HomeMy WebLinkAbout2025-09-19 BPMC Agenda and docsBRADLEY LAKE PROJECT MANAGEMENT COMMITTEE MEETING AGENDA September 19,2025 10:00 AM To participate dial 1-888-585-9008 and use code 212-753-619#
1. CALL TO ORDER
2. ROLL CALL (for Committee members)
3. PUBLIC ROLL CALL (for all others present)
4. AGENDA APPROVAL
5. PUBLIC COMMENTS
6. APPROVAL OF MEETING MINUTES – July 25, 2025
7. NEW BUSINESS - NONE
8. OLD BUSINESS
A. Resolution 25-03 In Support of Dixon Diversion Financing
B. Updates:
i. CIPLink (Grip 3, Phase 1 Update) Jim Mendenhall
ii. Bradley Lake Expansion Project Update Ryan McLaughlin (Dixon Diversion /Bradley Pool Raise)
iii. SQ Upgrade Update
C. Railbelt Regional Coordination Update Brian Hickey
9. OPERATORS REPORT Martin Law
10. COMMITTEE REPORTS
A. Audit Update Mark Ziesmer
B. O&D Report Josh Crowell
11. EXECUTIVE SESSION – (Bylaws Section 5.11.4) – To discuss (1) confidential financial matters the immediate knowledge of which may have an adverse effect on the Authority or Project; and (2)
confidential personnel matter.
12. MEMBERS COMMENTS
13. NEXT MEETING DATE – December 5, 2025
14. ADJOURNMENT
DRAFT
1
BRADLEY LAKE PROJECT MANAGEMENT COMMITTEE
RESOLUTION NO. 25- XX
INTRODUCTION
The Bradley Lake Project Management Committee (“BPMC”) is responsible for the
management, operation, maintenance, and improvement of the Bradley Lake Hydroelectric
Project (the “Project”), subject to the non-delegable duties of the Alaska Energy Authority (the
“Authority”). The Authority is currently pursuing an amendment to the Project’s Federal Energy
Regulatory Commission (“FERC”) license to include a diversion of water from the Dixon Glacier to
the existing Bradley Lake reservoir to increase the energy output at the Project (the “Dixon
Diversion”).
PURPOSE OF THE RESOLUTION
BPMC Resolution 25-XX sets forth the support of the BPMC for the Authority’s proposed
amendment to the FERC license for the Project and the financing necessary to complete the
Dixon Diversion in order to increase the delivery of sustainable low-cost clean energy produced
by the Project.
BPMC RESOLUTION NO. 25-XX
WHEREAS, the Bradley Lake Project Management Committee (“BPMC”) receives its
authority under the Bradley Lake Hydroelectric Project Agreement for the Sale and Purchase of
Electric Power (“Power Sales Agreement”) by and between Chugach Electric Association, Inc.
("CEA"), Homer Electric Association, Inc.("HEA"), Golden Valley Electric Association, Inc. ("GVEA"),
Matanuska Electric Association, Inc. ("MEA"), City of Seward d/b/a Seward Electric System
("SES"), Alaska Electric and the Alaska Energy Cooperative, Inc.("AEEC") and the Authority.
WHEREAS, the Project is among the lowest cost renewable energy generating facility on
the Railbelt Electric System.
WHEREAS, as the Authority pursues a FERC license amendment it is also evaluating
financing options for the Dixon Diversion. The Dixon Diversion is expected to increase the
energy output from Project by approximately 180,000MWh/year, beginning in the year 2031.
The project as proposed sits entirely on state land and efficiently utilizes existing Project
infrastructure.
NOW, THEREFORE, BE IT RESOLVED THAT, the aforementioned comments, statements
and recitals are incorporated and made part of this Resolution No. 25-XX.
BE IT ALSO RESOLVED THAT, the proposed amendment to the Project’s FERC license
includes a diversion of water from the Dixon Glacier to the existing Bradley Lake reservoir
increasing the energy output at the Project and may include the following components: a
DRAFT
2
diversion dam at the toe of the Dixon Glacier, a pipeline to convey water from the Dixon Glacier
into Bradley Lake, a new road, and modifications to the existing Bradley Dam that may raise the
pool elevation by 14 feet.
BE IT ALSO RESOLVED THAT, the BPMC supports the Authority as it develops a financing
plan to complete FERC licensing amendments and construction of the Dixon Diversion. As
Project Participants under the Power Sales Agreement each of CEA, HEA, GVEA, MEA, AEEC and
SES agree to accept and pay for the increase in energy output consistent with their Percentage
Share as defined in the Power Sales Agreement, subject to the following preconditions: (1) the
Dixon Diversion shall be deemed a Required Project Work project under the Power Sales
Agreement; and (2).the Required Project Work determination is supported by any necessary
industry and economic opinions and reviewed by the O&D Committee and Finance Committee
of the BPMC.
DATED at Anchorage Alaska, this _____ day of September 2025
______________________________
Chair, Tony Izzo
Attest : ______________________________
Secretary, Curtis Thayer
DRAFT
1
BRADLEY LAKE PROJECT MANAGEMENT COMMITTEE
RESOLUTION NO. 25- XX
INTRODUCTION
The Bradley Lake Project Management Committee (“BPMC”) is responsible for the
management, operation, maintenance, and improvement of the Bradley Lake Hydroelectric
Project (the “Project”), subject to the non-delegable duties of the Alaska Energy Authority (the
“Authority”). The Authority is currently pursuing an amendment to the Project’s Federal Energy
Regulatory Commission (“FERC”) license to include a diversion of water from the Dixon Glacier to
the existing Bradley Lake reservoir to increase the energy output at the Project (the “Dixon
Diversion”).
PURPOSE OF THE RESOLUTION
BPMC Resolution 25-XX sets forth the support of the BPMC for the Authority’s proposed
amendment to the FERC license for the Project and the financing necessary to complete the
Dixon Diversion in order to increase the delivery of sustainable low-cost clean energy produced
by the Project.
BPMC RESOLUTION NO. 25-XX
WHEREAS, the Bradley Lake Project Management Committee (“BPMC”) receives its
authority under the Bradley Lake Hydroelectric Project Agreement for the Sale and Purchase of
Electric Power (“Power Sales Agreement”) by and between Chugach Electric Association, Inc.
("CEA"), Homer Electric Association, Inc.("HEA"), Golden Valley Electric Association, Inc. ("GVEA"),
Matanuska Electric Association, Inc. ("MEA"), City of Seward d/b/a Seward Electric System
("SES"), Alaska Electric and Energy Cooperative, Inc. ("AEEC") and the Authority.
WHEREAS, the Project is among the lowest cost renewable energy generating facility on
the Railbelt Electric System.
WHEREAS, as the Authority pursues a FERC license amendment it is also evaluating
financing options for the Dixon Diversion. The Dixon Diversion is expected to increase the
energy output from Project by approximately 180,000MWh/year, beginning in the year 2031.
The project as proposed sits entirely on state land and efficiently utilizes existing Project
infrastructure.
NOW, THEREFORE, BE IT RESOLVED THAT, the aforementioned comments, statements
and recitals are incorporated and made part of this Resolution No. 25-XX.
BE IT ALSO RESOLVED THAT, the proposed amendment to the Project’s FERC license
includes a diversion of water from the Dixon Glacier to the existing Bradley Lake reservoir
increasing the energy output at the Project and may include the following components: a
Deleted: the Alaska
DRAFT
2
diversion dam at the toe of the Dixon Glacier, a pipeline to convey water from the Dixon Glacier
into Bradley Lake, a new road, and modifications to the existing Bradley Dam that may raise the
pool elevation by 14 feet.
BE IT ALSO RESOLVED THAT, the BPMC supports the Authority as it develops a financing
plan to complete FERC licensing amendments and construction of the Dixon Diversion. As
Project Participants under the Power Sales Agreement each of CEA, HEA, GVEA, MEA, AEEC and
SES agree to accept and pay for the increase in energy output consistent with their Percentage
Share as defined in the Power Sales Agreement, subject to the following preconditions: (1) the
Dixon Diversion shall be deemed a Required Project Work project under the Power Sales
Agreement; (2)the Required Project Work determination is supported by any necessary industry
and economic opinions; and (3) each Project Participant’s governing board shall authorize the
financing.
DATED at Anchorage Alaska, this day of September 2025
Chair, Tony Izzo
Attest :
Secretary, Curtis Thayer
Deleted: and
Deleted: .
Deleted:
Deleted: reviewed by the O&D Committee and
Finance Committee of the BPMC
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: BPMC THROUGH: Curtis Thayer, Executive Director FROM: Jim Mendenhall, P.E., Program Manager DATE: September 15, 2025
SUBJECT: Cook Inlet Power Link – Update
DOE Information Request
As previously reported AEA submitted a project package to the DOE Process Review Team in
June. On August 15, 2025 we received an email stating that “The DOE is working to complete
the data review process as expeditiously as possible and will be in contact as soon as possible.”
DOE Contract Status
AEA’s initial award covered a project budget period ending June 30, 2025. A formal “Go”
decision recommendation was submitted to DOE on May 9th based on preliminary design
documentation confirming the project can be completed on time and within budget. DOE technical staff indicated concurrence with AEA’s recommendation to proceed. A continuation request and cost estimate for Budget Period 2 (July 1, 2025 – June 30, 2027) was submitted to DOE in mid-May. DOE’s technical and contracting representatives provided verbal confirmation of support for continuing into Budget Period 2. However, execution of a continuation agreement is pending authorization from the DOE Process Review Team. As a result, contract execution for procurement, environmental and FEED-related work has been postponed. Project development activities are continuing in the interim to remain on schedule.
AEA determinied that we need to continue working on the project so we authorized two task
orders:
1)Environmental Review - Following submission of the Data Request package, a NEPA
Environmental Questionnaire was provided to DOE in support of Budget Period 2 scope of work.
A Categorical Exclusion determination was issued within 10 days, enabling environmental and
fieldwork activities to proceed in Summer 2026. AEA awarded a Task Order to HDR to complete
the environmental work needed to be executed next summer.
2) Development of major equipment procurement documents – Stantec will assist AEA with
planning, solicitation, and procurement contracts for major items of supply, in particular the
HVDC converters and the HVDC cable. These items are expected to have very long lead times, on the order of several years. This task will build on information gained during earlier execution of the earlier tasks including: preliminary design, the budgetary costs, and the project schedule
Alaska Energy Authority Page 2 of 2
(Task 1). Work on this task will include:
1) Determine contracting strategy for the HVDC cables and converters,
2) Prepare and issue a solicitation of interest / request for information (RFIs) to converter and cable suppliers to solicit interest, 3) Obtain budgetary pricing, preliminary delivery schedule, and technical information. AEA expects that the HVDC Converter procurement will be for a full EPC turnkey contract, on a negotiated, preferred supplier basis, not a competitive procurement of converters. AEA expects that the Cable procurement is assumed to involve a combined supply and install
contract on a competitive basis; contract may also evolve into a preferred supplier basis
depending on RFI responses.
Financial Status and Cost Share Strategy
AEA has secured $64.2 million in combined state appropriations and Bradley bond proceeds. An
additional $142.3 million is being sought to fully meet cost share obligations.
To date, $1,411,881 has been spent on the project
AEA is reviewing financing options to secure the balance of the funding, including;
1) Loans (Focus on DOE Loan Program Office)
2) Private Debt
3) P3 Arrangements
4) Private Equity
MEMORANDUM
TO: Bradley Project Management Committee
Through: Curtis Thayer, Executive Director
FROM: Ryan McLaughlin, PE, Senior Infrastructure Engineer
DATE: September 19, 2025
RE: Bradley Lake Expansion Project Update
Engineering
Design and licensing efforts are ongoing, with a target submittal of the Draft License
Amendment Application by January 2026. To ensure consistency and clarity throughout the
FERC licensing documents, design deliverables, and environmental reports, the overall project
will be called the “Bradley Lake Expansion Project” and sub-projects defined as follows:
Bradley Lake Expansion Project
o Dixon Diversion
▪ Diversion dam and tunnel inlet portal features
▪ Diversion tunnel
▪ Diversion tunnel exit portal features
▪ Exit portal access road
o Bradley Pool Raise
▪ Spillway crest raise
▪ Dam crest raise
Crews and equipment mobilized to Bradley by barge over the weekend to begin drilling and
geophysics at Bradley Dam. Over the next month 9 boreholes will be drilled through and around
Bradley Dam to set up monitoring, test stability, and collect samples of embankment material.
Additional geophysical surveys will be completed at the Bradley Dam and the Dixon Diversion
site. Equipment is onsite and first borehole is expected to spud on 9/15. The Drilling Plan
Program has been approved for FERC and AEA has received a DNR temporary water use
authorization permit for the work.
AEA and DOWL will be onsite 9/17-18 to complete annual operator training and safety
inspection of the Bradley Dam. This site visit will also include a trip to the Dixon Diversion Dam
site for the project engineers to evaluate current design against site conditions.
The next Board of Consultants meeting has been scheduled for October 29-31. This meeting will
review results from the PMP/PMF study, initial drilling results, and design documents. AEA has
responded to FERC comments on the PMF Scope of Work. Study is ongoing, but initial results
suggest PMP is slightly lower and PMF is slightly higher (larger drainage area) compared to the
original studies done in the 80’s.
AEA submitted an Inflow Design Flood recommendation (IDF) to FERC for the future Dixon
Diversion Dam. This was done using a conservatively estimated 100-year flood of 7,900 cfs. 100-
year flood is a common IDF for low-hazard dams, AEA is waiting on FERC acceptance of the low-
hazard classification for the Dixon Diversion Dam. Battle Creek Diversion and Bradley Dam are
both low-hazard, no structures or populations below the Dixon Diversion Dam, so it is expected
that the Dixon Diversion Dam will be low-hazard.
The design for 3-phase power from Bradley powerhouse to the dam is at 65%. EPS is on track to
complete the design and bid package by next summer in order purchase cable and transformers
in time for shipment and delivery for a summer 2027 install.
A decision has been made to fully line the Dixon Tunnel. This will have minimal cost impact to
the project compared to previous cost estimates, improve worker safety (24/7/365 operations
inside tunnel), improve hydraulics (no chokepoints), and reduce construction risk (many sections
may need lining anyway). A design criteria has been established for a 14’ minimum finished
inside diameter tunnel (16’ tunnel w/ 1’ concrete liner) which will provide up to 1650 cfs of flow.
This balances cost of a larger tunnel vs additional capacity of higher future flows.
Environmental
Aquatic, terrestrial, and cultural resources studies and summer 2025 field season is on schedule,
as per approved Study Plan. This is the final summer of environmental studies.
An August 29th stream gaging trip had the highest spot measurement of discharge recorded on
Martin River – 2490 cfs at the constriction. This will be very useful in continuing to build out the
stage-discharge relationship on the Martin River as many measurements have been collected at
mid flows, few at high flows.
ADFG counted 1479 sockeye through Red Lake, the highest count in three years of monitoring.
The Red Lake monitoring site is getting unsafe to access as Martin River channel is cutting
through to the video monitoring site. The next site visit with ADFG/DOWL will need to cut a new
landing zone. The Coho run is ongoing and ADFG is hoping the video site isn’t destroyed by
high flows until the run is complete.
Landing Zone: low vs high flow
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: BPMC
THROUGH: Curtis Thayer, Executive Director
FROM: Jim Mendenhall, P.E., Program Manager
DATE: September 15, 2025
SUBJECT: Transmission Upgrades – Sterling to Quartz Creek & Soldotna to Sterling
The Sterling Substation to Quartz Creek Transmission Line (SQ of SSQ Line)
•Overall length of the SQ Line is 39 miles.
•Prior to AEA’s acquisition of the SQ Line it was owned by Homer Electric Association.
•This section was damaged in 2019 during the Swan Lake Fire, and was unusable.
•The Alaska Energy Authority's acquired the line in late 2020 to repair it, and enablefuture upgrades. Specific benefits include: better cost alignment for customers,increased reliability, and future prospects for upgrades to decrease line losses andallow more power transmission from Bradley Lake. The SQ Line was identified asRequired Project Work under the Bradley Power Sales Agreement. As such, it isdeemed a critical component of the interconnected Railbelt transmission system,needed to ensure the consistent delivery of low-cost, renewable hydroelectric powerfrom the Bradley Lake Hydroelectric Project to population centers.
•The SQ Line is currently being upgraded from 115kV to 230kV standards to increase its
capacity and resilience.
•Bradley Lake hydro has a nameplate generating capacity of 120MW. However, the
maximum transfer capacity on the SQ line is significantly less. The reason for the
limitation is that the current transmission system is limited to an absolute maximum of
75MW for thermal over load and stability limitations. Note: At 75MW of power transfer,
losses are ~10%.
The SQ Upgrade Project
•The project is broken into three phases
o Each of the projects needs to have approximately a 40-day outage of the
transmission line.
o Phase 1 -The section is the 8 miles between Sterling and Johns Road and was
completed during the winter of 2024/2025. Field conditions for Phase 1 were
difficult due to the warm weather and required ground matting to support the
equipment. The section was as completed and energized to 115kV on February
28, 2025
Alaska Energy Authority Page 2 of 4
o Phase 2 – Will upgrade 17 miles through the Kenai National Wildlife Refuge. This
section will be constructed in the winter 2026/2027. When complete it will be
energized to 115kV.
o Phase 3 (previously 3 & 4) – Will upgrade 14 miles from The Russian River to the
Quartz Creek Substation (CEA). This section will be constructed during the winter
2028/2029
•Once all 3 projects are completed and CEA completes the upgrades between Quartz
Creek to Anchorage, HEA completes the SS (Soldotna-Sterling) and all upgrades at
substations are complete the entire circuit will be energized to 230kV.
Alaska Energy Authority Page 3 of 4
Project Map
Alaska Energy Authority Page 4 of 4
Updated Cost Projection by CEA Plus AEA Admin
Chugach Electric - Week Ending 08-31-25 Actuals Project 1 Remaining Fo Project 1 Total Actuals Project 2 Remaining Forec Project 2 Total Actuals Projec Remaining Forec Project 3 Totals Total Project Fore
E2290300 - SSQ (Sterling to Quartz)
Miscellaneous $14,212 $14,212 $0 $0 $14,212
Chugach Labor $71,142 $71,142 $15,631 $116,735 $132,366 $18,922 $133,575 $152,497 $356,006
Contract Services $1,507,782 $50,000 $1,557,782 $1,417,006 $2,740,239 $4,157,245 $650,355 $3,586,217 $4,236,572 $9,951,600
Materials $4,482,599 $4,482,599 $9,933,810 $9,933,810 $8,128,879 $8,128,879 $22,545,288
Transportation $3,948 $3,948 $0 $0 $3,948
Construction $6,099,260 $6,099,260 $16,194,179 $16,194,179 $13,726 $23,362,050 $23,375,776 $45,669,215
Overhead 13.81% $355,146 $7,000 $362,146 $211,066 $4,303,088 $4,514,154 $106,405 $5,863,723 $5,970,129 $10,846,429
Totals $12,534,090 $57,000 $12,591,090 $1,643,703 $33,288,051 $34,931,754 $789,408 $41,074,445 $41,863,853 $89,386,697
Total Actuals $14,967,201 $12,534,090 $1,643,703 $789,408
Add for AEA Admin 3.00%$377,733 $1,047,953 $1,255,916 $2,681,601
Projected Total with AEA Admin $12,968,822 $35,979,707 $43,119,769 $92,068,298
Project 1 Project 2 Project 3
Soldotna to Sterling Substation (SS Line)
• The section between Soldotna and Sterling Substation (SS) needs to be upgraded.
• This section is owned by HEA.
• This project was planned to be constructed in the 2025/2026 winter. However, the project was put on hold due to the extreme price of steel
for the structures and piling. In addition, the delivery window of the steel components did not fit with the anticipated construction window.
• The original planned cost of the SS Line upgrades was $24.4M, the revised cost estimate with contingency is $35.8M.
• With the SS line being postponed, the construction schedule has no work is planned for this winter.
• Budget issues related to the SS Line will be reviewed by the Bradley Lake Project Management Committee for guidance.
Sterling to Quartz Creek Transmission
Line Rebuild Project
BPMC Meeting
September 19, 2025
Agenda
2
•Project Overview
•Project Status and Schedule
•Project Costs
•Q&A
Project Overview
•Rebuilding 39 miles of the Quartz Creek transmission line
between Sterling Substation and Quartz Creek Substation
that is owned by AEA
•Existing 100-Foot-Wide ROW
•Will be constructed in three separate projects
•Project 1 –8 miles –Construction 2024/2025
•Project 2 –18 miles –Construction 2026/2027
•Project 3 –13 miles –Construction 2027/2028
3
Why?
4
Needs:
•End of lifespan
•Foundation/anchor corrosion and other damage
•Reliability for critical transmission infrastructure
−Transports power from Bradley Lake hydroelectric plants
−Delivers power to Kenai Peninsula communities
Scope of Work
5
Scope:
•Retire approx. 39 miles of transmission line between Sterling Substation
and Quartz Creek Substation
•Install new: conductor, fiber optic cable, structures, guys, anchors, and
foundations
•No distribution outages expected
Project Status and Proposed Schedule
Project 1 –8 miles –Sterling Substation to Three Johns Road at Structure 31-3
•Construction Completed
•As-builts and closeout in progress
Project 2 –18 miles –Three Johns Road at Structure 31-3 to Mystery Hills Structure 12-7
•Bids for Steel Pole Structures Received on September 15, 2025
•Final EA to be issued in October 2025
•Bid package in May 2026
Project 3 –13 miles –Mystery Hills Structure 12-7 to Quartz Creek Substation
•Final EA to be issued in October 2025
•Completed staking, engineering field review, and geotechnical
exploration between Quartz Creek Substation and the Russian
River
•Remaining section staking, engineering field review, and
geotechnical exploration planned for September 8 –October 21
6
Project Costs
7
•Material cost forecast for Projects 2 and 3 are based on the actuals from Project 1
•Expecting an 80% cost increase for steel poles structures
•Expecting a 100% cost increase for steel piling
•Expecting a 5-15% cost increase for remaining materials
•Construction cost forecast for Projects 2 and 3 are based on the actuals from Project 1
•Expecting a 5-15% cost increase for Project 2 construction due to labor, equipment, and material inflation
•Working with engineering consultant to produce updated Project 3 construction estimate due to permitting requirements for helicopter only work
(Mystery Hills and the Islanded section) and challenging access areas (between Cooper Creek and the Russian River)
Week Ending 08-31-25 Actuals FTC EAC Actuals FTC EAC Actuals FTC EAC Actuals FTC EAC
EAC with
Inflation
E2290300 -Sterling to Quartz T-Line Rebuild Project 1 Project 2 Project 3 Total Project
Miscellaneous $14,212 $14,212 $0 $0 $14,212 $0 $14,212 $14,212
Chugach Labor $71,142 $71,142 $15,631 $116,735 $132,366 $18,922 $133,575 $152,497 $105,695 $250,311 $356,006 $356,006
Contract Services $1,507,782 $50,000 $1,557,782 $1,417,006 $2,740,239 $4,157,245 $650,355 $3,586,217 $4,236,572 $3,575,143 $6,376,456 $9,951,600 $9,951,600
Materials $4,482,599 $4,482,599 $9,933,810 $9,933,810 $8,128,879 $8,128,879 $4,482,599 $18,062,689 $22,545,288 $33,778,329
Transportation $3,948 $3,948 $0 $0 $3,948 $0 $3,948 $3,948
Construction $6,099,260 $6,099,260 $16,194,179 $16,194,179 $13,726 $23,362,050 $23,375,776 $6,112,986 $39,556,229 $45,669,215 $51,604,708
Overhead $355,146 $7,000 $362,146 $211,066 $4,303,088 $4,514,154 $106,405 $5,863,723 $5,970,129 $672,618 $10,173,811 $10,846,429 $10,846,429
Totals $12,534,090 $57,000 $12,591,090 $1,643,703 $33,288,051 $34,931,754 $789,408 $41,074,445 $41,863,853 $14,967,201 $74,419,496 $89,386,697 $106,555,232
Q&A
1
Bradley Lake Project Management CommiƩee Report on Railbelt
Regional CoordinaƟon
September 15th, 2025
Overview:
The Bradley Lake Project Management CommiƩee is focused on two main objecƟves: expanding
the project's capacity from 90 MW to its full potenƟal of 120 MW and ensuring the reliable and
resilient delivery of energy and capacity to all stakeholders. Moreover, the commiƩee is
commiƩed to addressing and eliminaƟng large-scale, small-signal instability oscillaƟons that
arise when the Bradley Project interacts with the summer valley during periods of low lake
levels. Consistent with SecƟon 32 of the Power sales agreement, which commits the
parƟcipants to seek a high-capacity interƟe between the Kenai and Fairbanks, a comprehensive
regional transmission plan, named the Grid ModernizaƟon and Resiliency Plan (GMRP), has
been developed.
The implementaƟon of GMRP is expected to yield several ancillary benefits, including a more
resilient and robust grid capable of withstanding extreme weather events and other disrupƟons.
The modernizaƟon efforts will enhance power transfer capabiliƟes between regions, reduce the
need for thermal reserves, decrease fuel consumpƟon, and cut carbon emissions. AddiƟonally,
the upgraded grid will beƩer accommodate variable clean energy sources.
This report outlines our acƟviƟes related to these efforts over the months of August and
September.
Contractors:
None
Grant Efforts:
State Match efforts
The Legislature adjourned with minimal acƟvity in this area.
Looking Forward:
No specific acƟons are on the horizon, unless DOE iniƟated GRP cycle three funding.
Other AcƟviƟes:
As noted previously, on April 3rd, I transiƟoned to a reduced (40%) role at EDRRC as I
begin assisƟng the Seward Electric System with their uƟlity management. However, I will
conƟnue to oversee the Federal Grant applicaƟons process and aid as required in state
and uƟlity match efforts.
2
This report reflects our conƟnuous commitment to enhancing the Railbelt region's energy infrastructure
and resilience, marking significant milestones in our journey towards a more sustainable and efficient
energy future.
Bradley Lake Operators Report Page 1
Bradley Lake Operator Report
BPMC
September 19, 2025
Unit Statistics:
Generation Unit 1 (MWhrs) Unit 2 (MWhrs) Total (MWhrs)
July 2025
Aug. 2025
Sept. *2025
16,634
22,746
9,476
16,576
21,198
8,743
33,210
43,945
18,210
Hydraulics Avg. Lake Level
(ft.)
Bradley Fishwater
(ac ft.)
Battle Creek MIF
(ac ft.)
July 2025
Aug. 2025
Sept. *2025
1,137
1,153
1,167
1,699
4,098.3
2,257.7
1,115.8
1,066.9
660.6
Battle Creek Inflows to Bradley
(ac ft.)
July 2024
Aug. 2024
Sept. *2025
10,954.2
10,662.7
5,121.6
*Lake Level – 1,171.6’ As of Sept. 15, 2025
Activities
• Forced Outages – None to report.
• Dam/Spillway – Completed the monthly safety inspections, power tunnel and spillway drain
measurements.
• Battle Creek Diversion – The week of September 1, Battle Creek received a large rain event.
This increase in flow carried gravel into the diversion forebay that eventually overwhelmed the
sediment blocks and carried over to the Mif gate. The Mif gate became partially plugged with
gravel restricting flow to Battle Creek. The Mif gate was fully open to flush the gravel
downstream. We were able to restore normal flow through the Mif gate but discovered that
part of the support bracket had been damaged and prevented the gate from closing more than
50%. The flows are currently too high to access the Mif gate to make repairs.
• Safety – There have been no lost time or reportable accidents for the months of July, Aug., and
as of this date in Sept. 2025. Safety meetings were conducted in July, Aug., and Sept. 2025. Next
safety meeting is Oct. 8, 2025. DOWL will conduct Dam Safety Training for the Operators on 17
Sept. 2025.
• Unit #2 Breaker- EPC will be in on Sept. 24-25, 2025, to complete the final mechanical
adjustments to the breaker.
• Halon Fire System replacement- The Fire Marshal completed his review of the design. The
materials have begun to be shipped to Homer. An installation date is pending for Late Oct. 2025
• The RFB for the upgrade of the fire alarm system received no proposals.
• Fire system inspection and testing scheduled for 11 Sept 2025 was cancelled due to weather. The
plane was grounded due to dense fog that lasted all day.
Bradley Lake Operators Report Page 2
• Fire Huts - New fire huts that house the fire hydrants, portable fire carts, hoses and
miscellaneous tools have been installed.
• Personnel- We currently have one open Operator Position. We have completed interviews and
offered one candidate an onsite interview and project tour. He has accepted the invitation for
the first of Oct. 2025.
• Field Investigation- Drilling crew has arrived on site to begin drilling core samples at the dam.
Contractors/ Visitors
• HEA - Larry Jorgensen attended the safety meeting.
• Kleinschmidt- AEA contractor for Dixon Diversion Project.
• ADFG- Servicing the fish weir on Battle Creek.
• Cultural Resources- AEA contractor for Dixon Diversion Project.
• Anderson Brothers Construction- Installing hood vent at crew’s quarters.
• HEA- Marvin Super, Eric Ronnegard, Seth Carstens, Setting up Scanner.
• Bay Safety- Bill Noomah, Servicing fire extinguishers.
• Homer Soil and Water- Casey Greinstein, invasive weed control.
• DOWL- Underground line locates at Dam.
• Schnabel- Paul Pribyl, AEA contractor for Dixon Diversion Project.
• NRCA – Dan and Roxan Walsh for a project tour.
• Diamond Drilling- Field investigation for raising the dam for the Dixon project.
Bradley Lake Operators Report Page 3
Bradley Lake, Sept 6, 2025. Lake Elevation 1166.3
Bradley Lake Operators Report Page 4
Battle Creek Diversion 11 Sept. 2025 gravel removal.
Barge for Diamond Drilling New Fire Hut
Bradley Lake Operators Report Page 5
Bradley Powerhouse
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: Bradley Lake Project Management Committee THROUGH: Curtis W. Thayer, Executive Director FROM: Mark Ziesmer, Owned Assets Project Controller DATE: September 15, 2025
SUBJECT: Audit update
FY 25 Budget vs Actual and Surplus
There have been no significant updates since the draft presented at the July 25, 2025 BPMC Meeting.
FY25 AEA Audit
My current focus is on completing tasks associated with AEA’s FY25 audit, which follows a
defined timeline. Bradley Lake and Alaska Intertie-related work represents a significant portion
of the AEA audit. The audit is progressing as expected, and AEA Finance remains on track to
present the audited financial statements to the AEA Board on October 30, 2025. No material
changes are expected, and the projected surpluses are not anticipated to be significantly
impacted.
FY26 Budget vs Actual
Only a limited number of invoices were processed and available for reporting by the submission
deadline for this meeting. The next update will be provided at the BPMC meeting scheduled for
December 5, 2025.
Bradley Operation and Dispatch Committee Report
September 19, 2025
Meeting Dates:
August 22th, 2025 and September 12, 2025
Notable Discussions and Items:
□ Continued discussion on the assignment to SS and SSQ schedules and cost
Water Tracking & Lake Level:
□ As of September 1st, Bradley Lake contained approximately 222,590 MWh of energy.
Committee Assignments:
□ CEA continues work to address SCADA challenges to allow HEA wheeling capacity as
defined in the existing Bradley agreement.
□ BPMC approved - CEA & HEA investigating appropriate relay settings - $15k spend limit.
• HEA and CEA are working on the development of work scope for best practice
analysis.
□ SS and SSQ line schedule and cost review
Next Meeting:
October 17nd, 2025 @ 10am