HomeMy WebLinkAboutAPP_13001-REF Round 13 Standard Appilcation - NETC - 28Sept2020Renewable Energy Fund Round 13
Grant Application – Standard Form
AEA 21010 Page 1 of 51 9/28/2020
Application Forms and Instructions
This instruction page and the following grant application constitutes the Gr ant Application Form for
Round 13 of the Renewable Energy Fund (REF). A separate application form is available for
projects with a primary purpose of producing heat (see Request for Applications (RFA) Section
1.5). This is the standard form for all other projects, including projects that will produce heat and
electricity. An electronic version of the RFA and both application forms is available online at:
www.akenergyauthority.org/what-we-do/grants-loans/renewable-energy-fund-ref-grants/2020-ref-
application.
What follows are some basic information and instructions for this application:
The Alaska Energy Authority (AEA) expects this application to be used as part of a two-year
solicitation cycle with an opt-out provision in the second year of the cycle .
If you are applying for grants for more than one project, provide separate application forms for
each project.
Multiple phases (e.g. final design, construction) for the same project may be submitted as one
application.
If you are applying for grant funding for more than one ph ase of a project, provide milestones
and grant budget for each phase of the project (see Sections 3.1 and 3.2.2).
In order to ensure that grants provide sufficient benefit to the public, AEA may limit
recommendations for grants to preliminary development phases in accordance with 3 Alaska
Administrative Code (ACC) 107.605(1).
If some work has already been completed on your project and you are requesting funding for
an advanced phase, submit information sufficient to demonstrate that the preceding phases are
completed and funding for an advanced phase is warranted . Supporting documentation may
include, but is not limited to, reports, conceptual or final designs, models, photos, maps, proof
of site control, utility agreements, business and operation plans, power sale agreements,
relevant data sets, and other materials. Please provide a list of supporting documents in
Section 11 of this application and attach the documents to your application.
If you have additional information or reports you would like the Aut hority to consider in
reviewing your application, either provide an electronic version of the document with your
submission or reference a web link where it can be downloaded or reviewed. Please provide a
list of additional information; including any web l inks, in Section 12 of this application and attach
the documents to your application. For guidance on application best practices please refer to
the resource-specific Best Practices Checklists; links to the checklists can be found in the
appendices list at the end of the accompanying REF Round 13 RFA.
In the Sections below, please enter responses in the spaces provided. You may add additional
rows or space to the form to provide sufficient space for the information, or attach additional
sheets if needed.
If you need assistance with your application, please contact AEA’s Grants Manager Karin St.
Clair by email at grants@akenergyauthority.org or by phone at (907) 771-3081.
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Grant Application – Standard Form
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REMINDER:
AEA is subject to the Public Records Act AS 40.25, and materials submitted to AEA may be
subject to disclosure requirements under the act if no statutory exemptions apply.
All applications received will be posted on the Authority web site after final recommendations
are made to the legislature. Please submit resumes as separate PDFs if the applicant would
like those excluded from the web posting of this application.
In accordance with 3 AAC 107.630 (b) Applicants may request trade secrets or proprietary
company data be kept confidential subject to review and approval by AEA. If you want
information to be kept confidential the applicant must:
o Request the information be kept confidential.
o Clearly identify the information that is the trade secret or proprietary in their application.
o Receive concurrence from the Authority that the information will be kept confidential. If
the Authority determines it is not confidential, it will be treated as a public record in
accordance with AS 40.25 or returned to the applicant upon request.
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Grant Application – Standard Form
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SECTION 1 – APPLICANT INFORMATION
Please specify the legal grantee that will own, operate, and maintain the project upon completion .
Name (Name of utility, IPP, local government, or other government entity)
Nushagak Electric & Telephone Cooperative
Tax ID # 92-0177246
Date of last financial statement audit: April, 2020
Mailing Address: Physical Address:
Box 350 557 Kenny Wren Rd
Dillingham, AK 99576 Dillingham, AK 99576
Telephone: Fax: Email:
907-842-5251 907-842-2799 rhimschoot@nushagak.coop
1.1 Applicant Point of Contact / Grants Manager
Name: Robert Himschoot Title: CEO/GM
Mailing Address:
Nushagak Electric & Telephone Cooperative
Box 350
Dillingham, AK 99576
Telephone: Fax: Email:
907-843-0954 907-842-2799 rhimschoot@nushagak.coop
1.1.1 Applicant Signatory Authority Contact Information
Name: Robert Himschoot Title: CEO/GM
Mailing Address:
Nushagak Electric & Telephone Cooperative
Box 350
Dillingham, AK 99576
Telephone: Fax: Email:
907-842-5251 907-842-2799 rhimschoot@nushagak.coop
1.1.2 Applicant Alternate Points of Contact
Name Telephone: Fax: Email:
Bobby Armstrong 907-842-5251 907-842-2799 barmstrong@nushagak.coop
Angelita Venua 907-842-5251 907-842-2799 avenue@nushagak.coop
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1.2 Applicant Minimum Requirements
Please check as appropriate. If applicant s do not meet the minimum requirements, the application
will be rejected.
1.2.1 Applicant Type
☒ An electric utility holding a certificate of public convenience and necessity under AS 42.05
CPCN # 45
☐ An independent power producer in accordance with 3 AAC 107.695 (a) (1)
CPCN #______, or
☐ A local government, or
☐ A governmental entity (which includes tribal councils and housing authorities)
Additional minimum requirements
☒ 1.2.2 Attached to this application is formal approval and endorsement for the project by the
applicant’s board of directors, executive management, or other governing authority. If the
applicant is a collaborative grouping, a formal approval from each participant’s governing
authority is necessary. (Indicate yes by checking the box)
☒ 1.2.3 As an applicant, we have administrative and financial management systems and follow
procurement standards that comply with the standards set forth in the grant agreement
(Section 3 of the RFA). (Indicate yes by checking the box)
☒ 1.2.4 If awarded the grant, we can comply with all terms and conditions of the award as
identified in the Standard Grant Agreement template at www.akenergyauthority.org/what-we-
do/grants-loans/renewable-energy-fund-ref-grants/2020-ref-application (Any exceptions
should be clearly noted and submitted with the application.) (Indicate yes by checking the
box)
☒ 1.2.5 We intend to own and operate any project that may be constructed with grant funds for
the benefit of the general public. If no please describe the nature of the project and who will
be the primary beneficiaries. (Indicate yes by checking the box)
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SECTION 2 – PROJECT SUMMARY
2.1 Project Title
Provide a 4 to 7 word title for your project. Type in the space below.
Nuyakuk River Hydroelectric Project (Run of River Project)
2.2 Project Location
2.2.1 Location of Project – Latitude and longitude (preferred), street address, or
community name.
Latitude 59.910807 North Longitude 158.118627 West
The proposed Project would be located on the Nuyakuk River approximately 60 miles north of
Dillingham, AK (pop. 2,364). The Project is located within the watershed that drains the eastern
side of the Wood River Mountains. The Project site is inside the current Wood -Tikchik State Park
boundary by approximately 4 miles. The Project’s river intake would divert water from the Nuyakuk
River, above Nuyakuk Falls, located about 4.6 river miles downstream from the Tikchik Lake outlet
to the powerhouse located at the base of Nuyakuk Falls, at approximately river mile 5.3. From the
Project site, the Nuyakuk River runs approximately 40 miles before converging with the Nushagak
River, which continues to Bristol Bay.
2.2.2 Community benefiting – Name(s) of the community or communities that will be the
beneficiaries of the project.
Koliganek, New Stuyahok, Ekwok, Aleknagik, Dillingham, Levelock
2.3 Project Type
2.3.1 Renewable Resource Type
☐ Wind ☐ Biomass or Biofuels (excluding heat-only)
☒ Hydro, Including Run of River ☐ Hydrokinetic
☐ Geothermal, Excluding Heat Pumps ☐ Transmission of Renewable Energy
☐ Solar Photovoltaic ☐ Storage of Renewable
☒ Other (Describe) Dispatchable renewable heat, Broadband ☐ Small Natural Gas
2.3.2 Proposed Grant Funded Phase(s) for this Request (Check all that apply)
Pre-Construction Construction
☐ Reconnaissance ☒ Final Design and Permitting
☒ Feasibility and Conceptual Desig n ☐ Construction
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2.4 Project Description
Provide a brief, one-paragraph description of the proposed project.
The proposed Project is a new 10 -12 MW run of river hydropower project consisting of an intake
structure, power conduit, powerhouse forebay, powerhouse, and tailrace channel approximately 4
miles downstream of the Tikchik Lake outlet above a natural falls on the Nuyakuk River. Power
from the Project would be available to the customers of the Cooperative and potentially other areas
in the region. The renewable power provided by the Project would represent a significant
improvement in the current distribution system and minimize the reliance of local communities on
fossil fuels as their primary source of electricity. Currently, the population that w ould be served by
this Project relies wholly on diesel generation, which is barged upstream through the Nushagak
River drainage to requisite locations. The reduction (or elimination) of water transport of fuels will
reduce the potential for negative enviro nmental impacts due to spills. The primary industry in the
Project service area is related to commercial harvest and processing of salmon. The long -term
demand for more reliable, efficient, and cost -effective renewable electric power, dispatchable
renewable thermal heat, high-speed broadband, along with the likely limited resource impacts
makes this Project a highly viable opportunity.
Initially this project will replace up to 1.5 million gallons of diesel fuel annually , eventually up to 2.5
million gallons per year of diesel fuel will be replaced with renewable hydro energy which will
provide electric power, heating, or thermal conversion to other useful energy needs. We believe
the combination of renewable energy and increased broadband access will provid e the basis for
economic and social improvement and growth in the region for generations to come.
2.5 Scope of Work
Provide a short narrative for the scope of work detailing the tasks to be performed under this
funding request. This should include work paid for by grant funds and matching funds or performed
as in-kind match.
REF funding will be applied to Phases II and III of this Project.
Phase II will include the FERC Integrated Licensing Process (ILP) Study Seasons 2021, 2022, with
the completion milestone identified as filing the 2022 Study Season Report for FERC Project No.
14873 in the Fall of 2022 and NETC Board action to continue Project work. Specific REF Grant
Allocation spending will include: Ice Processes Study, Initial Geotechnical Study (Phase II),
Preliminary Design and Engineering and Land Access and Use Agreements. The overall Phase II
cost estimate is $1,175,000.
Phase III will culminate with the Project being ―shovel ready‖. Shovel ready will include final design
and engineering, operational planning including environmental & natural resource management
plans, Land use authorizations, water rights authorization, FERC Operating License and financial
agreements including Project construction funding and energy sales agreements. Specific REF
Grant Allocations will be used for Aquatics Studies, and Engineering, the Milestone for Phase
completion will be the Operating Permit Application for FERC Project No. 14873 in the Fall of 2023.
The overall Phase III cost estimate is $11,105,000.
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2.6 Previous REF Applications for the Project
See Section 1.15 of the RFA for the maximum per project cumulative grant award amount
Round
Submitted
Title of application Application
#, if known
Did you
receive a
grant? Y/N
Amount of REF
grant awarded
($)
No previous REF applications for this
Project
SECTION 3 – Project Management, Development, and Operation
3.1 Schedule and Milestones
Task # Milestones Tasks Start
Date End Date Deliverables
Phase II
Task 1
2022 Study Season
Report/NETC
Board action to
continue Project
Study: Water Quality
Assessment -
Dissolved Oxygen and
Water Temperatures
8/1/21 12/31/22 Study Report
Phase II
Task 2
2022 Study Season
Report/NETC
Board action to
continue Project
Study: Flow Duration
Curve Assessment 8/1/21 12/31/22 Study Report
Phase II
Task 3
2022 Study Season
Report/NETC
Board action to
continue Project
Study: Future Flows
Assessment 8/1/21 12/31/22 Study Report
Phase II
Task 4
2022 Study Season
Report/NETC
Board action to
continue Project
Study: Ice Processes
Assessment 8/1/21 12/31/22 Study Report
Phase II
Task 5
2022 Study Season
Report/NETC
Board action to
continue Project
Study: Botanical and
Wetlands Survey 8/1/21 12/31/22 Study Report
Phase II
Task 6
2022 Study Season
Report/NETC
Board action to
continue Project
Study: Recreation and
Aesthetics
Study/Noise Study
8/1/21 12/31/22 Study Report
Phase II
Task 7
2022 Study Season
Report/NETC
Board action to
continue Project
Initial Geotechnical
Study 8/1/21 12/31/22 Study Report
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Task # Milestones Tasks Start
Date
End
Date Deliverables
Phase III
Task 1
FERC Operating
License
Application
Study: Fish Species
Abundance and
Distribution Near the
Project Area
8/1/21 12/31/23 Study Report
Phase III
Task 2
FERC Operating
License
Application
Study: Nuyakuk
Falls Fish Passage
Study
8/1/21 12/31/23 Study Report
Phase III
Task 3
FERC Operating
License
Application
Study: Fish
Entrainment and
Impingement Study
8/1/21 12/31/23 Study Report
Phase III
Task 4
FERC Operating
License
Application
Study: Assessment
of False Attraction at
the Tailrace Fish
Barrier
8/1/21 12/31/23 Study Report
Phase III
Task 5
FERC Operating
License
Application
Design &
Engineering 8/1/21 12/31/23 Engineering/Design
documents
3.2 Budget
3.2.1 Funding Sources
Indicate the funding sources for the phase(s) of the project applied for in this funding request.
Grant funds requested in this application $ 2,000,000
Cash match to be provideda $10,280,000
In-kind match to be provideda $
Energy efficiency match providedb $
Total costs for project phase(s) covered in application (sum of
above)
$12,280,000
Describe your financial commitment to the project and the source(s) of match. Indicate whether
these matching funds are secured or pending future approvals. Describe the impact, if any, that
the timing of additional funds would have on the ability to proceed with the grant.
Nushagak has spent $578,624 to complete Phase I and an additional $81,193 on Phase II tasks to
date. The Board has approved a capital spending budget for this Project of $1,300,000 total. The
remaining $640,183 is secured in sinking funds invested. The remaining $9,670,000 needed to
complete Phase II and Phase III will come from a combination of direct allocations from the State
of Alaska, grant funding programs through Denali Commission, USDA /RUS, BIA Indian Energy,
DOE Indian Energy, and further Nushagak Electric & Telephone Cooperative capital investment
through debt service obligations.
Phase II is the larger funding issue, because grant programs at USDA/RUS, BIA and DOE do not
allow funding for feasibility studies. Meetings with all of the agencies listed indicate strong interest
in funding once a FERC Operational Permit is issued, a milestone for Phase III completion.
a Attach documentation for proof (see Section 1.18 of the Request for Applications)
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b See Section 8.2 of this application and Section 1.18 of the RFA for requirements for Energy Efficiency
Match.
3.2.2 Cost Overruns
Describe the plan to cover potential cost increases or shortfalls in funding.
Cost overruns/shortfalls will be met with additional capital spending by NETC. NETC has an
adequate line of credit with NRU/CFC to cover these contingencies. Current unencumbered line of
credit is $6,600,000
3.2.3 Total Project Costs
Indicate the anticipated total cost by phase of the project (including all funding sources). Use actual
costs for completed phases. Indicate if the costs were actual or estimated.
Reconnaissance Actual $578,624
Feasibility and Conceptual Design Estimated $ 1,175,000
Final Design and Permitting Estimated $11,105,000
Construction
(Broken Down)
Construction – Hydro facilities & Transmission to
Aleknagik & Dillingham
Estimated $98,000,000
Construction – Transmission to Koliganek, New
Stuyahok, Ekwok, & Levelock
Estimated $42,000,000
Total Project Costs (sum of above) Estimated $152,858,624
Metering/Tracking Equipment [not included in project
cost]
Estimated Included in
construction
costs
3.2.4 Funding Subsequent Phases
If subsequent phases are required beyond the phases being applied for in this application,
describe the anticipated source s of funding and the likelihood of receipt of those funds .
State and/or federal grants
Loans, bonds, or other financing options
Additional incentives (i.e. tax credits)
Additional revenue streams (i.e. green tag sales, carbon credits or other renewable energy
subsidies or programs that might be come available)
As part of developing the Project feasibility NETC held a series of meetings in advance of initiating
the FERC ILP licensing process. From October 2017 through the FERC Scoping Meeting in
December of 2019 we held 92 stakeholder meetings. While most of these meetings were intended
to introduce the Project and gauge support we also took the opportunity to explore funding options
for Project construction. Opportunities identified include:
• 12/17/2017 Met with NRUCFC, Sheldon Peterson/CEO, verbal support for debt service
with an operating license
• 12/17/2017 Met with USDA/RUS, Chris McLean acting administrator, also verbal support
for debt service with an operating license, specific program identified, use of underutilized SUTA
funds
• 1/26/2018 Met with AEA/AIDEA, discussed the Renewable Energy Fund, Power Project
Fund as opportunities for study or const ruction funding
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• 11/13/2019 Met with BIA Indian Energy & Economic Development, Jack Stevens,
discussed programs including EMDP and TEDC grants that could be applied for by Tribal
organizations for inter-tie transmission line build.
• 11/13/2019 Met with DOE Indian Energy Director Frost, discussed several grant and
technical assistance options including grant opportunities that could be applied for by Tribal
organizations for inter-tie transmission line build.
• Met with Denali Commission staff on multiple occasions in early 2020, Tom Wolf, Energy
Program Manager, and Janet Davis, Grants Management Officer. Applied for 2020 funding in
January and revised in February.
• Met on several occasions with State Legislative delegation and Administration. Have
submitted a CAPSIS request each of the last three years.
3.2.5 Budget Forms
Applications MUST include a separate worksheet for each project phase that was identified in
Section 2.3.2 of this application — I. Reconnaissance, II. Feasibility and Conceptual Design, III.
Final Design and Permitting, and IV. Construction. Please use the tables provided below to detail
your proposed project’s total budget. Be sure to use one table for each phase of your project, and
delete any unnecessary tables. The milestones and tasks should match those listed in 3.1 above.
If you have any question regarding how to prepare these tables or if you need assistance preparing
the application please feel free to contact AEA ’s Grants Manager Karin St. Clair by email at
grants@akenergyauthority.org or by phone at (907) 771-3081.
Phase 1 — Reconnaissance
Milestone or Task
Anticipated
Completion
Date
RE-
Fund
Grantee
Matching
Source of
Matching
Funds:
TOTALS
Grant
Funds Funds
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
Acquisition of Park Access
Legislation and Public
Outreach Expense
$ $32,615 Cash $32,615
Site logistics & transportation $ $46,159 Cash $46,159
Survey/Field work $ $156,523 Cash $156,523
Preliminary Permit
Application 6/11/2018 $ $20,000 Cash $20,000
Prepare Preliminary
Application Document (PAD)
& Notice of Intent (NOI)
10/8/2019 $ $40,000 Cash $40,000
FERC Scoping Process 3/18/2020 $ $20,000 Cash $20,000
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Proposed Study Plan (PSP)
Development 4/16/2020 $ $60,000 Cash $60,000
FERC Regulatory Process
Management 4/16/2020 $ $80,000 Cash $80,000
Conceptual Project Design 2/1/2020 $ $50,000 Cash $50,000
Initial Economic Feasibility
Assessment 10/8/2019 $ $30,000 Cash $30,000
Project Kickoff Meeting with
Agencies 11/18/2019 $ $20,000 Cash $20,000
Project Management
(Nushagak Coop). $ $23,327 Cash $23,327
TOTALS $ $578,624 $578,624
Budget Categories:
Direct Labor & Benefits $ $23,327 $23,327
Travel & Per Diem $ $76,159 $76,159
Equipment $ $ $
Materials & Supplies $ $ $
Contractual Services $ $446,523 $446,523
Construction Services $ $ $
Other Public Outreach $ $32,615 $32,615
TOTALS $ $578,624 $578,624
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Phase 2 — Feasibility and Conceptual Design
Milestone or Task
Anticipated
Completion
Date
RE- Fund Grantee
Matching
Source of
Matching
Funds:
TOTALS
Grant
Funds Funds
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
Final Milestone for this
Phase are Study Reports
for the tasks and the 2022
Study Season Report,
Board for review/action
$ $
Phase II Task 1: Study:
Water Quality Assessment -
Dissolved Oxygen and
Water Temperatures
12/31/2022 $35,000 $10,000 Cash $45,000
Phase II Task 2: Study:
Flow Duration Curve
Assessment
12/31/2021 $105,000 $20,000 Cash $125,000
Phase II Task 3: Study:
Future Flows Assessment 12/31/2021 $90,000 $10,000 Cash $100,000
Phase II Task 4: Study:
Ice Processes Assessment 12/31/2021 $40,000 $10,000 Cash $50,000
Phase II Task 5: Study:
Botanical and Wetlands
Survey
12/31/2022 $170,000 $30,000 Cash $200,000
Phase II Task 6: Study:
Recreation and Aesthetics
Study/Noise Study
12/31/2022 $35,000 $10,000 Cash $45,000
Phase II Task 7: Initial
Geotechnical Study 10/1/2021 $525,000 $75,000 Cash $600,000
Project Management and
Outreach (Nushagak Coop.) 6/30/2024 0 $10,000 Cash $10,000
TOTALS $1,000,000 $200,000 $1,200,000
Budget Categories:
Direct Labor & Benefits $ $10,000 $10,000
Travel & Per Diem $ $25,000 $25,000
Equipment $ $35,000 $35,000
Materials & Supplies $ $25,000 $25,000
Contractual Services $1,000,000 $55,000 $1,055,000
Construction Services $ $ $0
Other $ $ 0
TOTALS $1,000,000 $175,000 $1,175,000
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Phase 3 — Final Design and Permitting
Milestone or Task
Anticipated
Completion
Date
RE- Fund Grantee
Matching
Source of
Matching
Funds:
TOTALS
Grant
Funds Funds
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
Final Milestone for this Phase
are Study Reports and the
FERC Operating License
Application for the tasks and a
―Shovel Ready‖ project
$ $ $
Phase III Task 1: Study: Fish
Species Abundance and
Distribution Near the Project Area 12/31/2023 $500,000 $300,000 Cash $800,000
Phase III Task 2: Study:
Nuyakuk Falls Fish Passage
Study
12/31/2023 $100,000 $100,000 Cash $200,000
Phase III Task 3: Study: Fish
Entrainment and Impingement
Study
12/31/2023 $100,000 $100,000 Cash $200,000
Phase III Task 4: Study:
Assessment of False Attraction at
the Tailrace Fish Barrier
12/31/2023 $100,000 $150,000 Cash $250,000
Study: Caribou Population
Evaluation 12/31/2023 0 $75,000 Cash 75000
Study: Cultural Resources
Subsistence Study 12/31/2023 0 $100,000 Cash 100000
Study: Cultural Resources
Section 106 Evaluation 12/31/2023 0 $300,000 Cash $300,000
Study: Recreation Inventory by
Season 12/31/2023 0 $200,000 Cash $200,000
Phase III Task 5: Engineering
& Legal, resulting in an Engineer
Procure Construct (EPC) contract
and financial agreements
12/31/2023 $200,000 $800,000 Cash $1,000,000
Land Access and Use
Agreements 12/31/2023 $0 $200,000 Cash $200,000
Site/Study Permitting 12/31/2023 0 $250,000 Cash $250,000
Economic and Financial Analysis 12/31/2023 0 $100,000 Cash $100,000
FERC/Regulatory Process
Management and License
Application Preparation 6/30/2024 0 $2,000,000 Cash $2,000,000
Project Management and
Outreach (Nushagak Coop.) 6/30/2024 0 $60,000 Cash $60,000
Secondary Geotechnical Study 12/31/2026 $0 $1,300,000 Cash $1,300,000
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Engineering Design 12/31/2026 0 $2,300,000 Cash $2,300,000
Permits & Consultation 12/31/2026 0 $200,000 Cash $200,000
Preparation of
Environmental/Natural Resource
Management Plans 12/31/2026 0 $1,000,000 Cash $1,000,000
Land Use Authorization 12/31/2026 0 $500,000 Cash $500,000
Financing and Energy
Agreements 12/31/2026 0 $ $
Adjudication of Water Right 12/31/2026 0 $50,000 Cash $50,000
Project Management (Nushagak
Coop.) 12/31/2026 0 $20,000 Cash $20,000
TOTALS $1,000,000 $10,105,000 $11,105,000
Budget Categories:
Direct Labor & Benefits $ $80,000 $80,000
Travel & Per Diem $ $260,000 $260,000
Equipment $ $500,000 $500,000
Materials & Supplies $ $ $
Contractual Services $1,000,000 $9,265,000 $10,265,000
Construction Services $ $ $
Other $ $ $
TOTALS $1,000,000 $10,105,000 $11,105,000
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Phase 4 — Construction
Milestone or Task
Anticipated
Completion
Date
RE-
Fund
Grantee
Matching
Source
of
Matchin
g
Funds:
TOTALS
Grant
Funds Funds
Cash/In
-
kind/Fe
deral
Grants/
Other
State
Grants/
Other
(List milestones based on phase and
type of project. See Sections 2.3 thru
2.6 of the RFA )
$ $ $
EPC Construction Services 12/31/2028 $ $129,000,000 Cash $129,000,000
Environmental Monitoring &
Reporting 12/31/2028 $ $8,000,000 Cash $8,000,000
Permit Reporting 12/31/2028 $ $3,000,000 Cash $3,000,000
Project Management (Nushagak
Coop) $ $125,000 Cash $125,000
TOTALS $ $140,125,000 $140,125,000
Budget Categories:
Direct Labor & Benefits $ $125,000 $125,000
Travel & Per Diem $ $5,000,000 $5,000,000
Equipment $ $25,000,000 $25,000,000
Materials & Supplies $ $5,000,000 $5,000,000
Contractual Services $ $5,000,000 $5,000,000
Construction Services $ $100,000,000 $100,000,000
Other $ $ $
TOTALS $ $140,125,000 $140,125,000
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3.2.6 Cost Justification
Indicate the source(s) of the cost estimates used for the project budget , including costs for future
phases not included in this application.
The costs associated with Phase II through IV of this Project were developed with NETC’s project
consultant, McMillen Jacobs Associates, and reflects their experience in like kind hydroelectric
development in the State of Alaska. In the past 10 years, McMillen Jacobs Associates has worked
on over 15 hydroelectric projects in Alaska, with services including feasibility assessments,
engineering, design-build construction, natural resource study program management, and FERC
licensing, relicensing, license amendments, and license implementation and compliance. McMillen
Jacobs recently assisted Homer Electric Association (Kenai Hydro, LLC) with the acquisition of an
original license for the Grant Lake Hydroelectric Project (FERC No. P -13212), including all phases
of license application preparation, natural resource study program management, and engineering
design. The Grant Lake project received a FERC operating license in August 2019 and project
generation is expected to begin in 2024 following a 2 -year construction period.
3.3 Project Communications
3.3.1 Project Progress Reporting
Describe how you plan to monitor the progress of the project and keep AEA informed of the status.
Who will be responsible for tracking the progress? What tools and methods will be used to track
progress?
NETC will provide quarterly and annual progress reports to AEA. These reports with contain both
specific grant expenditures and overall Project progress including intra-milestone Project
advances. In addition, NETC will provide AEA copies of the FERC required annual/seasonal
reports and the go/no go Board actions associated with these reports.
Documents that mark the individual completion of Tasks and Phases that lead to the FERC
Operating Permit Application will also be posted to the Project website,
https://www.nuyakukhydro.com/ and to the FERC document portal using the identifier for this
Project P-14873, https://elibrary.ferc.gov/eLibrary/search
3.3.2 Financial Reporting
Describe the controls that will be utilized to ensure that only costs that are reasonable, ordinary
and necessary will be allocated to this project. Also discuss the controls in place that will ensure
that no expenses for overhead, or any other unallowable costs will be requested for reimbursement
from the REF Grant Program.
NETC utilizes holistic accounting National Information Solutions Cooperative (NISC) software that
includes project work order line item and categorical expenditures. NETC will provide these reports
to AEA quarterly and annually.
In the past 10 years NETC has su ccessfully completed reporting for two USDA/RUS HECG Grants
along with a previous AEA REF Grant.
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SECTION 4 – QUALIFICATIONS AND EXPERIENCE
4.1 Project Team
Include resumes for known key personnel and contractors, including all functions below, as an
attachment to your application . In the electronic submittal, please submit resumes as separate
PDFs if the applicant would like those excluded from the web posting of this application.
4.1.1 Project Manager
Indicate who will be managing the project for the Grantee and include contact information. If the
applicant does not have a project manager indicate how you intend to solicit project management
support. If the applicant expects project management assistance from AEA or another government
entity, state that in this section.
Project management duties for Phases II and III will be contracted to McMillen Jacobs Associates
to build on Project development accomplished in Phase I. In addition Project management support
will be provided by Mr. Bobby Armstrong, NETC’s Electric Operations Manager.
4.1.2 Project Accountant
Indicate who will be performing the accounting of this project for the grantee. If the applicant does
not have a project accountant indicate how you intend to soli cit financial accounting support.
Project accounting for Phases II and III will be provided by NETC’s in -house accounting
department led by Senior Accountant Angelita Venua. In addition NETC will undergo yearly third
party audits.
4.1.3 Expertise and Resources
Describe the project team including the applicant, partners, and contractors.
For each member of the project team, indicate :
the milestones/tasks in 3.1 they will be responsible for;
the knowledge, skills, and experience that will be used to successfully deliver the task s;
how time and other resource conflicts will be managed to successfully complete the task.
If contractors have not been selected to complete the work, provide reviewers with sufficient detail
to understand the applicant’s capacity to successfully select contractors and manage complex
contracts.
Applicant:
Nushagak Electric and Telephone Cooperative (NETC) is a member-owned Cooperative
providing electric and telecommunications services in rural Alaska. Offices and power production
facility are in Dillingham, Alaska. NETC’s electric division generates and distributes electric service
to the communities of Dillingham and Aleknagik and has been providing distributed electric energy
to these communities since 1965. NETC has 11.2 MW of diesel generation capacit y with 1,475
metered customers. For all Phases/Milestones: NETC will be responsible for Project outreach,
Project finance, Project accounting and supporting Project management. Direct milestone
responsibility in Phase II and Phase III includes: Economic and Financial Analysis, Project
Management and Outreach, Land Access and Use Agreements, and Site/Study Permitting.
NETC personnel are all residents of Bristol Bay and have extensive western Alaska logistical
knowledge. Scheduling and other resources will be process-driven and goal-oriented.
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Contractors:
McMillen Jacobs Associates will provide consulting services to the applicant, including regulatory
services, RFP development and contractor selection and Project Management. McMillen Jacobs
will also act as general Project manager through Phases II and III with overall responsibility to
maintain both the FERC ILP timeline and reporting and also meet REF Grant funding timelines and
Project update reporting. Phase II direct milestone responsibilities inclu de: Water Quality
Assessment - Dissolved Oxygen and Water Temperatures, Flow Duration Curve Assessment, Ice
Processes Assessment, Botanical and Wetlands Survey, Preliminary Design & Engineering,
FERC/Regulatory Process Management and License Application Pr eparation.
R2 Resource Consultants: R2 has extensive hydroelectric licensing experience including six
projects in Alaska. They will provide fish passage and aquatics consulting. They will be responsible
for Phase II and Phase III studies including: Fish Species Abundance and Distribution Near the
Project Area, Nuyakuk Falls Fish Passage Study, Fish Entrainment and Impingement Study,
Assessment of False Attraction at the Tailrace Fish Barrier
Cultural Resources Consultants: CRC has extensive background in cultural resource study and
evaluation. They will provide the Project with their experience in developing and completing our
cultural resource based Phase II and Phase III studies: Recreation and Aesthetics Study/Noise
Study, Cultural Resources Subsistence Study, Cultural Resources Section 106 Evaluation, and
Recreation Inventory by Season .
Initial Geotechnical Study: NETC, through McMillen Jacobs, has submitted an RFP and received
three responses for this study. We are evaluating the responses and expect to award the Phase II
work in 2020 for 2021 work and completion.
NOAA/NMFS: NMFS recommended the Future Flows Assessment during the study plan
development process. We have engaged with them in a collaborative effort to complete this Phase
II study.
Alaska Department of Fish & Game: We are engaging in a collaborative effort with ADF&G to
extend existing ADF&G programs to complete the Caribou Population Evaluation and the Cultural
Resources Subsistence Phase II and Phase III Study.
4.2 Local Workforce
Describe how the project will use local labor or train a local labor workforce.
NETC and McMillen Jacobs will continue to use local resources for logistical support and
encourage the use of local resources to complete the contracted studies where the exper tise exists
locally.
The power plant operations personnel will be trained from NETC existing power plant operational
personnel, all local. Additional necessary personnel will be hired locally through our local hire
initiative.
Transmission line operations will be handled by NETC’s current distribution line crew. Additional
workforce will be developed through our apprentice program.
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SECTION 5 – TECHNICAL FEASIBILITY
5.1 Resource Availability
5.1.1 Assessment of Proposed Energy Resource
Describe the potential extent/amount of the energy resource that is available, including average
resource availability on an annual basis. For pre-construction applications, describe the resource to
the extent known. For design and permitting or construction projects, please provide feasibility
documents, design documents, and permitting documents (if applicable) as attachments to this
application (See Section 11). Likelihood of the resource being available over the life of the project .
See the ―Resource Assessment‖ se ction of the appropriate Best Practice Checklist for additional
guidance.
The primary mode of operation for this Project will be level control, whereby outflow is balanced to
inflow. The Project is conceived as a run-of -river project, with no large storage component. As
such, power production will mimic some fraction of total river inflow to the Project site.
Mean daily discharge in the Nuyakuk River is presented, based on USGS gaging data available at
station 15302000 located near the outlet of Nuyakuk Lake. From the figure, it is clear that the
period of high flow in the river occurs between early summer and early fall. For the remainder of
the year, the river is running at near baseflow conditions. Because the Project will operate in run-
of -river mode, sizing the generating units should be done to either 1) optimize power production
during a specific time of year (e.g. during the winter months) or 2) produce power more or less
evenly throughout the year. Under the current Project conceptualization, units have been sized to
provide a stable amount of power from month to month while attempting to minimize overall capital
costs associated with the hydroelectric units, tunnel(s), and other Project components.
When powerhouse flows do not match the system loads, grid system electricity will have to be
supplemented with existing diesel generation. This will most likely be in the winter months when
the amount of water available to the powerhouse is less than the power demand would require.
The transmission grid will therefore have five diesel generation power plants tied together to
complete the electric grid system. The existing power plant in Dillingham has the ability to provide
energy for all six villages serviced by the transmission system throughout the year, except for the
month of July. This gives NETC the ability to feed the system from different sources as needed for
load or maintenance. NETC intends to optimize hydro generation unit design for high efficiencies
during winter low flow periods.
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The Project will have an installed total capacity of 10 to 12 MW and is based on the configuration
discussed above. Energy production also assumes the Project configuration described above, with
a single 30-ft diameter tunnel servicing the three units over a distance of 600 feet. For those
months in which the total available inflow to the powerhouse is less than the total powerhouse flow
capacity, a minimum instream flow of 1,000 cfs is assumed to pass downstream, while the
remainder is passed through the powerhouse to generate electricity. The predicted average annual
energy from the Project is 55,300 MWh representing a plant factor of 63%. Estimates will be
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revised once instream flow studies are completed, and any flow accretions below Nuyakuk Lake
are determined.
5.1.2 Alternatives to Proposed Energy Resource
Describe the pros and cons of your proposed energy resource vs. other alternatives that may be
available for the market to be served by your project.
The current distributed electrical energy d emand in the communities is met through diesel
generation; the no action alternative would be continued diesel generation. This is the basis for our
financial modeling.
There have been other alternatives explored including wind and an alternate hydroelect ric site;
NETC (Grant/Elva Hydro 2009, Wind Integration Study 2009) BBNC (Wind Feasibility Study 2005).
These were determined disadvantageous to the current diesel generation when evaluated and
were not pursued past the feasibility study.
The proposed Project has potential short and long term financial, energy resiliency and
environmental advantages over the no action alternative. It has financial, maintenance, reliability,
production and longevity advantages over the other alternatives studied. At a community level a
seasonal lower cost source of dispatchable renewable heat along with year round high speed
broadband will enhance community sustainability and positively impact local economies.
5.1.3 Permits
Provide the following information as it may relate to permitting and how you intend to address
outstanding permit issues. See the ―Environmental and Permitting Risks‖ section of the appropriate
Best Practice Checklist for additional guidance.
List of applicable permits
Anticipated permitting timeline
Identify and describe potential barriers including potential permit timing issues, public
opposition that may result in difficulty obtaining permits, and other permitting barriers
NETC worked directly and intensively with the Alaska State Legislature to develop SB91 which
allows for the requisite natural resource and engineering assessment activities and FERC
regulatory processes that need to be conducted for an ultimate project feasibility determination.
SB91 was unanimously passed by the Alaska State Legislature in 2019 allowing for the
comprehensive evaluation of the site.
NETC acquired a Special Use Permit from ADNR, Division of Parks & Outdoor Recreation on April
1, 2020 (Permit #LAS 33198). The permit authorizes temporary use of the project site to conduct
scientific research, including geotechnical investigations, land surveying, and bathymetric
surveying. The permit includes provisions for the installation of a man camp that will be used to
house Project personnel on site. The permit is effective May 1, 2020 through May 1, 2023.
NETC will continue to engage with all requisite agencies to obtain additional permits for conducting
natural resource studies and engineering evaluations , as needed. NETC is currently in the process
of developing natural resource study methodologies, and once study plans are finalized NETC will
coordinate with requisite agencies to obtain all required permits prior to initiating studies and on -
site engineering assessments. NETC anticipates applying for all additional study-related permits
needed from state and federal agencies in 2021, following the issuance of FERC’s Study Plan
Determination.
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5.2 Project Site
Describe the availability of the site and its suitability for the proposed energy system . Identify
potential land ownership issues, including whether site owners have agreed to the project or how
you intend to approach land ownership and access issues. See the ―Site control‖ section of the
appropriate Best Practice Checklist for additional guidance.
The Project site is on a bluff on the south bank of the Nuyakuk River adjacent to Nuyakuk Falls,
within Wood-Tikchik State Park. The Project site is currently undeveloped with the exception of a
portage trail used by boaters to bypass the Falls. As discussed above, SB91 provides NETC with
permission to comprehensively study the site for hydroelectric project development.
NETC is currently establishing a man camp at the site for use in housing personnel during the
assessment through construction phases of the Project as described in Section 5.1.3.
The proposed Project boundary consists of 2,860.60 acres which includes a 75 -ft buffer around all
Project facilities and on either side of the proposed transmission line. The Alaska Department of
Natural Resources (ADNR) manages a total of 1,666.57 acres (58.3 percent) of proposed Project
lands. Of this, 265.85 acres (9.3 percent) is land within Wood -Tikchik State Park. Native lands total
707.39 acres (24.7 percent) of proposed Project lands. The remainder of proposed Project lands
are owned or managed by the Bureau of Land Management (BLM) (357.08 acres or 12.5 percent)
and private or municipal entities own an additional 129.56 acres (4.5 percent). NETC plans to work
collaboratively with all landowners to obtain right -of -way as needed to install transmission lines
from the Project site to distribution locations.
5.3 Project Technical & Environmental Risk
5.3.1 Technical Risk
Describe potential technical risks and how you would address them.
Which tasks are expected to be mo st challenging?
How will the project team reduce the risk of these tasks?
What internal controls will be put in place to limit and deal with technical risks?
See the ―Common Planning Risks‖ section of the appropriate Best Practice Checklist for additional
guidance.
NETC has gone to significant effort to avoid technical risks associated with this project by engaging
in early consultation with stakeholders and agencies and by taking a collaborative approach with all
stakeholders. Stakeholders have been engaged from the initial feasibility stages of the Project, and
as discussed in Section 3.2.4, 92 stakeholder meetings were held between October 2017 and
December 2019. NETC voluntarily held a Project Kickoff Meeting in November 2019 in advance of
the FERC Scoping Meeting for the specific purpose of engaging both public and agency
stakeholders early in the licensing process. Currently, NETC is initiating virtual meetings to
maintain open communication and a collaborative working relationship with stakeholders un til a
time when in-person meetings and site visits are possible.
Geotechnical information about the Project site has not been collected thus far and is required to
avoid technical risks during Project design. To date, geologic reconnaissance has been limi ted to
review of geologic maps for the Project vicinity and aerial photographs of the proposed intake,
powerhouse, tunnel, and tailrace sites. During the Geotechnical Studies (Initial and Secondary),
NETC will collect data necessary to confirm the conceptual design layout and support the
engineering design development of the Project. The Initial Geotechnical Study is a preliminary site
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investigation to assess rock quality at the proposed facilities and confirm project feasibility. The
Secondary Geotechnical Study will provide geotechnical data for the final design of the proposed
facilities.
Obtaining necessary water appropriation for hydroelectric generation and Project design that is
protective of fisheries are expected to be the primary challenges assoc iated with this Project. A
robust natural resource study program has been developed in order to thoroughly investigate all
potential Project effects to natural resources. The results of the natural resource study program
and associated engineering assessments will inform final Project engineering and design. NETC
has retained FERC regulatory support and engineering services from McMillen Jacobs Associates,
a firm with experience designing and licensing new hydroelectric projects within the State of
Alaska. McMillen Jacobs Associates staff will assist NETC with the licensing and engineering
aspects of the Project in order to minimize risks to Project development, including securing water
appropriation from ADNR. R2 Resources will be the lead on all fishery assessments throughout the
natural resource study program. R2 has extensive experience conducting fishery studies in support
of FERC hydroelectric project licensing, thus protecting the Project against technical risk
associated with potential fishery resources impacts.
5.3.2 Environmental Risk
Explain whether the following environmental and land use issues apply, and if so which project
team members will be involved and how the issues will be addressed. See the ―Environmental and
Permitting Risks‖ section of the appropriate Best Practice Checklist for additional guidance.
Threatened or endangered species
Habitat issues
Wetlands and other protected areas
Archaeological and historical resources
Land development constraints
Telecommunications interference
Aviation considerations
Visual, aesthetics impacts
Identify and describe other potential barriers
The Project’s comprehensive natural resource study program has been designed to evaluate
potential environmental and land use issues, including:
Aquatics/Fishery Resources, including Fish Passage, and Fishery-related Project Design
Considerations (Entrainment, Impingement, and False Attraction to Tailrace Flows)
Water Resources, including Water Quality, Ice Processes, and Future Flows
Botanical/Wetlands Resources
Wildlife Resources and Wildlife Habitat
Cultural Resources, including Subsistence Use, Archaeological Resources, and Historical
Resources
Recreation and Aesthetic Resources
As discussed in Section 4.1.3, Project team members have extensive Alaska expertise that has
been retained to study environmental and land use issues . Each of the natural resource study
areas listed above consists of one or more studies, each of which is robust and designed to
investigate all aspects of Project development effects on the resource studied. The Project team
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consists of expertise in each resource area to ensure that study results provide detailed
information regarding the nature of any environmental and land use issues that may exist. The
results of the natural resource study program will allow FERC to prepare an Environmental
Assessment (EA) as part of the Project licensing process. The natural resource study program and
the FERC-prepared EA will identify any environmental and land issues that ma y exist as a result of
Project development. Environmental Protection, Mitigation, and Enhancement Measures (PM&Es)
will be identified during the FERC licensing process to address Project-related effects.
5.4 Technical Feasibility of Proposed Energy System
In this section you will describe and give details of the existing and proposed systems. The
information for existing system will be used as the baseline the proposal is compared to and also
used to make sure that proposed system can be integrated.
Only complete sections applicable to your proposal. If your proposal only generates electricity, you
can remove the sections for thermal (heat) generation.
5.4.1 Basic Operation of Existing Energy System
Describe the basic operation of the existing energy system including: description of control system;
spinning reserve needs and variability in generation (any high loads brought on quickly); and
current voltage, frequency, and outage issues across system. See the ―Understanding the Existing
System‖ section of the appropriate Best Pra ctice Checklist for additional guidance.
NETC’s current generation capacity includes eight Caterpillar diesel generation units, totaling
11.335MW of rated capacity, with Woodward EasyGen 3000XT controllers and SCADA monitoring
and control. Our power produ ction facility is continually manned 24/7/365. NETC’s system loads
vary between 1.4 MW and 3 MW during 9 months of the year, September till May with very little
instantaneous load variance. NETC targets generator load at 80% rated capacity, allowing for both
efficiency and spinning reserve. In 2019 a total of 19.268 GWh were generated, over the last
decade yearly generation has remained between 19 GWh and 20 GWh.
Between June and August salmon processing pushes NETC electric load past 6MW at times. The
processors also create demand variance of up 1 MW. NETC’s operators and the processors
operating staff coordinate these known variances allowing for efficiency and adequate spinning
reserve.
Generated voltage is 4.16 kV, substation transformers convert to 7.2 kV for distribution. This is the
only substation in the distribution system and is comprised of two 10 MVA transformers running
parallel with the associated switchgear needed for 1:1 redundancy.
NETC acts as both a Generation/Transmission Cooperative and a Distribution Cooperative
providing electric service to our members in a harsh western Alaska coastal environment , from fuel
delivery to member outlet. NETC computes annual outage time per member for USDA Form 7
reporting. This computation takes in t he number of outages, members affected by the outage, the
amount of time service was down and cause of outage to determine the average time per year a
member was out of service. NETC’s total outage time per member in 2019 was 23 minutes or
99.999956% reliability. Our five year average is 41.2 minutes per member or 99.999921%
reliability.
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5.4.2.1 Existing Power Generation Units
Include for each unit include: resource/fuel, make/model, design capacity (kW), minimum
operational load (kW), RPM, electronic/mechanical fuel injection, make/model of genset
controllers, hours on genset
Unit 1: Diesel/Caterpillar 3516/1130kW/565kW/1800RPM/Electronic/Woodward EasyGen
3000XT/138436
Unit 2: Diesel/Caterpillar 3512B/1050kW/525kW/1800RPM/Electronic/ EasyGen 3000XT
/90405
Unit 3: Diesel/Caterpillar 3512B/1050kW/525kW/1800RPM/Electronic/ EasyGen 3000XT
/75168
Unit 4: Diesel/Caterpillar 3512B/1050kW/525kW/1800RPM/Electronic/ EasyGen 3000XT
/81094
Unit 5: Diesel/Caterpillar 3512C/1050kW/525kW/1800RPM/Electronic/ EasyGen 3000XT
/62849
Unit 6: Diesel/Caterpillar 3512C/1050kW/525kW/1800RPM/Electronic/ EasyGen 3000XT
/64330
Unit 7: Diesel/Caterpillar 3456/455kW/223kW/1800RPM/Electronic/ EasyGen 3000XT /18400
Unit 8: Diesel/Caterpillar 3608A/2250kW/1125kW/900RPM/Electronic/ EasyGen 3000XT
/2562
Unit 9: Diesel/Caterpillar 3608A/2250kW/1125kW/900RPM/Electronic/ EasyGen 3000XT
/2136
5.4.2.2 Existing Distribution System
Describe the basic elements of the distribution system. Include the capacity of the step-up
transformer at the powerhouse, the distribution voltage(s) across the community, any transmission
voltages, and other elements that will be affected by the proposed project.
NETC’s existing electrical system is a standalone, isolated, grid consisting of a diesel power plant a
single substation located adjacent to the power plant and a distribution system. This is consistent
throughout the systems in the proposed Project.
NETC’s distribution system has a total of 85 miles of plant. Our single substation located at the
power plant consists of two 10 MVA transformers; distribution is at 7.2 kV, no transmission.
5.4.2 Existing Energy Generation Infrastructure and Production
In the following tables, only fill in areas below applicable to your project. You can remove extra
tables. If you have the data below in other formats, you can attach them to the application (see
Section 11).
Is there operational heat recovery? (Y/N) If yes estimated
annual displaced heating fuel (gallons)
Yes, approximately 50,000 gallons of
heating fuel oil is displaced for
community public schools &
community buildings along with an
additional 24,000 gallons of heating
fuel oil displaced for NETC facility and
tank farm heat.
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5.4.2.3 Existing Thermal Generation Units (if applicable to your project)
Generation
unit
Resource/
Fuel type
Design
capacity
(MMBtu/hr)
Make Model Average
annual
efficiency
Year
Installed
Hours
5.4.2.5 Annual Electricity Production and Fuel Consumption (Existing System)
Use most recent year. Replace the section (Type 1), (Type 2), and (Type 3) with generation
sources
Month Generation
(Type 1)
(kWh)
Gene
ration
(Type
2)
(kWh)
Gener
ation
(Type
3)
(kWh)
Fuel
Consumptio
n
(Diesel-
Gallons)
Fuel
Consu
mption
[Other]
Peak
Load
(kW)
Minimum
Load
(kW)
January 2020 1,590,147 109,978 2,830 1,665
February 2020 1,402,770 95,985 2,495 1,685
March 2020 1,335,718 93,384 2,210 1,475
April 2020 1,252,612 85,896 2,154 1,415
May 2020 1,441,690 100,687 2,910 1,410
June 2020 2,366,371 163,501 5,720 1,580
July 2020 1,812,560 125,957 5,525 1,440
August 2019 1,272,752 90,152 2,252 1,375
September 2019 1,247,318 88,438 2,160 1,380
October 2019 1,351,368 90,503 2,340 1,360
November 2019 1,389,478 97,968 2,460 1,525
December 2019 1,580,566 108,787 2,755 1,560
Total 18,043,350 1,251,236
5.4.2.4 O&M and replacement costs for
existing units
Power Generation Thermal Generation
i. Annual O&M cost for labor $1,099,075.43
ii. Annual O&M cost for non-labor $3,408,028.28
iii. Replacement schedule and cost for
existing units
$25,000,000 over the
next 30 years
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5.4.2.6 Annual Recovered Heating Fuel Savings (Existing System)
Use most recent year. Include only if your project affects the recovered heat off the diesel
genset or will include electric heat loads. Only include heat loads affected by the project.
Month Thermal
Loop Fuel
Savings
(Gallons)
Electricity Propane
(Gallons)
Coal
(Tons)
Wood
(Cords,
green tons,
dry tons)
Other NETC
internal
Thermal Loop
Savings
(Gallons)
January 5,787 1,736
February 6,887 2,066
March 5,536 1,661
April 5,232 1,570
May 4,382 1,315
June 3,327 998
July 528 158
August 5,143 1,543
September 4,391 1,317
October 3,738 1,122
November 4,865 1,460
December 5,947 1,784
Total 55,763 16,729
5.4.3 Future Trends
Describe the anticipated energy demand in the community, or whatever will be affected by the
project, over the life of the project. Explain how the fo recast was developed and provide year by
year forecasts. As appropriate, include expected changes to energy demand, peak load, seasonal
variations, etc. that will affect the project.
Presently hot water is recovered from diesel genset cooling systems via heat exchangers to
provide heating to NETC buildings and fuel tanks along with and external thermal loop that sells
distributed thermal heat to the Dillingham elementary, middle, high school, regional school office,
tribal, and State facilities. Approximately 50,000 gallons of heating fuel is displaced annually for
non-NETC heating use and approximately 24,000 gallons of heating fuel is displaced annually for
NETC facilities and fuel tank farm heating.
NETC is currently in the process of replacing and upgrading the existing thermal loop with
insulated non-corrosive underground pipe, heat exchangers, VFD circulating pumps and controls
to handle the existing thermal load, along with future expansion capacity to service thermal loop
expansion to other commun ity (Post Office, Bristol Bay College Campus, and City of Dillingham)
facilities. Funding for the current thermal heat loop is from NETC sources, funding for future
thermal loop expansion and additional heat exhaust recovery is being pursued through USDA/R US
High Energy Cost grant programs. If approved this expansion project when fully implemented will
recover and/or displace an additional 250,000 gallons of fuel per year.
The vision is that this upgraded thermal loop system can still be fully utilized once the new hydro
generation facility comes on -line, either alone utilizing non-firm renewable energy, in parallel with
diesel gensets, or alone with diesel gensets during winter low flow hydro generation months. It is
anticipated that NETC’s Dillingham the rmal loop system will be able to utilize approximately 5 to 7
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GWh/year of non-firm renewable energy for heating once the hydro generation facility becomes
operational.
NETC’s future financial projections are a forty-year term based on the expected FERC Operational
License term and resultant debt service terms.
A twenty year review of kWh sales by rate class shows level annual sales with a diminishing
residential sales component and an increasing large commercial sales component. At the same
time peak annual demand has risen with the large commercial sale, driven by salmon processing
seasonal loads.
As this Project matures we will build into excess capacity through a non -firm (dispatchable) rate
that will encourage space heating and energy storage invest ments (domestic hot water, ice
making, EVs) As the rates are lowered through increased utilization more demand will be
developed for firm power consumption. This new demand will be primarily driven by conversion of
previously dispatchable loads as the firm/non-firm rates converge.
As we model the cost of power production a 5% growth rate is anticipated. If a 5% growth rate is
achieved we will reach the average annualized power production, less transmission loss
(52.4GWh), in eighteen years at which time th e estimate cost of power production and
transmission will be .14/kWh. If the annual growth rate is 3% capacity will be reached in thirty years
and the cost of power production will be .15/kWh.
Forty years of modeled growth and power production costs , using a 5% growth rate. The beginning
annual sales reflect expected overall electric KWh sales for all communities in 2028 and do not
include current heat recovery sales. Growth includes firm and dispatchable KWh sales, and heat:
Year Annual Sales (GWh) Power Production
Cost/kWh
2028 22.60 $0.28
2029 23.73 $0.27
2030 24.92 $0.26
2031 26.16 $0.25
2032 27.47 $0.24
2033 28.84 $0.23
2034 30.29 $0.22
2035 31.80 $0.21
2036 33.39 $0.20
2037 35.06 $0.19
2038 36.81 $0.19
2039 38.65 $0.18
2040 40.59 $0.17
2041 42.62 $0.16
2042 44.75 $0.16
2043 46.98 $0.15
2044 49.33 $0.15
2045 51.80 $0.14
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2046 54.20 $0.14
2047 54.20 $0.14
2048 54.20 $0.14
2049 54.20 $0.14
2050 54.20 $0.14
2051 54.20 $0.14
2052 54.20 $0.14
2053 54.20 $0.14
2054 54.20 $0.14
2055 54.20 $0.15
2056 54.20 $0.15
2057 54.20 $0.15
2058 54.20 $0.15
2059 54.20 $0.15
2060 54.20 $0.15
2061 54.20 $0.15
2062 54.20 $0.16
2063 54.20 $0.16
2064 54.20 $0.16
2065 54.20 $0.16
2066 54.20 $0.16
2067 54.20 $0.17
5.4.4 Proposed System Design
Provide the following information for the proposed renewable energy system:
A description of renewable energy technology specific to project location
The total proposed capacity and a description of how the capacity was determined
Integration plan, including upgrades needed to existing system(s) to integrate renewable
energy system: Include a description of the controls, storage, secondary loads, distribution
upgrades that will be included in the project
Civil infrastructure that will be completed as part of the project —buildings, roads, etc.
Include what backup and/or supplemental system will be in place
See the ―Proposed System Design‖ section of the appropriate Best Practice Checklist for additional
guidance.
The Project will consist of a single primary development centered around a river intake/diversion
located above Nuyakuk Falls and a single powerhouse facility located downstream below Nuy akuk
Falls. Additional Project facilities will include a single -bore tunnel arrangement to convey water
from the intake to the powerhouse, a tailrace conveyance channel to return water to t he Nuyakuk
River, an airstrip with local access roads, a small building to house a maintenance shop on the
lower level and an operators’ residence on the upper level, and an electrical transformer and
switchyard area to step power up for high -voltage (34.5 kV) conveyance via overhead transmission
to watershed communities. Overhead transmission is currently estimated to cover 140 miles
according to the conceptu alized route. The Project will likely also include a lower dock facility
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located near the powerhou se/tailrace outlet to allow for docking of small water craft that can
navigate the Nuyakuk River back to the Nushagak River.
The powerhouse is conceptualized to contain three Kaplan -style reaction turbine generating units
to accommodate a combined maximum design flow of approximately 7,550 cfs divided evenly
among the units. This combined maximum designed flow is the 75% exceedance flow rate for the
months of June, July and August, less 1,000 cfs for instream uses. The rated capacity on each unit
would be approximately 3,333 kW. The gross head on the Project is approximately 26 feet, based
on site surveying work that occurred in June of 2019.
The proposed Project features have been developed based upon existing physical and
environmental information and are conceptual in nature. As part of the FERC Operating
Application pre-filing consultation process, additional information will be obtained through technical
and environmental studies, and continuing research and consultation will be conducted with
equipment manufacturers and resource agencies. In May 2020, site-specific topographic and
bathymetric LiDAR surveys were conducted, and these data will be used in site analysis and
Project design. As additional information becomes available, the design features presented below
can be expected to be refined and/or modified to accommodate any changed conditions, including
maintenance of instream flow requirements.
SUMMARY OF PROJECT FEATURES
Number of Generating Units 3
Turbine Type Kaplan (Z-style or Vertical)
Runner Diameter (estimated) 17-ft
Operating Speed 108.1 rpm
Generator Type Synchronous
Rated Generator Output
Unit 1 3.33 MW
Unit 2 3.33 MW
Unit 3 3.33 MW
Maximum Rated Turbine Discharge
Unit 1 2,517 cfs
Unit 2 2,517 cfs
Unit 3 2,517 cfs
Diversion Forebay Water Surface Elevation
Minimum (Preliminary) 250.0 (ft NAVD88)
Maximum (Preliminary) 265.0 (ft NAVD88)
Turbine Centerline Elevation (Preliminary) 231.67 (ft NAVD88)
Normal Tailwater Elevation
Minimum (Preliminary) 225.0 (ft NAVD88)
Maximum (Preliminary) 235.0 (ft NAVD88)
Average Annual Energy (assuming 18.4 feet of net head and an average monthly intake diversion
flow of 4,688 cfs or 6,287 kW) 55,300 MWh
Gross Head 26 feet ± fluctuation
Net Head at Maximum Rated Discharge 18.4 feet
Watershed Characteristics
Drainage Area 1,544 sq. mi.
Maximum Basin Elevation 5,250 (ft NAVD88)
Minimum Basin Elevation 248 (ft NAVD88)
Mean Annual Precipitation 59.0 inches
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Area of Ponds or Lakes 12.4 %
Nuyakuk River Diversion (All aspects to -be-determined (TBD) once bathymetry and sub -bottom
profiling work is completed in 2020 and geotechnical reconnaissance work is completed)
Structure Type Concrete Diversion / Low Head Weir (TBD)
Structure Length 530 feet
Average Monthly Water Height above Weir (Max) 3.75 feet
Average Monthly Water Height above Weir (Min) 0.25 feet
Crest Elevation x
Water Conveyance (Pressurized Tunnel from Intake to Powerhouse)
Intake Style Possibly a diversion structure feeding a concrete open channel short canal. Single
canal could feed three vertical intake shafts (one per turbine unit)
Typical Open Channel Allowable Velocity < 3.0 ft/sec
Open Channel typical depths 10 to 15 ft
Open Channel width 175 to 250-ft
Tunnel Lip Elevation at Open Channel 245.0 (ft NAVD88)
Tunnel Construction Type TBD once field geotechnical drilling and data are compiled
Length of inclined tunnels to powerhouse ~500 to 600 feet
Tunnel Velocity at Maximum Turbine Discharge ~ 10 ft/sec
Single Tunnel Configuration
(one feeding all three turbines)
Tunnel Flow Capacity 7,550 cfs
Unlined Tunnel Diameter 32-ft
Final Lined Diameter 30-ft
Base Elevation (Preliminary) 245.0 (ft NAVD88)
Top Elevation (Preliminary) 265.0 (ft NAVD88)
Powerhouse
Approximate Dimensions (for three -unit powerhouse) 40 feet x 120 feet x 30 feet high
Finished Floor Elevation 250.0 (ft NAVD88)
Tailrace
Type Open Channel
Length 200 to 300 feet
Typical Water Depth 8-ft +/-
Typical Width 120 to 150 ft
Transmission Line
Type Overhead
Length (to Dillingham) Approximately 60 miles
Voltage 34.5 kV
Access Roads (from Airstrip Runway to Powerhouse)
Type Single lane gravel surfacing with turnouts
Length 0.5 miles
When powerhouse flows do not match the system loads, grid system electricity will have to be
supplemented with existing diesel generation. This will most likely be in the winter months when
the amount of water available to the powerhouse is less than the power demand would require.
The transmission grid will therefore have five diesel generation power plants ti ed together to
complete the electric grid system. The existing power plant in Dillingham has the ability to provide
energy for all six villages serviced by the transmission system throughout the year, except for the
month of July. This gives NETC the ability to feed the system from different sources as needed for
load or maintenance.
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A concrete gravity diversion structure would be constructed above the falls on the Nuyakuk River.
The intake diversion would move water from the southern portion of the river above the falls into an
open-channel, concrete canal to convey the diverted water inland (towards the powerhouse) a
short distance. The canal is conceptualized to have a length equal to or greater than its width (L/W
> 1) in order to follow appropriate hydraulic standards for splitting the water into multiple intakes.
As such, the canal length would be on the order of 150 to 200 ft long. At the end of the canal
would be three vertical shafts, drop-inlets, with each drop inlet feeding an independent tunne l
connected to one turbine unit. The diversion and intake geometry will be advanced once field site
investigations (bathymetry, sub -bottom profiling, and geotechnical drilling) are completed. In
addition, two-dimensional river hydraulic modeling will be required for approximately 1,000 lineal
feet above the falls to aid in proper development of the intake diversion hydraulic and structural
design. It is anticipated that river hydraulic modeling and geotechnical studies will be conducted as
part of the overall Project licensing study program.
Each conveyance tunnel would be equipped with an isolation gate at the intake to be able to
independently shut down each tunnel and corresponding turbine unit for maintenance or other
emergency (e.g. turbine runaway) considerations. A canal gatehouse would be constructed with
large vertical telescoping control gates that can be designed to effectively isolate one tunnel and
shut off flow to that tunnel for maintenance or other reasons. The diversion structure and i ntake
canal would be equipped with redundant level transmitters to continuously monitor water levels in
these critical conveyance features.
The inlet zone to the open channel canal would be protected by steel inclined bar -screens (with
openings between bars on the order of 1 to 3 inches) to divert both ice and debris away from the
open channel and downstream over the natural falls. The trash rack would be oriented parallel to
river flow to maximize sweeping velocity on the rack face, thereby increasing pa ssive flushing of
debris from the rack. The trash rack would be necessary to protect both the downstream
telescoping vertical gates as well as the downstream turbine units. Final concept design would
need to investigate whether or not an additional isolat ion bulkhead or sluice gates would be
needed behind the trash rack for further safety or maintenance purposes.
Assuming that a three-turbine powerhouse is the most practical and reliable configuration for
power generation, the Project would be developed with either one larger water conveyance tunnel
feeding all three turbine units, or three smaller diameter tunnels, with each tunnel dedicated to one
turbine unit. Better system reliability and Project redundancy would be provided by an arrangement
that dedicates a tunnel to each unit, but the cost of providing three tunnels could be higher than
that of a single tunnel unit. Advantages of a three -tunnel project would include the following:
• Ability to run two turbine units while maintenance is performed o n the other isolation gate or
turbine unit.
• Design of the steel tunnel liners to fit inside the excavated rock tunnels may be significantly
easier with the smaller 15 -ft final steel liners than the larger and thicker requirements for the single
25-ft steel lined tunnel.
If on-site geotechnical drilling and investigations show that native rock quality is poor or
inconsistent, then it should be assumed that all tunnels would have to be lined with either a welded
in-place steel liner (a continuous steel shell liner likely of at least 1/2 -inch thickness) or perhaps
with a rock-bolt and shotcrete system to protect against the inherent structural weaknesses or
deficiencies in the native rock. If steel liners are used, they would be brought in longitudinal a rc-
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sections and seem-welded both longitudinally and horizontally inside the tunnel. Once the steel
liners are placed inside the tunnel, the annular void space between the liner and the native rock
would be pressure grouted with structural non -shrink grout mixes designed to be pumped and flow
through annular spaces.
If on-site geotechnical investigations show that native rock is of high enough quality and consistent
enough through the tunnel alignment zone, then it may be possible to omit the need for an i nterior
steel liner or rock-bolt and shotcrete liner system. This configuration would provide a large
economic benefit to the Project. Detailed on-site geotechnical investigations, including field drilling
and logging, will be used to clarify the design needs of the conveyance tunnels.
If a single conveyance tunnel system is pursued for the Project design, it will be necessary to
provide a trifurcation design near the outlet to the tunnel and prior to the powerhouse. The
trifurcation would be designed of steel pipe and would divide the flow to the three Kaplan units with
their horizontal spiral cage inlet configurations. Geometric symmetry would be required to ensure
an equal division of flow to the three units when all units are in operation. The l ow system net
heads (estimated at 26 feet or 11 psig (pounds per square inch, gage)) and lack of much external
groundwater or other external loading conditions suggest that the structural design and resulting
plate thickness of a steel pipe trifurcation sy stem should not be very thick. However, both handling
and site-specific seismic considerations will be taken into account in the final trifurcation design.
If three separate conveyance tunnels are pursued for the Project, then the trifurcation structure c an
be eliminated from the Project.
The powerhouse would be located on the south bank of the Nuyakuk River near the base of the
falls. The powerhouse is estimated to be approximately 40 feet wide by 120 feet long by 30 feet
high to accommodate three of th e Kaplan vertical shaft turbine units. The powerhouse would have
a large underground foundation that houses the entrance cage to the runner along with the
impeller section of each turbine unit. The main superstructure above ground would be a pre -
engineered metal building anchored to a concrete foundation.
The powerhouse concept is to contain three vertical shaft Kaplan -type turbine/generator units with
a rated capacity of 3,333 kW for each unit at a design flow of approximately 2,516 cfs per unit, and
associated switchgear and controls. The centerline of the turbine and generator units would be
approximately 232 feet above mean sea level (msl). The tailwater elevation at the powerhouse
would range from approximate elevations 225 feet above msl to 235 fe et above msl depending
upon output level. Final values for these elevations will be determined once the site topographic
and bathymetric surveys are completed in 2020. The turbines would be designed to operate at
high efficiencies over a range of flows f rom the maximum of 2,516 cfs to a minimum of around 755
cfs depending on conditions.
The tailrace would be an open rectangular concrete channel approximately 200 feet long and120
to 150 feet wide to convey water back to the Nuyakuk River. The tailrace outlet to the river would
be designed to reduce velocities relative to the natural river velocities in the discharge zone. This
will help prevent native anadromous fish from being attracted to the Project discharge flow instead
of the natural river channe l flow pathways. In addition, the need for vertical picket barriers or other
such fish barrier protection measures on the outlet of the Tailrace will need to be evaluated during
Project development.
The switchyard at the powerhouse will consist of a pad -mounted disconnect switch (i.e., breaker)
and a pad-mounted step-up transformer. An overhead 34.5 kV transmission line would run from
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the powerhouse switchyard approximately 60 miles to a point of interconnection with the NETC
electrical system. A right-of -way would be established along the proposed transmission line. This
route would be used to construct the transmission line, then serve as a land -based right of way for
the Project site. The route would incorporate setbacks from main waterways and alig nment
changes to minimize visual impacts.
The transmission line poles would be designed as tangent line structures located approximately
every 300 feet on center. Transmission line design will also incorporate the latest raptor protection
guidelines. Collision avoidance devices will be installed on the line at appropriate locations to
protect migratory birds.
The Project would be constructed over a 24 -month timeframe after the issuance of the Project
license. Construction would begin in the spring w ith the clearing of a right-of -way along the
transmission corridor and the construction of the localized access road at the Project works on the
river. A majority of the large equipment necessary to construct Project infrastructure would be
barged up the river and stored at the site during construction activities. An airstrip would be
constructed adjacent to the Project site to allow air transport of equipment, materials, and
manpower to support construction activities. A fully equipped man camp would be erected for the
Project construction staff. Portable generation facilities would provide power for the construction
work and man camp facilities. Initially, temporary cofferdams would be constructed at the intake
and powerhouse tailrace channel exit zon e into the river. This would allow the intake structure,
power conduit, and powerhouse construction to advance simultaneously to maximize the work
completed during a summer construction season. The intake and power conduit would be
completed first, with the powerhouse structure completed immediately following. The generation
equipment would be installed, and the balance of plant construction advanced during the winter
months. The diversion structure and tailrace channel would be the last components cons tructed
followed by removal of the river cofferdams. These work activities would be completed in the last
season followed by startup, commissioning, and initiation of commercial power generation.
5.4.4.1 Proposed Power Generation Units
Unit # Resource/
Fuel type
Design
capacity
(kW)
Make Model Expected
capacity
factor
Expected
life
(years)
Expected
Availability
1 Water 3333 Kaplan Style 65% 40+ 99%
2 Water 3333 Kaplan Style 65% 40+ 99%
3 Water 3333 Kaplan Style 65% 40+ 99%
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5.4.4.2 Proposed Thermal Generation Units (if applicable)
Generation
unit
Resource/
Fuel type
Design
capacity
(MMBtu/hr)
Make Model Expected
Average
annual
efficiency
Expected
life
5.4.5 Basic Operation of Proposed Energy System
To the best extent possible, describe how the proposed energy system will operate: When will
the system operate, how will the system integrate with the existing system, how will the
control systems be used, etc.
When and how will the backup system(s) be expected to be used
See the ―Proposed System Design‖ section of the appropriate Best Practice Checklist for additional
guidance.
The primary mode of operation for this Project will be level control, whereby outflow is balanced to
inflow. The Project is conceived as a run-of -river project, with no large storage component. As
such, power production will mimic some fraction of total river inflow to the Project site.
Mean daily discharge in the Nuyakuk River is based on USGS gaging data available at station
15302000 located near the outlet of Nuyakuk Lake. From the figure, it is clear that the period of
high flow in the river occurs between early summer and early fall. For the remainder of the year,
the river is running at near baseflow conditions. Because the Project will operate in run-of-river
mode, sizing the generating units should be done to either 1) optimize power production during a
specific time of year (e.g. during the winter months) or 2) produce power more or less evenly
throughout the year. Under the current Project conceptualization, units have been sized to provide
a stable amount of power from month to month while attempting to minimize overall capital costs
associated with the hydroelectric units, tunnel(s), and other Project components. Average monthly
power generation under this ope rational configuration is shown.
During periods when system firm power loads exceed hydro capacity, electric generation and
spinning reserve needs will be met with an economic dispatch model that will utilize th e least cost
generation option first. This will likely be NETC’s diesel generation plant initially.
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5.4.3.1 Expected
Capacity Factor 63%
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5.4.5.2 Annual Electricity Production and Fuel Consumption (Proposed System) – Year 1
Month Generation
(Proposed
Hydro
System)
(MWh)
Gener
ation
(Diesel
Genset
(MWh)
Generatio
n
(Type 3)
(kWh)
Fuel
Consumptio
n
(Diesel-
Gallons)
Fuel
Consumptio
n
[Other]
Secondar
y load
(kWh)
Storag
e
(kWh)
January 2,390,000
February 1,970,000
March 1,710,000
April 1,690,000
May 4,800,000
June 15,400,000
July 13,400,000
August 8,800,000
September 7,890,000
October 7,560,000
November 5,000,000
December 3,220,000
Total 73,830,000
5.4.5.3 Annual Heating Fuel Consumption (Proposed System) – Year 1
Month Recovered
Genset Heat –
Dillingham Thermal
Loop
Non-firm
Electricity –
Dillingham
Thermal
Loop
Propane
(Gallons)
Coal
(Tons)
Wood
(Cords,
green
tons, dry
tons)
Other
January
February
March
April
May
June
July
August
September
October
November
December
Total
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5.4.6 Proposed System Operating and Maintenance (O&M) Costs
O&M costs can be estimated in two ways for the standard application. Most proposed renewable
energy projects will fall under Option 1 because the new resource will not allow for dies el
generation to be turned off. Some projects may allow for diesel generation to be turned off for
periods of time; these projects should choose Option 2 for estimating O&M.
Option 1: Diesel generation ON
For projects that do not result in shutting down
diesel generation there is assumed to be no
impact on the base case O&M. Please indicate
the estimated annual O&M cost associated with
the proposed renewable project.
$
Option 2: Diesel generation OFF
For projects that will result in shutting down
diesel generation please estimate:
1. Annual non-fuel savings of shutting off
diesel generation
2. Estimated hours that diesel generation
will be off per year.
3. Annual O&M costs associated with the
proposed renewable project.
1. $3,135,771 (40 year average)
2. Hours diesel OFF/year:6600
3. $2,726,036 (40 year package)
5.4.7 Fuel Costs
Estimate annual cost for all app licable fuel(s) needed to run the proposed system (Year 1 of
operation)
Diesel
(Gallons)
Electricity Propane
(Gallons)
Coal
(Tons)
Wood
Other
Unit cost
($) $2.48
Annual
Units 1,558,733
Total
Annual
cost ($)
$3,846,725
5.5 Performance and O&M Reporting
For construction projects only
5.5.1 Metering Equipment
Please provide a short narrative, and cost estimate, identifying the metering equipment that will be
used to comply with the operations reporting requirement identified in Sect ion 3.15 of the Request
for Applications.
Metering and automatic data logging of all key operational and performance metrics will be
incorporated into final system design to comply with all AEA, FERC, and USDA/RUS reporting
requirements.
Because Broadband fiber will be incorporated into transmission line cables a real -time fiberoptic
based industrial dispatch and control system will be capable of controlling, monitoring and metering
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firm and non-firm electric system loads. This incorporated industrial fiber control system will provide
a long-term robust, reliable, and cost-effective control, dispatch, monitoring, and metering system.
5.5.2 O&M reporting
Please provide a short narrative about the methods that will be used to gather and store reliable
operations and maintenance data , including costs, to comply with the operations reporting
requirement identified in Section 3.15 of the Request for Applications
SCADA, metering and automatic data logging of all key operational and performance metrics wil l
be incorporated into final system design along with an asset management system to track and
document maintenance costs, history, and performance to comply with all AEA, FERC, and
USDA/RUS reporting requirements.
`
SECTION 6 – ECONOMIC FEASIBILITY AND BENEFITS
6.1 Economic Feasibility
6.1.1 Economic Benefit
Annual Lifetime (40 years)
Anticipated Diesel Fuel Displaced for Power
Generation (gallons)
1,500,000 60,000,000
Anticipated Fuel Displaced for Heat
(gallons)
58,033 25,743,923
Total Fuel displaced (gallons) 1,558,000 85,743,923
Anticipated Diesel Fuel Displaced for Power
Generation ($)
$3,846,725 $262,174,217
Anticipated Fuel Displaced for Heat ($) $253,569 $10,142,783
Anticipated Power Generation O&M Cost
Savings
$2,812,835 $112,513,399
Anticipated Thermal Generation O&M Cost
Savings
Total Other costs savings (taxes, insurance,
etc.)
Total Fuel, O&M, and Other Cost Savings $6,913,129 $384,830,399
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6.1.2 Economic Benefit
Explain the economic benefits of your project. Include direct cost savings and other economic
benefits, and how the people of Alaska will benefit from the project. Note that additional revenue
sources (such as tax credits or green tags) to pay for operations and/or financing, will not be
included as economic benefits of the project.
Where appropriate, describe the anticipated energy cost in the community, or whatever will be
affected by the project, over the life of the project. Explain how the forecast was developed and
provide year-by-year forecasts
The economic model used by AEA is available at www.akenergyauthority.org/What-We-Do/Grants-
Loans/Renewable-Energy-Fund-REF-Grants/2020-REF-Application. This economic model may be
used by applicants but is not required. The final benefit/cost ratio used will be derived from the
AEA model to ensure a leve l playing field for all applicants. If used, please submit the model with
the application.
The Nuyakuk River Hydroelectric Project will provide an alternative to diesel power production for
six Bristol Bay communities, initially lowering the cost of powe r production and eventually
significantly lowering the cost of power production as the investment matures. Two main drivers in
the increasing value of this Project when compared with the diesel alternative; load growth up to
the power production limits and the effects of inflation on fuel costs. As the cost of power lowers for
these communities they will be less reliant on PCE, possibly eliminating the need, benefitting the
State and all Alaskans.
Completion of this Project will also bring a level of energy security and self -sufficiency to the
communities served. There are risks in fuel delivery including low water grounding in the river
system and leaks during transfer that will be mitigated by the lessoning dependence on generator
fuel and space heating diesel.
Financial forecasting was developed by evaluation of NETC RUS form 7 reporting, NETC
replacement schedule/cost estimation from recent power plant investment and community PCE
reporting. The spreadsheet used to forecast has several user defined in puts including initial Project
capitalization costs and reinvestment cycle, existing power plant reinvestment costs and cycle,
interest rates for capital debt service, inflation rates and expected growth. Actual power production
O&M cost were used as legacy system baseline and Project O&M costs where estimated based on
operational expectations. The spreadsheet will be included with this application, the forty year cost
estimate and selected inputs:
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User Input Year Diesel Hydro
cost/KWH cost/KWH
Hydro debt service Initial 2028 0.31$ 0.28$
Interest rate 2 2029 0.32$ 0.27$
Term in years 40 2030 0.33$ 0.26$
Capital cost 151,000,000.00$ 2031 0.33$ 0.25$
Grants 20,000,000.00$ 2032 0.34$ 0.24$
Total cost 131,000,000.00$ 2033 0.35$ 0.23$
2034 0.36$ 0.22$
Diesel debt service Initial 2035 0.36$ 0.21$
Interest rate 1.97 2036 0.37$ 0.20$
Term in years 30 2037 0.38$ 0.19$
Capital cost 13,500,000.00$ 2038 0.39$ 0.19$
Grants -$ 2039 0.40$ 0.18$
Total cost 13,500,000.00$ 2040 0.41$ 0.17$
2041 0.42$ 0.16$
Hydro debt service 1st Reinvest 2042 0.43$ 0.16$
Interest rate 2 2043 0.44$ 0.15$
Term in years 40 2044 0.45$ 0.15$
Capital cost 12,000,000.00$ 2045 0.46$ 0.14$
Grants -$ 2046 0.47$ 0.14$
Total cost 12,000,000.00$ 2047 0.48$ 0.14$
2048 0.49$ 0.14$
Diesel debt service 1st Reinvest 2049 0.50$ 0.14$
Interest rate 2 2050 0.51$ 0.14$
Term in years 30 2051 0.52$ 0.14$
Capital cost 20,000,000.00$ 2052 0.53$ 0.14$
Grants 5,000,000.00$ 2053 0.55$ 0.14$
Total cost 15000000 2054 0.56$ 0.14$
2055 0.57$ 0.15$
Diesel debt service 2nd Reinvest 2056 0.58$ 0.15$
Interest rate 2 2057 0.60$ 0.15$
Term in years 30 2058 0.62$ 0.15$
Capital cost 45,000,000.00$ 2059 0.63$ 0.15$
Grants 10,000,000.00$ 2060 0.65$ 0.15$
Total cost 35000000 2061 0.66$ 0.15$
2062 0.68$ 0.16$
Rate of inflation 2.50%2063 0.69$ 0.16$
2064 0.71$ 0.16$
MWH Consumption Diesel 20328 2065 0.73$ 0.16$
Growth Diesel 0.05%2066 0.74$ 0.16$
2067 0.76$ 0.17$
MWH Consumption Hydro 22600
Growth Hydro 5.00%
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6.1.3 Economic Risks
Discuss potential issues that could make the project uneconomic to operate and how the project
team will address the issues. Factors may include:
Low prices for diesel and/or heating oil
Other projects developed in community
Reductions in expected energy demand : Is there a risk of an in sufficient market for energy
produced over the life of the project .
Deferred and/or inadequate facility maintenance
Other factors
The largest economic risk to this Project is the cost of construction, estimated at approximately
$153 million. The two largest drivers in the cost of construction are the penstock construction cost
at the power plant and the transmission plant build.
The cost of constructing the penstock will be determined by the quality of the substrate at the site.
NETC has released undertaken a RFP process for geotechnical study services in 2021. The
results of this study will have significant bearing on the cost of penstock construction and the
overall cost of construction. By completing this study early in the process NETC will gain cr itical
information for financial feasibility assessment.
The transmission line costs, and in particular the cost to access the smaller communities, is being
mitigated by evaluating build alternatives such as emerging pole placement technology and carbon
f iber core conductors that would allow for fewer pole placements and higher reliability. NETC has
also met with Tribal grant funding representatives from the Department of Energy and Bureau of
Indian Affairs Indian Energy Programs. The Project was well received and NETC will work with the
Tribal organizations in these communities to apply for these funds when appropriate.
NETC will continue it’s 55 year history of successful power plant operations by providing 24/7
operators onsite, operator training, ope rational maintenance and appropriate system reinvestment.
While other investments in renewable may impact the current load, NETC knows of none currently
in development and no local resource that would replace base load capacity as this Project does.
6.1.4 Public Benefit for Projects with Direct Private Sector Sales
For projects that include direct sales of power to private sector businesses (sawmills, cruise ships,
mines, etc.), please provide a brief description of the direct and indirect public bene fits derived
from the project as well as the private sector benefits and complete the table below. See Section
1.6 in the Request for Applications for more information.
N/A
Renewable energy resource availability (kWh per month)
Estimated direct sales to private sector businesses (kWh)
Revenue for displacing diesel generation for use at p rivate sector businesses ($)
Estimated sales for use by the Alaskan public (kWh)
Revenue for displacing diesel generation for use by the Alaskan public ($)
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6.2 Other Public Benefit
Describe the non-economic public benefits to Alaskans over the lifetime of the project. For the
purpose of evaluating this criterion, public benefits are those benefits that would be considered
unique to a given project and not generic to any renewable resource. For example, decreased
greenhouse gas emission, stable pricing of fuel source, won’t be considered under this category.
Some examples of other public benefits include:
The project will result in developing infrastructure (roads, trails, pipes, power lines, etc.) that
can be used for other purposes
The project will result in a direct long -term increase in jobs (operating, supplying fuel, etc.)
The project will solve other problems for the community (waste disposal, food sec urity, etc.)
The project will generate useful information that could be used by the public in other parts of
the state
The project will promote or sustain long -term commercial economic development for the
community
Broadband Deployment
The Project will include a fiber optic communications build that will have the ability to extend the
existing fiber network to these communities. NETC has contracted for 100GB/s of Direct Internet
Access on completion of the fiber build, equivalent to over 200 times the existing bandwidth to
these communities.
Achieving Urban standards of Broadband access will improve quality of life by providing access to
E-commerce, employment opportunity, governmental functions including access to elected
representation, education, ne ws, entertainment and social media.
Improved Broadband access will allow modernization of workforce tasks by allowing better access
to cloud-based services, secure data storage and training opportunities.
Increased Broadband access will allow businesses and job seekers better access to opportunities
and markets
Economic benefit of lower electric rates
Mature hydroelectric generation has several examples of rural communities providing service at, or
better than, urban rate equivalency. Examples include C ordova, Kodiak, Sitka, Valdez, Ketchikan
There are hydroelectric facilities in Alaska that have been providing power for over 100 years
Current PCE urban averaging is .19/kW h. That rate applied to the communities served by this
Project has significant yearly savings averaged over the last five years
Savings to the communities combined averages $3,632,155/year (non PCE customers)
Savings to the State in avoided PCE payments $1,289,290/year (2019 AEA PCE reports)
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SECTION 7 – SUSTAINABILITY
Describe your plan for operating the completed project so that it will be sustainable throughout its
economic life.
At a minimum for construction projects, a business and operations plan should be attached and the
applicant should describe how it will be implemented. See Section 11.
7.1.1 Operation and Maintenance
Demonstrate the capacity to provide for the long-term operation and maintenance of the proposed
project for its expected life
Provide examples of success with similar or related long -term operations
Describe the key personnel that will be available for operating and maintaining the
infrastructure.
Describe the training plan for existing and future employees to become proficient at operating
and maintaining the proposed system.
Describe the systems that will be used to track necessary supplies
Describe the system will be used to ensure that s cheduled maintenance is performed
Nushagak Electric Association was incorporated in March of 1964, and became Nushagak Electric
Cooperative with an amendment to the art icles of incorporation in September of 1972. It became
Nushagak Electric and Telephone Cooperative with articles of consolidation in May of 2002.
NETC has successfully operated power production and distribution over the last 55 years under
Certificate of Public Convenience and Necessity providing distributed electric service to the
communities of Dillingham and Aleknagik. NETC will maintain this new infrastructure under the
same systems of management and control methodology, using contemporary technology, w hich
has been proven successful since operations began in 1964.
Robert Armstrong, Electric Operations Manager, general project oversight and schedule
maintenance. Bob started in electric utilities in 1980, became a Journeyman Lineman in 1986,
Lead Lineman in 1995 and Line Superintendent in 2001. He became a District Manager in 2010.
Bob brought his accumulated experience, 35 years, to NETC in 2015 as the Electric Operations
Manager.
Jim Denslinger, Power Plant Supervisor, project quality control and integration. Jim has 17 years of
operational experience in this power plant, including all aspects of plant maintenance and repair.
Bernie Venua, Power Plant technician, project quality control and integration. Bernie has 22 years
of operational experience in this power plant, including all aspects of plant maintenance and repair.
In addition to these key individuals, NETC’s power plant staff includes six operator -mechanics with
a combined 98 years of service. The plant is staffed around the clock, every day of the year.
Operational supplies will be tracked through our existing software platform, provided and supported
by National Information Solutions Cooperative (NISC).
Daily and Monthly PM checks will be developed through the engineering process in con sultation
with vendors for best practices. We will train NETC’s existing power plant operators and mechanics
on these new Preventative Maintenance and expected Corrective Maintenance procedures. We
will integrate the data collection and review from the PM and CM procedures into the existing
processes.
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7.1.2 Financial Sustainability
Describe the process used (or propose to use) to account for operational and capital costs.
Describe how rates are determined (or will be determined). What process is required to set
rates?
Describe how you ensure that revenue is collected.
If you will not be selling energy, explain how you will ensure that the completed project will be
financially sustainable for its useful life.
Nushagak Electric and Telephone Cooperative have provided electric service to the communities
of Dillingham and Aleknagik, Alaska since 1964. The cooperative has grown to meet the increasing
distributed electric needs of the communities served, from total production of 5.5MW h’s and a peak
load of 1.5 MW in 1978 to 17.66 GW h’s and a peak of 6.3 MW in 2019. In meeting this growing
expectation, NETC has consistently managed operations to provide reliable service while trying to
minimize the economic impact to our members.
NETC operations include electric, telephone and cable TV, divisions I, II and III respectively.
Revenues are generated for each of these services under a cooperative structure, striving to
maintain a 1.50 TIER. Two in-house accountants and a bookkeeper manage grant funds and
financial reporting for NETC. Grant accounting is audited annually by a third party.
Angela Venua, Senior Accountant, and Robert Himschoot, CEO/GM, will have responsibility for
fiduciary concerns, project accounting, and financial reporting. NETC retains a third -party audit on
an annual basis; currently Aldrich CPA’s and Advisors, LLP, are under contract.
Angela Venua, Senior Accountant, project accounting, financial reporting and compliance. Angela
has been with NETC for 17 years, where she became Senior Accounta nt in 2015. Angela holds a
Bachelor’s in Accounting and is a RUS Borrower Accountant through the USDA Graduate School.
NETC will complete a cost-of -service study (―COSS‖) that allocates the electric utility costs of
Nushagak Electric & Telephone Cooperative (―NETC‖) to the various rate classes. Costs will be
based on the current budget but normalized for a full year interest and depreciation expenses as
well as other costs anticipated in the near future. Although NETC’s electric rates are not regulated
by the Regulatory Commission of Alaska (―RCA‖), the analysis will use the standards developed
within the industry.
Revenue collection will be completed through our existing software platform provided by NISC. We
have successfully used this platform for revenue collection across all our services since 2015. The
platform includes an online payment option.
7.1.2.1 Revenue Sources
Briefly explain what if any effect your project will have on electrical rates in the proposed benefit
area over the life of the project. If there is expected to be multiple rates for electricity, such as a
separate rate for intermittent heat, explain what the rates will be and how they will be determined
Collect sufficient revenue to cover operational and capital costs
What is the expected cost-based rate (as consistent with RFA requirements)
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If you expect to have multiple rate classes, such as excess electricity for heat, explain what
those rates are expected to be and how those rates account for the costs of delivering the
energy (see AEA’s white paper on excess electricity for heat)..
Annual customer revenue sufficient to cover costs
Additional incentives (i.e. tax credits)
Additional revenue streams (i.e. green tag sales or other renewable energy subsidies or
programs that might be available)
The Project will have a small but immediate reduction on rates across all rate classes, and a larger
reduction as the Project matures, consistent with the reduction in power production costs modeled
earlier in the application (6.1.2).
NETC has contracted supplemental heat sales since 1986. The revenue is generated based on
BTU consumption with the revenue model. NETC would continue selling thermal heat at a
competitive discount compared to conventional/heating fuel pricing.
Additional revenue, not modeled in the financial forecasting, would come from monetizing the
Broadband bandwidth derived from this Project. NETC also provides Broadband services and has
all the necessary technical, operational and financial mechanisms to market this capacity.
NETC’s study area includes the communities of Dillingham, Aleknagik, Manokotak, Clark’s Point,
Ekuk and Portage Creek. NETC’s Broadband product is available in Dillingham, Aleknagik and
Clark’s Point with a total of 811 su bscriptions. This capacity expansion would allow for expansion
of service to Manokotak, Ekuk and Portage Creek including the seasonal commercial and sports
fishing industry.
7.1.2.2 Power Purchase/Sale
The power purchase/sale information should include the following:
Identification of potential power buyer(s)/customer(s)
Potential power purchase/sales price - at a minimum indicate a price range (consistent with the
Section 3.16 of the RFA)
Identify the potential power buyer(s)/customer(s) and anticipated power purchase/sales price
range. Indicate the proposed rate of return from the grant -funded project. Include letters of support
or power purchase agreement from identified customers.
Currently there are no Power Purchase agreements modeled for this Project. Power sales to
communities can be handled as Large Commercial rate class sales. NETC currently sells power to
the Bristol Bay Area Health Corporation (BBAHC) under this arrangement. BBAHC owns and
maintains its own distribution system, energy and demand are metered at a system demarca tion
point.
This mechanism lends to COSS rate making by taking into account capital investment through
grant funds allocated to individual communities.
SECTION 8 – PROJECT READINESS
8.1 Project Preparation
Describe what you have done to prepare for this award and how quickly you intend to proceed with
work once your grant is approved.
Specifically address your progress towards or readiness to begin, at a minimum, the following:
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The phase(s) that must be completed prior to beginning the phase(s) pro posed in this
application
The phase(s) proposed in this application
Obtaining all necessary permits
Securing land access and use for the project
Procuring all necessary equipment and materials
Refer to the RFA and/or the pre -requisite checklists for the required activities and deliverables for
each project phase. Please describe below and attach any required documentation.
NETC has completed Phase I with the submission of the FERC ILP Scoping Documents. It has
initiated Phase II through the FERC ILP Study Plan development process. Although the ILP is
currently in Abeyance due mainly to COVID related delays it is NETC’s plan to continue study plan
development through a series of virtual meetings in the fall/winter of 2020 and reinitiate the ILP
March allowing for a summer 2021 study season.
In preparation for Phase II field study work NETC and McMillen Jacobs have identified and
engaged partners and contractors for the 2021 field work including R2 Resource Consultants,
Cultural Resources Consultants (CRC), Quantum Spatial, ADF&G and NOAA NMFS. We have
also engaged an RFP process for 2021 geotech work, having reviewed responses and will award
later this fall for a July 2021 contract.
NETC worked directly and intensively with the Alaska State Legislature to d evelop SB91 which
allows for the requisite natural resource and engineering assessment activities and FERC
regulatory processes that need to be conducted for an ultimate project feasibility determination.
SB91 was unanimously passed by the Alaska State Le gislature in 2019 allowing for the
comprehensive evaluation of the site.
NETC acquired a Special Use Permit from ADNR, Division of Parks & Outdoor Recreation on April
1, 2020 (Permit #LAS 33198). The permit authorizes temporary use of the Project site to conduct
scientific research, including geotechnical investigations, land surveying, and bathymetric
surveying. The permit includes provisions for the installation of a man camp that will be used to
house Project personnel on site. The permit is effective May 1, 2020 through May 1, 2023.
NETC will continue to engage with all requisite agencies to obtain additional permits for conducting
natural resource studies and engineering evaluations, as needed. NETC is currently in the process
of developing natural resource study methodologies, and once study plans are finalized NETC will
coordinate with requisite agencies to obtain all required permits prior to initiating studies and on -
site engineering assessments. NETC anticipates applying for all additional study -related permits
needed from state and federal agencies in 2021, following the issuance of FERC’s Study Plan
Determination.
8.2 Demand- or Supply-Side Efficiency Upgrades
If you have invested in energy efficiency projects that will have a positive impac t on the proposed
project, and have chosen to not include them in the economic analysis, applicants should provide
as much documentation as possible including:
1. Explain how it will improve the success of the RE project
2. Energy efficiency pre and post audit reports, or other appropriate analysis,
3. Invoices for work completed,
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4. Photos of the work performed, and/or
5. Any other available verification such as scopes of work, technical drawings, and payroll for
work completed internally.
As the Project becomes better defined efforts will be made to encourage Village/Tribal
organizations to pursue Energy Conservation Measures (ECM’s) at all locations that might
incorporate any new dispatchable thermal heating devices that utilize excess renewable
hydroelectricity.
SECTION 9 – LOCAL SUPPORT AND OPPOSITION
Describe local support and opposition, known or anticipated, for the project. Include letters,
resolutions, or other documentation of local support from the community that would benefit from
this project. Provide letters of support, memorandum of understandings, cooperative agreements
between the applicant, the utility, local government and project partners. The documentation of
support must be dated within one year of the RFA date of July 20, 2020. Please note that letters of
support from legislators will not count toward this criterion .
After two years of desktop Project feasibility studies and over ninety Project outreach meetings, in
October of 2019, NETC filed our Pre Application Document initiating the FERC Inte grated
Licensing Process (ILP) timeline. Recently NETC received letters and resolutions stating concern
for the effects of COVID-19 and the Bristol Bay fishing season on the ability to effectively
participate in the licensing process study plan development, specifically the aquatics and fish
passage studies that all consider paramount. Initially, these entities requested a delay of 12
months to the ILP schedule. NETC received these correspondences during the last week of May
from five regional entities, Bristol Bay Economic Development Corporation, Bristol Bay Native
Association, Bristol Bay Area Health Corporation, Bristol Bay Housing Authority and United Tribes
of Bristol Bay. On June 8th NETC received a copy of a consistent resolution passed by the Wood
Tikchik Management Council at their meeting on May 27th.
While NETC does not agree with all the conclusions in these correspondences, we do respect the
entities and want to address their concerns. NETC consulted with FERC on June 2nd regarding
these topics which lead to a request for an Abeyance (a suspension of the schedule) to the ILP
timeline. The request was submitted June 7th and approved by FERC on June 9th.
During this Abeyance the ILP timeline is suspended and will be reinitiated when NETC resub mits a
Proposed Study Plan. During this Abeyance it is NETC’s intent to create an Aquatics Resources
Working Group, inviting subject matter technical experts to participate in evaluating and creating
Aquatics and Fish Passage studies. It is also NETC’s in tent to hold additional in-person public
meetings as soon as it is safe to do so. It is our hope that this voluntary effort will alleviate the
concerns expressed.
NETC also received several Resolutions of support during our Public outreach process. The letters
of concern requesting NETC to apply for an Abeyance, NETC’s response letter and the letters of
support will be included with the application.
SECTION 10 – COMPLIANCE WITH OTHER AWARDS
Identify other grants that may have been previously aw arded to the Applicant by AEA for this or
any other project. Describe the degree you have been able to meet the requirements of previous
grants including project deadlines, reporting, and information requests .
In November of 2009 NETC received grant # 2195419 from the AEA REF. The award amount was
$4,031,500 of which $1,898,233.19 was expended for the study of Grant and Elva lake hydro
potential. When project feasibility was evaluated after the 2013 study season and the project was
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terminated the remaining $2,133,266.82 was returned to the Fund. The Grant was closed out in
August of 2014.
SECTION 11 – LIST OF SUPPORTING DOCUMENTATION FOR PRIOR PHASES
In the space below, please provide a list of additional documents attached to support completion of
prior phases.
Documents that mark the individual completion of Tasks and Phases that lead to the FERC
Operating Permit Application will also be posted to the Project website,
https://www.nuyakukhydro.com/ and to the FERC document portal using the identifier for this
Project P-14873, https://elibrary.ferc.gov/eLibrary/search
Supporting documentation for Phase I, desktop feasibility:
Pre Application Document for FERC Project P-14873 (Nuyakuk Hydro)
Scoping Document 1 and 2 for FERC P -14873
Proposed Study Plan for FERC P-14873
SECTION 12 – LIST OF ADDITIONAL DOCUMENTATION SUBMITTED FOR CONSIDERATION
In the space below, please provide a list of additional information submitted for consideration.
Grant Application Authorization Resolution
Certificate of Compliance
Application Signature Pages
Articles of Incorporation (1964)
Articles of Consolidation (2001)
Certificate of Public Convenience and Necessity (2002)
Growth Tracking
Financial Forecasting
Fuel Cost 2008_2020
Nuyakuk Power Projections
Abeyance Correspondence
o Letter of Concern BBEDC
o Letter of Concern BBAHC
o Letter of Concern UTBB
o Resolution BBNA
o Resolution WTSP Council
o ADF&G Abeyance Letter of Support
o NETC FERC P-14873 Abeyance Request
o FERC Abeyance Approval
Support
o Aleknagik Support Resolution
o BBNA Support Resolution
o NEA Support Resolution
o Curyung Support Resolution
o Dillingham Support Resolution
SECTION 13 – AUTHORIZED SIGNERS FORM
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Community/Grantee Name: Nushagak Electric & Telephone Cooperative
Regular Election is held: Annually, last election April
2020
Date: 9/28/2020
Authorized Grant Signer(s):
Printed Name Title Term Signature
Robert Himschoot CEO/GM
Signature page included
with Section 12
documents
I authorize the above person(s) to sign Grant Documents:
(Must be authorized by the highest ranking organization/community/municipal official)
Printed Name Title Term Signature
Pete Andrew President, Board of
Directors 2020-2022
Signature page included
with Section 12
documents
Grantee Contact Information:
Ma iling Address: Box 350
Dillingham, AK. 995765
Phone Number: 907-842-5251
Fax Number: 907-842-2799
Email Address: rhimschoot@nushagak.coop
Federal Tax ID #: 92-0177246
Please submit an updated form whenever there is a change to the above information.
SECTION 14 – ADDITIONAL DOCUMENTATION AND CERTIFICATION
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SUBMIT THE FOLLOWING DOCUMENTS WITH YOUR APPLICATION:
A. Contact information and resumes of Applicant’s Project Manager, Project Accountant(s),
key staff, partners, consultants, and suppliers pe r application form Section 3.1, 3.4 and
3.6.
Applicants are asked to provide resumes submitted with applications in separate electronic
documents if the individuals do not want their resumes posted to the project web site.
B. Letters or resolutions demonstrating local support per application form Section 9 .
C. For projects involving heat: Most recent invoice demonstrating the cost of heating fuel
for the building(s) impacted by the project.
D. Governing Body Resolution or other formal action taken by the applicant’s governing
body or management per RFA Section 1.4 that:
Commits the organization to provide the matching resources for project at the match
amounts indicated in the application.
Authorizes the individual who signs the application has the authority to commit the
organization to the obligations under the grant.
Provides as point of contact to represent the applicant for purposes of this
application.
Certifies the applicant is in compliance with applicable federal, state, and local, laws
including existing credit and federal tax obligations.
E. An electronic version of the entire application on CD or other electronic media, per RFA
Section 1.7.
F. CERTIFICATION
The undersigned certifies that this application for a renewable energy grant is truthful
and correct, and that the applicant is in compliance with, and will continue to comply
with, all federal and state laws including existing credit and federal tax obligations and
that they can indeed commit the entity to these obligations.
Print Name Robert Himschoot
Signature
Signature page included with Section 12 documents
Title CEO/GM
Date 9/28/2020