, with separate and
independent legal existence, created and existing pursuant to Chapter 83, Title 44 of the Alaska
Statutes (the “Act”) and NATIONAL COOPERATIVE SERVICES CORPORATION (“NCSC”),
a cooperative association organized and existing under the laws of the District of Columbia.
RECITALS
WHEREAS, the Borrower has applied to NCSC for a loan for the purposes set forth in
Schedule 1 hereto, and NCSC is willing to make such a loan to the Borrower on the terms and
conditions stated herein; and
WHEREAS, the Borrower has agreed to execute a promissory note to evidence an
indebtedness in the aggregate principal amount of the Commitment (as hereinafter defined)
authenticated and secured pursuant to the terms of the Bond Resolution and Bond Resolution
Supplement (each as hereinafter defined).
NOW, THEREFORE, for and in consideration of the premises and the mutual covenants
hereinafter contained, the parties hereto agree and bind themselves as follows:
ARTICLE I
DEFINITIONS
Section 1.01 Initially capitalized terms used herein shall have the meanings as set forth
(i)in the above introductory paragraph, (ii) below, or (iii) elsewhere herein as indicated by such
terms shown in quotation marks within parentheses. All such definitions shall be equally
applicable to the singular and the plural form thereof. Initially capitalized terms that are not
defined herein shall have the meanings as set forth in the Bond Resolution.
“Advance” shall mean the advance of funds by NCSC to the Borrower under the Note.
“Annual Project Cost” shall have the meaning ascribed to it in the Power Contract.
“Bond Resolution” shall have the meaning as described in Schedule 1 hereto.
“Bond Resolution Supplement” shall have the meaning as described in Schedule 1.
“Bradley Lake Project” shall mean the Bradley Lake Hydroelectric Project, as the same
is described in the Bond Resolution.
“Business Day” shall mean any day that both NCSC and the depository institution NCSC
utilizes for funds transfers hereunder are open for business.
“Closing Date” shall mean the date specified on Schedule 1. DRAFT
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“Commitment” shall have the meaning set forth on Schedule 1.
“Debt Service Coverage (“DSC”) Ratio” shall mean the ratio determined as follows: for
any fiscal year, as set forth in the Borrower’s annual audited financial statements, add (a) increase
(decrease) in net position (i.e. net income or other comparable term) of the Borrower with respect
to the Project, as determined in accordance with GAAP plus Depreciation and Amortization
Expense, and interest on Long-Term Debt for such year, divided by (b) the sum of all scheduled
payments of principal required to made during such year with respect to the Project and the amount
of interest expense related to such period on Long-Term Debt.
“Default Rate” shall mean a rate per annum equal to the interest rate in effect for the
Advance plus two hundred (200) basis points.
“Depreciation and Amortization Expense” shall mean an amount constituting the
depreciation and amortization of the Borrower with respect to the Project computed pursuant to
GAAP.
“Environmental Laws” shall mean all applicable laws, rules and regulations promulgated
by any Governmental Authority with which the Borrower is required to comply, regarding the use,
treatment, discharge, storage, management, handling, manufacture, generation, processing,
recycling, distribution, transport, release of or exposure to any Hazardous Material.
“Environmental Permits” shall mean permits or licenses issued by any Governmental
Authority under applicable Environmental Laws.
“Event of Default” shall have the meaning as described in Article VI hereof.
“Fixed Rate” shall mean [___].
“Fixed Rate Term” shall mean the period from the Closing Date to the Maturity Date.
“GAAP” shall mean generally accepted accounting principles in the United States of
America as in effect from time to time.
“Governmental Authority” shall mean the government of the United States of America,
or any state or other political subdivision thereof, whose laws, rules and regulations the Borrower
is required to comply with, whether state or local, and any agency, authority, instrumentality,
regulatory body, court or other entity exercising executive, legislative, judicial, taxing, regulatory
or administrative powers or functions of or pertaining to government.
“Hazardous Material” shall mean any (a) petroleum or petroleum products, radioactive
materials, asbestos-containing materials, polychlorinated biphenyls, lead and radon gas, and
(b) any other substance that is defined and regulated as hazardous or toxic or as a pollutant or
contaminant in any applicable Environmental Law.
“Lien” shall mean any statutory or common law consensual or non-consensual mortgage,
pledge, security interest, encumbrance, lien, right of set off, claim or charge of any kind, including, DRAFT
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without limitation, any conditional sale or other title retention transaction, any lease transaction in
the nature thereof and any secured transaction under the Uniform Commercial Code.
“Loan Documents” shall mean this Agreement, the Note, the Bond Resolution, the Bond
Resolution Supplement and all other documents or instruments executed, delivered or executed
and delivered by the Borrower and evidencing, securing, governing or otherwise pertaining to the
credit facility provided, and the Advance made, by NCSC hereunder.
“Long-Term Debt” shall mean an amount constituting the long-term debt of the Borrower
with respect to the Project computed pursuant to GAAP.
“Make-Whole Premium” shall mean, with respect to any Prepaid Principal Amount, an
amount calculated as set forth below. The Make-Whole Premium represents NCSC’s reinvestment
loss resulting from making a fixed rate loan.
(1) Compute the amount of interest (“Loan Interest”) that would have been due on the
Prepaid Principal Amount at the applicable Fixed Rate for the period from the prepayment date
through the end of the Fixed Rate Term (such period is hereinafter referred to as the “Remaining
Term”), calculated on the basis of a 30-day month/360-day year, adjusted to include any
amortization of principal in accordance with the amortization schedule that would have been in
effect for the Prepaid Principal Amount.
(2) Compute the amount of interest (“Investment Interest”) that would be earned on the
Prepaid Principal Amount (adjusted to include any applicable amortization) if invested in a United
States Treasury Note with a term equivalent to the Remaining Term, calculated on the basis of a
30-day month/360-day year. The yield used to determine the amount of Investment Interest shall
be based upon United States Treasury Note yields as reported no more than two Business Days
prior to the prepayment date in Federal Reserve statistical release H.15 (519), under the caption
“U.S. Government Securities/Treasury Constant Maturities”. If there is no United States Treasury
Note under said caption with a term equivalent to the Remaining Term, then the yield shall be
determined by interpolating between the terms of whole years nearest to the Remaining Term.
(3) Subtract the amount of Investment Interest from the amount of Loan Interest. If
the difference is zero or less, then the Make-Whole Premium is zero. If the difference is greater
than zero, then the Make-Whole Premium is a sum equal to the present value of the difference,
applying as the present value discount a rate equal to the yield utilized to determine Investment
Interest.
“Material Adverse Effect” shall mean a material adverse change in or material adverse
effect on (a) the Project, (b) the business, assets, liabilities (actual or contingent), operations, or
condition (financial or otherwise) of the Borrower and its Subsidiaries, taken as a whole, with
respect to the Project, (c) the ability of the Borrower to perform any of its obligations under this
Agreement or any of the other Loan Documents, (d) the validity or enforceability of this
Agreement, the Note or the Bond Resolution or (e) NCSC’s rights as a Holder of Bonds to exercise
the remedies set forth in Article VII hereof or as set forth in the Bond Resolution, in the manner
and to the extent provided for by this Agreement and the Bond Resolution, as applicable.
“Maturity Date” shall mean [___]. DRAFT
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“Note” shall mean the Power Revenue Bond, Eleventh Series 2022 (Bradley Lake
Hydroelectric Project), or such other title as agreed to by the parties hereto, dated as of even date
herewith, payable to the order of NCSC, executed by the Borrower pursuant to this Agreement as
identified on Schedule 1 hereto, as it may be amended, restated, modified, substituted or replaced
from time to time.
“Obligations” shall mean any and all liabilities, obligations or indebtedness owing by the
Borrower to NCSC under the Loan Documents, of any kind or description, irrespective of whether
for the payment of money, whether direct or indirect, absolute or contingent, due or to become
due, now existing or hereafter arising.
“Power Contract” shall mean the Agreement for the Sale and Purchase of Electric Power,
dated as of December 8, 1987, by and among the predecessor to AEA, Chugach Electric
Association, Inc., Golden Valley Electric Association, Inc., Alaska Electric Generation &
Transmission Cooperative, Inc., and the City of Seward, and as Additional Parties, Homer Electric
Association, Inc. and Matanuska Electric Association, Inc. (collectively, the “Power Purchasers”),
as it may have been or shall be in the future be supplemented, amended, consolidated, or restated
from time to time.
“Prepaid Principal Amount” shall mean all or any part of the outstanding principal of an
Advance bearing interest at the Fixed Rate paid prior to the expiration of the Fixed Rate Term
applicable thereto.
“Project” shall mean the Bradley Lake Project and the Transmission Project.
“Subsidiary” as to any Person, shall mean a corporation, partnership, limited partnership,
limited liability company or other entity in which shares of stock or other ownership interests
having ordinary voting power (other than such stock or other ownership interests having such
voting power only by reason of the happening of a contingency) to elect a majority of the board of
directors or other managers of such entity are at the time owned, or the management of which is
otherwise controlled, directly or indirectly through one or more intermediaries, or both, by such
Person. Unless otherwise qualified, all references to a “Subsidiary” or to “Subsidiaries” in this
Agreement shall refer to a Subsidiary or Subsidiaries of the Borrower.
“Transmission Project” shall mean the acquisition, improvement and development of the
electric transmission line systems between the Bradley Junction and Soldotna Substation, the
electric transmission line systems between the Soldotna Substation and the Sterling Substation,
the electric transmission line systems between the Sterling Substation and the Quartz Creek
Substation, and of battery energy storage systems, in each case including associated rights-of-way
and permits, collectively approved by the Committee as Required Project Work.
“Variable Rate” shall mean the variable rate established by NCSC from time to time for
loans similarly classified pursuant to NCSC’s policies and procedures then in effect.
ARTICLE II
REPRESENTATIONS AND WARRANTIES
Section 2.01 The Borrower represents and warrants to NCSC that as of the Closing Date: DRAFT
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A. Good Standing. The Borrower is duly organized, validly existing and in good
standing under the laws of the jurisdiction of its incorporation or organization, and, except where
the failure to do so individually or in the aggregate, would not reasonably be expected to result in
a Material Adverse Effect, is duly qualified to do business and is in good standing in those states
in which it is required to be qualified to conduct its business.
B. Authority; Validity. The Borrower has or had the power and authority to enter
into this Agreement, the Note and the Bond Resolution; to make the borrowing contemplated
hereunder and under the Note; to execute and deliver all documents and instruments required
hereunder and to incur and perform the obligations provided for herein, in the Note and in the
Bond Resolution, all of which have been duly authorized by all necessary and proper action; and
no consent or approval of any Person which has not been obtained is required as a condition to the
validity or enforceability hereof or thereof.
Each of this Agreement, the Note and the Bond Resolution is, and when fully executed and
delivered will be, legal, valid and binding upon the Borrower and enforceable against the Borrower
in accordance with its terms, subject to applicable bankruptcy, insolvency, reorganization,
moratorium or other laws affecting creditors’ rights generally and subject to general principles of
equity.
C. No Conflicting Agreements. The execution and delivery of the Loan Documents
and performance by the Borrower of the obligations hereunder and thereunder, and the transactions
contemplated hereby or thereby, will not in any material respect: (i) violate any provision of law,
any order, rule or regulation of any Governmental Authority, any award of any arbitrator, the Act,
the Bond Resolution or any material contract, agreement, mortgage, deed of trust or other
instrument to which the Borrower is a party or by which it or any of its property is bound; or (ii) be
in conflict with, result in a breach of or constitute (with due notice and/or lapse of time) a default
under, any such award, the Bond Resolution or any such contract, agreement, mortgage, deed of
trust or other instrument to which the Borrower is a party or by which it or any of its property is
bound, or result in the creation or imposition of any Lien (other than contemplated by the Bond
Resolution, including the issuance of additional bonds pursuant to the terms of the Bond
Resolution) upon the Project. The Borrower is not in default in any material respect under the
Bond Resolution.
D. Taxes. The Borrower has filed or caused to be filed all federal, state and local tax
returns which are required to be filed and has paid or caused to be paid all federal, state and local
taxes, assessments, and Governmental Authority charges and levies thereon, including interest and
penalties to the extent that such taxes, assessments, and Governmental Authority charges and
levies have become due, except (i) for such taxes, assessments, and Governmental Authority
charges and levies which the Borrower is contesting in good faith by appropriate proceedings for
which adequate reserves have been set aside, if such reserves are required by Account ing
Requirements, or (ii) to the extent the failure to do so would not reasonably be expected to have a
Material Adverse Effect.
E. Licenses and Permits. The Borrower has duly obtained and now holds all licenses,
permits, certifications, approvals and the like necessary to own and operate the Project that are DRAFT
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required by Governmental Authorities and each remains valid and in full force and effect, except
such as would not reasonably be expected to have a Material Adverse Effect.
F. Litigation. There are no outstanding judgments, suits, claims, actions or
proceedings pending or, to the knowledge of the Borrower, threatened against or affecting the
Borrower or the Project which, if adversely determined, either individually or collectively, would
reasonably be expected to have a Material Adverse Effect. The Borrower is not, to the Borrower’s
knowledge, in default or violation with respect to any judgment, order, writ, injunction, decree,
rule or regulation of any Governmental Authority which would reasonably be expected to have a
Material Adverse Effect.
G. Financial Statements. The audited financial statements of the Borrower as of the
date identified in Schedule 1 hereto heretofore furnished to NCSC, fairly present, in all material
respects, the financial condition of the Borrower as at said date and fairly reflect its operations for
the period ending on said date. There has been no change in the financial condition or operations
of the Borrower from that set forth in said financial statements that would reasonably be expected
to have a Material Adverse Effect.
H. Required Approvals. The Borrower has obtained all licenses, consents or
approvals of all Governmental Authorities that the Borrower is required to obtain in order for the
Borrower to enter into and perform under this Agreement, the Note and the Bond Resolution and
to enter into and perform under all contracts and agreements that the Borrower has entered into or
shall enter into in connection with the acquisition, construction, ownership and operation of the
Project, and the purchase of power from, or the sale of power to, the Project. Each such license,
consent or approval is in full force and effect.
I. Compliance With Laws. The Borrower is in compliance with all applicable
requirements of law and all applicable rules and regulations of each Governmental Authority,
except for any such failures of compliance as would not reasonably be expected to have a Material
Adverse Effect.
J. Disclosure. To the Borrower’s knowledge, information and belief, neither this
Agreement nor any document, certificate or financial statement furnished to NCSC by or on behalf
of the Borrower in connection herewith (all such documents, certificates and financial statements,
taken as a whole) as of the date of delivery thereof, taken as a whole, and in the light of the
circumstances under which they were made, contains any untrue statement of a material fact or
omits to state any material fact necessary in order to make the statements contained herein and
therein not materially misleading.
K. No Other Liens. The Borrower has not created, incurred, assumed or permitted to
exist, any Lien on the Project other than as provided for under the Bond Resolution or as permitted
by the Bond Resolution.
L. Environmental Matters. Except as to matters which individually or in the
aggregate would not reasonably be expected to have a Material Adverse Effect, (i) the Borrower
is in compliance with all applicable Environmental Laws (including, but not limited to, having any
required Environmental Permits), (ii) to the best of the Borrower’s knowledge, there have been no DRAFT
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releases (other than releases remediated in compliance with applicable Environmental Laws and
air emissions) from any underground or aboveground storage tanks (or piping associated
therewith) that are or were present at the Project, (iii) the Borrower has not received written notice
or claim of any violation of any Environmental Law from a Governmental Authority and failed to
take appropriate action to remedy, cure, defend or otherwise affirmatively respond to the matter in
order to comply with any Environmental Law that is the subject of such written notice or claim
and relating to the Project, (iv) to the best of the Borrower’s knowledge, there is no pending
investigation of the Borrower in regard to any Environmental Law relating to the Project, and (v) to
the best of the Borrower’s knowledge, there has not been any unauthorized release or
contamination (other than releases or contamination remediated in compliance with Environmental
Laws) resulting from the presence of Hazardous Materials on property owned, leased or operated
by the Borrower other than disclosed to and approved by NCSC.
M. Power Contract. The Power Contract is in full force and effect and is legal, valid
and binding upon the Borrower and enforceable against the Borrower in accordance with its terms,
subject only to limitations on enforceability imposed by general equitable principles or applicable
bankruptcy, insolvency, reorganization moratorium, or similar laws respecting creditors’ rights
generally. Pursuant to the Bond Resolution, the Borrower has pledged, assigned and transferred
to the Trustee, acting on behalf of the Bondholders, all of its rights under the Power Contract.
To the best of the Borrower’s knowledge, the Power Contract is valid and binding and enforceable
against each other party thereto, subject to limitations on enforceability imposed by general
equitable principles or applicable bankruptcy, insolvency, reorganization moratorium, or similar
laws respecting creditors’ rights generally.
ARTICLE III
LOANS
Section 3.01 Advances. NCSC agrees to make the Advance under the Note on the
Closing Date, for the purpose described on Schedule 1, in an aggregate principal amount which
shall not exceed the Commitment.
Section 3.02 Payment. The Note shall be payable as follows:
A. Payments. The Borrower shall make each payment required to be made by it
hereunder or under the Note (whether of principal, interest or fees, or otherwise) on the date when
due, in immediately available funds, without set-off or counterclaim, subject to the terms of the
Bond Resolution providing that payments under the Note are on a parity basis with the outstanding
Bonds and any additional Bonds.
B. Maturity. The Note shall have the Maturity Date as set forth therein.
C. Application of Payments. Each payment shall be applied to the Obligations first
to any fees, costs, expenses or charges other than interest or principal, second to interest accrued,
and the balance to principal.
D. Invoice. NCSC will invoice the Borrower at least ten (10) days before each
payment is due and shall send a copy of such invoice to the Trustee under the Bond Resolution, DRAFT
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provided, however, that NCSC’s failure to send an invoice shall not constitute a waiver by NCSC
or be deemed to relieve the Borrower of its obligation to make payments as and when due as
provided for herein.
Section 3.03 Amortization. The principal amount of the Note shall amortize on a level
principal payment basis through the Maturity Date as set forth on Schedule 2 hereto. For the
Advance the Borrower shall promptly pay (a) interest in the amount invoiced on January 1 and
July 1 in each year, commencing with July 1, 20[__] and (b) principal in the amount set forth on
Schedule 2 hereto on July 1 in each year, commencing with July 1, 20[__]. If not sooner paid, any
amount due on account of the unpaid principal, interest accrued thereon and fees, if any, shall be
due and payable on the Maturity Date.
Section 3.04 Interest Rate. The Note will bear interest as follows:
A. Interest Rate and Interest Rate Computation. The Advance shall bear interest
at the Fixed Rate and shall be in effect for the Fixed Rate Term. Interest on the Advance shall be
computed on the basis of a 30-day month and 360-day year.
B. Default Rate.
(i) Payment Default. If Borrower defaults on its obligation to make a pa yment due
hereunder by the applicable date payment is due, and such default continues for thirty (30) days
thereafter, then beginning on the thirty-first (31st) day after the payment is due and for so long as
such default continues, the Advance shall bear interest at the Default Rate.
(ii) Non-Payment Defaults. Upon the occurrence of an Event of Default, other than a
payment default as set forth in Section 3.04.B(i) above, the interest rate on the Advance shall be
the Default Rate until such Event of Default is cured.
(iii) No Multiples of Default Rate. Notwithstanding anything to the contrary contained
in this Section 3.04.B, in the event that more than one Event of Default shall exist at any time, the
aggregate interest rate applicable on the Advance pursuant to this Section 3.04.B shall be the
Default Rate.
C. Usury Savings Clause. No provision of this Agreement or of the Note shall require
the payment, or permit the collection, of interest in excess of the highest rate permitted by
applicable law.
Section 3.05 Optional Prepayment. The Borrower may prepay all or any part of the
outstanding principal of the Advance upon at least three (3) days prior written notice to NCSC. If
any principal of the Advance is prepaid (whether voluntarily by the Borrower or otherwise, and
regardless of the source of prepayment), then on the prepayment date there shall be due and owing,
and the Borrower shall pay on the amount of principal prepaid (i) all accrued but unpaid interest,
calculated up to the prepayment date and (ii) a Make-Whole Premium, if any. DRAFT
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ARTICLE IV
CONDITIONS
Section 4.01 Conditions of Closing. This Agreement shall become effective only upon
the satisfaction of the following conditions as of the Closing Date:
A. Legal Matters. All legal matters incident to the consummation of the transactions
hereby contemplated shall be reasonably satisfactory to counsel for NCSC and, as to all matters of
local law, to such local counsel as counsel for NCSC may retain. NCSC’s execution of this
Agreement shall evidence satisfaction of this condition.
B. Documents. NCSC shall have been furnished with:
(i) the executed Loan Documents;
(ii) certified copies of all such organizational documents and proceedings of the
Borrower authorizing the transactions hereby contemplated as NCSC shall require;
(iii) the final opinion of Bond Counsel;
(iv) to the extent the Note is executed and delivered under any of Section 202, 203 or
204 of the Bond Resolution, copies of all documents required to be delivered to the Trustee under
such Sections relating thereto;
(v) a copy of the Power Contract in effect on the date hereof, including any
amendments thereto;
(vi) evidence of funding of the Capital Reserve Fund so that the amount thereof is equal
to Capital Reserve Fund Requirement, taking into account the loan contemplated hereby;
(vii) an opinion of counsel from counsel to (a) each of the Power Purchasers except
Seward, or (b) the Power Purchasers participating in the Transmission Project and the Borrower,
as to the continued validity and enforceability of the Power Contract as to each Power Purchaser
except Seward; notwithstanding the forgoing, an opinion from counsel to the Bradley Lake
Management Committee on behalf of the Power Purchasers may be substituted for opinions of the
Power Purchasers;
(viii) a certificate from the General Manager and Chief Financial Officer (or other
comparable positions) of (a) each Power Purchaser, or (b) the Power Purchasers participating in
the Transmission Project and the Borrower, to the effect that there is no litigation pending
contesting the validity or enforceability of the Power Contract; and
(ix) all other such documents as NCSC may reasonably request. NCSC’s execution of
this Agreement shall evidence satisfaction of conditions set forth in this Section 4.01.B.
C. Government Approvals. The Borrower shall have furnished to NCSC true and
correct copies of all certificates, authorizations, consents, permits and licenses from Governmental DRAFT
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Authorities (if any) that are necessary for (i) the Transmission Project and (ii) the execution or
delivery of the Loan Documents or performance by the Borrower of the obligations thereunder.
D. Defaults. No event or condition has occurred that constitutes an Event of Default,
or which upon notice or lapse of time, or both, would, unless cured or waived, become an Event
of Default.
E. Material Adverse Effect. Since June 30, 2022, there shall not have occurred a
material adverse change in, or a material adverse effect on the business, assets, liabilities (actual
or contingent), operations or condition (financial or otherwise) of the Borrower.
F. Note Authentication. The Note shall have been duly authenticated by the Trustee
as an Additional Bond secured under the Bond Resolution.
G. Compliance. The Borrower shall be in compliance with the Bond Resolution, any
agreement for borrowed money and all other existing material financial obligations.
H. Litigation. Except as disclosed and agreed to by NCSC, there are no outstanding
judgments, suits, claims, actions or proceedings pending or, to the knowledge of the Borrower,
threatened against or affecting the Borrower or the Project which, if adversely determined, either
individually or collectively, would reasonably be expected to have a material adverse change in,
or a material adverse effect on, the business, assets, liabilities (actual or contingent), operations or
condition (financial or otherwise) of the Borrower.
ARTICLE V
COVENANTS
Section 5.01 Covenants. The Borrower covenants and agrees with NCSC that after
the date hereof and until payment in full of the Note and performance of all obligations of the
Borrower hereunder:
A. Compliance with Material Agreements. Borrower will comply, in all material
respects, with the Bond Resolution, the Power Contract and all other contractual obligations
binding upon it or its property.
B. DSC Ratio. The Borrower shall achieve an annual DSC Ratio of not less than 1.0.
C. Loan Proceeds. The Borrower shall use the proceeds of this loan solely for the
purposes identified on Schedule 1 hereto.
D. Annual Certificates. Within one hundred eighty (180) days after the close of each
fiscal year, the Borrower will deliver to NCSC a written statement, in form and substance
satisfactory to NCSC, either (a) signed by the Borrower’s Executive Director or Chief Financial
Officer or their designee, so long as such designee is an officer of the Borrower, or (b) submitted
electronically through means made available to the Borrower by NCSC, stating that during such
year, and that to the best of said person’s knowledge, the Borrower has fulfilled all of its
obligations under this Agreement, the Note, and the Bond Resolution throughout such year or, if
there has been a default in the fulfillment of any such obligations, specifying each such default DRAFT
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known to said person and the nature and status thereof. The Borrower shall also deliver to NCSC
such other information as NCSC may reasonably request from time to time.
E. Financial Books; Financial Reports; Right of Inspection.
(i) Within one hundred twenty (120) days after the end of each fiscal year of the
Borrower, the Borrower shall provide to NCSC a full and complete unaudited consolidated and
consolidating report of its financial condition and of its operations as of the end of such fiscal year,
which shall present fairly in all material respects the financial condition and results of operations
of the Borrower and its Subsidiaries on a consolidated basis in accordance with GAAP, subject to
changes resulting from audit and normal year-end audit adjustments.
(ii) Within one hundred eighty (180) days after the end of each fiscal year of the
Borrower, the Borrower shall provide to NCSC a full and complete consolidated and consolidating
report of its financial condition and of its operations as of the end of such fiscal year, reported on
by independent public accountants (without a “going concern” or like qualification or exception
and without any qualification or exception as to the scope of such audit) to the effect that such
consolidated financial statements present fairly in all material respects the financial condition and
results of operations of the Borrower and its Subsidiaries on a consolidated basis in accordance
with the GAAP.
(iii) Within ninety (90) days after the end of each of the first three (3) fiscal quarters of
each fiscal year of the Borrower, the Borrower shall provide to NCSC the quarterly report for the
revenue and operating funds of the Project and a balance sheet and income statement (or
comparable financial statement) therefor.
(iv) Within one hundred eighty (180) days after the end of each the Borrower’s fiscal
years during the term hereof, the Borrower shall furnish to NCSC a statement, setting forth in
reasonable detail its calculation of its DSC Ratio for the prior year, signed either by its Executive
Director or its Chief Financial Officer, or such other officer that reports directly or indirectly to
the Chief Financial Officer.
(v) The Borrower agrees to keep proper books of records and accounts in which full,
true and correct entries, are made of all dealings and transactions in relation to its business and
activities. The Borrower agrees to permit any representatives designated by NCSC, upon
reasonable prior notice, to visit and inspect its properties, to examine and make extracts from its
books and records, and to discuss its affairs, finances and condition with its officers and
independent accountants, all at such reasonable times and as often as reasonably requested;
provided, that NCSC shall keep all such information confidential (subject to any disclosure
required by applicable law or judicial process).
F. Compliance With Laws. The Borrower shall be, and remain, in compliance with
all applicable requirements of law and applicable rules and regulations of each Governmental
Authority except for any such failures of compliance as would not reasonably be expected to have
a Material Adverse Effect on the Project.
G. Taxes. The Borrower shall pay, or cause to be paid all taxes, assessments or
governmental charges lawfully levied or imposed on or against it and/or the Project prior to the DRAFT
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time they become delinquent, except (i) for such taxes, assessments, and governmental charges
and levies which the Borrower is contesting in good faith by appropriate proceedings for which
adequate reserves have been set aside or (ii) to the extent the failure to do so would not reasonably
be expected to have a Material Adverse Effect.
H. Further Assurances. The Borrower shall execute any and all further documents,
financing statements, agreements and instruments, and take all such further actions (including the
filing and recording of financing statements, fixture filings, mortgages, deeds of trust and other
documents) which are not inconsistent with the terms and conditions set forth in the Bond
Resolution, which may be required under any applicable law, or which NCSC may reasonably
request, to effectuate the transactions contemplated by the Loan Documents or to grant, preserve,
protect or perfect the pledge created or intended to be created by the Bond Resolution. The
Borrower also agrees to provide to NCSC, from time to time upon request, evidence reasonably
satisfactory to NCSC as to the perfection and priority, or the continued perfection and priority, of
the pledge preserved, created or intended to be created by the Bond Resolution.
I. Notices.
(i) Default. Upon receipt of any notices under the Bond Resolution with respect to a
default by the Borrower under the terms of the Bond Resolution or of any credit agreement or other
agreement relating thereto, the Borrower shall deliver copies of such notice to NCSC.
(ii) Environmental. If Borrower receives any written communication from a
Governmental Authority alleging Borrower’s material violation of any Environmental Law, then
Borrower shall provide NCSC with a copy thereof within thirty (30) days after receipt, and
promptly take appropriate action to remedy, cure, defend, or otherwise affirmatively respond to
the matter in order to comply with any Environmental Law that is the subject of such written
communication.
(iii) Power Contract. Borrower shall promptly deliver to NCSC notice of any material
modification of the Power Contract.
(iv) Litigation. Promptly after the commencement thereof, notice of the
commencement of all actions, suits or proceedings before any court, arbitrator, or governmental
department, commission, board, bureau, agency or instrumentality affecting the Borrower which
would reasonably be expected to have a Material Adverse Effect.
(v) Bradley Lake Hydroelectric Facility. Borrower shall promptly deliver to NCSC
notice of any material event with respect to the Project.
J. Insurance. Borrower will maintain insurance with responsible and reputable
insurance companies or associations in such amounts and covering such risks as is usually carried
by companies engaged in similar businesses and owning similar properties similarly situated.
K. Maintenance of Existence; Licenses, Permits, etc. The Borrower will do or cause
to be done all things necessary to preserve, renew or replace and keep in full force and effect its
legal existence and rights, privileges, licenses, franchises and permits with respect to the Project. DRAFT
13
4123-9575-7373.4
Subject to law, Borrower will qualify and remain qualified as a validly existing entity in good
standing in each jurisdiction in which such qualification is necessary under applicable law.
L. Power Contract. Borrower shall enforce the provisions of the Power Contract.
Section 5.02 Negative Covenants. The Borrower covenants and agrees with NCSC that
after the date hereof and until payment in full of the Note and performance of all obligations of the
Borrower hereunder:
A. Termination of Power Contract. Borrower shall not terminate, and shall not
consent to the termination of the Power Contract.
B. Limitation on Liens. Borrower shall not create, incur, assume or permit to exist
any Lien on the Project other than as provided for under the Bond Resolution or as permitted by
the Bond Resolution.
C. Power Contract. Borrower shall not amend the Power Contract so as to reduce
the payments required thereunder or otherwise materially affect the security for the credit facility
provided by NCSC hereunder.
ARTICLE VI
EVENTS OF DEFAULT
A. Representations and Warranties. Any representation or warranty made by the
Borrower herein, or in any of the other Loan Documents, or in any certificate or financial statement
furnished to NCSC hereunder or under any of the other Loan Documents shall prove to be false or
misleading in any material respect at the time made or deemed made.
B. Payment. The Borrower shall fail to pay (whether upon stated maturity, by
acceleration, or otherwise) any principal, interest, premium (if any) or other amount payable under
the Loan Documents within five (5) Business Days after the due date thereof.
C. Bond Resolution Obligations. An “Event of Default” as defined in the Bond
Resolution, shall have occurred and be continuing, provided, however, that NCSC may not declare
an Event of Default under this Section 6.01.C if, prior to such declaration, the “Event of Default”
under the Bond Resolution has been waived or cured as provided for under the terms thereof.
D. Other NCSC Obligations. The Borrower shall be in breach or default of any
Obligation, which breach or default continues uncured beyond the expiration of any applicable
grace period.
E. Other Obligations. Borrower shall (i) fail to make any payment of any principal,
premium or any other amount due or interest on any indebtedness with parties other than NCSC
related to the Project, which shall remain unpaid beyond the expiration of any applicable grace
period, or (ii) be in breach or default with respect to any other term of any evidence of any
indebtedness with parties other than NCSC related to the Project or of any loan agreement,
mortgage or other agreement relating thereto which breach or default continues uncured beyond
the expiration of any applicable grace period, if the effect of such failure, d efault or breach is to DRAFT
14
4123-9575-7373.4
cause the holder or holders of that indebtedness to cause that indebtedness to become or be declared
due prior to its stated maturity (upon the giving or receiving of notice, lapse of time, both or
otherwise).
F. Covenants.
(i) No Grace Period. Failure of the Borrower to observe or perform any covenant or
agreement contained in Sections 5.01.B, 5.01.C, 5.01.D, 5.01.E, 5.01.I, 5.01.K, 5.01.L or 5.02 of
this Agreement.
(ii) Thirty Day Grace Period. Failure of the Borrower to observe or perform any
other covenant or agreement contained in this Agreement or any of the other Loan Documents,
which shall remain unremedied for thirty (30) calendar days after written notice thereof shall have
been given to the Borrower by NCSC.
G. Involuntary Bankruptcy. An involuntary case or other proceeding shall be
commenced against Borrower seeking liquidation, reorganization or other relief with respect to it
or its debts under bankruptcy, insolvency or other similar law now or hereafter in effect or seeking
the appointment of a trustee, receiver, liquidator, custodian or other similar official of it or any
substantial part of its property and such involuntary case or other proceeding shall continue without
dismissal or stay for a period of sixty (60) consecutive days; or an order for relief shall be entered
against Borrower under the federal bankruptcy laws or applicable state law as now or hereafter in
effect.
H. Insolvency. Borrower shall commence a voluntary case or other proceeding
seeking liquidation, reorganization or other relief with respect to itself or its debts under any
bankruptcy, insolvency or other similar law now or hereafter in effect or seeking the appointment
of a trustee, receiver, liquidator, custodian or other similar official of it or any substantial part of
its property, or shall consent to any such relief or to the appointment of or taking possession by
any such official in an involuntary case or proceeding commenced against it, or shall make a
general assignment for the benefit of creditors, or shall admit in writing its inability to, or be
generally unable to, pay its debts as they become due, or shall take any action to authorize any of
the foregoing.
I. Dissolution, Liquidation, Reorganization. The dissolution, liquidation or other
termination of the existence of the Borrower or the reorganization of the Borrower, provided,
however, that any such event shall not be construed to include (i) the cessation of the existence of
the Borrower resulting either from a merger, consolidation or other reorganization of the Borrower
into or with another entity that includes a transfer of all or substantially all Project assets and the
Borrower’s rights in the Project to such successor or resulting entity, or (ii) a reorganization of the
Borrower into one or more entities that includes a transfer of all or substantially all Project assets
and the Borrower’s rights in the Project to one of such successor or resulting entities, so long as,
in either case that entity assumes the due and punctual payment of the Note and the due and
punctual performance of the covenants contained in this Agreement. DRAFT
15
4123-9575-7373.4
J. Validity of Documents. Any material provision of this Agreement or any other
Loan Document shall at any time cease to be valid and binding on Borrower, or shall be declared
to be null and void, or the validity or enforceability thereof shall be contested by Borrower.
K. Monetary Judgment. The Borrower shall suffer any money judgment with respect
to the Project, not covered by insurance, writ or warrant of attachment or similar process involving
an amount in excess of $5,000,000.00 and the same shall not be discharged, vacated, bonded or
stayed within a period of sixty (60) days. For the avoidance of doubt, a stay shall be deemed to
exist when an attachment or execution may not issue with respect to the Project under
AS 09.50.270.
L. Nonmonetary Judgment. One or more nonmonetary judgments or orders
(including, without limitation, injunctions, writs or warrants of attachment, garnishment,
execution, distraint, replevin or similar process) shall be rendered against the Borrower that, either
individually or in the aggregate, could reasonably be expected to have a Material Adverse Effect.
ARTICLE VII
REMEDIES
Section 7.01 General Remedies. If any of the Events of Default listed in Article VI
hereof shall occur after the date of this Agreement and shall not have been remedied within the
applicable grace periods specified therein (if any), then NCSC may, subject to the terms of the
Bond Resolution, as applicable:
(i) exercise rights of setoff or recoupment and apply any and all amounts held, or
hereafter by held, by NCSC or owed to the Borrower or for the credit or account of the Borrower
against any and all of the Obligations of the Borrower now or hereafter existing hereunder or under
the Note. The rights of NCSC under this Section 7.01 are in addition to any other rights and
remedies (including other rights of setoff or recoupment) which NCSC may have. The Borrower
waives all rights of setoff, deduction, recoupment or counterclaim;
(ii) cause the trustee under the terms of the Bond Resolution to pursue all rights and
remedies available to NCSC that are contemplated by the Bond Resolution in the manner, upon
the conditions, and with the effect provided in the Bond Resolution, including, but not limited to,
a suit for specific performance, injunctive relief or damages; and
(iii) pursue any other rights and remedies available to NCSC at law or in equity.
Section 7.02 Concurrent Remedies. Nothing herein shall limit the right of NCSC to
pursue all rights and remedies available to a creditor following the occurrence of an Event of
Default. Each right, power and remedy of NCSC shall be cumulative and concurrent, and recourse
to one or more rights or remedies shall not constitute a waiver of any other right, power or remedy.
ARTICLE VIII
MISCELLANEOUS
Section 8.01 Notices. All notices, requests and other communications provided for
herein including, without limitation, any modifications of, or waivers, requests or consents under, DRAFT
16
4123-9575-7373.4
this Agreement shall be given or made in writing (including, without limitation, by facsimile) and
delivered to the intended recipient at the “Address for Notices” specified below; or, as to any party,
at such other address as shall be designated by such party in a notice to each other party. All such
communications shall be deemed to have been duly given (i) when personally delivered including,
without limitation, by overnight mail or courier service, (ii) in the case of notice by United States
mail, certified or registered, postage prepaid, return receipt requested, upon receipt thereof, or
(iii) in the case of notice by facsimile, upon transmission thereof, provided such transmission is
promptly confirmed by either of the methods set forth in clauses (i) or (ii) above in each case given
or addressed as provided for herein. The Address for Notices of each of the respective parties is
as follows:
National Rural Utilities Cooperative Finance Corporation
20701 Cooperative Way
Dulles, Virginia 20166
Attention: General Counsel
Fax # 866-230-5635
The Borrower:
The address set forth in
Schedule 1 hereto
Section 8.02 Expenses. To the extent permitted by law, the Borrower shall reimburse
NCSC for any reasonable costs and out-of-pocket expenses paid or incurred by NCSC (including,
without limitation, reasonable fees and expenses of outside attorneys, paralegals and consultants)
for all actions NCSC takes, or reimburses the Trustee for taking on its behalf, (a) to enforce the
payment of any Obligation hereunder or under the Note, to effect collection of any of the property
pledged under the Bond Resolution, or in preparation for such enforcement or collection, (b) to
institute, maintain, preserve, enforce and the pledge under the Bond Resolution, whether through
judicial proceedings or otherwise, (c) to restructure any of the Obligations hereunder or under the
Note, (d) to review, approve or grant any consents or waivers hereunder, (e) to prepare, negotiate,
execute, deliver, review, amend or modify this Agreement, and (f) to prepare, negotiate, execute,
deliver, review, amend or modify any other agreements, documents and instruments deemed
necessary or appropriate by NCSC in connection with any of the foregoing.
The amount of all such expenses identified in this Section 8.02 shall be payable upon
demand, and if not paid, shall accrue interest at the then prevailing Variable Rate plus 200 basis
points.
Section 8.03 Late Payments. If payment of any amount due hereunder is not received
at NCSC’s office in Dulles, Virginia, or such other location as NCSC may designate to the
Borrower within five (5) Business Days after the due date thereof, the Borrower will pay to NCSC,
in addition to all other amounts due under the terms of the Loan Documents, any late -payment
charge as may be fixed by NCSC from time to time pursuant to its policies of general application
as in effect from time to time. DRAFT
17
4123-9575-7373.4
Section 8.04 Non-Business Day Payments. If any payment to be made by the Borrower
hereunder shall become due on a day which is not a Business Day, such payment shall be made on
the next succeeding Business Day and such extension of time shall be included in comp uting any
interest in respect of such payment.
Section 8.05 Filing Fees. To the extent permitted by law, the Borrower agrees to pay all
expenses of NCSC (including the reasonable fees and expenses of its counsel) in connection with
the filing, registration, recordation or perfection of the Bond Resolution, including, without
limitation, all documentary stamps, recordation and transfer taxes and other costs and taxes
incident to execution, filing, registration or recordation of any document or instrument in
connection herewith. The Borrower, payable solely as an Annual Project Cost under Section 8 of
the Power Contract, agrees to save harmless and indemnify, to the extent permitted by law, NCSC
from and against any liability resulting from the failure to pay any required documentary stamps,
recordation and transfer taxes, recording costs, or any other expenses incurred by NCSC in
connection with this Agreement. The provisions of this Section shall survive the execution and
delivery of this Agreement and the payment of all other amounts due under the Loan Documents.
Section 8.06 Waiver; Modification. No failure on the part of NCSC to exercise, and no
delay in exercising, any right or power hereunder or under the other Loan Documents shall operate
as a waiver thereof, nor shall any single or partial exercise by NCSC of any right hereunder, or
any abandonment or discontinuance of steps to enforce such right or power, preclude any other or
further exercise thereof or the exercise of any other right or power. No modification or waiver of
any provision of this Agreement, the Note or the other Loan Documents (except as otherwise
provided in the Bond Resolution) and no consent to any departure by the Borrower therefrom shall
in any event be effective unless the same shall be in writing by the party granting such
modification, waiver or consent, and then such modification, waiver or consent shall be effective
only in the specific instance and for the purpose for which given.
Section 8.07 GOVERNING LAW; SUBMISSION TO JURISDICTION; WAIVER
OF JURY TRIAL.
(A) THE PERFORMANCE AND CONSTRUCTION OF THIS AGREEMENT
SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH, THE LAWS OF
THE COMMONWEALTH OF VIRGINIA.
(B) THE BORROWER AND NCSC HEREBY SUBMIT TO THE EXCLUSIVE
JURISDICTION OF THE ALASKA SUPERIOR COURT LOCATED IN ANCHORAGE,
ALASKA FOR PURPOSES OF ALL LEGAL PROCEEDINGS ARISING OUT OF OR
RELATING TO THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED
HEREBY. THE BORROWER AND NCSC IRREVOCABLY WAIVE, TO THE FULLEST
EXTENT PERMITTED BY APPLICABLE LAW, ANY OBJECTIONS THAT EITHER OF
THEM MAY NOW OR HEREAFTER HAVE TO THE ESTABLISHING OF THE VENUE OF
ANY SUCH PROCEEDINGS BROUGHT IN SUCH COURT AND ANY CLAIM THAT SUCH
PROCEEDING HAS BEEN BROUGHT IN AN INCONVENIENT FORUM.
(C) THE BORROWER AND NCSC EACH HEREBY IRREVOCABLY WAIVES,
TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, ANY AND ALL RIGHT DRAFT
18
4123-9575-7373.4
TO TRIAL BY JURY IN ANY LEGAL PROCEEDING ARISING OUT OF OR RELATING TO
THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED HEREBY. THE
BORROWER AND NCSC AGREE THAT SUCH WAIVER SHALL NOT BE BINDING ON
THE TRUSTEE UNDER THE BOND RESOLUTION WITH RESPECT TO ANY ACTION
TAKEN BY THE TRUSTEE THEREUNDER.
Section 8.08 INDEMNIFICATION. THE BORROWER, PAYABLE SOLELY AS
AN ANNUAL PROJECT COST UNDER SECTION 8 OF THE POWER CONTRACT,
HEREBY INDEMNIFIES AND AGREES TO HOLD HARMLESS, AND DEFEND NCSC AND
ITS MEMBERS, DIRECTORS, OFFICERS, EMPLOYEES, AGENTS, ATTORNEYS AND
REPRESENTATIVES (EACH AN “INDEMNITEE”) FOR, FROM, AND AGAINST ALL
CLAIMS, DAMAGES, LOSSES, LIABILITIES, COSTS, AND EXPENSES (INCLUDING,
WITHOUT LIMITATION, COSTS AND EXPENSES OF LITIGATION AND REASONABLE
ATTORNEYS’ FEES) ARISING FROM ANY CLAIM OR DEMAND IN RESPECT OF THIS
AGREEMENT AND THE OTHER LOAN DOCUMENTS, THE PROPERTY PLEDGED
UNDER THE BOND RESOLUTION, OR THE TRANSACTIONS DESCRIBED IN THIS
AGREEMENT AND THE OTHER LOAN DOCUMENTS AND ARISING AT ANY TIME,
WHETHER BEFORE OR AFTER PAYMENT AND PERFORMANCE OF ALL
OBLIGATIONS UNDER THIS AGREEMENT AND THE OTHER LOAN DOCUMENTS IN
FULL, EXCEPTING ANY SUCH MATTERS ARISING SOLELY FROM, AND TO THE
EXTENT OF, THE GROSS NEGLIGENCE OR WILLFUL MISCONDUCT OF NCSC OR ANY
INDEMNITEE. NOTWITHSTANDING ANYTHING TO THE CONTRARY CONTAINED IN
SECTION 8.10 HEREOF, THE OBLIGATIONS IMPOSED UPON THE BORROWER BY
THIS SECTION SHALL SURVIVE THE REPAYMENT OF THE NOTE, THE TERMINATION
OF THIS AGREEMENT AND THE TERMINATION OR RELEASE OF THE LIEN OF THE
BOND RESOLUTION.
Section 8.09 Complete Agreement. This Agreement, together with the schedules to this
Agreement, the Note and the other Loan Documents, and the other agreements and matters referred
to herein or by their terms referring hereto, is intended by the parties as a final expression of their
agreement and is intended as a complete statement of the terms and conditions of their agreement.
In the event of any conflict in the terms and provisions of this Agreement and any other Loan
Documents (other than the Bond Resolution), the terms and provisions of this Agreement shall
control.
Section 8.10 Survival; Successors and Assigns. All covenants, agreements,
representations and warranties of the Borrower which are contained in this Agreement shall
survive the execution and delivery to NCSC of the Loan Documents and the making of the
Advance and shall continue in full force and effect until all of the obligations under the Loan
Documents have been paid in full. All covenants, agreements, representations and warranties of
the Borrower which are contained in this Agreement shall inure to the benefit of the successors
and assigns of NCSC. Unless otherwise required by law, the Borrower shall not assign its rights
or obligations under this Agreement without the prior written consent of NCSC.
Section 8.11 Use of Terms. The use of the singular herein shall also refer to the plural,
and vice versa. DRAFT
19
4123-9575-7373.4
Section 8.12 Headings. The headings and sub-headings contained in this Agreement are
intended to be used for convenience only and do not constitute part of this Agreement.
Section 8.13 Severability. If any term, provision or condition, or any part thereof, of
this Agreement, the Note or the other Loan Documents shall for any reason be found or held invalid
or unenforceable by any court of competent jurisdiction or other Governmental Authority, such
invalidity or unenforceability shall not affect the remainder of such term, provision or condition
nor any other term, provision or condition, and this Agreement, the Note and the other Loan
Documents shall survive and be construed as if such invalid or unenforceable term, provision or
condition had not been contained therein.
Section 8.14 Binding Effect. This Agreement shall become effective when it shall have
been executed by both the Borrower and NCSC and thereafter shall be binding upon and inure to
the benefit of the Borrower and NCSC and their respective successors and assigns as provided in
Section 8.10.
Section 8.15 Counterparts. This Agreement may be executed in one or more
counterparts, each of which will be deemed an original and all of which together will constitute
one and the same document. Signature pages may be detached from the counterparts and attached
to a single copy of this Agreement to physically form one document.
Section 8.16 Schedules. Schedules 1 and 2 are an integral part of this Agreement.
[REMAINDER OF PAGE INTENTIONALLY LEFT BLANK]
DRAFT
[Signature page to [____]]
4123-9575-7373.4
IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly
executed as of the day and year first above written.
ALASKA ENERGY AUTHORITY
By:
Title:
Attest:
Title:
NATIONAL COOPERATIVE SERVICES
CORPORATION
(SEAL)
By:
Assistant Secretary-Treasurer
Attest:
Assistant Secretary-Treasurer
DRAFT
21
4123-9575-7373.4
SCHEDULE 1
1. The purpose of the Advance is to finance capital costs of the Transmission Project, make
a deposit to the Capital Reserve Fund and pay Note issuance costs.
2. The aggregate NCSC Commitment is $[____].
3. The Closing Date referred to in Section 1.01 is December [__], 2022, or on such other
Business Day thereafter as may be agreed to by the Borrower and NCSC, so long as all the
conditions set forth in Section 4.01 have been fulfilled.
4. The Bond Resolution referred to in Section 1.01 is Resolution No. 1989-12 of the
Borrower, adopted by the Board of Directors of the Borrower on September 7, 1989, as it
may have been or shall be in the future be supplemented, amended, consolidated, or
restated from time to time, including by the Bond Resolution Supplement.
5. The Bond Resolution Supplement referred to in Section 1.01 is that certain Supplemental
Resolution No. 2022-[__], adopted by the Board of Directors of the Borrower on
October 26, 2022, as it may have been or shall be in the future be supplemented, amended,
consolidated, or restated from time to time.
6. The Note executed pursuant hereto is as follows:
LOAN
NUMBER AMOUNT
[____] $[___]
7. The date of the balance sheet and statement of operations referred to in Section 2.01.G is
June 30, 2022.
8. The address for notices to the Borrower referred to in Section 8.01 is:
If by personal delivery (including overnight mail or courier service) or United States Mail:
Alaska Energy Authority
813 West Northern Lights Blvd.
Anchorage, Alaska 99503
If by facsimile:
Fax: 907-771-3044
DRAFT
22
4123-9575-7373.4
SCHEDULE 2
Principal
Installment
Payment Dates
(July 1)
Principal
Installment
Amounts
Principal
Installment
Payment Dates
(July 1)
Principal
Installment
Amounts
$[___]
DRAFT
INSERT FINAL EXECUTED RESOLUTION 22-07
Corporate Office Central Peninsula Service Center
3977 Lake Street 280 Airport Way
Homer, Alaska 99603-7680 Kenai, Alaska 99611-5280
Phone (907) 235-8551 Phone (907) 283-5831
FAX (907) 235-3313 FAX (907) 283-7122
RESOLUTION 45.2022.23
APPROVAL OF THE FINANCING TRANSACTION FOR REQUIRED PROJECT WORK
WHEREAS, Homer Electric Association, Inc. is a Purchaser of the power generated by the Project;
WHEREAS, Homer Electric Association, Inc. is a Member of the BPMC which manages the
Project;
WHEREAS, On May 20, 2022 the BPMC adopted Resolution No. 2022-04 accepting the
recommendations from its Special Committee that the Project List it prepared was comprised of
Required Project Work. The Project List approved by the BPMC is attached to this Resolution,
and incorporated as if fully set forth herein:
WHEREAS, the BPMC resolved that the Project List contains projects that are essential for the
removal of the transmission constraints on the deliverability of energy generated by the Project
and can be financed using the Excess Payment funds for the Required Project Work;
WHEREAS, each of the projects listed in the Project List have been reviewed by the Department
of Law at the request of AEA and the Purchasers, and the Department of Law has determined that
the Project List constitutes Required Project Work consistent with the PSA;
WHEREAS, the BPMC supports the Project List and Proposed Transaction subject to the
following: (1) final approval of an independent economic and engineering analysis; and (2) that
the final Proposed Transaction does not exceed the amount of the Excess Payments;
WHEREAS, Homer Electric Association, Inc. has reviewed and considered the Project List, and
the Resolution No 2202-04 approved by the BPMC;
WHEREAS, the BPMC is responsible for selection among alternative methods that involve AEA
for funding Required Project Work;
WHEREAS, the BPMC has authorized entering into the Proposed Transaction subject to the total
amount of the financing not exceeding the Excess Payment amount as defined in the PSA;
RESOLUTION 45.2022.23, APPROVAL OF THE FINANCING TRANSACTION FOR REQUIRED PROJECT WORK
Page 2 of 2
WHEREAS, the Members of the BPMC would like an indication from their respective governing
boards whether the Proposed Project List and the Proposed Transaction are acceptable to the
individual utilities comprising the BPMC.
NOW, THEREFORE, BE IT RESOLVED THAT the governing board of Homer Electric
Association, Inc. has carefully reviewed and considered the cost and benefits of the Project List
and Proposed Transaction; and
BE IT FURTHER RESOLVED THAT Homer Electric Association, Inc. supports the Proposed
Transaction; and
BE IT FURTHER RESOLVED THAT Homer Electric Association, Inc. approves entering into
the financing for the Proposed Transaction to be approved by the BPMC and AEA so long as (1)
final approval of by independent economic and engineering analysis has been completed; (2) the
BPMC approves the Proposed Transaction and the Required Project Work; and (3) that the final
Proposed Transaction does not exceed the amount of the Excess Payments; and
BE IT FURTHER RESOLVED THAT the Management of Homer Electric Association, Inc. be
authorized to do all things necessary to effectuate the intent of this Resolution and support the
Proposed Transaction.
CERTIFICATION
I, Jim Duffield, do hereby certify that I am the Secretary of Homer Electric Association,
Inc., and that the foregoing resolution was adopted at a regular meeting of the Board of Directors,
held on August 9, 2022, at which meeting a quorum was present.
_________________________________
Jim Duffield, Secretary/Treasurer
7/13/2022
Project
Cost BPMC Special Committee Projects
($ million)
(estimate)
BPMC First Tranche "Required Project Work" 2022-2029
66.0$ New 230 kV (operated at 115 kV) Express Transmission Line - Bradley Project to Soldotna Sub
70.0$
115.0$ Battery Energy Storage Systems for Grid Stabilization
8.5$ SVC Upgrades (Soldotna and Dave's Creek)
10.0$ Routing study of Alternative Path to Export Energy off the Kenai Peninsula
269.5$ (note: assumes that CEA completes 230 kV upgrades from Quartz Sub to University Sub)
115 kV & 230 kV Double-circuit Transmission Line - Soldotna Substation to Sterling Substation and
230 kV Upgrade for Transmission Line between Sterling Substation and Quartz Creek Substation6
(includes substations upgrades for 230 kV operation)
1850 Parkway Place Suite 800 Marietta, GA 30067 770-425-8100 Fax 866-611-3791 www.gdsassociates.com
Georgia Texas Alabama New Hampshire Wisconsin Florida Maine Washington California
Kevin J. Mara, P.E., Executive Vice President
kevn.mara@gdsassociates.com
main 770-425-8100
fax 866-611-3791
September 7, 2022
Mr. Bryan Carey
Director of Owned Assets
Alaska Energy Authority
813 West Northern Lights Blvd.
Anchorage, Alaska 99503
Subject: Opinion of Battery Energy Storage System (“BESS”) Acquisitions
Mr. Carey:
Presented herewith is a summary of our analyses, and opinion with respect to the acquisition of the
Battery Energy Storage System (“BESS”) on the Railbelt system.
The Project Description
GDS Associates (“GDS”) has been retained by Alaska Energy Authority (“AEA”) to provide an independent
opinion (“Opinion”) of the proposed betterment of the Bradley Lake Project.
The proposed betterment is for AEA to acquire, upgrade, or build the following assets:
1. Homer Electric Association’s (“HEA”) existing BESS operating in Soldotna,
2. Golden Valley Electric’s (“GVEA”) existing BESS along with upgrade and/or replacements at
this site, and
3. A proposed Anchorage area BESS.
The proposed BESS Acquisition is $115 million. The HEA BESS is valued at $45 million, the Anchorage BESS
is estimated to cost $60 million and the replacement or upgrade to the GVEA existing BESS, is estimated
to cost $10 million.
This Opinion is GDS’s professional opinion on BESS Acquisitions in terms of solving oscillation incidents
and instability on the Railbelt System. This report addresses if the proposed acquisition is of sound
economics and national standards for prudent utility practice.
2022 Financing
The financing of these improvements (the 2022 Bonds) will be issued pursuant to AEA’s Power Revenue
Bond Resolution, adopted September 7, 1989, as amended and supplemented and the Alaska Energy Act
(AS 44.83) (collectively Power Revenue Bond Resolution). Terms used herein but not defined shall have
the meaning set forth in the Power Revenue Bond Resolution.
The proceeds of the 2022 Bonds financing may be issued in either bond form or as a loan and may be
either taxable or tax-exempt. The 2022 financing proceeds, deemed as Additional Bonds under the Power
Revenue Bond Resolution will be used to pay (i) acquisition of existing BESS system from HEA and GVEC,
upgrades to the GVEA BESS system, and construction of a new BESS in the Anchorage area; and (ii) cost
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of issuance of the 2022 Bonds. The 2022 Bonds will consist of a not to exceed principal amount of
$115,000,000.
The 2022 Bonds, and bonds issued on a parity basis under the terms of the Power Revenue Bond
Resolution, are direct and general obligations of the AEA secured by full faith and credit of AEA, which are
secured as to payment of the principal of, and interest on, in accordance with the terms and provisions of
the Resolution, by a pledge of Revenues and moneys, securities and funds held or set aside to be held by
the AEA under the Power Revenue Bond Resolution.
This Opinion summarizes our work to date hereof. We make no representations for changed conditions
occurring or becoming known after such date which could affect the material presented herein to the
extent of such changes.
Power Sales Agreement
AEA is a public corporation and an agency of the state of Alaska. AEA is the State’s energy office. In
December of 1987, AEA, at that time the Alaska Power Authority, entered into an agreement for the sale
and purchase of electric power (Agreement). The Agreement details a disposition of energy from the
Bradley Lake Hydroelectric Project (Project), in which AEA sells the output to multiple municipals and
cooperatives (Purchasers) through Alaska’s Railbelt Region. The Project is a 120-megawatt hydroelectric
project which provides 10 percent of the Railbelt area’s energy needs. The Agreement has a 50-year term
and each Purchaser has a share in the energy generated by the facility. For the Purchasers to the north of
the Project, such energy shares are transferred from the Project to the Purchasers via a 115 kV
transmission line between Sterling and Cooper Landing on the Kenai Peninsula of Alaska (SSQ Line). In
December 2020 AEA purchased the following from HEA: capacity rights of the SS Line (Soldotna to Sterling
Substation); ability to direct HEA to repair/upgrade the SS Line; HEA’s property rights to the SSQ line; and
all of HEA’s property rights to the 69 kV line between Soldotna and Quartz Creek Substation. The Sterling
to Quartz Creek Transmission Upgrade is the next step in upgrading the transmission capacity and
reliability of the delivery from the Bradley Lake Project
The Agreement, among other things, established the Bradley Lake Project Management Committee
(BPMC). The purpose of the BPMC is to facilitate the operation and maintenance at the project as well as
power scheduling, power production and power dispatch. The members of the BPMC include the AEA and
the six utilities that purchase power under the Agreement, consisting of:
• Chugach Electric Association (CEA)
• Municipal Light & Power (ML&P) (now part of CEA)
• HEA 1
• Matanuska Electric Association (MEA)
• Golden Valley Electric Association (GVEA)
• City of Seward
AEA issued bonds in support of the Bradley Lake Project from 1989 through 2020 which mature annually
each July 1 through the year 2021 with interest rates ranging from 3.5 percent to 6.25 percent.
1 Homer Electric Association, Inc. and its single-member cooperative Alaska Electric and Energy Cooperative.
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Under the Agreement, if a participating utility fails to make payments, the AEA may, after consultation
with the other participating utilities, terminate or suspend delivery of power to the non-paying
participant. If power deliveries are suspended or terminated to the non-paying participant, the AEA has
the right to proportionally increase the percentage shares of the remaining participants with the caveat
that no participant’s share can be increased by more than 25 percent. The remaining participants’
allocation of project costs and power generation will be based on the updated percentage shares.
Agreement Project Work Definitions
The Agreement contemplates that work will be needed during the 50-year term to keep the Project in
efficient operating condition. The Agreement addresses ongoing work for the Project by breaking the
work into two categories; (i) Required Project Work 2; and (ii) Optional Project Work.3
Required Project Work is defined as “repairs, maintenance, renewables, replacements, improvements or
betterments required by federal or state law, a licensing or agency with jurisdiction over the Project, or
this Agreement, or otherwise necessary to keep the Project in good and efficient operating condition,
consistent with (1) sound economics for the Project and the Purchasers, and (2) national standards for the
industry.”
Optional Project Work is defined as “Project repairs, renewals and replacements, improvements,
betterments, additions, or expansions that do not constitute Required Project Work.”
GDS’s opinion is that the BESS Acquisition is Required Project Work. Specifically, Required Project Work
includes work that is “…otherwise necessary to keep the Project in efficient operating condition…”. This
work should be “…consistent with sound economics for the Project and the Purchasers...” and “…national
standards for the industry.” GDS addresses these two tests for Project necessity separately as (1)
Economics; and (2) Industry Standard.
2 Section 1 (hh), Agreement for the Sale and Purchase of Electric Power dated December 8, 1987
3 Section 1 (t), Agreement for the Sale and Purchase of Electric Power dated December 8, 1987
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Economics
The sound economics test for BESS Acquisition, extends to both the Project and the Purchasers. It is GDS’s
opinion that the BESS Acquisition meets the economics test for Required Project Work as further detailed
in this Opinion.
GDS reviewed the financials of AEA as well as for each of the Purchasers. The borrowed amount of $115
million is assumed over a 30 year term at a rate of 5%. Principal and Interest payments for the 2022 Bonds
are $7.5 million annually. Bradley Lake Power Revenue Refunding Bonds mature by June 2022 reducing
the overall debt service obligation by over $10 million in 2023. Existing debt payments in Table 2 also
include the $10 million prepayment for the Series 10 bonds paid on June 29, 2022. The $53 million in
additional 2022 Bonds for the SSQ Line Upgrade (Sterling to Quartz Creek Upgrade) and $85.4 million for
the BLS (Bradley Lake to Soldotna) and SS (Soldotna to Sterling) Transmission Upgrades are also
considered in the analysis of financial feasibility.
Annual net margins for AEA were reviewed from 2015 through 2021 based on audited financial
statements including all outstanding long-term debt. AEA’s average net margin over this period is $22
million. Earnings before interest, tax, and amortization averaged $29 million over this period which more
than covers the average annual debt service obligation over the next 30 years.
Finally, Purchasing utilities will raise rates, reduce costs, or use other means available to pay their share
of the annual debt service associated with the 2022 Bonds.
Industry Standard
The Required Project Work definition includes any improvements or betterments required by federal or
state law plus an additional efficiency test that improvements are within industry standard. In the
contiguous United States, authority over generation and transmission siting and reliability resides with
Federal Energy Regulatory Commission (FERC).4 Section 215 of the Federal Power Act, however, carves
out Alaska and Hawaii. In 2017, AEA signed a memo of understanding (MOI) with certain Railbelt Utilities.
The MOI commenced the process to create reliability standards that are similar to those required by FERC
and are considered industry standard in the lower 48 states. These standards address transmission
reliability, generation ownership, operation and system vulnerabilities. Specifically relating to the
acquisition of BESS, is the requirement for sufficient controls or actions to return the frequency to
acceptable levels within 10 minutes after an excess contingency disturbance.5
It is GDS’ opinion the industry standard for generation and transmission reliability requires betterments
and upgrades to the system which are achieved with the BESS Acquisition. The betterments and upgrades
are consistent with Prudent Utility Practice (as that term is defined by the Bond Resolution) and therefore
should be considered Required Project Work as set forth in the Agreement.
4 https://www.ferc.gov/enforcement/enforce-res/EPAct2005.pdf
5 Alaska Railbelt Standard AKBAL-001-2 – Real Power Balancing Control Performance, paragraph R4.
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Stability of the Railbelt System
The goal of the acquisition of BESS systems is to improve the stability of the Railbelt system and to meet
the requirements of Alaska Railbelt Standard AKBAL-001-2. The Railbelt system is a very weak electrical
system, characterized by the load centers on the Kenai, in the Anchorage/Mat-Su area and in Fairbanks,
connected by long, single transmission lines. The system topography, unlike the mesh type grid in the
Lower 48 is prone to large oscillations and high frequency operation when one of the single
interconnecting lines are lost.
On June 2, 2021, an Alaska intertie trip event resulted in a 220 MW peak to peak oscillation along the
Kenai Tie. Oscillations of this magnitude are a security risk to the reliability of the Railbelt as well as
potentially causing catastrophic damage to plant-wide sets of turbines and generators within the entire
Railbelt.6
These oscillations negatively impact generation units including Bradley Lake units. In fact, the Bradley
Lake Project may cause and/or otherwise exacerbate the conditions for instability of the Railbelt.7 Thus
Bradley Lake Project can be seen as being responsible for correcting the instability issue on the Railbelt
System.8
To full utilize the capacity of Bradley Lake to all participants in the Power Sales Agreement, it is necessary
to develop controls to limit large oscillations and high frequency excursions.
Bradley Lake Project was designed with dividers which were to control large deviations in system
frequency. When the frequency is high, the dividers run into the stream full stroke, attempting to bring
frequency down to the plant’s control point. During a frequency oscillation, as the frequency returns back
toward nominal, the dividers quickly withdraw from the water stream only to re-enter the water stream
again on the next increasing frequency portion of the oscillation. On a larger, stronger transmission grid,
the dividers would normally help to dampen and control the oscillations.
A 2004 report by Virginia Tech studied the Bradley Lake Turbine itself and focused on the inherent design
deficiencies of the original Bradley Lake deflectors, the turbine pit design and the corresponding
interaction and oscillations that result from these two issues. This report did not investigate the tie
between electrical oscillations at Bradley Lake and the impact or contribution of a weak electrical system
on those oscillations.
A report by Electric Power Systems, Inc (“EPS”) provided analysis and modeling of an actual measured
large oscillation event on June 3, 2021. The conclusion of the EPS report is that
“The interaction between the Bradley Lake turbine pit design and the divider characteristics in
combination with the weak transmission system and characteristics of the Railbelt are the cause
of the extremely large power oscillations. The two reports by VA Tech and EPS respectively
focused on the mechanical and electrical results of the mismatch between the plant design and
6 Railbelt Oscillation Investigation and Mitigation Study by Electric Power Systems, Inc., March 1, 2022
7 Railbelt Oscillation Investigation and Mitigation Study by Electric Power Systems, Inc., March 1, 2022, page 1
8 Railbelt Oscillation Investigation and Mitigation Study by Electric Power Systems, Inc., March 1, 2022, page 1
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the power system it is used on, essentially providing two different methodologies to arrive at the
same conclusion, the characteristics of the Bradley Lake Plant combined with the weak Railbelt
transmission system results in the observed oscillations and operational problems.”9
Betterment of the System
BESS systems can be utilized during over-frequency conditions. The BESS help absorb energy of the
oscillations by means of charging the BESS. This requires tuning the control of the BESS to achieve this
result. There are three (3) BESS systems one in the Kenai, one in the Anchorage area, and one in
Fairbanks area. Each BESS is required for certain contingencies to meet the industry standards for
stability.10
The EPS Report states that control of over-frequency events on the Kenai could be accomplished with
the proposed Anchorage area BESS for loss of the Anchorage-Fairbanks intertie and some contingencies
may require the combined capability of both the Kenai BESS and Anchorage BESS. For system reliability
and performance, these BESS locations should be used to ensure adequate capability to prevent the
severe oscillations.11
In addition, if there is a loss of a large 100 MW load in Fairbanks, the Fairbanks BESS currently located at
the Wilson Substation combined with the other proposed BESS in Anchorage and Kenai can provide
stability to the Railbelt. Without the BESS systems, an over-frequency event will occur and the Bradley
Lake plant can lose synchronism.12
Thus, loss of intertie or significant loads along the Railbelt can be stabilized by the proposed BESS
systems. However, the logic for operation of the BESS systems will need to be revised such that each
resource contributes during over-frequency conditions.
Other Project Considerations
AEA’s ongoing powers are strictly limited to the Energy Program for Alaska which includes the Bradley
Lake Project and the Alaska Intertie.13 The use of the BESS system is linked to the Bradley Lake Project,
in that, the oscillations on the Railbelt are cause by or exacerbated by Bradley Lake. The use of the BESS
to maintain stability of the grid will be beneficial to ratepayers and the public in general.
Use of the BESS for other purposes such as backup for outages will need to meet the legislative
limitations and these uses are not considered in GDS’s Opinion for Acquisition BESS systems.
9 Railbelt Oscillation Investigation and Mitigation Study by Electric Power Systems, Inc., March 1, 2022, Addendum
dated February 2021
10 Alaska Railbelt Standard AKBAL-001-2 – Real Power Balancing Control Performance, paragraph R4.
11 Railbelt Oscillation Investigation and Mitigation Study by Electric Power Systems, Inc., March 1, 2022
12 Addendum to Railbelt Oscillation Investigation and Mitigation Study, by EPS, dated March 28, 2022
13 Chap. 18 SLA 1993. Specifically, the words “construct, acquire, construction, acquisition” were deleted, and new
power projects were made subject to legislative approval.
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Summary and Conclusion
Based on our analyses, we are of the opinion that:
1. The BESS Acquisitions represent prudent utility practice and are within the definition of Required
Project Work. The BESS Acquisitions are necessary to maintain stability of the Railbelt from single
contingency outages in the Kenai all the way to Fairbanks. This project is effective compared to
other solutions which may require shut down of the hydro-electric facilities.
2. Neither the issuance of the 2022 Bonds, nor any payments associated with the BESS Acquisitions
will impair the ability of the AEA to pay debt service on the outstanding bonds and the 2022 Bonds
through the collection of revenues under the PSA and the auxiliary services contemplated under
the Definitive Agreements.14
3. The BESS Acquisitions are expected to provide Railbelt stability and limit over-frequency events
from the Bradley Lake Hydroelectric Project. Thus meeting the industry standards for stability
and frequency controls.
Respectfully submitted,
Kevin J. Mara
Executive Vice President
14 Such agreements are conditions precedent to the Proposed Transaction (Page 19 of the Resolution).
Exhi bit
Table 1
AEA Audited Financial Statements
Fiscal Year 2015 2016 2017 2018 2019 2020 2021
Revenues
Charges for Services $17,289 $18,974 $19,179 $21,848 $21,426 $21,889 $23,209
Grants and Contributions 104,208 32,467 31,244 19,642 24,745 14,082 17,292
Investment Income 35,095 11,048 114,443 79,344 78,008 51,411 151,983
Total Revenue $156,592 $62,489 $164,866 $120,834 $124,179 $87,382 $192,484
Expenses
Grants and Projects $111,719 $69,116 $62,629 $56,692 $48,582 $47,969 $45,927
General and Administrative 6,113 6,590 4,704 4,454 5,672 5,742 20,605
Interest Expense 3,668 3,177 2,652 2,371 1,746 827 1,159
Plant Operations 3,985 4,709 4,330 5,772 5,350 5,376 7,797
Depreciation 10,487 10,529 10,808 15,594 10,862 10,917 12,356
Provision for Loan Loss 6 -2 154 -51 169 61 -33
Total Expenses $135,978 $94,119 $85,277 $84,832 $72,381 $70,892 $87,811
State Re-appropriation of
Funds
$0 $0 ($13,556) ($10,067) ($1,097,695) ($21,222) $1,017,213
Net Margin $20,614 ($31,630) $66,033 $25,935 ($1,045,897) ($4,732) $1,121,886
EBITA $28,273 ($23,746) $73,169 $34,027 ($1,038,632) $1,532 $1,130,809
Exhi bit
Table 2
Debt Service Schedule ($1,000s)
Existing Long-Term Debt1 SSQ, BLS, & SS Line 2022 Bonds2 BESS 2022 Bonds3 Total
Debt
Service
Principal Interest Total Principal Interest Total Principal Interest Total
2022 $23,184 $2,632 $25,816 $25,816
2023 $1,603 $1,869 $3,472 $2,083 $6,920 $9,003 $1,731 $5,750 $7,481 $19,956
2024 $1,612 $1,803 $3,415 $2,187 $6,816 $9,003 $1,817 $5,663 $7,481 $19,899
2025 $1,620 $1,736 $3,356 $2,297 $6,706 $9,003 $1,908 $5,573 $7,481 $19,840
2026 $1,629 $1,670 $3,299 $2,411 $6,592 $9,003 $2,004 $5,477 $7,481 $19,783
2027 $1,638 $1,602 $3,240 $2,532 $6,471 $9,003 $2,104 $5,377 $7,481 $19,724
2028 $1,647 $1,534 $3,181 $2,659 $6,344 $9,003 $2,209 $5,272 $7,481 $19,665
2029 $1,657 $1,466 $3,123 $2,792 $6,212 $9,003 $2,320 $5,161 $7,481 $19,607
2030 $1,667 $1,397 $3,064 $2,931 $6,072 $9,003 $2,436 $5,045 $7,481 $19,548
2031 $1,677 $1,329 $3,006 $3,078 $5,925 $9,003 $2,557 $4,924 $7,481 $19,490
2032 $1,687 $1,259 $2,946 $3,232 $5,772 $9,003 $2,685 $4,796 $7,481 $19,430
2033 $1,698 $1,190 $2,888 $3,393 $5,610 $9,003 $2,819 $4,661 $7,481 $19,372
2034 $1,710 $1,120 $2,830 $3,563 $5,440 $9,003 $2,960 $4,520 $7,481 $19,314
2035 $1,721 $1,050 $2,771 $3,741 $5,262 $9,003 $3,108 $4,372 $7,481 $19,255
2036 $1,734 $979 $2,713 $3,928 $5,075 $9,003 $3,264 $4,217 $7,481 $19,197
2037 $1,746 $908 $2,654 $4,124 $4,879 $9,003 $3,427 $4,054 $7,481 $19,138
2038 $1,759 $837 $2,596 $4,331 $4,672 $9,003 $3,598 $3,882 $7,481 $19,080
2039 $1,773 $765 $2,538 $4,547 $4,456 $9,003 $3,778 $3,703 $7,481 $19,022
2040 $1,787 $692 $2,479 $4,775 $4,229 $9,003 $3,967 $3,514 $7,481 $18,963
2041 $1,801 $619 $2,420 $5,013 $3,990 $9,003 $4,166 $3,315 $7,481 $18,904
2042 $1,374 $554 $1,928 $5,264 $3,739 $9,003 $4,374 $3,107 $7,481 $18,412
2043 $1,374 $496 $1,870 $5,527 $3,476 $9,003 $4,593 $2,888 $7,481 $18,354
2044 $1,374 $437 $1,811 $5,803 $3,200 $9,003 $4,822 $2,659 $7,481 $18,295
2045 $1,374 $378 $1,752 $6,094 $2,909 $9,003 $5,063 $2,418 $7,481 $18,236
2046 $1,374 $321 $1,695 $6,398 $2,605 $9,003 $5,317 $2,164 $7,481 $18,179
2047 $1,374 $262 $1,636 $6,718 $2,285 $9,003 $5,582 $1,899 $7,481 $18,120
2048 $1,374 $204 $1,578 $7,054 $1,949 $9,003 $5,861 $1,619 $7,481 $18,062
2049 $1,374 $145 $1,519 $7,407 $1,596 $9,003 $6,155 $1,326 $7,481 $18,003
2050 $1,374 $88 $1,462 $7,777 $1,226 $9,003 $6,462 $1,019 $7,481 $17,946
2051 $1,374 $29 $1,403 $8,166 $837 $9,003 $6,785 $696 $7,481 $17,887
1. Includes Series 1, 4, 6, 7, 8, and 10 bonds.
2. Debt service on SSQ, BLS, and SS line sections totaling $137.5 million,
3. Debt schedules for BESS project only totaling $115 million, as described in this Opinion.
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September 6, 2022
Mr. Bryan Carey
Director of Owned Assets
Alaska Energy Authority
813 West Northern Lights Blvd.
Anchorage, Alaska 99503
Subject: Opinion on Upgrade to Transmission Line between Bradley Lake and Sterling Substation
Mr. Carey:
Presented herewith is a summary of our analyses, investigations, studies and opinion with respect to the
proposed system upgrade: Upgrade from Bradley Lake to Soldotna (“BLS Upgrade”) and the Soldotna to
Sterling Upgrade (“SS Line Upgrade”) related to the Bradley Lake Project.
The Project Description
GDS Associates (GDS), has been retained by Alaska Energy Authority (AEA) to provide an independent
opinion (Opinion) of the proposed upgrade to the Transmission Line from Bradley Lake power plant to
Soldotna (“BLS Upgrade”) and Soldotna Substation to Sterling Substation (“SS Line Upgrade”).
The goal of both the BLS and SS Upgrades will allow for AEA to improve the assets of the Bradley Lake
Project. The BLS and SS Upgrades combined with other work planned along the route from Bradley Lake
to Anchorage allows for increased the efficiency and reliability of this portion of the transmission system
which is necessary for the power delivery from the Bradley Project.
The BLS Upgrade is still in its infancy, because the design and planning has not started and will likely take
several years. This proposed project will add a new 115kV transmission line from the Bradley Lake Project
through Bradley Junction to the Soldotna Substation. This new line will parallel the existing line providing
additional capacity as well as redundancy. The line from Bradley Junction to Soldotna is within Homer
Electric Association’s (“HEA”) service territory and was built by HEA for the Bradley Lake Project. The
Agreement for Sale of Transmission Capacity dated December 8, 1987 defines the participating utilities
obligations related to this section of line. AEA has acquired certain transmission rights through the
acquisition of the transmission line from Sterling Substation to Quartz Creek Substation (SSQ line). The
proposed new transmission will not adversely affect the existing HEA line although the two lines will be
general in the same right-of-way. The total length of the line is roughly 68 miles. This project includes
modifications to the existing GIS switchgear and 0.5 miles of 115 kV solid-dielectric cable at the Bradley
Lake power plant. The northern end of the line would terminate in a new 115kV substation connected to
the existing HEA substation through the existing AEA SVC bay. The new station will be 115kV ring bus
station. The estimated cost of the BLS Upgrade including the substations is $66.6 million.
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The SS Upgrade proposes to convert 14 miles of existing 115 kV transmission line from Soldotna
Substation to Sterling Substation to a double circuit 115 kV and 230 kV transmission line. HEA has retained
ownership of the SS Line and AEA has purchased transmission capacity in the SS line. The SS Line is
operated under the Amendment to Agreement for Sale of Transmission Capacity. Further AEA has
retained the right to direct HEA to repair or upgrade the SS Line. The double circuit will allow the Sterling
Substation to continue to operate at 115 kV and provide capacity for HEA to this station. The cost to
upgrade this is $24.4 million and SS Upgrade does not include any substation upgrades at Soldotna. The
SS Upgrade is necessary to keep the Bradley Lake Project in good and efficient operating condition.
GDS reviewed the Power Sales Agreement, financial statements of purchasing utilities and the AEA, and
engineering and design studies provided to GDS. This Opinion is GDS’s professional opinion. In particular,
this Opinion addresses whether the BLS and SS Transmission Upgrades are of sound economics and
national standards for prudent utility practice based on information available during the assessment.
2022 Financing
The financing of these improvements (the 2022 Bonds) will be issued pursuant to AEA’s Power Revenue
Bond Resolution, adopted September 7, 1989, as amended and supplemented and the Alaska Energy Act
(AS 44.83) (collectively Power Revenue Bond Resolution). Terms used herein but not defined shall have
the meaning set forth in the Power Revenue Bond Resolution.
The proceeds of the 2022 financing may be issued in either bond form or as a loan and may be either
taxable or tax-exempt. The 2022 financing proceeds, deemed as Additional Bonds under the Power
Revenue Bond Resolution will be used to pay (i) capital costs for the BLS and SS Transmission Upgrades;1
and (ii) cost of issuance of the 2022 Bonds. The 2022 Bonds will consist of a not to exceed principal amount
of $85,400,000.
The 2022 Bonds, and bonds issued on a parity basis under the terms of the Power Revenue Bond
Resolution, are direct and general obligations of the AEA secured by full faith and credit of AEA, which are
secured as to payment of the principal of, and interest on, in accordance with the terms and provisions of
the Resolution, by a pledge of Revenues and moneys, securities and funds held or set aside to be held by
the AEA under the Power Revenue Bond Resolution.
This Opinion summarizes our work to date hereof. We make no representations for changed conditions
occurring or becoming known after such date which could affect the material presented herein to the
extent of such changes.
Power Sales Agreement
AEA is a public corporation and an agency of the state of Alaska. AEA is the State’s energy office. In
December of 1987, AEA, at that time the Alaska Power Authority, entered into an agreement for the sale
and purchase of electric power (Agreement). The Agreement details a disposition of energy from the
Bradley Lake Hydroelectric Project (Project), in which AEA sells the output to multiple municipals and
cooperatives (Purchasers) through Alaska’s Railbelt Region. The Project is a 120-megawatt hydroelectric
project which provides 10 percent of the Railbelt area’s energy needs. The Agreement has a 50-year term
1 Bradley Lake Project Management Committee: Report of the Bradley O&D Committee, Review of the Proposed
Transaction.
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and each Purchaser has a share in the energy generated by the facility. For the Purchasers to the north of
the Project, such energy shares are transferred from the Project to the Purchasers via a 115 kV
transmission line between Sterling and Cooper Landing on the Kenai Peninsula of Alaska (SSQ Line). In
December 2020 AEA purchased the following from HEA: capacity rights of the SS Line (Soldotna to Sterling
Substation); ability to direct HEA to repair/upgrade the SS Line; HEA’s property rights to the SSQ line; and
all of HEA’s property rights to the 69 kV line between Soldotna and Quartz Creek Substation. The Sterling
to Quartz Creek Transmission Upgrade is the next step in upgrading the transmission capacity and
reliability of the delivery from the Bradley Lake Project
The Agreement, among other things, established the Bradley Lake Project Management Committee
(BPMC). The purpose of the BPMC is to facilitate the operation and maintenance at the project as well as
power scheduling, power production and power dispatch. The members of the BPMC include the AEA and
the six utilities that purchase power under the Agreement, consisting of:
• Chugach Electric Association (CEA)
• Municipal Light & Power (ML&P) (now part of CEA)
• HEA 2
• Matanuska Electric Association (MEA)
• Golden Valley Electric Association (GVEA)
• City of Seward
AEA issued bonds in support of the Bradley Lake Project from 1989 through 2020 which mature annually
each July 1 through the year 2021 with interest rates ranging from 3.5 percent to 6.25 percent.
Under the Agreement, if a participating utility fails to make payments, the AEA may, after consultation
with the other participating utilities, terminate or suspend delivery of power to the non-paying
participant. If power deliveries are suspended or terminated to the non-paying participant, the AEA has
the right to proportionally increase the percentage shares of the remaining participants with the caveat
that no participant’s share can be increased by more than 25 percent. The remaining participants’
allocation of project costs and power generation will be based on the updated percentage shares.
Agreement Project Work Definitions
The Agreement contemplates that work will be needed during the 50-year term to keep the Project in
efficient operating condition. The Agreement addresses ongoing work for the Project by breaking the
work into two categories; (i) Required Project Work 3; and (ii) Optional Project Work.4
Required Project Work is defined as “repairs, maintenance, renewables, replacements, improvements or
betterments required by federal or state law, a licensing or agency with jurisdiction over the Project, or
this Agreement, or otherwise necessary to keep the Project in good and efficient operating condition,
consistent with (1) sound economics for the Project and the Purchasers, and (2) national standards for the
industry.”
2 Homer Electric Association, Inc. and its single-member cooperative Alaska Electric and Energy Cooperative.
3 Section 1 (hh), Agreement for the Sale and Purchase of Electric Power dated December 8, 1987
4 Section 1 (t), Agreement for the Sale and Purchase of Electric Power dated December 8, 1987
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Optional Project Work is defined as “Project repairs, renewals and replacements, improvements,
betterments, additions, or expansions that do not constitute Required Project Work.”
GDS’s opinion is that the BLS and SS Transmission Upgrades are Required Project Work. Specifically,
Required Project Work includes work that is “…otherwise necessary to keep the Project in efficient
operating condition…”. This work should be “…consistent with sound economics for the Project and the
Purchasers...” and “…national standards for the industry.” GDS addresses these two tests for Project
necessity separately as (1) Economics; and (2) Industry Standard.
Economics
The sound economics test for BLS and SS Transmission Upgrades, extends to both the Project and the
Purchasers. It is GDS’s opinion that the Proposed Transaction meets the economics test for Required
Project Work as further detailed in this Opinion.
GDS reviewed the financials of AEA as well as for each of the Purchasers. The borrowed amount of $85.4
million is assumed over a 30 year term at a rate of 5%. Principal and Interest payments for the 2022 Bonds
are $5.6 million annually. Bradley Lake Power Revenue Refunding Bonds (Series 4 and 6 included in
Existing debt) mature by June 2022 reducing the overall debt service obligation by over $10 million in
2023. Existing debt payments in Table 2 also include the $10 million prepayment for the Series 10 bonds
paid on June 29, 2022. Finally, Table 2 also considers the 2022 Bonds for the SSQ Line Upgrade (Sterling
to Quartz Creek Upgrade) in the analysis of financial feasibility.
Annual net margins for AEA were reviewed from 2015 through 2021 based on audited financial
statements including all outstanding long-term debt. AEA’s average net margin over this period is $22
million. Earnings before interest, tax, and amortization averaged $29 million over this period which more
than covers the average annual debt service obligation over the next 30 years.
Finally, The Bradley Lake Project Bonds matured on July 1, 2021, resulting in the availability of the Excess
Payments to be applied toward the annual 2022 debt service issued to fund Required Project Work. This
can be done in accordance with Section 29 of the Power Sales Agreement. The SS Transmission Upgrade
will reduce system losses once completed. The value of these system losses is estimated at $15.5 million
in net present value over 30 years, or $1 million per year in reduced operating costs along just the SS Line.5
The benefit of reduced losses on the BLS section is estimated to be greater than what was estimated for
the SSQ/SS sections. If the losses are the same as the SSQ/SS section, operating costs for the BLS Upgrade
could be reduced by $3.4 million per year on average over 30 years.6
5 CEA. Soldotna to Quartz Creek Upgrade Evaluation Memorandum. August 6, 2021. Value of losses calculated
based on CEA’s cost of generation and is considered a conservative estimate. Soldotna to Quartz section total
value of losses is estimated at $58.6 million. $43.1 million for the Sterling to Quartz Creek section and $15.5
million for the Soldotna to Sterling section.
6 The SSQ/SS line losses are valued at $58.6 million over 30 years for 53.4 miles of line. At 47.3 miles of line, the
BLS line losses might be valued at $51.9 million.
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Further, future energy flows could increase by 25 to 40%. The increased flows provides additional avoided
loss benefits as well as the potential for future resource development.
Industry Standard
The Required Project Work definition includes any improvements or betterments required by federal or
state law plus an additional efficiency test that improvements are within industry standard. In the
contiguous United States, authority over generation and transmission siting and reliability resides with
Federal Energy Regulatory Commission (FERC).7 Section 215 of the Federal Power Act, however, carves
out Alaska and Hawaii. In 2017, AEA signed a memo of understanding (MOI) with certain Railbelt Utilities.
The MOI commenced the process to create reliability standards that are similar to those required by FERC
and are considered industry standard in the lower 48 states. These standards address transmission
reliability, generation ownership, operation and system vulnerabilities.
It is GDS’ opinion the industry standard for generation and transmission reliability requires betterments
and upgrades to the transmission system such as those detailed in the BLS and SS Transmission Upgrades.
The betterments and upgrades are consistent with Prudent Utility Practice (as that term is defined by the
Bond Resolution) and therefore should be considered Required Project Work as set forth in the
Agreement.
Summary and Conclusion
Based on our analyses, we are of the opinion that:
1. The BLS and SS Transmission Upgrades represent prudent utility practice and are within the
definition of Required Project Work. The BLS and SS Transmission Upgrades are necessary to keep
the Project in efficient running conditions and is both economical and in accordance with industry
standard practices. Alaska is advancing reliability standards, similar to those required by FERC
through NERC in the lower 48 states. These standards will require greater transmission reliability
in the future and the BLS and SS Transmission Upgrades will position AEA and the Purchasers to
fully comply.
2. Neither the issuance of the 2022 Bonds, nor any payments associated with the BLS and SS
Transmission Upgrades, will impair the ability of the AEA to pay debt service on the outstanding
bonds and the 2022 Bonds through the collection of revenues under the PSA and the auxiliary
services contemplated under the Definitive Agreements.8
3. The BLS and SS Transmission Upgrades are expected to provide stable and reliable delivery from
the Bradley Lake Hydroelectric Project. The BLS and SS Transmission Upgrades will increase the
conductor size and the insulation level of the existing transmission line. Such increased
transmission capacity will reduce losses and enable the reliable delivery of the output from the
Bradley Lake Hydroelectric Project.
4. The BLS and SS Transmission Upgrades are also expected to support future development of
hydropower, wind, and solar projects on the Kenai Peninsula. As development of these resources
occur, losses would increase significantly if the transmission upgrade were not implemented. The
7 https://www.ferc.gov/enforcement/enforce-res/EPAct2005.pdf
8 Such agreements are conditions precedent to the Proposed Transaction (Page 19 of the Resolution).
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benefit of the upgrade increases as new projects are developed and allows for an increase of 25-
40% in energy flows.
Respectfully submitted,
Kevin J. Mara, P.E.
Executive Vice President
Exhi bit
Table 1
AEA Audited Financial Statements
Fiscal Year 2015 2016 2017 2018 2019 2020 2021
Revenues
Charges for Services $17,289 $18,974 $19,179 $21,848 $21,426 $21,889 $23,209
Grants and Contributions 104,208 32,467 31,244 19,642 24,745 14,082 17,292
Investment Income 35,095 11,048 114,443 79,344 78,008 51,411 151,983
Total Revenue $156,592 $62,489 $164,866 $120,834 $124,179 $87,382 $192,484
Expenses
Grants and Projects $111,719 $69,116 $62,629 $56,692 $48,582 $47,969 $45,927
General and Administrative 6,113 6,590 4,704 4,454 5,672 5,742 20,605
Interest Expense 3,668 3,177 2,652 2,371 1,746 827 1,159
Plant Operations 3,985 4,709 4,330 5,772 5,350 5,376 7,797
Depreciation 10,487 10,529 10,808 15,594 10,862 10,917 12,356
Provision for Loan Loss 6 -2 154 -51 169 61 -33
Total Expenses $135,978 $94,119 $85,277 $84,832 $72,381 $70,892 $87,811
State Re-appropriation of
Funds
$0 $0 ($13,556) ($10,067) ($1,097,695) ($21,222) $1,017,213
Net Margin $20,614 ($31,630) $66,033 $25,935 ($1,045,897) ($4,732) $1,121,886
EBITA $28,273 ($23,746) $73,169 $34,027 ($1,038,632) $1,532 $1,130,809
Exhi bit
Table 2
Debt Service Schedule ($1,000s)
Existing Long-Term Debt1 SSQ Line 2022 Bonds2 BLS and SS Line 2022 Bonds3 Total
Debt
Service Fiscal Year Principal Interest Total Principal Interest Total Principal Interest Total
2022 $23,184 $2,632 $25,816 $25,816
2023 $1,603 $1,869 $3,472 $798 $2,650 $3,448 $1,285 $4,270 $5,555 $12,475
2024 $1,612 $1,803 $3,415 $838 $2,610 $3,448 $1,350 $4,206 $5,555 $12,418
2025 $1,620 $1,736 $3,356 $879 $2,568 $3,448 $1,417 $4,138 $5,555 $12,359
2026 $1,629 $1,670 $3,299 $923 $2,524 $3,448 $1,488 $4,067 $5,555 $12,302
2027 $1,638 $1,602 $3,240 $970 $2,478 $3,448 $1,562 $3,993 $5,555 $12,243
2028 $1,647 $1,534 $3,181 $1,018 $2,430 $3,448 $1,641 $3,915 $5,555 $12,184
2029 $1,657 $1,466 $3,123 $1,069 $2,379 $3,448 $1,723 $3,833 $5,555 $12,126
2030 $1,667 $1,397 $3,064 $1,122 $2,325 $3,448 $1,809 $3,747 $5,555 $12,067
2031 $1,677 $1,329 $3,006 $1,179 $2,269 $3,448 $1,899 $3,656 $5,555 $12,009
2032 $1,687 $1,259 $2,946 $1,238 $2,210 $3,448 $1,994 $3,561 $5,555 $11,949
2033 $1,698 $1,190 $2,888 $1,299 $2,148 $3,448 $2,094 $3,462 $5,555 $11,891
2034 $1,710 $1,120 $2,830 $1,364 $2,083 $3,448 $2,198 $3,357 $5,555 $11,833
2035 $1,721 $1,050 $2,771 $1,433 $2,015 $3,448 $2,308 $3,247 $5,555 $11,774
2036 $1,734 $979 $2,713 $1,504 $1,943 $3,448 $2,424 $3,132 $5,555 $11,716
2037 $1,746 $908 $2,654 $1,579 $1,868 $3,448 $2,545 $3,010 $5,555 $11,657
2038 $1,759 $837 $2,596 $1,658 $1,789 $3,448 $2,672 $2,883 $5,555 $11,599
2039 $1,773 $765 $2,538 $1,741 $1,706 $3,448 $2,806 $2,750 $5,555 $11,541
2040 $1,787 $692 $2,479 $1,828 $1,619 $3,448 $2,946 $2,609 $5,555 $11,482
2041 $1,801 $619 $2,420 $1,920 $1,528 $3,448 $3,093 $2,462 $5,555 $11,423
2042 $1,374 $554 $1,928 $2,016 $1,432 $3,448 $3,248 $2,307 $5,555 $10,931
2043 $1,374 $496 $1,870 $2,117 $1,331 $3,448 $3,411 $2,145 $5,555 $10,873
2044 $1,374 $437 $1,811 $2,222 $1,225 $3,448 $3,581 $1,974 $5,555 $10,814
2045 $1,374 $378 $1,752 $2,334 $1,114 $3,448 $3,760 $1,795 $5,555 $10,755
2046 $1,374 $321 $1,695 $2,450 $997 $3,448 $3,948 $1,607 $5,555 $10,698
2047 $1,374 $262 $1,636 $2,573 $875 $3,448 $4,146 $1,410 $5,555 $10,639
2048 $1,374 $204 $1,578 $2,701 $746 $3,448 $4,353 $1,203 $5,555 $10,581
2049 $1,374 $145 $1,519 $2,836 $611 $3,448 $4,570 $985 $5,555 $10,522
2050 $1,374 $88 $1,462 $2,978 $469 $3,448 $4,799 $756 $5,555 $10,465
2051 $1,374 $29 $1,403 $3,127 $321 $3,448 $5,039 $516 $5,555 $10,406
1. Includes Series 1, 4,6, 7, 8, and 10 bonds.
2. Debt service on SSQ Line section only ($53 million).
3. Debt schedules for BLS and SS only totaling $84.5 million, as described in this Opinion.
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May 25, 2022
Mr. David Lockard
Infrastructure Engineer
Alaska Energy Authority
813 West Northern Lights Blvd.
Anchorage, Alaska 99503
Subject: Opinion on Upgrade to Transmission Line between Sterling Substation and Quartz Creek
Substation
Mr. Lockard:
Presented herewith is a summary of our analyses, investigations, studies and opinion with respect to the
proposed system upgrade: Upgrade to Transmission Line between Sterling Substation and Quartz Creek
Substation.
Introduction
GDS Associates (GDS), has been retained by Alaska Energy Authority (AEA) to provide an independent
opinion (Opinion) of the proposed upgrade to the Transmission Line between Sterling Substation to
Quartz Creek Substation (“Sterling to Quartz Creek Transmission Upgrade”).
1. The Sterling to Quartz Creek Transmission Upgrade will allow for AEA to increase the efficiency
and reliability of this portion of the transmission system which is necessary for the power delivery
from the Bradley Project. The Sterling to Quartz Creek Transmission Upgrade work includes the
upgrade of approximately 39.4 miles of transmission line between the Sterling Substation and
Quartz Creek Substation (SSQ Line) from 115 kV to 230 kV.
The cost of the Sterling to Quartz Creek Transmission Upgrade is estimated at $53 million (including issuing
costs). GDS reviewed the Power Sales Agreement, financial statements of purchasing utilities and the
AEA, and engineering and design studies provided to GDS. This Opinion is GDS’s professional opinion. In
particular, this Opinion addresses whether the Sterling to Quartz Creek Transmission Upgrade is of sound
economics and national standards for prudent utility practice based on information available during the
assessment.
2022 Bonds
The 2022 Bonds will be issued pursuant to AEA’s Power Revenue Bond Resolution, adopted September 7,
1989, as amended and supplemented and the Alaska Energy Act (AS 44.83) (collectively Power Revenue
Bond Resolution). Terms used herein but not defined shall have the meaning set forth in the Power
Revenue Bond Resolution.
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The proceeds of the 2022 Bonds, deemed as Additional Bonds under the Power Revenue Bond Resolution
will be used to pay (i) capital costs for the Sterling to Quartz Creek Transmission Upgrade;1 and (ii) cost of
issuance of the 2022 Bonds. The 2022 Bonds will consist of a not to exceed principal amount of
$53,000,000.
The 2022 Bonds, and bonds issued on a parity basis under the terms of the Power Revenue Bond
Resolution, are direct and general obligations of the AEA secured by full faith and credit of AEA, which are
secured as to payment of the principal of, and interest on, in accordance with the terms and provisions of
the Resolution, by a pledge of Revenues and moneys, securities and funds held or set aside to be held by
the AEA under the Power Revenue Bond Resolution.
This Opinion summarizes our work to date hereof. We make no representations for changed conditions
occurring or becoming known after such date which could affect the material presented herein to the
extent of such changes.
Power Sales Agreement
AEA is a public corporation and an agency of the state of Alaska. AEA is the State’s energy office. In
December of 1987, AEA, at that time the Alaska Power Authority, entered into an agreement for the sale
and purchase of electric power (Agreement). The Agreement details a disposition of energy from the
Bradley Lake Hydroelectric Project (Project), in which AEA sells the output to multiple municipals and
cooperatives (Purchasers) through Alaska’s Railbelt Region. The Project is a 120-megawatt hydroelectric
project which provides 10 percent of the Railbelt area’s energy needs. The Agreement has a 50-year term
and each Purchaser has a share in the energy generated by the facility. For the Purchasers to the north of
the Project, such energy shares are transferred from the Project to the Purchasers via a 115 kV
transmission line between Sterling and Cooper Landing on the Kenai Peninsula of Alaska (SSQ Line). In
December 2020 AEA purchased the following from HEA: capacity rights of the SS Line (Soldotna to Sterling
Substation); ability to direct HEA to repair/upgrade the SS Line; HEA’s property rights to the SSQ line; and
all of HEA’s property rights to the 69 kV line between Soldotna and Quartz Creek Substation. The Sterling
to Quartz Creek Transmission Upgrade is the next step in upgrading the transmission capacity and
reliability of the delivery from the Bradley Lake Project
The Agreement, among other things, established the Bradley Lake Project Management Committee
(BPMC). The purpose of the BPMC is to facilitate the operation and maintenance at the project as well as
power scheduling, power production and power dispatch. The members of the BPMC include the AEA and
the six utilities that purchase power under the Agreement, consisting of:
• Chugach Electric Association (CEA)
• Municipal Light & Power (ML&P) (now part of CEA)
• HEA2
• Matanuska Electric Association (MEA)
1 Bradley Lake Project Management Committee: Report of the Bradley O&D Committee, Review of the Proposed
Transaction.
2 Homer Electric Association, Inc. and its single-member cooperative Alaska Electric and Energy Cooperative.
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• Golden Valley Electric Association (GVEA)
• City of Seward
AEA issued bonds in support of the Bradley Lake Project from 1989 through 2020 which mature annually
each July 1 through the year 2021 with interest rates ranging from 4.0 percent to 6.25 percent.
Under the Agreement, if a participating utility fails to make payments, the AEA may, after consultation
with the other participating utilities, terminate or suspend delivery of power to the non-paying
participant. If power deliveries are suspended or terminated to the non-paying participant, the AEA has
the right to proportionally increase the percentage shares of the remaining participants with the caveat
that no participant’s share can be increased by more than 25 percent. The remaining participants’
allocation of project costs and power generation will be based on the updated percentage shares.
Agreement Project Work Definitions
The Agreement contemplates that work will be needed during the 50-year term to keep the Project in
efficient operating condition. The Agreement addresses ongoing work for the Project by breaking the
work into two categories; (i) Required Project Work3; and (ii) Optional Project Work.4
Required Project Work is defined as “repairs, maintenance, renewables, replacements, improvements or
betterments required by federal or state law, a licensing or agency with jurisdiction over the Project, or
this Agreement, or otherwise necessary to keep the Project in good and efficient operating condition,
consistent with (1) sound economics for the Project and the Purchasers, and (2) national standards for the
industry.”
Optional Project Work is defined as “Project repairs, renewals and replacements, improvements,
betterments, additions, or expansions that do not constitute Required Project Work.”
GDS’s opinion is that the Sterling to Quartz Creek Transmission Upgrade is Required Project Work.
Specifically, Required Project Work includes work that is “…otherwise necessary to keep the Project in
efficient operating condition…”. This work should be “…consistent with sound economics for the Project
and the Purchasers...” and “…national standards for the industry.” GDS addresses these two tests for
Project necessity separately as (1) Economics; and (2) Industry Standard.
Economics
The sound economics test for Sterling to Quartz Creek Transmission Upgrade, extends to both the Project
and the Purchasers. It is GDS’s opinion that the Proposed Transaction meets the economics test for
Required Project Work as further detailed in this Opinion.
GDS reviewed the financials of AEA as well as for each of the Purchasers. The borrowed amount of $53
million is assumed over a 30 year term at a nontaxable rate of 5%. Principal and Interest payments for
the 2022 Bonds are $3.4 million annually. Bradley Lake Power Revenue Refunding Bonds mature by June
3 Section 1 (hh), Agreement for the Sale and Purchase of Electric Power dated Decemb er 8, 1987
4 Section 1 (t), Agreement for the Sale and Purchase of Electric Power dated December 8, 1987
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2022 reducing the overall debt service obligation by $7 million after the 2022 Bonds are added to the
obligation. See Table 2 at the end of this Opinion.
Annual net margins for AEA were reviewed from 2015 through 2021 based on audited financial
statements including all outstanding long-term debt. AEA’s average net margin over this period is $22
million. Earnings before interest, tax, and amortization averaged $29 million over this period which more
than covers the average annual debt service obligation over the next 30 years.
Finally, Purchasing utilities will raise rates, reduce costs, or use other means available to pay their share
of the annual debt service associated with the 2022 Bonds. The Sterling to Quartz Creek Transmission
Upgrade will reduce system losses once completed. The value of these system losses is estimated at $29.3
million in net present value over 30 years for CEA’s share.5 Factoring in the full Bradley production, the
value of losses avoided with the upgrade increases to $43.1 million over 30 years for the Sterling to Quartz
Creek section.
Industry Standard
The Required Project Work definition includes any improvements or betterments required by federal or
state law plus an additional efficiency test that improvements are within industry standard. In the
contiguous United States, authority over generation and transmission siting and reliability resides with
Federal Energy Regulatory Commission (FERC).6 Section 215 of the Federal Power Act, however, carves
out Alaska and Hawaii. In 2017, AEA signed a memo of understanding (MOI) with certain Railbelt Utilities.
The MOI commenced the process to create reliability standards that are similar to those required by FERC
and are considered industry standard in the lower 48 states. These standards address transmission
reliability, generation ownership, operation and system vulnerabilities.
It is GDS’ opinion the industry standard for generation and transmission reliability requires betterments
and upgrades to the transmission system such as those detailed in the Sterling to Quartz Creek
Transmission Upgrade. The betterments and upgrades are consistent with Prudent Utility Practice (as that
term is defined by the Bond Resolution) and therefore should be considered Required Project Work as set
forth in the Agreement.
Summary and Conclusion
Based on our analyses, we are of the opinion that:
1. The Sterling to Quartz Creek Transmission Upgrade represents prudent utility practice and is
within the definition of Required Project Work. The Sterling to Quartz Creek Transmission
Upgrade is necessary to keep the Project in efficient running conditions and is both economical
and in accordance with industry standard practices. Alaska is advancing reliability standards,
similar to those required by FERC through NERC in the lower 48 states. These standards will
5 CEA. Soldotna to Quartz Creek Upgrade Evaluation Memorandum. August 6, 2021. Value of losses calculated
based on CEA’s cost of generation and is considered a conservative estimate.
6 https://www.ferc.gov/enforcement/enforce-res/EPAct2005.pdf
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require greater transmission reliability in the future and the Sterling to Quartz Creek Transmission
Upgrade will position AEA and the Purchasers to fully comply.
2. Neither the issuance of the 2022 Bonds, nor any payments associated with the Sterling to Quartz
Creek Transmission Upgrade, will impair the ability of the AEA to pay debt service on the
outstanding bonds and the 2022 Bonds through the collection of revenues under the PSA and the
auxiliary services contemplated under the Definitive Agreements.7
3. The Sterling to Quartz Creek Transmission Upgrade is expected to provide stable and reliable
delivery from the Bradley Lake Hydroelectric Project. The Sterling to Quartz Creek Transmission
Upgrade will increase the conductor size and the insulation level of the existing transmission line
known as the SSQ Line. Such increased transmission capacity will reduce losses and enable the
reliable delivery of the output from the Bradley Lake Hydroelectric Project.
4. The Sterling to Quartz Creek Transmission Upgrade is also expected to support future
development of hydropower, wind, and solar projects on the Kenai Peninsula. As development
of these resources occurs, losses would increase significantly if the transmission upgrade were
not implemented. The benefit of the upgrade increases as new projects are developed.
Respectfully submitted,
Kevin Mara, P.E.
Executive Vice President
7 Such agreements are conditions precedent to the Proposed Transaction (Page 19 of the Resolution).
Exhibit
Table 1
AEA Audited Financial Statements
Fiscal Year 2015 2016 2017 2018 2019 2020 2021
Revenues
Charges for Services $17,289 $18,974 $19,179 $21,848 $21,426 $21,889 $23,209
Grants and Contributions 104,208 32,467 31,244 19,642 24,745 14,082 17,292
Investment Income 35,095 11,048 114,443 79,344 78,008 51,411 151,983
Total Revenue $156,592 $62,489 $164,866 $120,834 $124,179 $87,382 $192,484
Expenses
Grants and Projects $111,719 $69,116 $62,629 $56,692 $48,582 $47,969 $45,927
General and Administrative 6,113 6,590 4,704 4,454 5,672 5,742 20,605
Interest Expense 3,668 3,177 2,652 2,371 1,746 827 1,159
Plant Operations 3,985 4,709 4,330 5,772 5,350 5,376 7,797
Depreciation 10,487 10,529 10,808 15,594 10,862 10,917 12,356
Provision for Loan Loss 6 -2 154 -51 169 61 -33
Total Expenses $135,978 $94,119 $85,277 $84,832 $72,381 $70,892 $87,811
State Re-appropriation of
Funds
$0 $0 ($13,556) ($10,067) ($1,097,695) ($21,222) $1,017,213
Net Margin $20,614 ($31,630) $66,033 $25,935 ($1,045,897) ($4,732) $1,121,886
EBITA $28,273 ($23,746) $73,169 $34,027 ($1,038,632) $1,532 $1,130,809
Exhibit
Table 2
Debt Service Schedule ($1,000s)
Existing Long-Term Debt 2022 Bonds Total Debt
Service FY Principal Interest Total Principal Interest Total
2022 $12,245 $2,630 $14,875 $14,875
2023 $2,020 $2,245 $4,265 $798 $2,650 $3,448 $7,713
2024 $2,042 $2,161 $4,203 $838 $2,610 $3,448 $7,651
2025 $2,066 $2,082 $4,148 $879 $2,568 $3,448 $7,596
2026 $2,089 $1,998 $4,087 $923 $2,524 $3,448 $7,535
2027 $2,168 $1,744 $3,912 $970 $2,478 $3,448 $7,360
2028 $2,168 $1,744 $3,912 $1,018 $2,430 $3,448 $7,360
2029 $2,168 $1,744 $3,912 $1,069 $2,379 $3,448 $7,360
2030 $2,168 $1,744 $3,912 $1,122 $2,325 $3,448 $7,360
2031 $2,168 $1,744 $3,912 $1,179 $2,269 $3,448 $7,360
2032 $2,317 $1,301 $3,618 $1,238 $2,210 $3,448 $7,066
2033 $2,317 $1,301 $3,618 $1,299 $2,148 $3,448 $7,066
2034 $2,317 $1,301 $3,618 $1,364 $2,083 $3,448 $7,066
2035 $2,317 $1,301 $3,618 $1,433 $2,015 $3,448 $7,066
2036 $2,317 $1,301 $3,618 $1,504 $1,943 $3,448 $7,066
2037 $2,494 $829 $3,324 $1,579 $1,868 $3,448 $6,771
2038 $2,494 $829 $3,324 $1,658 $1,789 $3,448 $6,771
2039 $2,494 $829 $3,324 $1,741 $1,706 $3,448 $6,771
2040 $2,494 $829 $3,324 $1,828 $1,619 $3,448 $6,771
2041 $2,494 $829 $3,324 $1,920 $1,528 $3,448 $6,771
2042 $1,375 $437 $1,812 $2,016 $1,432 $3,448 $5,260
2043 $1,375 $437 $1,812 $2,117 $1,331 $3,448 $5,260
2044 $1,375 $437 $1,812 $2,222 $1,225 $3,448 $5,260
2045 $1,375 $437 $1,812 $2,334 $1,114 $3,448 $5,260
2046 $1,375 $437 $1,812 $2,450 $997 $3,448 $5,260
2047 $1,375 $146 $1,520 $2,573 $875 $3,448 $4,968
2048 $1,375 $146 $1,520 $2,701 $746 $3,448 $4,968
2049 $1,375 $146 $1,520 $2,836 $611 $3,448 $4,968
2050 $1,375 $146 $1,520 $2,978 $469 $3,448 $4,968
2051 $1,375 $146 $1,520 $3,127 $321 $3,448 $4,968
MEMORANDUM State of Alaska
Department of Law
TO:
FROM:
Curtis Thayer
Executive Director
Alaska Energy Authority
Stefan A. Saldanha
Senior Assistant Attorney General
Public Corporations and
Governmental Affairs Section
DATE:
FILE NO.:
TEL. NO.:
SUBJECT:
May 19, 2022
2021103317
(907) 269-6612
Bradley Lake Project -
Whether the upgrade of the
SS Line meets the definition
of “Required Project Work”
CONFIDENTIAL—DOCUMENT
The participants in the Bradley Lake hydroelectric facility (“Bradley Lake
Project”) have requested the Department of Law to review whether a series of proposed
developments can be considered required project work under the Power Sales Agreement
(“PSA”). For the purpose of this memorandum, we will consider these proposed
developments to be agreed upon by all participants.
In this memorandum, we review the upgrade of the Soldotna to Sterling
transmission line, whether as a new line or the replacement of the existing line (the line,
“SS line” and the upgrade or replacement work, “SS Upgrade”).1
This analysis is important for State financial reasons, because if found to be
required project work as defined in the PSA (“Required Project Work”), future payments
paid by the participating utilities to the State of Alaska under the PSA could be reduced
by the debt service payments related to the work.
1. Transmission Line Upgrade within the Bradley Lake Project
Issue: Does the SS Upgrade meet the requirements of the PSA to be considered
Required Project Work?
1 We have researched this question internally at the Department of Law, and
reviewed historical documents concerning AEA and the Bradley Lake Project. However,
we have not analyzed other aspects of this transaction, such as the political, financial, tax
or accounting aspects.
Curtis Thayer, Executive Director May 19, 2022
Re: Is the SS Upgrade Required Project Work? Page 2 of 5
CONFIDENTIAL - DOCUMENT
Short Answer: The SS Upgrade should be considered Required Project Work
under the PSA. Additional analysis required by the PSA should also be done by the
relevant experts regarding its economics and consistency with national standards in the
industry.
2. Recent DOL interpretations of Required Project Work
The BPMC has begun work on the following developments and asked the
Department of Law whether they constitute Required Project Work under the PSA:
1. The purchase of certain transmission line assets, including the
Sterling to Quartz Creek line (SQL) from HEA;
2. The upgrade of the SQL;
3. The long-term repair and replacement program at the Project;
4. The upgrade of the Bradley Junction to Soldotna transmission line
(BJS line); and
5. The purchase of three battery energy storage systems (BESS).
The Department of Law, in memoranda dated May 19, 2020, November 10, 2021,
January 24, 2022, March 7, 2022 and April 27, 2022, concluded that these developments
were considered Required Project Work under the PSA. In each case, it was also
concluded that AEA had the statutory authority to improve the Bradley Lake Project
under AS 44.83.080(5) which grants AEA the authority “to improve, equip, operate, and
maintain power projects.”
Our memoranda came to the following relevant conclusions that do not need to be
re-analyzed here.
• Required Project Work appears to be a catch-all that combines several
different types of developments for the benefit of the Bradley Lake Project,
such as repair, maintenance, renewal, replacement, improvements or
betterments.
• There is no requirement in the PSA that the Required Project Work be
located in areas originally part of the Bradley Lake Project such as that
identified in Exhibit C of the PSA, which describes some of the project
assets.
• A development may have non-Project uses and still be considered Required
Project Work.
Curtis Thayer, Executive Director May 19, 2022
Re: Is the SS Upgrade Required Project Work? Page 3 of 5
CONFIDENTIAL - DOCUMENT
3. Can the SS Upgrade be considered Required Project Work?
a. Description of SS Upgrade
The utilities are now seeking to finance the upgrade of the transmission line from
Soldotna to Sterling on the Kenai Peninsula (SS Line). The estimated cost of this
upgrade is $14-15 million.
The Bradley Lake Project already owns two segments of the main transmission
path northwards: the 20-mile transmission line from the powerhouse to Bradley Junction,
and the 40-mile transmission line from Sterling to Quartz Creek. The Bradley Lake
Project also already owns certain rights on the SS line, namely transmission capacity
subject to HEA’s native load and rights to require maintenance and upgrades to the line.
The utilities plan for the upgrade of the SS line is still unclear, because design and
planning has not started. The tentative plan is to build a new 230kV transmission line.
The utilities have presented a preliminary agreement in the form of a letter of intent to
AEA, dated Februar y 16, 2022. In summary, the letter of intent provides that AEA on
behalf of the Project would take ownership of the facilities added and increased
capability as assets of the Project. HEA would retain its current rights in existing
infrastructure and rights of way.
While the line loss due to the state of the line has not been calculated for the SS
line, it is thought to be less than the SQL, which is approximately $672,950 per year.
While the line losses are not eliminated with an upgrade, the larger capacity lines at 230
kV have significantly less line losses.
b. Statutory analysis
AEA is no longer allowed to construct or acquire new power projects, such as
hydroelectric facilities or interties, without legislative approval.2 However, AEA has the
power to “improve, equip, operate and maintain power projects”, such as the Bradley
Lake Project, which has been approved by the legislature.3 Additionally, AEA has the
power to “enter into contracts with any person … for the purchase, sale, exchange,
transmission or use of any power from a project, or any right to the capacity of it.4
2 SLA 1993, ch. 18, Sec. 10.
3 AS 44.83.080(5).
4 AS 44.84.080(11).
Curtis Thayer, Executive Director May 19, 2022
Re: Is the SS Upgrade Required Project Work? Page 4 of 5
CONFIDENTIAL - DOCUMENT
Because this project will significantly improve the Bradley Lake Project, we
conclude that the SS Upgrade is within AEA’s statutory powers.
c. Contractual analysis
As mentioned, the Required Project Work definition in the PSA combines several
types of projects:
“Required Project Work” means repairs, maintenance, renewals, replacements,
improvements or betterments required by federal or state law, a licensing or
regulatory agency with jurisdiction over the Project, or this Agreement, or
otherwise necessary to keep the Project in good and efficient operating condition,
consistent with (1) sound economics for the Project and the Purchasers, and (2)
national standards for the industry.5
The SS Upgrade can be described as an improvement or betterment of the Bradley
Lake Project because of its benefits to the transmission of Bradley Lake-generated power.
The utilities argue that major infrastructure assets such as the SS line should become part
of the project. This will allow them to be managed by the BPMC, costs will be
mutualized and disputes should be minimized.
Finally, the BPMC must approve any alternative methods of carrying out and
funding Required Project Work, inherently protecting all participants’ rights. There may
be alternative methods of carrying out and funding this project, so the BPMC may also
review these specific alternatives prior to the agreement on the SS Upgrade.
d. Comparison with previous project works
There are two earlier developments that the SS Upgrade can be compared to, the
upgrade of the SQL and the BESS purchase.
We argued that the purchase and the upgrade to the SQL was Required Project
Work because it was clearly an improvement to the Project as it is critical for the
transmission of Project power. Similarly, an upgrade to the SS line is also critical for the
transmission of Project power.
While reviewing the BESS purchase, we determined that non-Project uses do not
by themselves limit the determination of whether a development is Required Project
Work. There may also be non-Project uses for the upgraded SS line, such as transmission
5 Section 1(hh), p.7, PSA.
Curtis Thayer, Executive Director May 19, 2022
Re: Is the SS Upgrade Required Project Work? Page 5 of 5
CONFIDENTIAL - DOCUMENT
of HEA’s native load, but they do not take away from the significance of the line for the
Project.
In summary, the SS Upgrade would not be a completely unique transaction for the
Bradley Lake Project, and projects with similar characteristics were thought to be
Required Project Work.
4. Conclusion
The Department of Law concludes that the SS Upgrade should be considered
Required Project Work under the PSA as an improvement work for the Bradley Lake
Project. With the approval of all Parties to the PSA, and opinions supporting the
economics and compliance with industry standards, the SS Upgrade can be seen as
necessary to keep the Bradley Lake Project in good and efficient operating condition.
MEMORANDUM State of Alaska
Department of Law
TO:
FROM:
Curtis Thayer
Executive Director
Alaska Energy Authority
Stefan A. Saldanha
Senior Assistant Attorney General
Public Corporations and
Governmental Affairs Section
DATE:
FILE NO.:
TEL. NO.:
SUBJECT:
April 27, 2022
2021103317
(907) 269-6612
Bradley Lake Project -
Whether the purchase of
battery systems meets the
definition of “Required
Project Work”
CONFIDENTIAL COMMUNICATION
The participants in the Bradley Lake hydroelectric facility (“Bradley Lake
Project”) have requested the Department of Law to review whether a series of
infrastructure upgrades and equipment purchases can be considered required project work
under the governing agreement. In this memorandum, we review the purchase of battery
energy storage systems (“BESS”).1
This analysis is important for State financial reasons, because if found to be
required project work (“Required Project Work”) as defined in the Power Sales
Agreement (“PSA”), future payments paid by the participating utilities to the State of
Alaska under the PSA could be reduced or eliminated by the costs related to such
development. However, since we have already approved as Required Project Work
sufficient developments to expend all payments due to the State, there is also the question
of prioritization and financing of Required Project Work and AEA’s involvement.
1. Purchase of BESS by the Bradley Lake Project
Question A: Does the purchase of BESS meet the requirements of the PSA to be
considered Required Project Work?
1 We have researched this question internally at the Department of Law, and
reviewed historical documents concerning AEA and the Bradley Lake Project. However,
we have not analyzed other aspects of this transaction, such as the political, financial, tax
or accounting aspects.
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 2 of 11
CONFIDENTIAL COMMUNICATION
Short Answer A: The purchase of BESS should be considered Required Project
Work under the PSA. Additional analysis required by the PSA should also be done by the
relevant experts with respect to how this purchase is consistent with sound economics
and national standards in the industry.
Question B: What are AEA’s rights with respect to prioritization or other
determinations about Required Project Work?
Short Answer B: It should be noted that AEA has considerable rights under the
PSA and the BPMC bylaws to determine the necessity, scheduling and the approaches to
financing of Required Project Work. To the extent that AEA has preferences, AEA is
able to make these known at the BPMC and may exert control over certain approval
issues.
2. Most recent DOL interpretations of Required Project Work
The BPMC has recommended the following proposed developments and asked the
Department of Law whether they constitute Required Project Work under the PSA:
1. The purchase of certain transmission line assets, including the Sterling to
Quartz Creek (“SQ line”) from HEA;
2. The upgrade of the SQ line;
3. The long-term (34 years) repair and replacement program at the Bradley
Lake Project; and
4. The upgrade of the Bradley Junction to Soldotna transmission line (“BJS
line”).
The Department of Law, in memoranda dated May 19, 2020, November 10, 2021,
January 24, 2022, and March 7, 2022 concluded that AEA had the legal authority to carry
out these four developments, and that they were authorized under the PSA’s Required
Project Work provision.
Our memoranda and related analysis came to the following conclusions that do not need
to be re-analyzed here.
Required Project Work appears to be a catch-all that combines several
different types of projects, such as construction, maintenance, repair or
purchase of new equipment whether to improve operations or to replace
existing equipment.
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 3 of 11
CONFIDENTIAL COMMUNICATION
AEA has the statutory powers to carry out transactions considered a
replacement, repair or improvement of assets related to the Bradley Lake
Project.
Historically, the Bradley Lake Project has not carried out many large
replacement or improvement developments, which make comparisons
difficult. These upcoming developments are breaking new ground under
the PSA.
With the approval of all Parties to the PSA, and studies or reports
supporting the economics and industry standards, large replacements and
improvements to the Bradley Lake Project can be seen as Required Project
Work necessary to keep it in good and efficient operating condition.
The payments to the State under the PSA can be reduced or eliminated by
annual debt service for Reduced Project Work.
The location of the developments is not required to be within the historical
boundaries as outlined in the PSA, so long as the development can be
substantially linked to the Bradley Lake Project.
3. Can the BESS purchase be considered as Required Project Work?
a. Description of BESS
The utilities are now suggesting the purchase by the Bradley Lake Project of
BESS. The ask is for three systems, estimated at a cost of $115-145 million:
1. The HEA BESS, operating in Soldotna since January 19, 2022, and
valued at $45 million, with financing from commercial lenders;
2. The Anchorage BESS, estimated to cost $60 million, and the
procurement process has been started; and
3. A replacement or significant upgrade to Golden Valley Electric’s
(GVEA) existing BESS, estimated to cost between $10-40 million.
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 4 of 11
CONFIDENTIAL COMMUNICATION
BESS have many uses. GVEA on its website focuses on the impact of its battery
on power outages.2 In 2019, 49 outages were prevented.3 HEA also features its battery on
its website.4 It focuses on the benefits of renewable energy integration and lowered
greenhouse gas emissions during outages due to use of batteries, instead of firing up a
diesel or natural gas-powered generator. Neither of the pages mention that the batteries
could have uses with respect to the Bradley Lake Project.
While BESS have the uses as outlined above, the link to the Bradley Lake Project
is highly technical. The utilities received a new power engineer’s report showing that the
BESS will improve power oscillations that may be caused and/or exacerbated by the
Bradley Lake Project. Such oscillations could cause damage to the power grid and the
Bradley Lake powerhouse in a severe case. According to the utilities, as the Railbelt grid
has evolved, these oscillations have increased in recent years. The report has been
prepared by Electric Power Systems, Inc., based in Anchorage, and it is entitled Railbelt
Oscillation Investigation and Mitigation Study, which is dated February 21, 2022
(“Engineer’s Report”). The Engineer’s Report analyzes historical data, in particular, data
recorded during and after a sudden, large outage on June 3, 2021, and makes conclusions
on whether the damaging oscillations were caused by the Bradley Lake Project and what
might cause, dampen or resolve the oscillations when they might re-occur.
The Engineer’s Report analyzes the potential mitigation effects of the existing
HEA battery, the Soldotna BESS, on the oscillations related to the Bradley Lake Project.
It concludes the existing HEA battery to be sufficient to mitigate the impacts of the
oscillations.
The addition of either the HVDC line or Soldotna BESS can
provides (sp) a beneficial impact on the transient response of the
system. In the base case without the HVDC line and the Soldotna
BESS, the transient response of the system is unstable. In the
subsequent cases where either the HVDC line, the Soldotna BESS,
or both components are in-service, the transient response of the
system is stable.5
2 See https://gvea.com/battery-system/.
3 Id.
4 See https://www.homerelectric.com/my-cooperative/power-generation/battery-
energy-storage-system-has-arrived/
5 Engineer’s Report, p.18.
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 5 of 11
CONFIDENTIAL COMMUNICATION
The report also mentions that an Anchorage-located BESS would also be helpful
to mitigate the damaging oscillations.
We also note that the control of over frequency on the Kenai could
be accomplished with the proposed Anchorage area BESS for loss of
the Anchorage – Fairbanks intertie and some contingencies may
require the combined capability of both BESS systems. For system
reliability and performance, both BESS locations should be used to
ensure adequate capability to prevent the severe oscillations. For the
purposes of this study, references to the Soldotna BESS should also
include the understanding that the Anchorage area BESS is also part
of the proposed solution.6
However, nowhere in this report is the current or future upgrade to the GVEA
BESS mentioned. When this point was raised by AEA, the utilities received a new report
from their engineer. This addendum report is entitled, “Addendum to the Railbelt
Oscillation Investigation and Mitigation Study” and dated March 28, 2022
(“Addendum”).7 It focuses on the value of an upgraded GVEA BESS. It uses a
hypothetical situation, where a very large load such as a mining operation in the GVEA
service territory is suddenly disconnected from the grid. This would likely cause large
damaging oscillations, but with batteries at Soldotna and Fairbanks, so long as properly
optimized for this purpose, the grid and the Bradley Lake Project could be protected from
the damaging oscillations. The Addendum concludes:
The additional of (sp) BESSs in Fairbanks and in Anchorage and/or
the Kenai can stabilize the system and reduce the risk of the Bradley
Lake plant going out of step. However, the BESSs logic must be
revised such that each BESS resource contributes during the over-
frequency condition and helps stabilize the overall Railbelt
response.8
The BPMC recognizes the responsibility of the Bradley Lake Project for these
oscillation incidents and to maintain operations in good repair. The Bradley Lake Project
can be seen as responsible for correcting the instability issue on the Railbelt System
caused or exacerbated by its facilities in the most economical manner and in accordance
with prudent utility practice. Re-working the Bradley Lake powerhouse is not as
6 Id., p.12.
7 Note that the Addendum was received by email on April 8, 2022.
8 Addendum, p.1.
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 6 of 11
CONFIDENTIAL COMMUNICATION
economically reasonable or practical as purchasing BESS, primarily because of the high
cost of shutting down power generation. The purchase of the existing BESS in Soldotna,
the installation of one in Southcentral Alaska, and the upgrade or replacement of one in
the Interior, appears to be necessary to keep the Bradley Lake Project in good and
efficient operating condition and is supported by the Engineer’s Report and the
Addendum.
The corresponding bond issuances are estimated at approximately $115-145
million for the BESS purchase. The financing structure has not been determined yet. The
financing needs for the battery development is likely to be combined with the other
development work in process. It is likely that AEA issues one series of long-term bonds
in the amount of $200-300 million in the near future to take advantage of the current
interest rates. These AEA bonds issued on behalf of the Bradley Lake Project should be
cost effective, taking advantage of lower costs of a government issuer, the cost shifting
allowed under the PSA, i.e. no repayment to the State since it is Required Project Work,
and perhaps other federal subsidies and programs designed to incentivize new energy
projects.
b. Statutory analysis
AEA has broad statutory authority with respect to the Bradley Lake Project and in
particular to comply with the terms of the PSA. However, AEA is no longer allowed to
construct or acquire new power projects, such as hydroelectric facilities or interties,
without legislative approval.9 AEA also has the power to “improve, equip, operate and
maintain power projects,” such as the Bradley Lake Project, which has been approved by
the legislature.10 Additionally, AEA has the power to “enter into contracts with any
person … for the purchase, sale, exchange, transmission or use of any power from a
project, or any right to the capacity of it.11
Statutory changes in 1993 eliminated AEA’s power to construct and acquire new
power projects, and AEA’s ongoing powers were strictly limited to the Energy Program
for Alaska, namely Bradley Lake Project and the Alaska Intertie.12 When a BESS is not
used for the Bradley Lake Project, this could be considered an unauthorized power
9 SLA 1993, ch. 18, Sec. 10.
10 AS 44.83.080(5).
11 AS 44.84.080(11).
12 Chap. 18 SLA 1993. Specifically, the words “construct, acquire, construction,
acquisition” were deleted, and new power projects were made subject to legislative
approval.
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 7 of 11
CONFIDENTIAL COMMUNICATION
project. In such characterization, AEA would not have the powers to acquire or manage
it, except with legislative approval.
There is little evidence to support this argument. The Engineer’s report and
Addendum supports the linkage of the BESS to the Bradley Lake Project using historical
data and simulations. The utilities are in favor of managing the BESS for the Bradley
Lake Project. It is uncertain how it will be managed among the utilities, other than such
use and management will be beneficial to ratepayers and the public in general and will
support AEA’s statutory purpose.
Note, however, that it is unlikely that AEA, as potential owner of the BESS, will
be paid directly by utilities for non-Project uses of the BESS, such as for outage
management. This is not in itself a problem for AEA. It is also permitted to “to make
grants or loans to any person and enter into contracts or other transactions regarding the
grants or loans.”13 So AEA can grant use of the BESS to the participating utilities when
not used by the Bradley Lake Project.
Based primarily on the Engineer’s Report and Addendum, the Department of Law
concludes that the purchase of BESS for the Bradley Lake Project is within AEA’s
statutory powers.
c. Contractual language analysis
As mentioned, the Required Project Work definition in the PSA combines several
types of projects:
“Required Project Work” means repairs, maintenance, renewals,
replacements, improvements or betterments required by federal or
state law, a licensing or regulatory agency with jurisdiction over the
Project, or this Agreement, or otherwise necessary to keep the
Project in good and efficient operating condition, consistent with (1)
sound economics for the Project and the Purchasers, and (2) national
standards for the industry.14
As explained by the Engineer’s Report and Addendum, the purchase of BESS can
be described as an improvement or betterment of the Bradley Lake Project. It should be
considered as Required Project Work as defined in the PSA.
13 AS 44.83.080(16).
14 Section 1(hh), p.7, PSA.
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 8 of 11
CONFIDENTIAL COMMUNICATION
The utilities are confident that the BESS purchase is consistent with sound
economics and will meet national standards for the industry. To that end a formal
economic analysis will be carried out, and a consultant or engineer will opine on the
consistency of the BESS purchase with national standards for the industry. This is also
being done prior to the other developments deemed Required Project Work.
Finally, the BPMC must approve any alternative methods of carrying out and
funding Required Project Work, inherently protecting all participants’ rights. There may
be alternative methods of carrying out and funding this purchase, so the BPMC may also
review these specific alternatives.
d. Comparison with previous project works
There are two earlier developments that the BESS purchase can be compared to,
the 2016 decision to replace the static VAR compensation systems (SVCs) and the 2020
decision to purchase the SQ line and other transmission assets and rights.
In summary, the purchase of the BESS would not be a completely unique
transaction for the Bradley Lake Project, and similar projects were thought to be
Required Project Work.
i. SVCs
As part of the Bradley Lake Project in 1993, AEA installed two static VAR
compensation systems (SVCs), which control line voltages, to improve the transmission
of Bradley Lake power. They are located in utility-owned substations in Soldotna and
Dave’s Creek on the Kenai Peninsula. Both substations are along the transmission path of
Bradley Lake power.
On April 21, 2016, as the original SVCs were nearing the end of their life, the
BPMC decided to replace them with a full system upgrade. The approximate cost of this
work was $7.2 million with a service life of at least 20 years. AEA determined that the
SVC replacement was Required Project Work in accordance with the PSA. However, for
financial reasons, this expenditure was not financed using AEA bonding, and so did not
impact payments to the State under the PSA.
There are several similarities with the purchase of BESS. Both are large technical
equipment related to the power transmission of the Bradley Lake Project. Both are
improvement projects to equipment benefitting the Bradley Lake Project. In terms of
location, both the SVCs and BESS are located similarly on the transmission path of
Bradley Lake power, and somewhat distant to the core part of the Bradley Lake Project,
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 9 of 11
CONFIDENTIAL COMMUNICATION
comprising the powerhouse, the dam and the lake. In fact, one of the BESS and SVC are
located in Soldotna.
The main difference is that the original SVC equipment was part of the Bradley
Lake Project from the start, and SVCs can be thought of as early stage batteries with
respect to managing power transmission. A BESS is fairly new technology, and BESS
were not available at the start of the Bradley Lake Project in the early 1990’s.
ii. SQ Line Acquisition
In 2020, the BPMC approved the purchase of certain assets (“SQL acquisition”)
for $17 million: the SQ line; transmission capacity from Soldotna to Sterling, and other
agreements between the parties.
The Department of Law, in a May 19, 2020 memorandum, concluded that AEA
had the legal authority to acquire the SQ line and related assets, concluding that the
transaction was authorized under the PSA contract’s Required Project Work provision in
order to improve delivery of power from the Bradley Lake Project. It was also concluded
that AEA had the statutory authority to acquire the transmission line as an improvement
to the Bradley Lake Project under AS 44.83.080(5) which grants AEA the authority “to
improve, equip, operate, and maintain power projects.”15
There are several similarities with the purchase of BESS. Both are large
infrastructure related to the power transmission of the Bradley Lake Project. Both are
acquisition projects of infrastructure, benefitting the Bradley Lake Project as shown by
expert opinions and the utilities. In terms of location, both the SQ line and BESS are
located similarly on the transmission path of Bradley Lake power, and somewhat distant
to the core part of the Bradley Lake Project.
The main difference is that the SQ acquisition is for traditional transmission assets
wholly dedicated to the Bradley Lake Project and was important to transmission of
project power from the start. As mentioned, BESS is fairly new technology, which was
not contemplated at the start of the Bradley Lake Project, but now can be shown to be
important to its efficiency.
15 There were also two technical opinions received approving the acquisition: O&D
(Operations and Dispatch) Subcommittee of the BPMC, comprising engineers from the
participating utilities, and an independent consultant, EES Consulting, approved the SQL
acquisition with respect to compliance with national standards in the industry and
declaring it sound economically.
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 10 of 11
CONFIDENTIAL COMMUNICATION
4. AEA’s Role in Required Project Work
The utilities have been busy planning to spend monies made available under the
PSA. Once financed by AEA as Required Project Work, the costs of these developments
will be subsidized because they will reduce payments to the State due under the PSA.
However, there is a limit to the subsidy provided by the State to roughly $12.45 million
in debt service per year. To the extent that financing costs exceed this amount, a
prioritization of developments is likely to occur to reduce cost and minimize any out of
pocket amounts needed.
The PSA provides AEA with considerable rights to carry out and finance Required
Project Work.16 Additionally, the BPMC Bylaws require AEA approval, along with a
majority of utility interest, to determine the scheduling and financing of such work.17 The
BPMC bylaws state the following:
5.10.5 The following matters shall require the affirmative vote of
at least four representatives of the Purchasers whose percentage
shares of Project capacity are greater than 51% plus the affirmative
vote of the representative of the Authority.
…
(e) Evaluation of necessity for and scheduling of Required
Project Work.
…
(f) Selection among alternative methods that involve the
Authority for funding Required Project Work.
(emphasis added).
5. Conclusion
The BESS purchase should be considered Required Project Work under the PSA
as an improvement work for the Bradley Lake Project. AEA has certain rights under the
PSA and bylaws to determine necessity, scheduling and financing for Required Project
16 PSA, Sec. 4(c), p.9.
17 Bylaws of BPMC, p.4, section 5.10.5(e), (h).
Curtis Thayer, Executive Director April 27, 2022
Re: Is the BESS purchase “Required Project Work”? Page 11 of 11
CONFIDENTIAL COMMUNICATION
Work, which AEA could use to help determine a priority of developments should
financing be constrained.
With the approval of all Parties to the PSA, and opinions supporting the
economics and compliance with industry standards, the purchase of BESS can be seen as
necessary to keep the Bradley Lake Project in good and efficient operating condition.
MEMORANDUM State of Alaska
Department of Law
TO:
FROM:
Curtis Thayer
Executive Director
Alaska Energy Authority
Stefan A. Saldanha
Senior Assistant Attorney General
Public Corporations and
Governmental Affairs Section
DATE:
FILE NO.:
TEL. NO.:
SUBJECT:
January 24, 2022
2021103317
(907) 269-6612
Bradley Lake Project -
Whether the long-term repair
and replacement program
meets the definition of
“Required Project Work”
CONFIDENTIAL COMMUNICATION
The participants in the Bradley Lake hydroelectric facility (“Bradley Lake
Project”) have requested the Department of Law to review whether a series of upgrades
and equipment purchases can be considered required project work under the project
agreement. The proposed work is outlined in a letter from the Bradley Project
Management Committee (“BPMC”), dated August 20, 2021, and for the purpose of this
memorandum will be considered to be agreed upon by all participants. The main
agreement governing the Bradley Lake Project is the Power Sales Agreement (“PSA”).
The BPMC has encouraged the Department of Law to break up the review of the
list of requested upgrades and equipment purchases. In this memorandum, we review the
long-term repair and replacement of infrastructure and equipment at the Bradley Lake
Project as outlined in a detailed report by D. Hittle & Associates, Inc., dated
December 7, 2021 (“engineer’s report”).1
This analysis may have an important fiscal impact to the State, because if found to
be required project work as defined in the PSA (“Required Project Work”), future
payments paid by the participating utilities to the State of Alaska under the PSA could be
reduced or eliminated.
1 We have researched this question internally at the Department of Law, and
reviewed historical documents concerning AEA and the Bradley Lake Project. However,
we have not analyzed other aspects of this transaction, such as the political, financial, tax
or accounting aspects.
Curtis Thayer, Executive Director January 24, 2022
Re: Is long-term repair and replacement “Required Project Work”? Page 2 of 6
CONFIDENTIAL COMMUNICATION
1. Long-term repair and replacement within the Bradley Lake Project
Issue: Is the long-term repair and replacement program as outlined in the
engineer’s report Required Project Work?
Short Answer: The long-term repair and replacement program as outlined in the
engineer’s report should be considered Required Project Work under the PSA.
2. Recent DOL interpretations of Required Project Work
The Department of Law most recently reviewed work on the Bradley Lake Project
in 2020 and 2021.2 Those transactions involved the purchase (“SQ Acquisition”) and
upgrade (“SQ Upgrade”) of the transmission lines in the Soldotna to Quartz Creek area
and related assets and rights, which improve transmission of Bradley Lake power. We
found that the SQ Acquisition and Upgrade would constitute Required Project Work.
The SQL Acquisition closed on December 17, 2020. It was financed through the
issuance of $17 million in bonds by AEA that were purchased by AIDEA in a private
placement transaction. Because this was Required Project Work, all debt service will be
deductible against payments owed to the State during the term of the bonds. This will
result in a reduction of approximately $23.9 million being paid to the State.
The SQL Upgrade has been approved by the BPMC, but financing is still under
discussion. It will take some time to determine the design, procure services and
equipment, and carry out the eventual construction. The cost estimate for the SQ Upgrade
is $53 million.
Our memoranda and related analysis came to the following conclusions that do not
need to be re-analyzed here.
Required Project Work in the PSA appears to be a catch-all that combines
several different types of projects, such as construction, infrastructure
upgrade or replacement or purchase of new equipment and related rights.
AEA has the statutory powers to carry out such work because they were
considered an addition or improvement of the existing Bradley Lake
Project. However, considering the potential impact to State government
2 The memorandum, dated November 10, 2021, reviews the PSA and historical
project work in more detail than this memorandum.
Curtis Thayer, Executive Director January 24, 2022
Re: Is long-term repair and replacement “Required Project Work”? Page 3 of 6
CONFIDENTIAL COMMUNICATION
finances, it is something that should be made publically known, such as by
communication with the legislature.
With the approval of all Parties to the PSA, and studies or reports
supporting the economics and industry standards, the works could be seen
as Required Project Work necessary to keep the Bradley Lake Project in
good and efficient operating condition.
3. Can the long-term repair and replacement outlined in the engineer’s report
be considered as Required Project Work?
a. Description of the long-term repair and replacement program -
engineer’s report
On a regular basis, the long-term repair and replacement costs at the
Bradley Lake Project are estimated by a specialty engineering firm, D. Hittle &
Associates, Inc. The report contains inspection notes, recommendations and projected
expenditures. Except for the transmission lines, it reviews all of the infrastructure and
equipment comprising the Bradley Lake Project. The infrastructure inspected includes
the powerhouse, living quarters, dams, roads, bridges, and airport. Systems and
equipment inspected include the electrical, water and sewage systems, boats, trucks,
heavy machinery and snow machines. The latest report is dated December 7, 2021, and
estimates approximately $64.1 million in repair and replacement costs for a period from
2022 to 2056, or an average annual cost of about $1.7 million.
The report provides extensive guidance. A noteworthy comment in the
report is:
Another significant issue for the [Bradley Lake Project] is the obsolescence of
certain components and equipment. In particular, control systems over the years
have transitioned from mechanical relays and manual switches to digital controls.
The systems at [Bradley Lake Project] have generally been upgraded over time,
however, some components are in need of replacement since parts are no longer
readily available.3
Of particular interest for this memo, it notes that “[t]he [Bradley Lake Project] is
of an age when small things need attention” and “as the [Bradley Lake Project] ages
these small things will become bigger problems and increase the level of maintenance
3 Estimated Long-Term Repair and Replacement Costs, D. Hittle & Associates, Inc., Dec.
7, 2021, at page 3.
Curtis Thayer, Executive Director January 24, 2022
Re: Is long-term repair and replacement “Required Project Work”? Page 4 of 6
CONFIDENTIAL COMMUNICATION
required to maintain a first-class facility or allow for conditions to deteriorate to the point
that major capital replacements will be required that could have been deferred.”4
Historically, these on-going capital costs have been paid for by the utilities with
annual contributions to the budget and without financing through an AEA bond issuance.
However, because the utilities are planning several other projects requiring bond
financing, these costs could now be included in a new AEA bond issuance.
These repair and replacement works would likely be overseen by the BPMC with
direct supervision by Homer Electric Association, who contracts with AEA to operate
and maintain the Bradley Lake Project.
b. Statutory analysis
AEA has broad statutory authority with respect to the Bradley Lake Project and in
particular to comply with the terms of the PSA. However, AEA is no longer allowed to
develop, construct or acquire new power projects, such as hydroelectric facilities or
interties, without legislative approval.5 AEA does have the power to “improve, equip,
operate and maintain power projects”, such as the Bradley Lake Project, which project
has been approved by the legislature.6
Because this work will repair, replace and/or maintain the assets of the Bradley
Lake Project, the Department of Law concludes that this work is within AEA’s statutory
powers.
c. Contractual language analysis
As mentioned, the Required Project Work definition in the PSA combines several
types of projects:
“Required Project Work” means repairs, maintenance, renewals, replacements,
improvements or betterments required by federal or state law, a licensing or
regulatory agency with jurisdiction over the Project, or this Agreement, or
otherwise necessary to keep the Project in good and efficient operating condition,
4 Id. at page 4.
5 SLA 1993, ch. 18, Sec. 10.
6 AS 44.83.080(5).
Curtis Thayer, Executive Director January 24, 2022
Re: Is long-term repair and replacement “Required Project Work”? Page 5 of 6
CONFIDENTIAL COMMUNICATION
consistent with (1) sound economics for the Project and the Purchasers, and (2)
national standards for the industry.7
The repair and replacement program in the engineer’s report should clearly be
considered required project work. The engineer’s report also provides support for the
work to be considered “necessary to keep the Project in good and efficient operating
condition, consistent with (1) sound economics for the Project and the Purchasers, and (2)
national standards for the industry.”
Even though this repair and replacement program has not been considered
Required Project Work in the past, there is no indication in the PSA that this change in
financing of this program should have any impact on its status as Required Project Work.
Section 24 (Waiver Not Continuing) of the PSA is helpful in that “[a]ny waiver at any
time by either party … shall not be considered a waiver with respect to any subsequent
default, right or matter.”
Finally, the BPMC must approve any alternative methods of carrying out and
funding Required Project Work, inherently protecting all participants’ rights. There may
be alternative methods of carrying out and funding this work, so the BPMC may also
review these specific alternatives prior to the agreement.
d. Comparison with previous project works
An earlier project replacing transmission equipment is most similar to this long-
term repair and replacement work. As part of the Bradley Lake Project in 1993, AEA
installed two static VAR compensation systems (SVCs), which control line voltages, to
improve the transmission of Bradley Lake power. They are located in substations in
Soldotna and Dave’s Creek on the Kenai Peninsula. Both substations are along the
transmission path of Bradley Lake power.
On April 21, 2016, as the original SVCs were nearing the end of their life, the
BPMC decided to replace them with a full system upgrade. The approximate cost of this
work was $7.2 million with a service life of at least 20 years. AEA determined that the
SVC replacement was Required Project Work in accordance with the PSA.
There are several similarities between these two projects. Both involve
replacement and improvement work to equipment that was already part of the Bradley
Lake Project. The items to be repaired or replaced in the engineer’s report are important
or even critical for the operation of the Bradley Lake Project.
7 Section 1(hh), p.7, PSA.
Curtis Thayer, Executive Director January 24, 2022
Re: Is long-term repair and replacement “Required Project Work”? Page 6 of 6
CONFIDENTIAL COMMUNICATION
In summary, the long-term repair and replacement work would not be a
completely unique transaction for the Bradley Lake Project, and the similar project of
SVC replacement was also thought to be Required Project Work.
4. Conclusion
The long-term repair and replacement work as outlined in the engineer’s report
should be considered Required Project Work under the PSA. With the approval of all
parties to the PSA, the long-term repair and replacement work can be seen as necessary to
keep the Bradley Lake Project in good and efficient operating condition.
MEMORANDUM State of Alaska
Department of Law
TO:
FROM:
Curtis Thayer
Executive Director
Alaska Energy Authority
Stefan A. Saldanha
Senior Assistant Attorney General
Public Corporations and
Governmental Affairs Section
DATE:
FILE NO.:
TEL. NO.:
SUBJECT:
November 10, 2021
2021103317
(907) 269-6612
Bradley Lake Project -
Whether the upgrade of the
SQL meets the definition of
“Required Project Work”
CONFIDENTIAL COMMUNICATION
The participants in the Bradley Lake hydroelectric facility (“Bradley Lake
Project”) have requested the Department of Law to review whether a series of upgrades
and equipment purchases can be considered required project work under the project
agreement. The proposed work is outlined in a letter from the Bradley Project
Management Committee (“BPMC”), dated August 20, 2021, and for the purpose of this
memorandum will be considered to be agreed upon by all participants. The main
agreement governing the Bradley Lake Project is the Power Sales Agreement (“PSA”).
The BPMC has encouraged the Department of Law to break up the review of the
list of requested upgrades and equipment purchases. This memorandum will be one of a
series analyzing work requested by the participating utilities. In this memorandum, we
review the upgrade of the Sterling to Quartz Creek transmission line (the line, “SQL” and
the upgrade work, “SQL Upgrade”).1
This analysis is important for State financial reasons, because if found to be
required project work as defined in the PSA (“Required Project Work”), future payments
paid by the participating utilities to the State of Alaska under the PSA could be reduced
by the costs of the work.
1 We have researched this question internally at the Department of Law, and
reviewed historical documents concerning AEA and the Bradley Lake Project. However,
we have not analyzed other aspects of this transaction, such as the political, financial, tax
or accounting aspects.
Curtis Thayer, Executive Director November 10, 2021
Re: Is the SQL Upgrade “Required Project Work”? Page 2 of 6
CONFIDENTIAL COMMUNICATION
1. Transmission Line Upgrade within the Bradley Lake Project
Issue: Does the SQL Upgrade meet the requirements of the PSA to be considered
Required Project Work?
Short Answer: The SQL Upgrade should be considered Required Project Work
under the PSA. Additional analysis required by the PSA should also be done by the
relevant experts with respect to how the SQL Upgrade is consistent with sound
economics and national standards in the industry.
2. Most recent DOL interpretation of Required Project Work
The Department of Law most recently reviewed work on the Bradley Lake Project
in May 2020.2 That transaction involved AEA’s purchase of the SQ Line and related
assets and rights (“SQ Acquisition”) to improve transmission of Bradley Lake power. It
was structured as a purchase by AEA for the Bradley Lake Project from Homer Electric
Association. We found that the SQ Acquisition would constitute Required Project Work.
The SQL Acquisition closed on December 17, 2020. It was financed through the
issuance of $17 million in bonds by AEA that were purchased by AIDEA in a private
placement transaction. Because this was Required Project Work, all debt service will be
deductible against payments owed to the State during the term of the bonds (19 years).
This will result in a reduction of approximately $23.9 million being paid to the State.
Our memorandum and related analysis came to the following conclusions that do
not need to be re-analyzed here.
• Required Project Work appears to be a catch-all that combines several
different types of projects, such as construction, equipment replacement or
purchase of new equipment.
• AEA has the statutory powers to carry out the transaction because the SQL
Acquisition was considered an addition or improvement of the existing
Bradley Lake Project. However, considering the potential impact to State
government finances, it is something that should be made widely known
such as by communication with the legislature.
2 The memorandum, dated May 20, 2020, reviews the PSA and historical project
work in more detail than this memorandum in analyzing the prior transaction.
Curtis Thayer, Executive Director November 10, 2021
Re: Is the SQL Upgrade “Required Project Work”? Page 3 of 6
CONFIDENTIAL COMMUNICATION
• No other historical projects were similar to the SQL Acquisition, and other
historical analysis did not shed much light on the interpretation that should
be used for future projects. This is reasonable because due to the original
construction bond termination, the State will help to fund Required Project
Work going forward in accordance with the PSA.
• With the approval of all Parties to the PSA, and studies or reports
supporting the economics and industry standards, the SQL Acquisition can
be seen as Required Project Work necessary to keep the Bradley Lake
Project in good and efficient operating condition.
3. Can the SQL Upgrade be considered as Required Project Work?
a. Description of SQL Upgrade
The SQL Upgrade involves the replacement and upgrade of the current
transmission line from Sterling to Quartz Creek on the Kenai Peninsula, a distance of
approximately 39.3 miles. The SQL is part of the critical transmission path from Bradley
Lake to ratepayers along the Railbelt.3
An upgrade of the line, which was built in the early 1990’s, is also important for
grid stability and improvements. It will increase the line’s capacity, which is currently
115 kV. At the current capacity, there is a restriction on Bradley Lake power that may be
transferred on the SQ Line. The Bradley Lake project is rated for 120 MW, but it rarely
runs at this power level, because the transmission grid is not suitable. When it was first
built in the early 1990’s, the electrical infrastructure in Southcentral Alaska was very
different. This current medium-capacity line also incurs high line losses, which are
estimated at 13,459 MWh per year, which can be valued at $672,950 per year.
The upgrade would cost approximately $53.3 million, or a $1.4 million per mile.
The high cost per mile is because it goes through a national wildlife refuge, is partially in
an aquatic environment and is remote and subject to harsh Alaska weather. This would
upgrade the line to 230kV, which with other upgrades to the grid would allow more
utilization of Bradley Lake power. For example, Bradley Lake could be better used as a
peaking electrical generator, displacing at times natural gas turbines and perhaps even
lowering greenhouse gas emissions and costs. Line losses are estimated to be
significantly reduced to 2,315 MWh per year, resulting in an approximate savings of
$557,000 per year.
3 The current importance of SQL to the Bradley Lake Project was outlined in the previous
DOL memorandum, dated May 20, 2020.
Curtis Thayer, Executive Director November 10, 2021
Re: Is the SQL Upgrade “Required Project Work”? Page 4 of 6
CONFIDENTIAL COMMUNICATION
The overall time period for design and construction of a new line is expected to be
6-7 years. This breaks down to about 3-4 years in design and permitting, and 2-3 years of
construction, which must be carefully planned due to weather and seasonal requirements
of the Kenai National Wildlife Refuge. This large implementation project would require
specialist staff, equipment and materials to be brought in from the lower 48. The newer
higher capacity line will run along the existing easement, and would completely replace
the existing transmission line.
These works would be overseen by the BPMC, and planning, design and
construction and other rights and obligations would be done in accordance with the
Bradley Lake agreements.
The corresponding bond issuances are estimated at approximately $53.3 million
for this project. The financing structure has not been determined yet, but could include
multiple issuances of both short- and long-term financing. It may involve multiple
tranches of AEA bonds on behalf of the Bradley Lake Project, which cost to the utilities
(and ratepayers) is defrayed by the State of Alaska as part of the PSA.
b. Statutory analysis
AEA has broad statutory authority with respect to the Bradley Lake Project and in
particular to comply with the terms of the PSA. However, AEA is no longer allowed to
construct or acquire new power projects, such as hydroelectric facilities or interties,
without legislative approval.4 AEA also has the power to “improve, equip, operate and
maintain power projects”, such as the Bradley Lake Project, which project has been
approved by the legislature.5 Additionally, AEA has the power to “enter into contracts
with any person … for the purchase, sale, exchange, transmission or use of any power
from a project, or any right to the capacity of it.6
Because this project will improve and maintain the assets of the Bradley Lake
Project, the Department of Law concludes that the SQL Upgrade is within AEA’s
statutory powers.
c. Contractual language analysis
4 SLA 1993, ch. 18, Sec. 10.
5 AS 44.83.080(5).
6 AS 44.84.080(11).
Curtis Thayer, Executive Director November 10, 2021
Re: Is the SQL Upgrade “Required Project Work”? Page 5 of 6
CONFIDENTIAL COMMUNICATION
As mentioned, the Required Project Work definition in the PSA combines several
types of projects:
“Required Project Work” means repairs, maintenance, renewals, replacements,
improvements or betterments required by federal or state law, a licensing or
regulatory agency with jurisdiction over the Project, or this Agreement, or
otherwise necessary to keep the Project in good and efficient operating condition,
consistent with (1) sound economics for the Project and the Purchasers, and (2)
national standards for the industry.7
As outlined above, the SQL Upgrade can be described as a renewal, replacement,
improvement or betterment of the Bradley Lake Project. It should be considered as
Required Project Work as defined in the PSA.
The utilities are confident that the SQL Upgrade is consistent with sound
economics and will meet national standards for the industry. To that end, the utilities plan
to perform a formal economic analysis and have a consultant opine on the consistency of
the SQL Upgrade with national standards for the industry. This was also done prior to the
SQL Acquisition.
Finally, the BPMC must approve any alternative methods of carrying out and
funding Required Project Work, inherently protecting all participants’ rights. There may
be alternative methods of carrying out and funding this project, so the BPMC may also
review these specific alternatives prior to the agreement on the SQL Upgrade.
d. Comparison with previous project works
An earlier project replacing transmission equipment is most similar to the SQL
Upgrade. As part of the Bradley Lake Project in 1993, AEA installed two static VAR
compensation systems (SVCs), which control line voltages, to improve the transmission
of Bradley Lake power. They are located in substations in Soldotna and Dave’s Creek on
the Kenai Peninsula. Both substations are along the transmission path of Bradley Lake
power.
On April 21, 2016, as the original SVCs were nearing the end of their life, the
BPMC decided to replace them with a full system upgrade. The approximate cost of this
work was $7.2 million with a service life of at least 20 years. AEA determined that the
SVC replacement was Required Project Work in accordance with the PSA.
7 Section 1(hh), p.7, PSA.
Curtis Thayer, Executive Director November 10, 2021
Re: Is the SQL Upgrade “Required Project Work”? Page 6 of 6
CONFIDENTIAL COMMUNICATION
There are several similarities between these two upgrade projects. Besides being
related to power transmission, both are replacement and improvement projects to
equipment that was already part of the Bradley Lake Project. It is clear that the SQL is
critical for transmission of Bradley Lake power to the Railbelt. In terms of location, both
the SVCs and the SQL Project are located similarly on the transmission path of Bradley
Lake power.
In summary, the SQL Upgrade would not be a completely unique transaction for
the Bradley Lake Project, and a similar project was thought to be Required Project Work.
4. Conclusion
The SQL Upgrade should be considered Required Project Work under the PSA as
a replacement and improvement work for the Bradley Lake Project. With the approval of
all Parties to the PSA, and opinions supporting the economics and compliance with
industry standards, the SQL Upgrade can be seen as necessary to keep the Bradley Lake
Project in good and efficient operating condition.
419 SW 11th Ave, Suite 400 | Portland, OR 97205
KIRK H. GIBSON
Direct (503) 290-3626
kirk@mrg-law.com
main: 503 595 3922 | fax: 503 595 3928 | www.mrg-law.com
419 SW 11th Ave, Suite 400 | Portland, Oregon 97205-2605
August 20, 2021
VIA U.S.P.S. and Email
Stefan Saldanha
Assistant Attorney General
Alaska Department of Law
1031 W 4th Ave #200
Anchorage, AK 99501
Stefan.saldanha@alaska.gov
Re: Bradley Lake Project Management Committee
Request for Determination – Required Project Work
Stefan:
I am writing to you as the Alaska Department of Law’s (DOL) representative for
the Alaska Energy Authority (AEA) to request on behalf of the Bradley Lake Project
Management Committee (BPMC) that the DOL confirm that certain projects proposed
by the BPMC to upgrade and improve the operations of the Bradley Lake Hydroelectric
Project (Bradley Project) meet the definition of Required Project Work as that term is
defined in the Agreement for the Sale and Purchase of Electric Power by and among
The Alaska Power Authority,1 The Chugach Electric Association, Inc., The Golden
Valley Electric Association, Inc., The Municipality of Anchorage d/b/a Municipal Light
and Power, The City of Seward d/b/a Seward Electric System, The Alaska Electric
Generation & Transmission Cooperative, Inc., Homer Electric Association, Inc., and
Matanuska Electric Association, Inc., dated December 8, 1987 (PSA).
1 Alaska Power Authority is the predecessor agency to the Alaska Energy Authority (AEA).
Stefan Saldanha
August 20, 2021
Page 2
The BPMC 2 and AEA3 have identified certain opportunities to optimize the value
provided by the Bradley Project to the customers along the Alaska Railbelt. These
“shovel ready” projects are intended to remove transmission constraints, reduce
damaging oscillations, and allow for better use of the Bradley Project’s potential by not
only increasing the ability of the Bradley Project to deliver more energy throughout the
Railbelt system, but to allowing more flexible and cost-effective use of energy from the
Bradley Project.
The BPMC would also like the DOL to confirm that the work identified in the
Bradley Project’s Repair, Replacement and Reclamation Plan (R&R Plan)4 would be
considered Required Project Work. Because of the benefits of moving forward on some
of these projects is substantial, the BPMC is asking that the DOL provide an
accommodation to the BPMC by: 1) immediately providing its response to the BPMC’s
conclusion that two of the projects identified are Project Required Work; and 2) issuing
its determination that a project included in this letter meets the definition of Required
Project Work on a project-by-project basis as soon as practicable once the DOL’s
determination on a project has been made.
I. BRADLEY PROJECT BACKGROUND
The Bradley Project was completed in 1991. It is located 27-air miles northeast of
Homer, Alaska on the Kenai Peninsula. The Bradley Project has 120 MW of installed
capacity and generates between five and ten percent of the total power used by the
electric utilities that serve the Railbelt. The Bradley Project provides some of the lowest
cost power to more than 550,000 Alaskans.
2 The BPMC is the committee authorized under Section 13 of the PSA which is responsible for
the management, operation, maintenance, and improvement of the Bradley Lake Project. The
current members of the BPMC are: AEA, Chugach Electric Association, Inc. (Chugach), Golden
Valley Electric Association, Inc. (GVEA), City of Seward, d/b/a Seward Electric System
(Seward), Homer Electric Association, Inc. (HEA), and Matanuska Electric Association, Inc.
(MEA).
3 AEA’s mission is to reduce the cost of energy in Alaska. The statutory responsibilities of AEA
are outlined in Alaska Statute (AS) 44.83.070.
4 The R&R Plan is prepared every five years for the Bradley Project by outside engineering
consultant, D.H. Hittle & Associates, Inc., and identifies equipment and facilities at the Bradley
Project which are in need of repair or replacement.
Stefan Saldanha
August 20, 2021
Page 3
The BPMC and AEA have partnered on projects that have enhanced the benefits
produced by the Bradley Project through the years that the Bradley Project has been
operational. From 1995 through 2018, the Bradley Project averaged 386,000 MWh of
generated energy annually. In the Fall of 2020, the West Fork Upper Battle Creek
Diversion Project was completed. By diverting glacial water from the West Fork Upper
Battle Creek for use by the Bradley Project, the Bradley Project now averages another
approximately 37,300 MWh of generated energy annually, or about a ten percent
increase totaling about 423,300 MWh of generation annually.
AEA recently purchased certain transmission facilities 5 from HEA with the
purpose of making the transmission path for delivery of power generated by the Bradley
Project more robust and resilient. The purchase of the transmission assets from HEA
was intended to be the first step towards upgrading the transmission facilities delivering
energy produced by the Bradley Project. The increased transmission capability will
reduce energy losses and further enable the efficient, reliable delivery of the output from
the Bradley Project. This transaction was reviewed by the DOL and determined that with
the approval of all parties to the PSA, and studies or reports supporting the economics
and industry standards, the transaction can be seen as necessary to keep the Bradley
Project in good and efficient operating condition, consistent with national industry
standards and sound economics. The conclusion was that the AEA/HEA transaction
could be Required Project Work.6
The BPMC O&D Committee and consulting engineer for AEA, EES Consulting,
provided additional review and analyses and came to the conclusion that the transaction
was Required Project Work. The AEA deemed the transaction to be Required Project
Work.
5 The principal part of the transaction involved the sale of the transmission line from Sterling
Substation to Quartz Creek Substation (SSQ Line). Also included in the transaction were: 1) the
sale of transmission capacity between Soldotna Substation and Sterling Substation (SS Line);
2) certain rights regarding the SS Line; 3) the purchase of right-of-way containing an unused
69kV transmission line between Sterling Substation and Quartz Creek Substation; and 4) the
planning for future upgrades of the SQ Line and the SSQ Line. Certain permits allowing access
to the Kenai Wildlife Refuge were also transferred.
6 See Memorandum to BPMC participants, AEA Board of Directors, and Curtis Thayer, AEA
Executive Director from Stefan A. Saldanha dated May 20, 2020.
Stefan Saldanha
August 20, 2021
Page 4
AEA and BPMC wish to further improve the value of the Bradley Project by
unconstraining the transmission facilities that deliver the energy generated by Bradley
Project.
II. THE CHALLENGE – ELECTRIC TRANSMISSION SYSTEM NEEDS UPGRADE
The BPMC and AEA want to improve the transmission grid from Homer to
Fairbanks to foster sustainable low-cost clean energy to grow the economy and make
Alaska a great place to work, live, and play. The current system is not capable of
maximizing efficiency of energy deliveries and has not been reliable for firm energy
transactions. Moreover, access to renewable clean energy is difficult today. Resources
such as wind, solar and hydroelectric are often located outside the urban area, requiring
adequate and reliable transmission to reach populated areas.
The improvements being considered by the BPMC and AEA to the existing
electric utility grid are designed to have the electric delivery system in the Railbelt be
unconstrained and allow adequate access to all those wishing to transmit power.
Indeed, AEA has identified projects that would provide looped transmission service that
will improve transfer capability, provide redundancy, and provide open access to all
Railbelt utilities and Independent Power Producers (IPPs). The total capital required for
these projects is significant.
Having an unconstrained Railbelt electric grid is the goal of the Railbelt utilities.
The BPMC plans to continue to review, consider, and develop the various projects
needed to unconstrain the entire Railbelt electric grid and maximize the benefits
produced by the Bradley Project through a series of capital project plans. The first
phase of the BPMC’s effort is designed to optimize Bradley Project’s value without
incurring significant additional costs to Alaskans and is the subject of this letter.7 The
current transmission path from Bradley Project to Anchorage is limited to 75MW due to
grid stability. The addition of grid stability-enhancing batteries has been shown to raise
this stability limit to 95 MW. Further, the conversion of the entire line from Bradley
Project to Anchorage to 230 kV increases the ability to transfer Bradley Project’s energy
off of the Kenai. The first phase of the BPMC’s plan will serve to enhance the
7 The BPMC expects to be requesting determinations from the DOL regarding whether such
projects are also Required Project Work under the PSA in the future.
Stefan Saldanha
August 20, 2021
Page 5
deliverability of the energy generated at the Bradley Project to protect the Bradley
Project from potentially damaging large-scale grid power oscillations.
III. PHASE 1 PROJECTS TO ENHANCE DELIVERABILITY OF BRADLEY
PROJECT ENERGY
The Phase 1 proposed projects included in this letter are intended to remove
transmission constraints and allow for much better use of the Bradley Project’s potential
for the benefit of Railbelt electric customers. The transmission upgrade projects involve
the transmission facilities that delivery Bradley Project energy from Bradley Junction to
Soldotna Substation. The projects have been broken out separately for review; the
segment between Bradley Junction and Sterling Substation; has been subdivided into
two sections, the segment between Bradley junction and Soldotna and the segment
between Sterling Substation and Soldotna Substation. Together, these projects are
estimated to cost $66 million.
A. 115 kV Transmission Line between Bradley Junction to Soldotna Substation
This project will allow for increased power flow from the Bradley Project through the
construction of a second 115 kV transmission line from Bradley Junction to the
Soldotna Substation. Additionally, this line will remove the current constraint on the
Bradley Project when the existing Bradley Junction to Soldotna line is out of service.
HEA’s current line between Bradley Junction and Soldotna will continue to be used
however, Bradley Project energy will be shared between the two parallel lines and
losses will decline significantly; particularly at higher production levels. Building a
second line requires the construction of a 115 kV switchyard at Bradley Junction.
This transmission line will become part of the Bradley Project.
B. Upgrade to Transmission Line between Soldotna Substation and Sterling
Substation
This project will allow for increased power flow from the Bradley Project through the
construction of an upgrade of the transmission line from 115 kV to 230 kV from the
Soldotna Substation to the Sterling Substation in accordance with the results of
engineering studies. This transmission facility upgrade was an expected component
of the acquisition of transmission capacity rights by AEA on the Soldotna to Sterling
Transmission Line Segment (SS Line) subject to reservation or HEA’s native load
Stefan Saldanha
August 20, 2021
Page 6
requirements and for AEA to have the right to require maintenance and upgrades on
the Sterling Segment.8 The SS Line (as well as the transmission line between the
Sterling Substation and Quartz Creek Substation) are the sections of the Bradley
Project to Anchorage interconnection that incur the most significant energy losses.
These line losses currently result in a significant reduction of Bradley energy as it
transitions through these line sections. This additional transmission capacity will
become part of the Bradley Project.
C. Upgrade to Transmission Line between Sterling Substation to Quartz Creek
Substation
This proposed project is intended to increase power delivery from the Bradley
Project. The project involves the upgrade of the transmission line between the
Sterling Substation and Quartz Creek Substation (SSQ Line) from 115 kV to 230 kV.
The SSQ Line is part of the Bradley Project. All property rights and obligations in the
SSQ Line were purchased by AEA in 2020 and made part of the Bradley Project.9
This project includes approximately 50 miles of a transmission line. It would also
upgrade the switchgear in the Soldotna Substation, Sterling Substation, and Quartz
Creek Substation to 230 kV. As noted above, Bradley Lake output is significantly
reduced as it transitions these line sections. This project is estimated to cost
$53 million.
D. Battery Energy Storage Systems for Grid Stabilization
Large-scale power oscillations are damaging to powerplants and other equipment.
Large-scale power oscillations generated by the interaction of the Bradley Project
with the Railbelt grid were identified in the original the commissioning test results of
the Bradley Project. Using Bradley Project funds, significant investment was made
by the Purchasers of Bradley Project energy to mitigate these damaging events. In
8 See SECOND AMENDMENT TO AGREEMENT FOR SALE OF TRANSMISSION
CAPABILITY by and among The HOMER ELECTRIC ASSOCIATION, INC. and The
CHUGACH ELECTRIC ASSOCIATION, INC., The GOLDEN VALLEY ELECTRIC
ASSOCIATION, INC., The MUNICIPALITY OF ANCHORAGE d/b/a MUNICIPAL LIGHT &
POWER, and The ALASKA ELECTRIC GENERATION AND TRANSMISSION COOPERATIVE,
INC., dated effective December 17, 2020.
9 See THIS PURCHASE AND SALE AGREEMENT between Alaska Electric and Energy
Cooperative, Inc., Homer Electric Association, Inc, and Alaska Energy Authority, dated effective
December 17, 2020.
Stefan Saldanha
August 20, 2021
Page 7
1990s these power oscillations were responsible for the cracking of buckets on the
Bradley Project runners. Subsequent analysis and mitigation resulted in replacement
of the runners, deflectors (with dividers) and other control systems. These changes
were sufficient to dampen the oscillations for the makeup of the Railbelt grid at the
time.
As the Railbelt grid has evolved, these oscillations have returned at an even larger
scale than previously experienced. It is likely that the generator stator damage to the
Bradley Project generator in 2019 was a result of these oscillations. Studies have
determined that Battery Energy Storage Systems (BESS) are required to “fix” the
Railbelt operating point outside these unstable zones. Thus, BESS located in each
region of the Railbelt grid (Fairbanks, Kenai, and Central)10 are required for system
stabilization, and to prevent damage to the Bradley Project.11 Further, BESS high-
speed action will provide valuable response to electric utility system disturbances
and allow the use of Bradley Project spinning reserve in an effective and economical
way.
The BESS projects consist of an upgrade to existing BESS system in Fairbanks, and
also new BESS systems in the Kenai, and Central regions of the grid. The Fairbanks
BESS is located at the Wilson substation, the Kenai BESS is to be located adjacent
to the Soldotna Substation, the Central Region BESS will be located at Chugach’s
International Station (and potentially a portion near Fossil Creek). It is noted that
studies have shown that in the future, BESS will be needed to fully realize the
benefits of a 230 kV bulk power supply system and to integrate a second line
between Anchorage and the Kenai.
These BESS related projects are estimated to cost between $115 and $145 million
depending on technology choices for the Fairbank’s BESS ($10 million to
$40 Million). The BESS project located adjacent to the Soldotna Substation
10 Technically, these regions are defined in this way due to the nature of the transmission lines
which join the load load-balancing areas in each of these regions together. Stabilizing the grid
operating point in each region will prevent the regions from electrically “swinging” against each
other when there is a disturbance. Fixing the operating points in this way will maintain regional
and overall grid operation outside these unstable zones.
11 Other generators along the Railbelt will also receive the benefit from these system
stabilization efforts.
Stefan Saldanha
August 20, 2021
Page 8
represents an investment of approximately $45 million and the central region BESS
is estimated to cost approximately $60 million.
E. Study of Alternative Path to Export Energy Off the Kenai Peninsula
A second transmission line to export energy from the Kenai Peninsula is critically
important to the Railbelt bulk power system and to reliability deliver the full output of
Bradley Lake to northern participants. A second transmission line was anticipated at
the time of construction of the Bradley Project.12 The BPMC and AEA propose to
study the feasibility of the best alternative transmission line path to deliver Bradley
Project energy off the Kenai Peninsula. The study is estimated to cost up to
$500,000.
As noted above, the proposed projects included in Phase 1 are intended to
remove transmission constraints and allow for much better use of the Bradley Project’s
potential for the benefit of Railbelt electric customers. The following table provides a
summary of the Phase 1 projects.
Summary Table -Estimated Costs of the Phase-One Projects
Description Estimated Cost
Bradley Junction to Sterling $ 66,000,000
Sterling to Quartz Creek $ 53,250,000
Grid Stabilization Batteries* $ 145,000,000
Second Southern Intertie Study $ 500,000
Total $ 264,750,000
*Depending on requirements for the
Fairbanks installation this amount could be
reduced $30M
12 Sec 29(a), Section 32 Bradley Lake Power Sales Agreement, Preamble to the Services
Agreement For Bradley Lake Energy pp. 1-2.
Stefan Saldanha
August 20, 2021
Page 9
IV. REQUIRED PROJECT WORK
Required Project Work is defined in the PSA to mean “…repairs, maintenance,
renewals, replacements, improvements or betterments required by federal or state law,
a licensing or regulatory agency with jurisdiction over the [Bradley] Project, or this
Agreement, or otherwise necessary to keep the [Bradley] Project in good and efficient
operating condition, consistent with (1) sound economics for the [Bradley] Project and
the Purchasers and (2) national standards for the industry.”13 In other words, for the
proposed projects to be considered “Required Work” under the PSA, the work must be
intended to keep the project in good and efficient operating condition. The measures of
this work must: (1) be based on sound economics for the Project and the Purchasers,
and (2) be consistent with national standards for the industry.14
The BPMC is requesting the DOL to determine that the above-referenced
proposed projects (and analyzed below) to enhance the efficiency and deliverability of
Bradley Project energy, which are the subject of this letter, are improvements necessary
to keep the Bradley Project in good and efficient operating condition, consistent with
national industry standards and sound economics, i.e., the proposed projects meet the
definition of Required Project Work as that term is defined in the PSA. The following
section of this letter provides summary analyses which shows the above-referenced
proposed projects do meet the definition of Required Project Work as that term is
defined in the PSA.
V. EVALUATION OF PHASE 1 PROJECTS
A. 115 kV Transmission Line between Bradley Junction to Sterling Substation
Two 115 kV transmission lines deliver power from the Bradley Project around the
north end of Kachemak Bay to Bradley Junction. From there, one line travels north
to the Soldotna Substation and one line travels southwards towards Homer and from
13 See Section 1 (hh) of the PSA, Required Project Work.
14 For purposes of the Power Revenue Bond Resolution (Bond) “national standards for the
industry" was deemed to be defined by Prudent Utility Practice. The Bond defines Prudent Utility
Practice generally as “…any of the practices, methods, and acts, engaged in or approved by a
significant portion of the electric utility industry at such time, or which, in the exercise of
reasonable judgment in the light of facts known at such time could have been expected to
accomplish the desired result at the lowest reasonable cost consistent with good business
practices, reliability, safety, and reasonable expedition…” See Bond at Article I, Section 101.
Definitions “Prudent Utility Practice.”
Stefan Saldanha
August 20, 2021
Page 10
there travels near the western shore (Western Segment) of the Kenai Peninsula to
Soldotna. The western loop and the single line 115 kV line connecting directly to the
Soldotna substation limit the amount of energy that can be transported from the
Bradley Project to the Soldotna Substation, and from Soldotna to the other Railbelt
utilities.
B. Upgrade to Transmission Line between Soldotna Substation and Sterling
Substation
As noted earlier, the potential for upgrading this portion of the transmission facilities
which deliver power from the Bradley Project was contemplated when AEA
purchased the various property rights and transmission facilities from HEA in 2020.
The additional Bradley Project 230 kV upgrade will increase energy flow from the
Bradley Project to the north and will also provide some system redundancy resulting
in additional system reliability.
The current configuration of the SS Line is not capable of transporting all participants
full capacity share at the same time without incurring significant line losses. This
upgrade will allow the SS Line to transmit the entire output of the Bradley Project
when all of the projects contemplated by AEA and the BPMC are complete.
C. Upgrade to Transmission Line between Soldotna Substation to Quartz Creek
Substation
The upgrade of the SSQ Line from 115 kV to 230 kV was contemplated when AEA
purchased the transmission facilities from HEA in 2020. The BPMC O&D Committee
concluded that upgrading the SSQ Line will save power and reduce utility system
stress making the Bradley Project more efficient and reliable. 15
The SSQ line is currently operated at 115 kV and crosses land owned by private
individuals as well as several government entities, including the Kenai National
Wildlife Refuge. The SSQ Line utilizes wood pole construction over a combination of
mountainous and swampy terrain. The SSQ Line was originally constructed to
interconnect HEA and Chugach Electric Association, Inc., service territories, and
15 See Report of the Bradley O&D Committee Review of the Proposed Transaction at page 1
of 10.
Stefan Saldanha
August 20, 2021
Page 11
later was utilized to provide the pathway to access Bradley Project power by the
northern utilities located North of the Kenai Peninsula. The SSQ Line is rated for
75 MW during normal operation and 85 MW during emergency operation such as
Pending Spill at the Bradley Project. The Bradley Project is rated at 120 MW. The
current configuration of the SSQ Line is not capable of transporting all participants
full capacity share at the same time. This upgrade will allow the SSQ Line to transmit
the entire output of the Bradley Project when all of the projects contemplated by AEA
and the BPMC are complete.
The BPMC O&D Committee concluded that there would be additional immediate
benefits to upgrading the SSQ Line which would be a reduction in losses on the line.
The analysis performed by the BPMC O&D Committee estimated that as much as
11,144 MWh per year could be saved if the SSQ Line was upgraded. Based on the
accepted average value of Bradley Project Power at the rate of $50/MWh this would
be an additional $557,000/year of benefit to the Purchasers of Bradley Project
Power if the SSQ line was upgraded.16
D. Battery Energy Storage Systems for Grid Stabilization
A BESS has the ability to deliver or absorb power-based system frequency
variations and on commands received from the System Control And Data Acquisition
(SCADA) System. The BESS can also do this much more rapidly than any traditional
generating station with the ability to deliver or take energy in as little as 100 msecs
(1/10 of a second). From a control standpoint, the BESS offers much greater
flexibility and control for the system by the speed and dual directionality in which it
can operate. The BESS can be used to provide “deliverable” spin and regulation that
is difficult and problematic with thermal units on a small system such as the Railbelt.
This operational advantage comes from the fact that the BESS’s solid state controls
are much quicker, precise, and controllable than are governor systems for thermal
units.
As noted above, since commissioning, large-scale power oscillations have been
shown to be caused be the interaction of the Bradley Project with the Railbelt Grid.
The Bradley Project is the southern “anchor” of these oscillations and all energy
16 See Report of the Bradley O&D Committee Review of the Proposed Transaction at page 7 of
10.
Stefan Saldanha
August 20, 2021
Page 12
associated with the oscillations is eventually reflected in the mechanical system of
the Bradley Project generators. The ability of the BESS to precisely deliver spin and
regulation in response to system variations and disturbances in the millisecond
timeframe allows the BESS to “fix” the operating point of the load balancing region in
which it located nearly precisely at 60 Hz. As noted above, fixing the regional and
combined Railbelt grid operating point of the at 60 Hz. maintains grid operations
outside the unstable zones (poles) found in the right half of the complex frequency
plane (i.e., sigma plus j-omega plane). Operating outside these unstable zones will
prevent uncontrolled large-scale power oscillations. Such oscillations can potentially
damage the Bradley Project as well as other generators and may cause
unanticipated system cascading regional grid black-outs.
The transmission line that delivers the power from the Bradley Project is called the
Anchorage-to-Kenai intertie or the Southern Tie. The Southern Tie’s transfer
capability is stability-limited to 75 MW and differs somewhat from the traditional
NERC definition of “transfer capability” since it is only one path, albeit a long one,
and transfer capability generally refers to the total ability to transfer power over
multiple paths. There are many factors that go into determining what the limit is for
total transfer capacity of an intertie. In the case of the Southern Tie, the line is
relatively long for the size of the Railbelt System, so voltage collapse and power flow
oscillations are a real concern. The Static VAR Compensators (SVCs) at Soldotna
and Daves Creek were installed by AEA to deal with the voltage collapse issue and
to limit power oscillations with their power oscillation dampeners (POD). The SVCs
at Soldotna and Daves Creek are part of the Bradley Project.
The inertia of the bulk electrical system provides a reasonable measure of the
stability of the system or grid. At the time of the construction of the Bradley Project,
heavier “frame” combustion turbines constituted most of the prime movers in the
Railbelt. These machines, being heavier, were much less efficient, yet they provided
significantly more system inertia. Currently the combustion turbines used on the
Railbelt are the mostly lighter and more efficient aero-derivative combustion
turbines, the evolution to these types of prime movers has resulted in a net decrease
in Railbelt system inertia. Further, the introduction of non-dispatchable renewables,
and plant control system response have resulted in a significant degradation of
frequency control and thus variation in the grids operating point
As noted above, a BESS can maintain the operating point of the region at a nearly
fixed point and thus prevent oscillations. Further, the BESS control systems can be
Stefan Saldanha
August 20, 2021
Page 13
tuned, much like an SVC, to some degree to dampen system power flow oscillations
should they occur. Due to the decoupling of Watts and VARS, dampening with a
four-quadrant real-reactive power device like a BESS, will, by definition, be more
effective than dampening by a two-quadrant device like and SVC POD. As noted
above, a BESS is required in each region to fix the relative operating points and
prevent the region area from “Swinging” against each other. Such a configuration will
enhance the Bradley Project and system stability and provide support under most
foreseeable conditions. The eigen vector/value-analysis, power flow and transient
stability studies will determine the optimal control setting for each BESS. It is
important to note that the BESS will also provide storage for hydroelectric energy to
reduce the need for water spillage, facilitate peak shaving, and shifting and enhance
the integration of a non-dispatchable renewables. The BESS will help prevent large
scale power outages on the Railbelt. The type of storage provided by the BESS is
particularly important to the array of projects under consideration by AEA and the
BPMC.
The regional BESS will provide real power control to effectively fix the regional
operating points at 60 Hz.; backup reactive power control to aid the SVCs voltage
support; and provide enhanced transfer capability across the Southern Tie
increasing it from 75MW to 95 MW. However, most important, the BESS will limit
oscillations in the grid preventing damage to machines and aiding in the effective
and efficient delivery of Bradley Project energy and capacity.
E. Study of Alternative Path to Export Energy Off the Kenai Peninsula
To fully realize the economic benefits of a 230 kV system, redundant paths for
transmission of power will ensure energy security and resiliency for the region and
allow for firm power transfers thus reducing the cost to the end-users and promote
economy energy sales between regions. A feasibility study is required to determine
the best alternate transmission path for delivery of Bradley Project energy.
VI. R&R PLAN
The R&R Plan is the product of a review of the equipment and facilities of the
Bradley Project by an independent engineering firm. The review takes place every five-
years. The results of the review are reported to HEA, the Operator of the Bradley
Project. This plan ensures that Bradley Project will continue to provide clean, cost-
Stefan Saldanha
August 20, 2021
Page 14
effective energy in the future. A copy of the 2016 R&R Plan report is provided with this
letter. The current update is being finalized at this time.17
VII. SPECIAL ACCOMMODATION
The benefits of the upgrade to the SSQ Line and performing the tasks identified
in the R&R Plan are of substantial value to the Bradley Project. The BPMC would like to
immediately begin work on these two projects to obtain the benefits for the Bradley
Project as soon as possible. The BPMC believes that both of these projects clearly
meet the definition of Required Project Work as that term is defined in the PSA.
Therefore, given the BPMC’s desire to immediately move forward on these two projects,
the BPMC respectfully requests that the DOL inform the BPMC immediately if the
BPMC’s understanding understanding is different than that held by the DOL. Moreover,
if practicable, the BPMC respectfully requests that the DOL issue its determination on
any of the other projects discussed in this letter on a sequential basis. In other words,
the BPMC asks that the DOL issue its determination on each of the projects identified in
this letter as that determination is made.
VIII. SUMMARY & CONCLUSION
AEA has the authority to improve and maintain its power projects.18 The projects
described herein will increase the ability of the Bradley Project to transmit the energy
generated in greater amounts with more flexibility and efficiency; a true betterment of
current circumstances. Moreover, prior review and analysis of the projects as part of the
aforementioned purchase of HEA transmission facilities by AEA indicates the projects
are prudent and economically sound.
The improvements resulting from the development of these proposed projects
will serve, over time, to effectively reduce the per unit cost of power generated by the
Bradley Project to the benefit of all Railbelt electric consumers. The transmission
upgrades between Bradley Junction Substation to Soldotna Substation will increase the
amount of power flowing from the Bradley Project and increase the flexibility and
efficiency of the system. The upgrades to the Bradley Project’s SSQ Line will also
increase the amount of power flowing from the Bradley Project and significantly reduce
17 The next iteration of the R&R Plan report is expected in the Fall of 2021.
18 AS 44.83.080(5).
Stefan Saldanha
August 20, 2021
Page 15
line losses currently being experienced. While the prudency of studying the potential
development of a redundant path for transmission of power from the Bradley Project
that will ensure energy security and resiliency for the region and allow for firm power
transfers which would reduce the cost to the end-users and promote economy energy
sales between regions in the bulk power system is clear, it is important to understand
the economics of having an alternative path for delivering the energy generated by the
Bradley Project. The development and installation of BESS to support the work of the
SVCs installed by the Bradley Project will provide further system stabilization and
provide a better response to system disturbances in the most economical way. It is
noted that while there is no doubt that the development of the BESS will provide
immediate identifiable benefits, the development of BESS will become a necessary
component of the transmission system to fully realize the benefits of a 230 kV bulk
power supply system along the Railbelt in the future. An alternative transmission path
for delivery of energy from the Bradley Project would provide a significant level of
additional reliability to utilities located north of the Kenai Peninsula that purchase energy
generated by Bradley Project.
All of the work recommended in the R&R Plan involves repairs, maintenance,
renewals, replacements, improvements or betterments to keep the Bradley Project in
good and efficient operating condition. Indeed, that is the primary purpose of using an
outside engineering consultant; to receive independent advice on recommended work to
keep the Bradley Project in good working order.
The projects described in this letter are designed to keep the Bradley Project in
good and efficient operating condition by maintaining the current equipment and
facilities as well as increasing the efficient deliverability of the energy generated at the
Bradley Project. Much of the economics surrounding these projects were examined as
part of the Proposed Transaction which was the subject of the DOL’s memorandum
dated May 20, 2020.19 The conclusion of the various reviews was that the upgrading the
deliverability of the Bradley Project was economically sound and evidence of Prudent
Utility Practice.
19 See Report of the Bradley O&D Committee Review of the Proposed Transaction and EES
Consulting’s Engineers Report to AEA dated October 26,2020.
Stefan Saldanha
August 20, 2021
Page 16
As always, please do not hesitate to contact me should you have any questions
or desire further information, including any of the documents and analyses referenced in
this letter. Thank you.
Sincerely,
Kirk H. Gibson, Counsel to the BPMC
C: BPMC (Electronically)
813 West Northern Lights Boulevard, Anchorage, Alaska 99503 T 907.771.3000 Toll Free 888.300.8534 F 907.771.3044
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
Board Action and Media Coverage for Power Revenue Bonds
Aug. 3, 2022 Board Meeting
Old Business
BPMC’s prepayment of certain debt obligations to the SSQ
Line
July 26, 2022 NRECA Alaska Co-ops Work With State to Improve Railbelt Transmission Capacity
June 5, 2022 Petroleum News AEA, Railbelt utilities to modernize, boost capacity of Kenai Pen. system
May 29, 2022 Fairbanks Daily News-Miner $200 million upgrade powers energy improvements in Railbelt communities
May 27, 2022 ADN Alaska utilities plan $200M investment in grid to boost renewable power, increase reliability
May 26, 2022 Alaska Public Media Major upgrade to Railbelt transmission lines could pave the way for more renewable energy
May 25, 2022 Press Release AEA, Railbelt Utilities Unveil More Than $200 Million in Transmission Upgrades
May 25, 2022 Board Meeting Old Business Required Project Update / Law MEMOS: (1) Soldotna to Sterling; (2) BESS Purchase; (3) Bradley to Junction to Soldotna; (4) D. Hitle Report; (5) Sterling to Quartz
April 13, 2022 Board Meeting New Business BPMC Required Project Work and Department of Law Memo
Jan. 27, 2021 Board Meeting Director Comments
Bradley Lake Required Project Work Update
Dec. 15, 2021 Press Release AEA Statement on Governor Dunleavy’s Budget Proposal for Fiscal Year 2023
Dec. 8, 2021 Board Old Business Bradley Lake Required Project Work Memo and Letter from BPMC Utilities to LAW
Nov. 12, 2021 Petroleum News AEA evaluating Bradley Lake expansion with Dixon Glacier melt
Aug. 12, 2021 Board Meeting New Business Resolution 2021-03 Alaska Energy Authority Investigate and Develop a Strategic Plan for Railbelt Assets
Jan. 6, 2021 KUAC Utilities Execs Say Alaska Energy Authority’s Power-line Purchase To Promote Hydropower
Dec. 27, 2020 Fairbanks Daily News-Miner GVEA to benefit from Alaska Energy Authority acquisition of transmission line
Dec. 18, 2020 OpEd in ADN The Alaska Energy Authority is helping prepare the Railbelt for tomorrow
Alaska Energy Authority Page 2 of 2
Dec. 17, 2020 Press Release AEA Completes Acquisition of Homer Electric Association’s 115-kV Transmission Line
Dec. 9, 2020 Board Meeting Old Business Resolution 2020-08 Providing for the Sale of Revenue Bonds for Transmission Line Projects (SSQ Line)
Aug. 26, 2020 KTUU Bradley Lake Project expansions likely to benefit ratepayers along the entire Railbelt
Aug. 26, 2020 Alaska Journal Hydro expansion another step in grid improvement
Aug. 6, 2020 Press Release AEA Board Supports Purchase of Soldotna-Quartz Creek Transmission Line
813 West Northern Lights Boulevard, Anchorage, Alaska 99503 T 907.771.3000 Toll Free 888.300.8534 F 907.771.3044
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
Board Action and Media Coverage for Power Revenue Bonds
Aug. 3, 2022 Board Meeting
Old Business
BPMC’s prepayment of certain debt obligations to the SSQ
Line
July 26, 2022 NRECA Alaska Co-ops Work With State to Improve Railbelt Transmission Capacity
June 5, 2022 Petroleum News AEA, Railbelt utilities to modernize, boost capacity of Kenai Pen. system
May 29, 2022 Fairbanks Daily News-Miner $200 million upgrade powers energy improvements in Railbelt communities
May 27, 2022 ADN Alaska utilities plan $200M investment in grid to boost renewable power, increase reliability
May 26, 2022 Alaska Public Media Major upgrade to Railbelt transmission lines could pave the way for more renewable energy
May 25, 2022 Press Release AEA, Railbelt Utilities Unveil More Than $200 Million in Transmission Upgrades
May 25, 2022 Board Meeting Old Business Required Project Update / Law MEMOS: (1) Soldotna to Sterling; (2) BESS Purchase; (3) Bradley to Junction to Soldotna; (4) D. Hitle Report; (5) Sterling to Quartz
April 13, 2022 Board Meeting New Business BPMC Required Project Work and Department of Law Memo
Jan. 27, 2021 Board Meeting Director Comments
Bradley Lake Required Project Work Update
Dec. 15, 2021 Press Release AEA Statement on Governor Dunleavy’s Budget Proposal for Fiscal Year 2023
Dec. 8, 2021 Board Old Business Bradley Lake Required Project Work Memo and Letter from BPMC Utilities to LAW
Nov. 12, 2021 Petroleum News AEA evaluating Bradley Lake expansion with Dixon Glacier melt
Aug. 12, 2021 Board Meeting New Business Resolution 2021-03 Alaska Energy Authority Investigate and Develop a Strategic Plan for Railbelt Assets
Jan. 6, 2021 KUAC Utilities Execs Say Alaska Energy Authority’s Power-line Purchase To Promote Hydropower
Dec. 27, 2020 Fairbanks Daily News-Miner GVEA to benefit from Alaska Energy Authority acquisition of transmission line
Dec. 18, 2020 OpEd in ADN The Alaska Energy Authority is helping prepare the Railbelt for tomorrow
Alaska Energy Authority Page 2 of 2
Dec. 17, 2020 Press Release AEA Completes Acquisition of Homer Electric Association’s 115-kV Transmission Line
Dec. 9, 2020 Board Meeting Old Business Resolution 2020-08 Providing for the Sale of Revenue Bonds for Transmission Line Projects (SSQ Line)
Aug. 26, 2020 KTUU Bradley Lake Project expansions likely to benefit ratepayers along the entire Railbelt
Aug. 26, 2020 Alaska Journal Hydro expansion another step in grid improvement
Aug. 6, 2020 Press Release AEA Board Supports Purchase of Soldotna-Quartz Creek Transmission Line
AEA at 6/15/22 9/30/22 Update
Column1 Column2 Column3
October
Issued financial statements submitted to SOA (finals due 10/17/22-see DOA DOF ACFR
letter dated 6/3/22)10/26/2022 Week of 12/19/22
Board meeting to review final draft of financial statements 10/26/2022 Week of 12/19/22
BAS Committee meeting - review final draft of financial statements 10/11/2022 Week of 12/19/22
Draft financial statements submitted to Legislative Budget & Audit and DOA 10/3/2022 12/16/2022
September
Provide last draft financial statements to auditors 9/30/2002 11/30/2022
Auditors complete testing of State items (GASB 68 PERS & GASB 75 OPEB)9/28/2022 11/21/2022
Provide State items (GASB 68 PERS & GASB 75 OPEB) to auditors 9/21/2022 11/21/2022
Final Federal Schedule due to SOA - SEFA 11/15/2022
Subrecipient Pass-Through Report due to SOA 9/16/2022 11/16/2022
Advances schedule due to SOA (per SOA ACFR letter June 2022)9/7/2022 11/7/2022
Final Fieldwork week 4 (remote)9/12/2022 10/31/2022
Final Fieldwork week 3 (remote)9/5/2022 10/24/2022
August
Final Fieldwork week 2 (on-site)8/29/2022 N/A
Final Fieldwork week 1 (remote)8/22/2022 10/17/2022
Send Auditors GL details, payroll, and final draft trial balances (not including items
pending from State) through 6/30 8/15/2022 10/15/2022
PCE sweep calculation workpapers to DOF for review 8/15/2022 N/A
All fund workpapers completed 8/15/2022 10/15/2022
SBED & RDIF Loan fund loan loss analysis due to AIDEA N/A N/A
SBED & RDIF Loan fund schedules due from DCCED (AIDEA to e-mail deadlines)N/A N/A
Final reconciliations reviewed 8/15/2022 10/12/2022
Follow up to track down all legal invoices (internal and external)TBD Aug 2022 8/30/2022
Request RSA's be closed out by 8/xx/22 (Karin to check on SOA deadline) TBD Aug 2022 10/6/2022
Federal quarterly reports & draws due N/A 10/31/2022
Prepare PCE estimate and final draw N/A 8/5/2022
All reconciliations completed 8/5/2022 10/14/2022
Operating budget to actual review/adjustments 8/5/2022 10/6/2022
ICAP/GAD/Indirects posted & T's complete (dependent upon payroll)7/29/2022 9/21/2022
Payroll Accrual for end of month 7/29/2022 N/A
AIDEA CIP Receipt Entry to be posted 8/2/2022 N/A
July
Final 6/30 Payroll posted (allocation posted as well)7/29/2022 8/31/2022
Final day for accruals & adjusting entries completed 7/25/2022 10/6/2022
Investments done (including accr int.)7/22/2022 10/6/2022
7/10/22 Payroll (includes end of June) download 7/22/2022 8/31/2022
Finance turnaround - FY22 Close Out Only (7/25 - 8/5)N/A N/A
FY22 Annual Audit
Internal Year-End Schedule
As of October 07, 2022
AEA at 6/15/22 9/30/22 Update
FY22 Annual Audit
Internal Year-End Schedule
As of October 07, 2022
Loan reports to Finance for AIDEA and PPF 7/19/2022 7/19/2022
Travel/CC posted 7/22/2022 8/30/2022
A/P cutoff (week of) - last AP run 7/22/2022 7/29/2022
Get estimate of outstanding invoices for AIDEA/AEA from PM's 7/15/2022 7/15/2022
Prepare interest paybacks to SOA 9/2/2022
Loan Confirms generated (AEA and AIDEA)7/11/2022 7/25/2022
Loan Close out for 6/30 (all payments posted)7/11/2022 7/11/2022
Begin review of open encumbrances-operating budget/closeout NTP's expiring 6/30
(use Jet Report)7/8/2022 9/5/2022
Reconciled CC statements to Finance from all employees 7/5/2022 8/30/2022
All TA's to accounting (any travel done last week of June due 7/8/22)7/8/2022 8/3/2022
Begin review of open RSA's-initiate close out for RSA's terming 6/30 7/8/2022 9/8/2022
RCA & legal invoices - send email to get outstanding invoices or estimates before final
AP run 7/8/2022 8/25/2022
AEA Payback AIDEA 6/28/2022
Update memo's to audit files 7/8/2022 9/8/2022
June
Coordinate with DOF ACFR staff to confirm GASB 68 PERS & GASB 75 OPEB delivery.
Tentatively expected by Sep 15.6/27/2022 N/A
Send out credit card statements (PDF) to employees 6/27/2022 6/27/2022
Controller Request Investment Managers not trade over 6/30 6/15/2022 N/A
TEAMS coordination meeting with DOA DOF 6/27/2022 8/3/2022
Email to project managers for them to contact vendors re: YE invoices 6/1/2022 6/25/2022
E-mail to Staff to turn in TA's & submit c/c recons 6/1/2022 6/1/2022
May
Confirm w/ DCCED deadline for Loan fund schedules (requested by 8/16/2022)5/13/2022 N/A
Preliminary Federal Schedule due to SOA 5/13/2022 5/13/2022
March
Pre Audit Staff Meetings - Weekly and Ongoing 3/14/2022 3/14/2022
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
PRESS RELEASE
Contact Information:
Alaska Energy Authority: Brandy M. Dixon, (907) 771-3078, bdixon@akenergyauthority.org
Golden Valley Electric Association: Meadow Bailey, (907) 451-5676, mpbailey@gvea.com
FOR IMMEDIATE RELEASE
September 27, 2022
AEA and GVEA Awarded $12.8 Million Grant to Expand Electricity to Black Rapids Training Site
(Anchorage) — The Department of Defense announced Friday that the Alaska Energy Authority (AEA) was awarded a $12,752,540 grant from the Office of Local Defense Community Cooperation under the Defense Community Infrastructure Pilot Program.
The grant was applied for by AEA in collaboration with Golden Valley Electric Association (GVEA) and will support the construction of a 34-mile electric distribution line extension along the Richardson Highway to the Black Rapids Training Site (BRTS). “We are honored to partner with GVEA on this important infrastructure project that supports our military,” said Curtis W. Thayer, AEA Executive Director. “This extension will improve long-term sustainability and reliability for Black Rapids by tying them into GVEA’s power grid. This project fits squarely within Governor Dunleavy’s strategy of developing and implementing low-cost-reliable energy solutions for Alaskans.” “We recognize and value the military’s vital presence in Interior Alaska,” said John Burns, GVEA President. “We are proud to expand electric service to further support the mission of our military members. This line extension will enable Black Rapids to transition from diesel generator power, which will improve resiliency, save money and benefit the environment.”
Operated by Fort Wainwright, Black Rapids is a primary site for state-of-the-art cold weather
and mountain warfare tactics and techniques training for the United States military. Currently,
the site is solely dependent on power supplied by diesel fuel generators. The Department of
Defense estimates that the savings due to reduced operational costs and deferred capital
improvements will pay for the line extension within a few years.
GVEA is a not-for-profit member-owned cooperative that has operated for 76 years in Interior
Alaska. GVEA’s existing power line ends about 10 miles south of Delta Junction, and
approximately 30 miles north of Black Rapids.
Design and permitting for the new distribution line will begin immediately, with construction
anticipated to begin in late 2023. The project is scheduled for completion by late 2025.
Alaska Energy Authority Page 2 of 2
The Defense Community Infrastructure Pilot Program is a competitive program that assists
states and communities in the development of infrastructure enhancements including resiliency
measures that support mission-critical military operations and quality of life benefits for local
service members and their families. BRTS is a primary site for state-of-the-art cold weather and
mountain warfare tactics and techniques training for the U.S. military. # # #
Alaska Energy Authority supports critical projects that improve energy safety, reliability and affordability through the development, operations and financing of energy projects around the state. Golden Valley Electric Association serves over 100,000 residents in Interior Alaska. The cooperative’s mission is to safely provide members with reliable electric service, quality
customer service and innovative energy solutions at fair and reasonable prices.
OFFICE OF LOCAL DEFENSE COMMUNITY COOPERATION
2231 Crystal Drive, Suite 520
Arlington, VA 22202-3711
…
Mr. Curtis Thayer
Project Manager
Alaska Energy Authority
813 West Northern Light Blvd
Anchorage, AK 99503-2407
Dear Mr. Thayer,
In response to your proposal for Black Rapids Training Center Line Extension in support
of Black Rapids Training Site under the Fiscal Year 2022 Defense Community Infrastructure
Pilot Program, this correspondence formally invites you to make an application for grant funding
of not more than $12,752,540 in Federal funding, for a total $13,024,868 project with the Office
of Local Defense Community Cooperation no later than 5 p.m. PDT on Friday, September 2,
2022.
This invitation reflects the ranking your proposal received from the Defense Community
Infrastructure Pilot Program Review Panel as well as the amount of appropriations available for
this program. It is imperative for this application to remain materially consistent with the scope
and funding of the proposal you provided in response to the May 9, 2022 Defense Community
Infrastructure Pilot Program Notice of Funding Opportunity, including the scope, construction-
ready status, validation of cost estimates and status of funding sources. If you are unable to
submit a grant application, or if we determine your application materially differs from the
proposal that was considered and ranked by the Review Panel, this invitation may be revoked.
A complete grant application by the above date ensures we can perform our due diligence
to ensure the project being funded is reasonable, allowable, and allocable, and issue an award to
be countersigned no later than 5 p.m. EDT Friday, September 23, 2022, to ensure obligation of
funding available for this program.
To assist you with this application and to carry out the proposed infrastructure
enhancement, Tim Robert, timothy.b.robert.civ@mail.mil, (916) 557-7315 has been designated
to be your Project Manager. Any questions related to this invitation may be directed to Tim
Robert or Adam Wright, Program Activity Lead, adam.g.wright8.civ@mail.mil, (571) 721-9861.
We look forward to working with you to enable the completion of this important project.
Sincerely,
Patrick J. O’Brien
Director
O'BRIEN.PATRIC
K.J.1231200319
Digitally signed by
O'BRIEN.PATRICK.J.123120031
9
Date: 2022.08.16 16:36:02 -04'00'
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
RGYAUTHORITY.ORG
MEMORANDUM
TO: Curtis Thayer, Executive Director
FROM: Bryan Carey, P.E., Dirctor of Owned Assets
DATE: October 10, 2022
SUBJECT: IIJA 40101(D) Grid Resiliency Grant Program Update
Description
The Infrastructure, Investment, and Jobs Act (IIJA) Section 40101 D provides funding to states for
improvements in energy resilience, modernize grid infrastructure, invest in decarbonization
solutions, and create good paying jobs. Under the current formula Alaska is elgible to receive
up to $12,100,00 (exclusive of grant funds directly to Indian Tribes) annully for for five years.
Update
When announced in July 2022 the grant application deadline by states was September 30, 2022.
Two public meetings were held in early September about AEA’s plan to distribute funding. In
early September the Department of Energy changed the grant application date to March 31,
2023.
AEA is working with a contractor in writing the Alaska Grid Resilience Implementation Plan
(Plan). Schedule is:
Febraury 2023: Revise Plan and public meetings.
March – April 2023: DOE Plan approval
May-June 2023: AEA issues request for grant applications; AEA receives grant
applications
July – August 2023: AEA and DOE review of applications
September 2023: Issuance of sub-Awards
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
MEMORANDUM
TO: Alaska Energy Authority Board
THRU: Curtis. W. Thayer, Executive Director FROM: Conner Erickson, AEA Planning Manager DATE: October 12, 2022
RE: Renewable Energy Fund (REF) Update
REF Round 14 (FY2023)
The Governor approved and signed, under HB281, the REF Budget of $15 million to fund the 27 Round 14 REF projects as recommended by AEA.
AEA is currently assigning project managers, developing and executing project charters, drafting
and finalizing grant agreements. Currently, the status of the 27 Round 14 REF projects is:
• 8 Grant completed.
• 16 Grants Agreements pending.
o 8 grant agreements with grantee for signature
o 5 grants being drafted by AEA grants coordinator
o 3 grants in sharepoint pending AEA approvals for delivery to grantee for
signature
• 3 Project Management Plans in progress.
o City of Kotzebue - redacted its grant cancellation request – the City has undergone some City Hall personnel changes and is now moving forward with accepting the grant.
o Kongiganak Utility – AEA Project Manager has been in regular contact with the
community, they are wishing to extend their Round 13 grant period of
performance so that all turbine blade replacements can occur at the same time.
Project schedule is currently being refined by the grantee.
o City of Homer – City Council approved the grant scope, City is now finalizing matching funds with sub-contractors.
• All projects have been assigned a project manager.
REF Round 15 (FY2024) Update
AEA submitted its request for $15 million to be appropriated from the State’s General Fund to
fund REF Round 15 projects. Owing to the increase in eligible power consumption for the Power
Cost Equalization (PCE) program, and general poor market performance, funding for Round 15
(FY2024) projects was not requested be appropriated from the PCE endownment fund, as was
done in Round 14 (FY2023).
Alaska Energy Authority Page 2 of 3
On Tuesday October 4th AEA issued its Request for Applications for Round 15 of the REF. The deadline for applications is set for Monday, December 5th, 2022. The tentative timeline for Round 15 is as follows:
• October 4, 2022 – RFA Issued
• December 5, 2022 – Deadline for Submission of Applications
• Late February 2023 – AEA's Evaluation of Applications Complete
• Early March 2023 – REFAC Meeting and Submission of Recommendations to Legislature
• June – July 2023 - Capital funds appropriated by Legislature
• July – August 2023 – Execution of Grant Agreements
REF Program Extension Update
The current sunset date for the REF program is set for June 30, 2023. House Bill (HB) 358 was introduced to the 32nd Legislature for the extension of the REF for another ten years to 2033; the second such extension since the REF’s inception in 2008. The bill was successful in its passage through the House with 38 - 2 yays to nays. The bill was then referred to the Senate. The bill died in the Senate Finance Committee as the clock ran out.The delay in passage of HB 358 was due to Covid-induced delays suffered by the Legislature in the beginning months of the Legislative session.
AEA remains in discussions with those appropriate parties as it plans to pursue the REF extension during the upcoming 33rd legislative session in January 2023.
Attachments
Attachment A - AEA Round 14 Approved REF Projects List
Alaska Energy Authority Page 3 of 3
Attachment A:
AEA Round 14 Approved REF Projects List
CommunityApplicant NameProject NameTechnologyRd 14 Approved FundingApplication NumberAkiachakAkiachak Native CommunityAkiachak Wind FeasibilityWind371,000.00$ 14021Ambler; Kiana; Noorvik; SelawikNorthwest Arctic BoroughDesign and Permitting for Solar PV and Battery Storage for Ambler, Kiana, Noorvik, and SelawikSolar590,000.00$ 14007DillinghamNushagak Electric & Telephone CooperativeNuyakuk River Hydroelectric ProjectHydro1,000,000.00$ 14001Fairbanks; Delta Junction; Fort Greely; FoxGolden Valley Electric AssociationInterior Alaska Wind Energy Resource AssessmentWind855,000.00$ 14029False PassCity of False PassUNGA Man Creek Hydroelectric ProjectHydro321,000.00$ 14035GalenaCity of GalenaGalena Community Scale Solar PV and Battery ProjectSolar2,000,000.00$ 14034Holy CrossAlaska Village Electric CooperativeHoly Cross Solar Energy & Battery Storage Feasibility Study ProjectSolar135,000.00$ 14002HomerCity of Homer, Department of Public WorksHomer Energy Recovery ProjectHydro79,500.00$ 14006KakeInside Passage Electric CooperativeJenny Creek Hydro Reconnaissance - Kake IPECHydro62,368.00$ 14027KongiganakPuvurnaq Power CompanyKongiganak Wind Upgrade with Airfoil Blades for TurbinesWind278,716.00$ 14020KotzebueKotzebue Electric Association, Inc.Kotzebue Wind to PV Transition Utilizing Existing Wind InfrastructureSolar1,900,000.00$ 14018KotzebueCity of KotzebueKotzebue Wind to Heat SystemWind (to heat)702,435.00$ 14015KwigillingokKwig Power CompanyKwigillingok Wind Turbine UpgradeWind278,716.00$ 14016Moose PassAlaska Electric & Energy Cooperative, Inc.AEEC Summit Lake WindWind232,000.00$ 14009Native Village of EklutnaNative Village of EklutnaEklutna Village Solar Energy Project - Feasibility StudySolar22,500.00$ 14019NenanaCity of NenanaNenana Biomass District Heat SystemBiomass676,121.00$ 14028NikiskiAlaska Electric & Energy Cooperative, Inc.AEEC East Foreland/Nikiski WindWind200,000.00$ 14010NinilchikAlaska Electric & Energy Cooperative, Inc.AEEC Ninilchik WindWind192,000.00$ 14008Ninilchik/Fox RiverAlaska Electric & Energy Cooperative, Inc.AEEC Caribou Hills WindWind209,600.00$ 14011NomeNome Joint Utility SystemNome Battery Energy Storage SystemStorage2,000,000.00$ 14026OuzinkieCity of OuzinkieOuzinkie Wind Energy Feasibility and Conceptual Design ProjectWind172,600.00$ 14005Pilot PointCity of Pilot PointPilot Point Comprehensive Community Wind/Solar/Storage & Heat ProjectStorage423,500.00$ 14025Pilot StationAlaska Village Electric CooperativePilot Station Wind Energy Feasibility Study & Conceptual Design ProjectWind229,500.00$ 14004Point MackenziePoint MacKenzie SolarPoint MacKenzie SolarSolar75,000.00$ 14003QuinhagakNative Village of KwinhagakKwinhagak Reconnaissance StudySolar81,000.00$ 14017RailbeltChugach Electric Association, Inc. On behalf of the Bradley Lake Management Committee (BPMC)Dixon Diversion Feasibility ProjectHydro1,000,000.00$ 14022SoldotnaAlaska Electric & Energy Cooperative, Inc.AEEC/KPB CPL Landfill Gas CHP Project Biomass884,986.00$ 14012TOTAL14,972,542.00$ Alaska Energy Authority - Renewable Energy Fund - Round 14 - Approved Projects (FY2023)
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
MEMORANDUM
DATE: October 11, 2022
TO: Curtis W. Thayer, Executive Director
THROUGH: Audrey Alstrom, Director - Alternative Energy & Energy Efficiency
FROM: Taylor Asher, Project Manager
SUBJECT: Quarter 2, Electric Vehicle Update
IIJA NEVI Program
The federal Infrastructure Investment and Jobs Act (IIJA) National Electric Vehicle Infrastructure (NEVI) Program will provide Alaska with more than $50 million over the
next five years. The NEVI formula funds will help Alaska complete the statewide EV fast-charging network and community-based charging installations in urban and rural areas
throughout the state. Alaska’s NEVI funds will be routed through the Alaska Department of Transportation and Public Facilities (DOT&PF) and managed by the Authority.
AEA and DOT&PF have identified roles and responsibilities and meet biweekly to discuss
progress and ensure deadlines are being met. A formal Memorandum of Agreement (MOA) is forthcoming.
The NEVI Program required states to develop a comprehensive five-year
Implementation Plan that addresses how states will “build out” their Alternative Fuel
Corridors (AFC) and access NEVI funds. AEA hired Michael Baker International to assist in the development and implementation of the Plan. The Plan was developed with the
support of DOT&PF and stakeholder input throughout Alaska.
AEA gathered input via a request for information, presentations, workshops, and social media campaigns. AEA will continue to gather feedback for future iterations of the Plan.
The Plan was submitted on July 29, 2022, and was officially approved by the Federal Highway Administration on September 27, 2022. The Plan can be accessed on the AEA
website 1. AEA is now in the beginning steps of implementing the Plan, which will include
a Request for Qualifications from potential site hosts followed by a recommendation for
submission of a full application. Siting criteria will be published for a 30-day public
1https://www.akenergyauthority.org/Portals/0/Electric%20Vehicles/2022.07.29%20State%20of%20Alask
a%20NEVI%20Plan%20(Final).pdf?ver=2022-06-29-152835-320
Alaska Energy Authority Page 2 of 2
comment period before soliciting for full applications. Grant agreements are anticipated
to be in place by Quarter 3 for summer 2023 construction.
In addition to the funds above, the IIJA Charging and Fueling Infrastructure Program appropriates $2.5 billion nationwide in competitive grants to fund publicly accessible
EVSE or transportation electrification. The Governor included $1.5 million in the FY23 budget to help AEA apply for competitive EV grant funding. AEA submitted concept
papers to the federal DOE, for outreach and education, and for installing charging stations in rural Alaska. Over the next quarter, AEA will work with project partners to
submit a full application to DOE. AEA will partner with DOT&PF, a clean cities coalition (required), a native entity, Launch Alaska, Alaska Municipal League, and the Alaska
Center for Energy and Power. The DOE anticipates making awards by March 2023.
Award No Project Name DC Funding Perf. Period Beg Perf. Period Thru Actions Since Last Report
Estimated Jobs
Created
Permanent Jobs
Created
01432-11 BFU - Tatitlek 1,472,000 6/1/2013 8/31/2022 None 30 2
01474-08 BFU - Chalkytsik 517,500 6/16/2015 12/31/2022 None 30 2
01485-05 START Communities Tech Asst 375,000 11/1/2015 3/31/2023 None 2 0
01492-09 BFU - Beaver 608,000 7/6/2016 12/31/2022 None 5 2
01500-08 Bulk Fuel Operator Training 1,610,000 9/1/2016 6/30/2023 None 3 0
01515-08 Circuit Rider Program 1,200,000 1/1/2017 12/31/2022 None 3 0
01516-07 RPSU - Maintenance & Improvement 748,776 10/1/2016 12/31/2022 None 20 0
01523-07 Miscellaneious Small M&I Projects 1,220,000 6/1/2017 12/31/2022 None 20 0
01525-07 Power Plant Operator Training 872,514 8/15/2017 6/30/2023 None 3 0
01544-06 Itinerant Utility Training 500,000 3/1/2018 12/31/2023 Extend Period of Performance 3 0
01548-07 RPSU M&I - Statewide 3,090,000 5/1/2018 9/30/2023 None 20 0
01551-06 RPSU - Venetie 250,000 5/1/2018 12/31/2022 None 5 2
01557-03 Barge Headers and Fill Lines 3,976,820 10/1/2018 12/31/2024 Extend Period of Performance 60 0
01571-02 BFU - Nunapitchuk 3,522,546 8/15/2019 12/31/2023 None 30 2
01574-02 RPSU - Nikolai 1,733,740 8/1/2019 3/31/2023 None 5 2
01575-04 RPSU - Nelson Lagoon 135,455 8/1/2019 12/31/2022 None 5 2
01576-04 RPSU - Rampart 1,733,740 8/1/2019 12/31/2024 Extend Period of Performance 5 2
01577-05 RPSU - Napaskiak 335,455 8/1/2019 12/31/2024 Extend Period of Performance 26 2
01600-02 VEEP - Statewide 875,000 6/15/2020 12/31/2023 None 3 0
01610-03 BFU - Ekwok 100,000 9/1/2020 6/30/2022 None 30 2
01611-01 Engineering Library 100,000 9/1/2020 12/31/2022 Extend Period of Performance 1 0
01618-00 Fivemile Creek Hydroelectric Project 2,880,000 9/1/2020 12/31/2022 None 65 2
01628-01 Craig High School Biomass Project 440,417 11/1/2020 12/31/2022 None 8 2
01645-01 O&M Manual Conversion and Training 75,000 4/1/2021 9/30/2023 Extend Period of Performance 4 0
01646-00 Bulk Fuel Inventory and Assessment 480,000 4/1/2021 12/31/2023 None 20 0
01647-01 Port Heiden Electrical Distribution Upgrades 1,905,600 4/1/2021 12/31/2024 None 8 0
01666-01 DOE Littoral Power Systems Hydrokinetic Project 80,642 11/15/2021 3/31/2023 None 1 0
01704-00 RPSU - Chalkyitsik 200,000 10/1/2022 3/31/2024 New 5 2
01705-00 RPSU - Red Devil 200,000 10/1/2022 3/31/2024 New 5 2
Total Funding for Active DC Awards:31,238,205
Less Total Spending on Active DC Awards:(16,260,727)
Total Funding Remaining on Active DC Awards:14,977,478
Active Denali Commission Awards
As of 10/13/2022
Alaska Energy Authority
MEMORANDUM
TO: Alaska Energy Authority Board
THRU: Curtis. W. Thayer, Executive Director FROM: Conner Erickson, AEA Planning Manager DATE: October 12, 2022
RE: Sweetheart Lake Hydroelectric Plant Construction
On August 17, 2022 Juneau Hydropower, Inc. (“JHI”) signed a joint-development agreement with
Tokyo-based hydroelectric developer Electric Power Development Company, Ltd. (d.b.a. J-
POWER) to construct the Sweetheart Lake Hydroelectric Development Project (“Project”). The
project is being financed through the U.S. Department of Energy, with JHI and J-POWER
providing the equity portion1. Project Overview
The Project, which has been ongoing since 2009 per JHI, is designed as a hydroelectric facility to be constructed on Sweetheart Creek, at the southern outlet of Sweetheart Lake. Rated at 19.8
Megawatts (“MW”), it is anticipated to generate an annual average of 116,000 Megawatt-hours
(“MWh”). The project is estimated to cost approximately $200 million 2 and is comprised of hydroelectric power plant, 40+ miles transmission lines and a district heating system in Juneau 3. The joint-developers of the project state construction will begin next year and will last 2-3 years,
with commissioning projected sometime after 2025. The Project will utilize a roadless
alternative construction design, as stated by JHI, due to the Project being located within the
bounds of the Tongass National Forest, utilizing a larger 15’ by 15’ tunnel for water conveyance from the lake to the powerhouse, which will allow for material and equipment to be moved to and from the site, without the construction of a traditional access road4.
J-POWER, JHI’s equity partner in the Project, is a major Japanese hydroelectric company which builds, owns and operates generation and transmission facilities across Japan, Australia, China, the Philippines, and the U.S. As per representatives of J-POWER, the company owns and operates 61 hydroelectric facilities, in addition to over 1,500 miles of transmission lines across Japan.
1 Juneau Empire, Sep. 15, 2022, https://www.juneauempire.com/news/juneau-hydropower-announces-
sweetheart-deal/
2 KTOO Public Media, Sep. 16, 2022, https://www.ktoo.org/2022/09/16/juneau-hydropower-sweetheart-
lake/
3 Clarion Energy – Hydro Review, Aug. 17, 2022, https://www.hydroreview.com/hydro-industry-news/j-
power-signs-agreement-to-develop-sweetheart-lake-hydro-in-alaska/#gref
4 JHI, https://juneauhydro.com/sweetheart-lake/design-and-development-philosophy/
Alaska Energy Authority
Project Location The Project is to be constructed on the east shore of Gilbert Bay, about 33 miles southeast of Juneau, Alaska. The existing 78.2 MW Snettisham hydroelectric facility lies approximately straight-line 15 miles north of the Project site. Kensington Mine, an active Coeur Mining-owned gold mine operation is the Project’s primary energy customer, and is located about 44 straight-
line miles north of downtown Juneau, as illustrated in Figure 1 below.
Figure 1 – Project Area Map
Project Revenue Sources The Project, is slated to increase the electrical generation capacity of the Juneau area by 20-25 percent 5. The Project will require interconnection with the existing Alaska Industrial Development and Export Authority (“AIDEA”) - owned Snettisham transmission line, via a new
8.6 mile line north from the Project site, in addition to a new 31-mile transmission line extension
north from Alaska Electric Light & Power’s (“AEL&P”) existing transmission infrastructure in order
to deliver power to the Project’s primary power purchaser, Kensington Mine, a Coeur Mining
operation6. Alaska Electric Light & Power (“AEL&P”), the RCA-regulated utility serving the City and Borough of Juneau, operates and maintains the Snettisham generation and transmission
assets on behalf of AIDEA, through an existing O&M agreement. The Snettisham line is an
existing 44 mile long high-voltage overland and undersea transmission line providing
interconnection from the Snettisham hydroelectric plant to AEL&P’s Juneau transmission lines.
5 See footnote #1
6 See footnote #2
Alaska Energy Authority
Currently, the Snettisham hydroelectric plant provides the majority (65%) of the power requirements for AEL&P 7. Additionally, interconnection with AEL&P’s grid would provide the potential for the project to wholesale power to AEL&P under a negotiated and Regulatory Commission of Alaska-approved Power Purchase Agreement (“PPA”), providing potential future power-sales revenue to the Project. Future additional power requirements for the Juneau City & Borough, as would be provided via AEL&P, include additional cruise-ship dock electrification, electric vehicle charging infrastructure, and JHI’s high-temperature seawater heat pump district heating system, the development of which is being pursued by JHI’s subsidiary, Juneau District Heating 8.
Project History
The Project began in 2009 and has been progressing steadily in its licensing and financing process. In the second half of 2009, Federal Energy Regulatory Commission (“FERC”) issued a preliminary permit to begin the necessary studies required for a full FERC license. In May 2014, JHI submitted its Final License Application and related Preliminary Draft Environmental Assessment for the Project. In October 2015, FERC approved the draft Environmental Impact Statement (“EIS”) for agency and public comment. In May 2016, FERC issued its final EIS for agency and public comment. In September 2016, FERC issued the Final License (FERC project no. 13563-003) for the Project 9. In an effort to assist JHI in its interconnection with the AIDEA-owned Snettisham transmission lines, AIDEA and JHI have entered into a Memorandum of Understanding (MOU) to study such interconnection requirements. Discussions between JHI
and AEL&P concerning the interconnection with AEL&P’s transmission infrastructure across the
City and Borough of Juneau north to the Kensington mine site are still ongoing.
Project Cost
Table 1 and Table 2, as found in Appendix A, are provided to give a high-level cost comparison of Alaska power plant development since 2009. Table 1 provides a nominal cost comparison, whereas Table 2 provides an inflation-adjusted, real-cost comparison. At an estimated cost of
$200 million, the Project cost, in comparison with other power generation projects throughout
Alaska over the last decade or so, is on the higher end of the range.
As indicated in Table 1, projects of similar MW capacities range from $1.3 million to $12.3
million per MW of capacity. On a energy generation basis, Sweetheart Lake falls within the
lower half of the range of those plants surveyed at a cost of $1,724 per MWh. The significant
amount of new transmission line construction (40+ miles), along with the remote location of the
site, and current inflationary pressures impacting the prevailing cost of raw materials, labor, and
management are assumed to be the major contributing factors to the high cost of the project.
It is important to note that not all power plants are created equal. Many items need to be considered when assessing the cost of a plant, which are not addressed in this memo. Some
7 AIDEA, 2020Q2 Snettisham Status Update,
http://www.aidea.org/Portals/0/PDF%20Files/PFS_Snettisham.pdf
8 Juneau Hydropower, Inc., https://juneauhydro.com/sweetheart-lake/juneaus-community-values-in-
action/
9 Juneau Hydropower, Inc., https://juneauhydro.com/sweetheart-lake/
Alaska Energy Authority
critical items to consider are the plant type/application (i.e. peaking, baseload, reserve, etc…), technology (i.e. gas turbine, wind, solar, hydro, or other), project financing arrangement (i.e.
private equity, grant funded, bond financing, conventional loans, or other sources), power
dispatchability (e.g. intermittement vs. load-following), site location (i.e. remote, or urban), and
others. The information provided in Table 1 and Table 2 of Appendix A are only for purposes of
high-level comparison only.
Attachments
Appendix A – Power Plant Cost Comparison Tables
Alaska Energy Authority
Appendix A – Power Plant Cost Comparison Tables
Plant NameTechnologyOwner/OperatorCommissioning YearNameplate Capacity / Size (MW)Cost (Nominal)Cost / MW ($/MW - Nominal)Annual Generation at 100% Capacity Factor (MWh)Average Annual Generation (MWh)Cost / Average Generation MWh ($/MWh - Nominal)Capacity Factor (%)Southcentral Power Plant Gas TurbineChugach Electric Association2013200.2 370,206,767$ 1,849,185$ 1,753,752 1,042,049 355$ 59%Eklutna Generation StationGas TurbineMatanuska Electric Association2015171 339,814,633$ 1,987,220$ 1,497,960 678,552 501$ 45%Plant 2A (George Sullivan)Gas TurbineChugach Electric Association (ML&P)2016178 289,453,752$ 1,626,145$ 1,559,280 622,392 465$ 40%Sweetheart Lake HydroHydroelectricJuneau Hydropower, Inc. / J-Power202619.8 200,000,000$ 10,101,010$ 173,448 116,000 1,724$ 67%Blue Lake Dam HydroHydroelectricCity & Borough of Sitka201515.9 146,000,000$ 9,182,390$ 139,284 66,251 2,204$ 48%Eva Creek Wind FarmWindGolden Valley Electric Association201224.6 94,000,000$ 3,821,138$ 215,496 45,644 2,059$ 21%Fire Island Wind - Phase IWindCook Inlet Region Incorporated201217.6 90,000,000$ 5,113,636$ 154,176 47,000 1,915$ 30%Soldotna Combustion Turbine Gas TurbineHomer Electric Association (HEA/AEEC)201548 81,177,661$ 1,691,201$ 420,480 31,863 2,548$ 8%Lake Dorothy HydroHydroelectricAlaska Electric Light & Power200914.3 68,644,348$ 4,800,304$ 125,268 88,704 774$ 71%Allison CreekHydroelectricCopper Valley Electric Association20166.551,000,000$ 7,846,154$ 56,940 15,000 3,400$ 26%Industrial BlvdGas TurbineAlaska Electric Light & Power201623.49 24,363,574$ 1,037,189$ 205,772 204 119,429$ 0%Plant NameTechnologyOwner/OperatorCommissioning YearNameplate Capacity / Size (MW)Cost (Real)Cost / MW ($/MW)Annual Generation at 100% Capacity Factor (MWh)Average Annual Generation (MWh)Cost / Average Generation MWh ($/MWh)Capacity Factor (%)Southcentral Power Plant Gas TurbineChugach Electric Association2013200.2 504,540,313$ 2,520,181$ 1,753,752 1,042,049 484$ 59%Eklutna Generation StationGas TurbineMatanuska Electric Association2015171 454,674,616$ 2,658,916$ 1,497,960 678,552 670$ 45%Plant 2A (George Sullivan)Gas TurbineChugach Electric Association (ML&P)2016178 383,228,883$ 2,152,971$ 1,559,280 622,392 616$ 40%Sweetheart Lake HydroHydroelectricJuneau Hydropower, Inc. / J-Power202619.8 200,000,000$ 10,101,010$ 173,448 116,000 1,724$ 67%Blue Lake Dam HydroHydroelectricCity & Borough of Sitka201515.9 195,349,133$ 12,286,109$ 139,284 66,251 2,949$ 48%Eva Creek Wind FarmWindGolden Valley Electric Association201224.6 130,061,559$ 5,287,055$ 215,496 45,644 2,849$ 21%Fire Island Wind - Phase IWindCook Inlet Region Incorporated201217.6 124,527,025$ 7,075,399$ 154,176 47,000 2,650$ 30%Soldotna Combustion Turbine Gas TurbineHomer Electric Association (HEA/AEEC)201548 108,616,340$ 2,262,840$ 420,480 31,863 3,409$ 8%Lake Dorothy HydroHydroelectricAlaska Electric Light & Power200914.3 102,949,707$ 7,199,280$ 125,268 88,704 1,161$ 71%Allison CreekHydroelectricCopper Valley Electric Association20166.567,522,611$ 10,388,094$ 56,940 15,000 4,502$ 26%Industrial BlvdGas TurbineAlaska Electric Light & Power201623.49 32,256,708$ 1,373,210$ 205,772 204 158,121$ 0%Note: Nominal values adjusted per the U.S. Army Corps of Engineers Civil Works Construction Cost System (CWCCIS); Feature Code: 07 - Power Plant - Published March 2022Table 1: Nominal Cost (Year of Construction)Table 2: Real Cost ($2022)
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
MEMORANDUM
TO: Dana Pruhs, Board Chair
FROM: Curtis Thayer, Executive Director
DATE: October 26, 2023
SUBJECT: Alaska Energy Authority Board Meeting dates for 2023
Alaska Energy Authority(AEA) recommends the Board consider the following proposed dates for
the 2023 AEA Boardmeeting schedule:
AEA 2023 Proposed Board Schedule:
1.Wednesday, January 18, 2023
2.Wednesday, March 1, 2023
3.Wednesday, April 12, 2023
4.Wednesday, May 24, 2023
5.Wednesday, June 21, 2023
6.Wednesday, August 2, 2023
7.Thursday, September 21, 2023
8.Wednesday,October 25, 2023
9.Wednesday, December 6, 2023
813 W Northern Lights Blvd, Anchorage, AK 99503 • Phone: (907) 771-3000 Fax: (907) 771-3044 • Email: info@akenergyauthority.org • Website: akenergyauthority.org
DATE DESCRIPTION TOPIC AND AUDIENCE LOCATION TEAM MEMBER
Ocotber 10, 2022 Public Comment Alaska Electric Vehicle (EV) Infrastructure Plan to Fairbanks City Council Phone Taylor Asher
Ocotber 6, 2022 Presentation Energy and Infrastructure in Alaska to Seward Chamber of Commerce In Person Curtis W. Thayer
September 30, 2022 Press Conference Governor's Signs Administative Order No. 340 Press Conference In Person Curtis W. Thayer
September 29, 2022 Media Interview Alaska’s EV Infrastructure Deployment Plan with KUAC Phone Curtis W. Thayer
September 28, 2022 Media Interview Alaska’s EV Infrastructure Deployment Plan with KSRM Phone Curtis W. Thayer
September 27, 2022 Presentation Alaska EV Technical Session Virtual AEA EV Team
September 26, 2022 Presentation FY24 AEA Budget Development Presentation to Office of Management
and Budget Virtual Curtis W. Thayer
September 26, 2022 Attendees 2022 Clean Transportation Leadership Roundtable In Person AEA EV Team
September 20, 2022 Workshop Presentation Alaska EV Infrastructure Deployment Plan Workshop Presentation to
Fairbanks Stakeholders In Person Curtis W. Thayer
Audrey Alstrom
September 20, 2022 Presentation AEA Overview Presentation to Golden Valley Electric Association In Person Curtis W. Thayer
September 14-16, 2022 Participant National Renewable Energy Laboratory: Executive Energy Leadership
Program
NREL
Golden, CO Curtis W. Thayer
September 14, 2022 Attendee Houston Solar Farm Groundbreaking Ceremony Houston, AK Conner Erickson
Karen Bell
September 7, 2022 Attendees/Exhibitor Infrastructure Grant Symposium Hosted by Senator Lisa Murkowski In Person AEA Team
August 24, 2022 Presentation Transmission Upgrades Presentation to GFCC Energy, Environment &
Natural Resources Committee Virtual Curtis W. Thayer
August 24, 2022 Media Interview Hydropower in Alaska with Alaska Business Phone Curtis W. Thayer
August 23, 2022 Presentation Alaska EV Infrastructure Plan Presentation to FEDC Energy for All Alaska
Task Force Virtual Curtis W. Thayer
August 19, 2022 Exhibitor 2022 Alaska State Fair Energy Day In Person AEA Team
August 15, 2022 Presentation Bradley Lake and Dixon Overview Presentation to National Hydropower
Association In Person Audrey Alstrom
AEA COMMUNITY OUTREACH
Updated on October 12, 2022 (6-Month Look Back)
AEA Community Outreach Page 2 of 4
DATE DESCRIPTION TOPIC AND AUDIENCE LOCATION TEAM MEMBER
August 12, 2022 Exhibitor Golden Valley Electric Association's EV Member Event & Car Display In Person Taylor Asher
August 10, 2022 Presentation AEA Overview Presentation for United States Department of Energy Office
of Indian Energy Policy and Programs In Person Curtis W. Thayer, Audrey Alstrom
Brandy Dixon
August 10, 2022 Presentation AEA Overview Presentation to Ahtna In Person Curtis W. Thayer
August 8, 2022 Presentation Energy and Infrastructure in Alaska to Juneau Chamber of Commerce In Person Curtis W. Thayer
August 8, 2022 Presentation Alaska EV Infrastructure Deployment Plan to AEA Board of Directors In Person Audrey Alstrom
July 27, 2022 Presentation Energy and Infrastrucutre in Alaska to Anchorage Chamber of Commerce In Person Curtis W. Thayer
July 20-22, 2022 Participant National Renewable Energy Laboratory: Executive Energy Leadership
Program
NREL
Golden, CO Curtis W. Thayer
July 20, 2022 Legislative Inquiry Representative Mike Cronk on EV Plan and Volkswagen Mitigation Plan Phone Curtis W. Thayer
July 18, 2022 Legislative Inquiry Senator Lyman Hoffman on Senate 243: Pwr Cost EQ: Raise, Endow Fund
Investment Email Curtis W. Thayer
July 15, 2022 Provide Quote Arctic Road Rally for Fairbanks Daily News-Miner Email Curtis W. Thayer
July 15, 2022 Provide Quote Power Cost Equalization Kilowatt Increase for Office of Governor Mike
Dunleavy Press Release Email Curtis W. Thayer
July 15, 2022 Media Interview Alaska’s EV Infrastructure Implementation Plan with KDLL Phone Curtis W. Thayer
July 14, 2022 Renewable Energy Alaska Native Science and Engineering Program’s Science, Technology,
Engineering, and Math Career Exploration In Person Audrey Alstrom
July 13, 2022 Presentation EV Plan Listening and Public Feedback Session #2 to Public In Person and Virtual Audrey Alstrom, Dan Aicher,
Taylor Asher, Josi Hartley
July 13, 2022 Presentation EV Plan Listening and Public Feedback Session #1 to Alaska EV Working
Group In Person and Virtual Audrey Alstrom, Dan Aicher,
Taylor Asher, Josi Hartley
July 1, 2022 Media Interview Alaska’s EV Infrastructure Implementation Plan with Alaska's News
Source In Person Curtis W. Thayer
June 23, 2022 Presentation EV Virtual Information Session #4 to Alaska EV Working Group and Public In Person and Virtual Audrey Alstrom, Dan Aicher,
Taylor Asher, Josi Hartley
June 22-24, 2022 Participant National Renewable Energy Laboratory: Executive Energy Leadership
Program
NREL
Golden, CO Curtis W. Thayer
June 22, 2022 Presentation EV Virtual Information Session #3 to Alaska EV Working Group and Public In Person and Virtual Audrey Alstrom, Dan Aicher,
Taylor Asher, Josi Hartley
AEA Community Outreach Page 3 of 4
DATE DESCRIPTION TOPIC AND AUDIENCE LOCATION TEAM MEMBER
June 15, 2022 Presentation EV Virtual Information Session #2 to Alaska EV Working Group and Public In Person and Virtual Audrey Alstrom, Dan Aicher,
Taylor Asher, Josi Hartley
June 14, 2022 Presenter/Attendee Joint Agency and Public Meeting on Dixon Diversion Projects Aspen Suites Hotel
Homer, AK
Bryan Carey
Curtis W. Thayer
June 8, 2022 Presentation EV Virtual Information Session #1 to Alaska EV Working Group and Public In Person/Virtual Audrey Alstrom, Dan Aicher,
Taylor Asher, Josi Hartley
June 3, 2022 Media Interview Infrastructure Upgrades/Railbelt Utilities with Tim Bradner Phone Curtis W. Thayer
May 27, 2022 Media Interview Transmission Upgrades with Fairbanks Daily News-Miner Phone Curtis W. Thayer
May 27, 2022 Media Interview Senate Bill 234 with Alaska's News Source Phone Curtis W. Thayer
May 25, 2022 Media Interview Transmission Upgrades with Fairbanks Daily News-Miner Phone Curtis W. Thayer
May 25, 2022 Moderator Alaska Sustainable Energy Conference: Uniting the Grid Panel Dena'ina Center
Anchorage, AK Curtis W. Thayer
May 24-26, 2022 Attendees/Exhibitor Booth Alaska Sustainable Energy Conference Dena'ina Center
Anchorage, AK
Curtis W. Thayer, Audrey Alstrom,
Taylor Asher, Karen Bell, Brandy
Dixon, Josi Hartley, Dan
Johnston, David Lockard, T.W.
Patch
May 20, 2022 Exhibitor Booth Chugach Electric Association Member Appreciation Day ChangePoint Alaska
Anchorage, AK
Dan Aicher, Bryan Carey
Brandy Dixon, Conner Erickson
May 13, 2022 Media Interview In-State Energy Security Working Group with Anchorage Daily News Phone Curtis W. Thayer
May 12, 2022 Media Interview Power Cost Equalization with Alaska's News Source Phone Curtis W. Thayer
May 11, 2022 Legislative Hearing House Finance Committee - House Bill 170 Energy Independence
Program & Fund: AIDEA Phone Curtis W. Thayer
May 10, 2022 Media Interview Dixon Diversion Project with KDLL Phone Curtis W. Thayer
May 6, 2022 Legislative Hearing House Finance Committee - House Bill 283 Approp: Cap; Reapprop; Supp Phone Curtis W. Thayer
May 6, 2022 Legislative Hearing House Labor & Commerce Committee - House Bill 301: Utilities:
Renewable Portfolio Standard Phone Curtis W. Thayer
May 4, 2022 Presentation EV Program Update to FAST Planning Technical Committee Virtual Audrey Alstrom
May 3, 2022 Legislative Hearing House Finance Committee - House Bill 358: Renewable Energy Grant
Fund Phone Curtis W. Thayer
May 3, 2022 Brief Remarks Alaska Sustainable Energy Conference:
Pre-Event Virtual Workshop Series - Electrify EVERYTHING!?Virtual Curtis W. Thayer
May 2, 2022 Legislative Hearing House Labor and Commerce Committee - HB 301: Utilities: Renewable
Portfolio Standard Phone Curtis W. Thayer
AEA Community Outreach Page 4 of 4
DATE DESCRIPTION TOPIC AND AUDIENCE LOCATION TEAM MEMBER
April 28, 2022 Attendee BPMC Special Meeting In Person Curtis W. Thayer
April 28, 2022 Legislative Hearing House Energy Committee - HB 301: Utilities: Renewable Portfolio
Standard Phone Curtis W. Thayer
April 28, 2022 Legislative Hearing House Finance Committee - House Bill 170: Energy Independence
Program & Fund: AIDEA Phone Curtis W. Thayer
April 27, 2022 Attendee State Energy Office Teams Meeting Alaska/Washington State Phone Curtis W. Thayer
April 27, 2022 Legislative Hearing Senate Finance Committee - Senate Bill 243: Pwr Cost EQ: Raise, Endow
Fund Investment Phone Curtis W. Thayer
April 26, 2022 Exhibitor Matanuska Electric Association’s Annual Meeting Menard Center
Wasilla, AK
Brandy Dixon
Dan Johnston
April 26, 2022 Legislative Hearing House State Affairs - House Bill 271: AIDEA: Membership; Responsibilities Phone Curtis W. Thayer
April 26, 2022 Legislative Hearing House Finance Committee - House Bill 170: Energy Independence
Program & Fund: AIDEA Phone Curtis W. Thayer
April 26, 2022 Legislative Hearing House Energy Committee - House Bill 301: Utilities: Renewable Portfolio
Standard Phone Curtis W. Thayer
April 26, 2022 Media Interview Renewable Energy Fund Round 14 with KSRM Radio Phone Curtis W. Thayer
April 22, 2022 Media Interview Renewable Energy Fund Round 14 with KDLL 91.9 Radio Station Phone Curtis W. Thayer
April 22, 2022 Legislative Hearing House Finance Committee - House Bill 170: Energy Independence
Program & Fund: AIDEA Phone Curtis W. Thayer
April 20, 2022 Attendee EV Program Update with Alaska EV Working Group In Person/Virtual Curtis W. Thayer
April 20, 2022 Presentation EV Program Update to Alaska EV Working Group In Person/Virtual Audrey Alstrom
April 20, 2022 Attendee Statewide CEDS Strategy Committee Meeting #2 - Goals, Objectives, &
Strategies Phone Curtis W. Thayer
April 20, 2022 Legislative Hearing Senate Finance Committee - An Act Relating to Power Cost Equalization Phone Curtis W. Thayer
April 19, 2022 Legislative Hearing House Finance Committee - House Bill 414 Approp: Supplemental:
Capital Phone Curtis W. Thayer
April 19, 2022 Legislative Hearing Senate Finance Committee - Senate Bill 241 Approp: Supplemental:
Capital Phone Curtis W. Thayer
April 15, 2022 Attendee Renewable Energy Fund Advisory Committee In Person Curtis W. Thayer
April 14, 2022 Legislative Hearing House State Affairs - House Bill 412: Perm Fund Corp & AIDEA BD
Confirmation Phone Curtis W. Thayer
April 13, 2022 Legislative Hearing Senate Finance Committee - Senate Bill 241: Approp: Supplemental;
Capital Phone Curtis W. Thayer
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone: (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
RGYAUTHORITY.ORG
PRESS RELEASE
Brandy M. Dixon
Communications Director
(907) 771-3078
FOR IMMEDIATE RELEASE
October 4, 2022
AEA Opens Application Period for Renewable Energy Fund Round 15
Grants provide financial assistance for renewable energy projects statewide
(Anchorage) – The Alaska Energy Authority (AEA) is accepting applications for Renewable Energy
Fund (REF) grants to help diversify Alaska’s energy portfolio by supporting the advancement of
renewable energy projects. Applications are due by 4 p.m. on Monday, December 5, 2022.
“High energy costs are a burden on communities across Alaska. The REF aims to lower the cost
of energy by developing renewable energy projects,” said AEA Executive Director Curtis W.
Thayer. “The Governor and the Legislature funded Round 14 at $15 million, the largest
capitalization since Fiscal Year 2014. With this Round 15 announcement, we aim to build upon
that success.”
Following the deadline, AEA will evaluate all applications received and consult with the REF
Advisory Committee before making final recommendations to the Legislature. AEA will submit a
report summarizing each application and make recommendations for the Fiscal Year 2024
funding. Funding decisions are made at the discretion of the Governor and the Legislature.
REF was established in 2008 by the Alaska State Legislature to provide grant funding for the
development of qualifying and competitively selected renewable energy projects. To date, 271
REF grants totaling $300 million have been awarded. With REF contributions, more than 100
operating projects have been developed.
In consideration of program feedback provided to AEA and to assist in funding viable renewable
energy projects, the REF per-project funding limits for Round 15 have been increased to $2
million and $4 million, respectively, for low and high-energy-cost communities.
For more information on REF and to apply for a Round 15 grant, click on 2022 REF Application. If
you need assistance, please contact the AEA Grants Coordinator by email at
grants@akenergyauthority.org or by phone at (907) 771-3081.
The Alaska Energy Authority is a public corporation of the state. Its mission is to reduce the cost
of energy in Alaska.
###
For Alaska’s Railbelt, more rain means more hydropower
https://www.kdll.org/local-news/2022-09-30/for-alaskas-railbelt-more-rain-means-more-hydropower 1/3
For Alaska’s Railbelt, more
rain means more hydropower
KDLL | By Sabine Poux
Published September 30, 2022 at 11:16 AM AKDT
The Bradley Lake Dam in 2014
Southcentral’s rainy summer means more hydroelectric power for Homer
Electric Association and other utilities on Alaska’s Railbelt. Last month, the
water level at Bradley Lake was just five feet away from spiling over the top of
the dam — letting utilities take more energy from the 120-megawatt
For Alaska’s Railbelt, more rain means more hydropower
https://www.kdll.org/local-news/2022-09-30/for-alaskas-railbelt-more-rain-means-more-hydropower 2/3
hydroelectric project and cut back on using more expensive fuel sources, like
natural gas.
Bradley Lake, across Kachemak Bay, generates energy for six utilities across the
Railbelt. HEA gets about 14% of its power from Bradley today; the remainder
comes from Cook Inlet natural gas.
And the impacts of rain on the water levels at Bradley Lake are two-fold.
First, the rain itself means higher water levels on the lake.
But the rain also quickens the melting of snow and glaciers, sending more
water down to the lake.
“When the lake hits this certain elevation, it is literally quite close to the top of
the dam,” said HEA Board Member Erin McKittrick, of Seldovia.
She said there are certain rules built in to make sure that water isn’t wasted by
spilling over the dam. The project reaches what’s called “imminent spill” when
the water level hits 1,175 feet, as it did last month. (The real spill level is 1,180
feet.)
As it stands, HEA is sometimes the biggest beneficiary of that extra water
because of its proximity to the resource. But all the utilities are able to take
more water power and, in turn, turn back the dial on how much natural gas
they use to electrify their grids.
Power from Bradley Lake is cheaper than that gas, at 4 cents per kilowatt hour.
And in rainy years, like this one, that power is even cheaper.
“The costs that they’re incurring right now at Bradley are not higher because it
rained more,” McKittrick said. “They’re about the same as they would be any
For Alaska’s Railbelt, more rain means more hydropower
https://www.kdll.org/local-news/2022-09-30/for-alaskas-railbelt-more-rain-means-more-hydropower 3/3
September. But there’s more water, so more water gets generated. So all that
power is cheaper.”
As for rates, HEA Director of Strategic Services David Thomas said the changes
do make a difference — albeit, a small one.
HEA base rates remain the same for a year or more at a time. But the utility’s
so-called Cost of Power Adjustment changes every quarter and reflects the co-
op’s use of fuel. When there’s more hydropower, that adjustment can change
by one or two tenths of a cent.
According to a report from the Alaska Energy Authority, Bradley Lake has only
had levels this high this soon in the summer twice before — once in 2003-
2004 and again in 2014-2015.
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
RGYAUTHORITY.ORG
PRESS RELEASE
Brandy M. Dixon
Communications Director
(907) 771-3078
FOR IMMEDIATE RELEASE
September 27, 2022
AEA and DOT&PF Secure Approval for Alaska’s EV Infrastructure Deployment Plan
The announcement unlocks $19 million to expand EV charging infrastructure in Alaska
(Anchorage) — Today, the Alaska Energy Authority (AEA) and the Department of Transportation
& Public Facilities (DOT&PF) received approval from the United States Department of
Transportation Federal Highway Administration (FHWA) to implement Alaska’s Electric Vehicle
(EV) Infrastructure Deployment Plan (The Plan) to build a network of EV charging stations along
the state’s highway corridors.
As part of the Infrastructure Investment and Jobs Act, AEA will receive $7.8 million in federal
fiscal year 2022 and $11.2 million in federal fiscal year 2023 under the FHWA National Electric
Vehicle Infrastructure (NEVI) Formula Program. AEA anticipates receiving approximately $52
million over the next five years through this program.
“Now, the work begins to turn The Plan’s vision into a reality,” said Curtis W. Thayer, AEA
Executive Director. “We look forward to continuing our efforts with DOT&PF and other
agencies and stakeholders to use these federal dollars to build a statewide interconnected EV
charging station network making EV charging infrastructure more accessible and connected for
visitors and Alaskans.”
“This is one of the first steps in developing DOT&PF’s Sustainable Transportation Plan, which
strives to reduce energy costs for Alaskans,” said DOT&PF Commissioner Ryan Anderson, PE.
“In collaboration with AEA, we will ensure efficient and equitable deployment across Alaska.”
Alaska suffers from some of the highest fuel costs in the nation. The implementation of
transportation electrification will help to lower the cost of transportation energy for all Alaskans
by ensuring that they can transition to EVs, which typically have a lower total cost of ownership.
As NEVI funds must be used initially on federally-designated Alternative Fuel Corridors (AFC),
Phase 1 of The Plan will focus on the installation of EV charging stations every 50 miles along
the state’s designated AFC, which is the 358 miles of Glenn and Parks Highways between
Alaska Energy Authority Page 2 of 2
Anchorage and Fairbanks. The new charging stations must have at least four EV fast charging
ports and be located within one travel mile of the highway. Phase 1 is expected to be complete
by 2024. After that, AEA will deploy NEVI funds to build out the state’s remaining highways
including communities along the Alaska Marine Highway and rural hub communities.
AEA’s primary mission is to lower the cost of energy in Alaska. A secondary mission is to reduce
barriers to EV adoption. The Plan provides the framework for utilizing NEVI formula funds to
deliver EV charging infrastructure and enable passenger EV travel throughout the state. The
charging network will provide EV drivers with confidence when traveling for work, recreation,
and tourism.
Per this U.S. Department of Energy Office of Energy Efficiency and Renewable Energy’s press
release, each State now has a wide range of options to use NEVI Formula funding for projects
directly related to the charging of a vehicle including:
Upgrade of existing and construction of new EV charging infrastructure
Operation and maintenance costs of these charging stations
Installation of on-site electrical service equipment
Community and stakeholder engagement
Workforce development activities
EV charging station signage
Data sharing activities
Related mapping analysis and activities
For more information about the Alaska Electric Vehicle Infrastructure Deployment Plan, please
review it here. For future community engagement opportunities, please visit
https://www.akenergyauthority.org/evs.
###
The Alaska Energy Authority 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.
The Alaska Department of Transportation and Public Facilities oversees 237 airports, 9 ferries
serving 33 communities along 3,500 marine miles, over 5,600 miles of highway and 839 public
facilities throughout the state of Alaska. The mission of the department is to “Keep Alaska
Moving through service and infrastructure.”
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
RGYAUTHORITY.ORG
PRESS RELEASE
Contact Information:
Alaska Energy Authority: Brandy M. Dixon, (907) 771-3078, bdixon@akenergyauthority.org
Golden Valley Electric Association: Meadow Bailey, (907) 451-5676, mpbailey@gvea.com
FOR IMMEDIATE RELEASE
September 27, 2022
AEA and GVEA Awarded $12.8 Million Grant to Expand Electricity to Black Rapids Training Site
(Anchorage) — The Department of Defense announced Friday that the Alaska Energy Authority
(AEA) was awarded a $12,752,540 grant from the Office of Local Defense Community
Cooperation under the Defense Community Infrastructure Pilot Program.
The grant was applied for by AEA in collaboration with Golden Valley Electric Association (GVEA)
and will support the construction of a 34-mile electric distribution line extension along the
Richardson Highway to the Black Rapids Training Site (BRTS).
“We are honored to partner with GVEA on this important infrastructure project that supports our
military,” said Curtis W. Thayer, AEA Executive Director. “This extension will improve long-
term sustainability and reliability for Black Rapids by tying them into GVEA’s power grid. This
project fits squarely within Governor Dunleavy’s strategy of developing and implementing low-
cost-reliable energy solutions for Alaskans.”
“We recognize and value the military’s vital presence in Interior Alaska,” said John Burns, GVEA
President. “We are proud to expand electric service to further support the mission of our
military members. This line extension will enable Black Rapids to transition from diesel generator
power, which will improve resiliency, save money and benefit the environment.”
Operated by Fort Wainwright, Black Rapids is a primary site for state-of-the-art cold weather
and mountain warfare tactics and techniques training for the United States military. Currently,
the site is solely dependent on power supplied by diesel fuel generators. The Department of
Defense estimates that the savings due to reduced operational costs and deferred capital
improvements will pay for the line extension within a few years.
GVEA is a not-for-profit member-owned cooperative that has operated for 76 years in Interior
Alaska. GVEA’s existing power line ends about 10 miles south of Delta Junction, and
approximately 30 miles north of Black Rapids.
Design and permitting for the new distribution line will begin immediately, with construction
anticipated to begin in late 2023. The project is scheduled for completion by late 2025.
Alaska Energy Authority Page 2 of 2
The Defense Community Infrastructure Pilot Program is a competitive program that assists
states and communities in the development of infrastructure enhancements including resiliency
measures that support mission-critical military operations and quality of life benefits for local
service members and their families. BRTS is a primary site for state-of-the-art cold weather and
mountain warfare tactics and techniques training for the U.S. military.
# # #
Alaska Energy Authority supports critical projects that improve energy safety, reliability and
affordability through the development, operations and financing of energy projects around the
state.
Golden Valley Electric Association serves over 100,000 residents in Interior Alaska. The
cooperative’s mission is to safely provide members with reliable electric service, quality
customer service and innovative energy solutions at fair and reasonable prices.
Project leaders break ground on state’s largest solar farm
https://www.alaskasnewssource.com/2022/09/15/project-leaders-break-ground-states-largest-solar-farm/ 1/3
HOUSTON, Alaska (KTUU) - Matanuska Electric Association hosted a
groundbreaking ceremony at the site of a new solar farm in Houston on
Wednesday morning.
The project will occupy 45 acres of land and will be six times larger than the
Willow Solar Farm. Gov. Mike Dunleavy stood alongside leaders of the project
and spoke about the potential benefits of renewable solar energy to the few
dozen individuals in attendance.
“This is just the beginning of tremendous, tremendous amounts of power we
can produce here in Alaska,” Dunleavy said.
Project leaders break ground on state’s largest solar farm
https://www.alaskasnewssource.com/2022/09/15/project-leaders-break-ground-states-largest-solar-farm/ 2/3
The farm will be the second of its kind and becomes the largest solar grid in
the Matanuska-Susitna Borough, as well as the state. Located off Hawk Lane
near Houston High School, the grid will consist of over 6,000 foundation piles
and 14,400 solar panels.
The project is the result of a four-way partnership, with the borough leasing
the land, Renewable Independent Power Producers building and maintaining
the grid, Matanuska Electric Association purchasing the wholesale power,
and CleanCapital funding and owning the project.
CEO of MEA Tony Izzo said the cost to purchase the power is lower than
anything they generate themselves and helps diversify their fuel supply
portfolio, making them less reliant on natural gas.
“We plan to continue in any way we can to reduce our carbon footprint, and
to increase the diversity of our fuel supply mix that will result in increased
reliability and lower cost to our consumers,” Izzo said
This particular project is not expected to lower the price of electricity for MEA
customers, but it is cost-competitive with MEA generation which helps
stabilize rates.
Renewable IPP is an Alaskan-grown company started by a group of four
engineers in 2017. CEO Jenn Miller said she and her three partners worked in
the oil and gas industry when they realized the potential solar power had in
delivering low-cost energy to Alaskans. The company built the Willow Solar
Farm as a pilot project before expanding it in 2019.
“We’ve hired all local employees to build this solar farm, and we’re building
that expertise here in the state,” Miller said. “We are diversifying our energy
supply for Alaskans. Because we have an isolated grid we are responsible for
sourcing all that energy, and so by diversifying it, it extends out our Cook Inlet
gas supply and bringing in lower carbon energy.”
Project leaders break ground on state’s largest solar farm
https://www.alaskasnewssource.com/2022/09/15/project-leaders-break-ground-states-largest-solar-farm/ 3/3
According to Miller, the useful life of a solar panel is close to 40 years, if not
more. The bifacial panels are also designed to harness the reflective light off
the snow, gathering energy during the winter months.
“When we get that reflective light in the wintertime it’s going to bounce off
the snow and produce on the backside of the solar panel,” Miller said.
“February, March is that super reflective sun, and as the daylight starts coming
back, you know, I would say that solar provides good energy about 10 months
of the year.”
Development is already underway at the site as crews continue to drive
foundation piles into the ground. Miller hopes all piles will be in before the
season ends so panels and wiring can be installed next year. The panels are
expected to go live sometime next summer.
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
RGYAUTHORITY.ORG
PRESS RELEASE
Brandy M. Dixon
Communications Director
(907) 771-3078
FOR IMMEDIATE RELEASE
August 31, 2022
AEA Invites Input on DOE Grid Resilience Formula Grant Program
Alaska is expected to receive $60 million over five years to strengthen grid resilience
(Anchorage) — The Alaska Energy Authority (AEA) will host two public meetings on Alaska’s
application for the annual allocation of approximately $12.1 million made available through the
United States Department of Energy’s (DOE) Grid Resilience Formula Grant Program to improve
the resiliency of the electric grid infrastructure against disruptive events. Under this Program,
Alaska expects to receive $60 million over five years to strengthen grid resilience.
The Program, funded through Section 40101(d) Formula Grants to States & Indian Tribes of the
Infrastructure Investment and Jobs Act (IIJA), will be administered through AEA, as designated
by Governor Mike Dunleavy. The National Program provides $2.3 billion in formula grants to
States and Indian Tribes to improve the all-hazards resilience of electric grids. These public
meetings will only address the State of Alaska’s annual allocation of $12.1 million in formula
grant funds. Alaska’s Tribal entities have been allocated their own funding.
The objective of this Program is to improve the resilience of the electric grid against disruptive
events, which are defined as "an event in which operations of the electric grid are disrupted,
preventively shut off, or cannot operate safely due to extreme weather, wildfire, or a natural
disaster." Eligible entities that may apply for subawards under this Program include electric grid
operators, electricity storage operators, electricity generators, and transmission owners or
operators holding a Certificate of Public Necessity and Convenience as issued by the Regulatory
Commission of Alaska.
AEA, in conjunction with applicants, will focus on building upon existing efforts throughout the
state and supplement existing funding to improve the electric grid infrastructure, as it relates to
the ability to withstand and recover from potential disruptions.
All interested stakeholders are invited to attend one of two public meetings at AEA’s office
located at 813 W Northern Lights Blvd, Anchorage, AK 99503. Participants may join in person or
virtually.
Wednesday, September 7 from 1-2 p.m. (Alaska Time)
Tuesday, September 13 from 11 a.m.-noon (Alaska Time)
Alaska Energy Authority Page 2 of 2
For public meeting participant information, comment submissions, and program updates, please
visit https://www.akenergyauthority.org/gridresiliency.
A draft plan for public comment will be provided in advance of the meeting on Wednesday,
September 7, 2022. Comments will be incorporated into the plan submitted to DOE on
September 30, 2022.
The Alaska Energy Authority is a public corporation of the state. Its mission is to reduce the cost
of energy in Alaska.
###
Arctic Road Rally aims to show electric vehicles’ potential in Alaska
https://www.ktoo.org/2022/08/15/arctic-road-rally-aims-to-show-electric-vehicles-potential-in-alaska/ 1/4
Ten electric vehicles set out Friday from Fairbanks on a thousand-mile journey
up the Dalton Highway and back. The Arctic Road Rally is intended to
demonstrate the ability of electric vehicles to operate in the far north.
Organizers say the rally also will showcase EV technology and promote efforts
to enable the vehicles to drive anywhere on the state’s road system.
“With this event, we’re showing that it’s possible to electrify even the most
remote parts of Alaska very quickly and cost-effectively,” says Dimitri Shein,
the executive director of the Alaska Electric Vehicle Association. AKEVA is one
Arctic Road Rally aims to show electric vehicles’ potential in Alaska
https://www.ktoo.org/2022/08/15/arctic-road-rally-aims-to-show-electric-vehicles-potential-in-alaska/ 2/4
of the main supporters of the rally, along with Launch Alaska, an Anchorage-
based startup-business accelerator.
Shein, one of the organizers of the rally, says he’ll be one of those traversing
the remote stretch of the Dalton between Fairbanks and Oliktok Point — the
farthest-north point in North America accessible by road.
“I’ll be driving my wife’s Tesla, and I hope she forgives me for driving her car
down this stretch of road,” he said.
The federal Department of Energy also
is supporting the event, along with the
Alaska Energy Authority, Sandia
National Laboratories and the Center
for Technology and the Environment, a
Georgia-based nonprofit that
promotes electrifying the nation’s
transportation system.
The state Department of
Transportation is providing power for
an electric-vehicle fast charger at the
Yukon River crossing, the first of four
charging stations on the route. The
others are at Coldfoot Camp, Trans-
Alaska Pipeline Pump Station 4 and
Deadhorse.
“This will the most advanced charging
network and highway in Alaska,” he
said in a recent interview.
Arctic Road Rally aims to show electric vehicles’ potential in Alaska
https://www.ktoo.org/2022/08/15/arctic-road-rally-aims-to-show-electric-vehicles-potential-in-alaska/ 3/4
Shein says the arrangement is only temporary, but he says the infrastructure
that’ll be built-out at the four sites will remain after the rally ends. He says that
would enable charging stations to be permanently set up those locations,
once the state gets around to the Dalton as part of its plan to enable EVs to
travel throughout the road system.
“We’re pro-charging anywhere in Alaska,” he said. “So, I mean, that would be a
great outcome.”
That’s one of the objectives of the rally, says Tim Leach, who heads up Launch
Alaska’s transportation program.
“We’re interested in increasing the awareness and adoption of electric vehicles
here in the state of Alaska,” he said. “We want to make sure that electric
vehicle savings and emissions benefits are accessible to all folks who are
interested in electric vehicles.”
Leach says the rally will bring together manufacturers of EVs and charging-
station suppliers, and startups that will use the lessons learned from the rally
to understand how to make more EVs and the facilities needed to power them
available to Alaskans, wherever they live in the state.
“Some of this technology demonstration that we’re undertaking here at the
Arctic Road Rally will help us identify what technology solutions are suitable
both on the vehicle and the charging side for some of these communities that
have different sets of infrastructure,” he said.
Electric vehicle owner and advocate Phil Wight says he hopes the rally also will
help Alaskan’s understand the benefits of converting to an electric vehicle.
“The electrification of transportation can save Alaskans ultimately billions of
dollars,” he said.
Arctic Road Rally aims to show electric vehicles’ potential in Alaska
https://www.ktoo.org/2022/08/15/arctic-road-rally-aims-to-show-electric-vehicles-potential-in-alaska/ 4/4
Wight is an assistant professor of history and Arctic and Northern Studies at
the University of Alaska Fairbanks, and he’s a policy analyst with the Alaska
Public Interest Research Group. He says wasn’t able to sign up in time to enter
his Chevy Bolt in this year’s rally, but hopes to next year.
Wight hopes Alaskans will pay attention to the event because it will
demonstrate the billions in savings for would come in the form of keeping
money Alaskans keeping the money they pay local utilities for transportation
here, instead of the corporate offices of oil companies Outside.
“We spend, I think, one billion dollars every year paying for oil. We do not get
a hometown discount for our oil.”
Wight says the other savings come in the form of health benefits that come
from breathing cleaner air — an especially important consideration for people
who live in the Fairbanks area.
“Local air pollution — right? There is a significant chunk of air pollution which
emanates from light- and heavy-duty vehicles,” he said.
The 2022 Arctic Road Rally got under way at 11 a.m. Friday, Aug. 12. The
starting line was at the Golden Valley Electric Association’s headquarters on
Illinois Street in Fairbanks. The 1,096-mile rally isexpected to wrap up on
Tuesday.
By JaMes Brooks
Alaska Beacon
Up to 82,000 rural Alaskans will see lower electric bills be-cause of legislation signed into law last month.Senate Bill 243, passed by the Legislature this spring, raises the maximum subsidy under the state’s Power Cost Equal-ization program, which reduc-es the cost of electricity in rural Alaska. Gov. Mike Dunleavy signed the measure into law on July 14.The bill, authored by Bethel Sen. Lyman Hoffman, increas-es the maximum available sub-sidy from 500 kilowatt-hours
per month to 750 kilo-
watt-hours per month. The av-
erage Alaska home consumes
552 kilowatt-hours per month,
according to figures from the
U.S. Energy Information Ad-
ministration.
Alaska’s average home elec-
tricity rate is 22.57 cents per kilo-watt-hour, the third-highest rate
in the country, according to the
EIA, but prices in rural Alaska
can be much higher.
In the Kuskokwim River town
of McGrath, for example, a resi-
dential customer pays almost
58 cents per kilowatt-hour, ac-
cording to figures from the Reg-
ulatory Commission of Alaska.
With the PCE subsidy, that falls
to 37.21 cents — still above av-
erage for the state, but almost
20 cents lower than the unsub-
sidized cost.
The subsidy covers homes,
apartments and community fa-
cilities.
Residential customers in
Wrangell, which is not covered
by the rural subsidy program,
generally pay between 12 cents
and 14.5 cents per kilowatt-hour.
As created in 1984, PCE was
intended to serve as part of a
grand compromise across the
state: Coastal communities,
including Wrangell, received
hundreds of millions of dol-
lars for hydroelectric projects;
Southcentral Alaska received
cheap natural gas; and rural
Alaska received PCE.
The program originally
subsidized up to 750 kilo-
watt-hours per month, but
legislators reduced that to 500
in 2000 because of the cost of
the program.
Lawmakers subsequently
created an endowment fund to
pay for PCE in perpetuity, and
cost estimates indicate that the
endowment’s earnings are suf-
ficient to pay for the 750 kilo-
watt-hour program.
The endowment also funds
community assistance grants
and renewable-energy proj-
ect grants. Legislators were
warned this spring that in-
creased spending on PCE
could mean insufficient money
for those other programs.
Members of the Senate Fi-
nance Committee were told
that an additional $320 mil-
lion deposit into the PCE
endowment was necessary
to avoid the risk. No deposit
was made.
The AlaskaBeacon.com is a do-
nor-funded independent news or-
ganization in Alaska.
Page 8 - August 3, 2022 WRANGELL SENTINEL
By cLarise Larson
Juneau Empire
The summer Dungeness crab commercial season ended
Saturday, with reports of low catch rates.
“On a regionwide level, there are no bright spots, and gen-
erally regionwide catch rates have been down,” said Joseph
Stratman, the lead Southeast crab biologist for the Alaska Department of Fish and Game.
It was a shorter-than-typi-cal summer Dungeness season
for the 201 permitted crabbers in Southeast. The department
trimmed about two weeks from the season after data collected from the first week of the season,
which started June 15, pointed to an estimated full-season harvest
of about 2 million pounds, which is lower than the 2.25 million
pound threshold in regulation.It was only the third time in the past 20 years that the
department had cut short the summer season.
But, Stratman said, South-east Alaska can expect the
fall Dungeness season to last at least a month and possibly longer pending port sampling
data analysis that will be con-ducted in between the seasons.
The sampling data will give in-sight as to what fishermen saw
during the summer months and help determine the po-
tential harvest numbers that could be expected for the fall.He said people can likely ex-
pect the decision on the length of the fall season to be an-
nounced in mid-August. The
fall season will start Oct. 1.
Last year, the summer season
lasted around two months —
mid-June to mid-August — and
the overall Dungeness crab har-
vest numbers for summer and
fall clocked in at around 4.23
million pounds, well above the
10-year harvest average in the
region but not nearly as high as
2020’s nearly record-breaking
harvest at 5.87 million.
“Nobody did good at all, it’s
one of the worst seasons that
I’ve heard of in I don’t know
how long,” said Mitch Mork,
a former crabber in Wrangell.
Stratman said he can’t iden-
tify any specific causes as to why catch rates are down,
but said it’s not atypical to
see numbers fluctuate from
year to year. “From what I’ve
heard, people weren’t catching
a lot of crabs.”
Studies by the Office of
National Marine Sanctuaries
at the National Oceanic and
Atmospheric Administra-
tion suggest that Dungeness
populations will likely face
challenges as climate change
continues to grow as more of
a threat to ocean sustainability.
Ocean acidification has
been linked to a projected de-
cline over the next 50 years
in Dungeness crab, larval de-velopment rates and survival and an overall loss in econom-
ic value, according to a case
study published by NOAA
fisheries in collaboration with
the National Marine Sanctuary
Foundation and NOAA Ocean
Acidification Program.
State ended summer
Dungeness season
early last Saturday
By GarLand kennedy
Sitka Sentinel
After the longest summer king salmon troll opening in nearly 20 years, the Southeast Alaska commercial troll fishery closed to the taking of all salmon for three days as a coho conservation measure, the Department of Fish and Game an-nounced July 25.The closure went into effect at 11:59 p.m. July 28 and ended at 12:01 a.m. on Monday, Aug. 1.Despite the lengthy four-week king opening, the fleet hooked less than three-quarters of its an-ticipated July catch. All told, trollers were expect-ed to have taken about 87,000 king salmon by the time of the shutdown, leaving 67,000 fish in the summer allocation uncaught.The troll fishery now will remain open indefi-nitely until closed by emergency order.The goal of the three-day closure was to ensure that adequate numbers of coho salmon could make it to their home streams, said Grant Hager-man, troll management biologist with the Alaska Department of Fish and Game in Sitka.“It’s just to ensure that we’re getting enough fish that are passing to inside waters and moving toward more terminal areas for escapement and to the river mouths,” Hagerman said July 26.Regardless of coho catch rates, king salmon catch rates were low.
While a number of factors are in play in the low
king salmon harvest, Hagerman said, reduced fish-ing effort and lower king salmon abundance likely
have a significant role in the diminished haul.At the start of July, about 580 boats were active
in the Southeast fishery, he said, but as the weeks
drew on, that number declined by roughly half. Initially, the department estimated that the first
summer troll opener would last about 12 days, but it ran for 28. In 2003, a year of tremendous salmon
abundance, the king opener lasted for 39 days.
The upcoming closure is the first-ever July coho conservation closure. Such closures have previ-
ously happened in August, and can sometimes last for more than a week.
A number of trollers have been targeting cohos
instead of kings, which Hagerman said has fur-ther reduced the overall chinook catch and led to
a longer king opening.The brief duration of the closure is likely to
cause bottlenecks for the fleet, said Alaska Troll-
ers Association president Matt Donohoe, of Sitka.“A three-day closure really bottlenecks the fleet.
It screws up the plants for packers and ice. If, like us, you’re out on the grounds trying to fish it’s a
day at least to get back to town,” Donohoe said.Meanwhile, trollers can continue to target hatchery salmon in designated terminal harvest
areas during the closure.
Troll fishery closed 3 days to preserve coho
State will provide more help with high-cost electric bills
Alaska to receive funding for electric vehicle charging program
https://www.alaskasnewssource.com/2022/08/03/alaska-receive-funding-electric-vehicle-charging-program/ 1/2
ANCHORAGE, Alaska (KTUU) - Alaska is expected to receive millions in federal
funding for electric vehicle (EV) charging infrastructure.
The Alaska Energy Authority and the Alaska Department of Transportation and
Public Facilities submitted the State of Alaska Electric Vehicle Infrastructure
Implementation Plan, on Friday according to the AEA’s press release.
“This plan builds on Alaska’s interest in clean transportation, reducing
greenhouse gas emissions, and ensuring that Alaskans and visitors alike have a
reliable, convenient network of EV chargers,” AEA Executive Director Curtis W.
Thayer said.
Alaska to receive funding for electric vehicle charging program
https://www.alaskasnewssource.com/2022/08/03/alaska-receive-funding-electric-vehicle-charging-program/ 2/2
The release said that Alaska will be granted $50 million from the National
Electric Vehicle Infrastructure program over a span of five years, beginning this
year.
The first year of funding will be dedicated to installing electric charging stations every 50
miles along the Alternative Fuel Corridor, and within one travel mile of the highway.
Alaska to receive funding for electric vehicle charging program
https://www.alaskasnewssource.com/2022/08/03/alaska-receive-funding-electric-vehicle-charging-program/ 1/1
ANCHORAGE, Alaska (KTUU) - Alaska is expected to receive millions in federal funding
for electric vehicle (EV) charging infrastructure.
The Alaska Energy Authority and the Alaska Department of Transportation and Public
Facilities submitted the State of Alaska Electric Vehicle Infrastructure Implementation
Plan, on Friday according to the AEA’s press release.
“This plan builds on Alaska’s interest in clean transportation, reducing greenhouse gas
emissions, and ensuring that Alaskans and visitors alike have a reliable, convenient
network of EV chargers,” AEA Executive Director Curtis W. Thayer said.
The release said that Alaska will be granted $50 million from the National Electric
Vehicle Infrastructure program over a span of five years, beginning this year.
The first year of funding will be dedicated to installing electric charging stations every 50
miles along the Alternative Fuel Corridor, and within one travel mile of the highway.
813 W Northern Lights Blvd, Anchorage, AK 99503 Phone (907) 771-3000 Fax: (907) 771-3044 Email: info@akenergyauthority.org
REDUCING THE COST OF ENERGY IN ALASKA AKENERGYAUTHORITY.ORG
RGYAUTHORITY.ORG
PRESS RELEASE
Brandy M. Dixon
Communications Director
(907) 771-3078
FOR IMMEDIATE RELEASE
August 3, 2022
AEA Submits Alaska’s National Electric Vehicle Infrastructure Plan
Alaska is slated to receive $50 million over five years for EV charging infrastructure
(Anchorage) — On Friday, the Alaska Energy Authority (AEA), in coordination with the Alaska
Department of Transportation & Public Facilities (DOT&PF), submitted its State of Alaska Electric
Vehicle Infrastructure Implementation Plan (The Plan) to the United States Joint Office of Energy
and Transportation. Once approved, The Plan will allow Alaska to receive millions in federal
funding to strategically deploy electric vehicle (EV) charging infrastructure.
Through the National Electrical Vehicle Infrastructure (NEVI) program included in the
Infrastructure Investment and Jobs Act (IIJA), Alaska will receive $50 million over five years to
build out a network of EV charging stations along highway corridors. The funds will be received
by DOT&PF and administered by AEA for the duration of the program. The Plan was developed
in collaboration with multiple State agencies and partners, local governments, utilities, and other
stakeholder groups in Alaska. The Plan is a five-year vision and is intended to be a living
document updated regularly to reflect changes to initiatives and focus areas.
“Alaskans have an incredible opportunity to benefit from these federal infrastructure
investments,” said AEA Executive Director Curtis W. Thayer. “This plan builds on Alaska’s
interest in clean transportation, reducing greenhouse gas emissions, and ensuring that Alaskans
and visitors alike have a reliable, convenient network of EV chargers.”
“We are pleased to partner with AEA, an agency that shares our commitment to Alaskans," said
DOT&PF Commissioner Ryan Anderson, PE. “Together, we combine AEA’s expertise in energy
infrastructure with DOT&PF’s knowledge of Alaskans’ distinct transportation needs, allowing us
to ensure EV charging infrastructure investments by the State are strategic, coordinated,
efficient, and equitable.”
The NEVI funding will be distributed over five years (2022-2026). The first round of funding
prioritizes the installation of EV charging stations every 50 miles along the State’s designated
Alternative Fuel Corridor (AFC) and within one travel mile of the highway. The new charging
stations must have at least four EV fast charging ports. The NEVI program also allocates $2.5
billion for discretionary grants to support charging stations along other highway corridors and
community charging grants. The Joint Office will provide additional guidance for discretionary
grants in Fall 2022.
Alaska Energy Authority Page 2 of 2
The NEVI Program provides formula funding to states to award grants to private, public, and
nonprofit entities to build, own, maintain and operate chargers. The program pays up to 80
percent of eligible costs for charging infrastructure. Neither AEA nor DOT&PF plans to own or
operate any EV chargers.
The Plan outlines a strategy for using the NEVI formula funds to deliver EV charging
infrastructure that will enable light-duty EV travel and provide confidence when commuting
throughout the state for work, recreation, and tourism. This Plan supports the goals and
objectives of the State’s long-range transportation plan. Programs and projects funded through
the NEVI Program will follow the U.S. Department of Transportation and Federal Highway
Administration’s regulatory requirements and will be included in DOT&PF’s Statewide
Transportation Improvement Plan.
AEA will continue to be open to questions and comments on The Plan, and those can be
submitted to electricvehicles@akenergyauthority.org. We encourage the public to periodically
visit this site for installation progress, FAQs, and further planning updates. For more information,
visit Alaska’s NEVI Plan.
The Alaska Energy Authority is a public corporation of the state. Its mission is to reduce the cost
of energy in Alaska.
###