HomeMy WebLinkAboutFINAL Holy Cross REF 2021 ApplicationRenewable Energy Fund Round 14
Grant Application – Standard Form
AEA 23001 Page 1 of 36 11/16/2021
SECTION 1 – APPLICANT INFORMATION
Please specify the legal grantee that will own, operate, and maintain the project upon completion.
Name (Name of utility, IPP, local government, or other government entity)
Alaska Village Electric Cooperative, Inc.
Tax ID # 92-0035763 Not-for-Profit
Date of last financial statement audit: December 2020
Mailing Address: Physical Address:
4831 Eagle Street 4831 Eagle Street
Anchorage, AK 99503 Anchorage, AK 99503
Telephone: Fax: Email:
(907) 561 – 1818 (800) 478 – 1818 fbutton@avec.org
1.1 Applicant Point of Contact / Grants Coordinator
Name: Title:
Forest Button Manager, Project Development & Key Accounts
Mailing Address:
4831 Eagle Street
Anchorage, AK 99503
Telephone: Fax: Email:
(907) 646 - 5961 (800) 561 - 2388 fbutton@avec.org
1.1.1 Applicant Signatory Authority Contact Information
Name: Title:
William R. Stamm President and CEO
Mailing Address:
4831 Eagle Street
Anchorage, AK 99503
Telephone: Fax: Email:
(907) 565 - 5351 (800) 562 - 4086 bstamm@avec.org
1.1.2 Applicant Alternate Points of Contact
Name Telephone: Fax: Email:
Onya Stein (907) 561 – 1818 (800) 478 -1818 ostein@avec.org
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Grant Application – Standard Form
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1.2 Applicant Minimum Requirements
Please check as appropriate. If applicants do not meet the minimum requirements, the application
will be rejected.
1.2.1 Applicant Type
☒ An electric utility holding a certificate of public convenience and necessity under AS 42.05
CPCN #169, or
☐ An independent power producer in accordance with 3 AAC 107.695 (a) (1)
CPCN #______, or
☐ A local government, or
☐ A governmental entity (which includes tribal councils and housing authorities)
Additional minimum requirements
☒ 1.2.2 Attached to this application is formal approval and endorsement for the project by the
applicant’s board of directors, executive management, or other governing authority. If the
applicant is a collaborative grouping, a formal approval from each participant’s governing
authority is necessary. (Indicate yes by checking the box)
☒ 1.2.3 As an applicant, we have administrative and financial management systems and follow
procurement standards that comply with the standards set forth in the grant agreement
(Section 3 of the RFA). (Indicate yes by checking the box)
☒ 1.2.4 If awarded the grant, we can comply with all terms and conditions of the award as
identified in the Standard Grant Agreement template at
https://www.akenergyauthority.org/What-We-Do/Grants-Loans/Renewable-Energy-
Fund/2021-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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Grant Application – Standard Form
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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.
Holy Cross Solar Energy and Battery Storage Feasibility Study Project
2.2 Project Location
2.2.1 Location of Project – Latitude and longitude (preferred), street address, or
community name.
Latitude and longitude coordinates may be obtained from Google Maps by finding you project’s
location on the map and then right clicking with the mouse and selecting “What is here? The
coordinates will be displayed in the Google search window above the map in a format as follows:
61.195676.-149.898663. If you would like assistance obtaining this information, please contact
AEA’s Grants Coordinator by email at grants@akenergyauthority.org or by phone at (907) 771-
3081.
Latitude 62.2005 North Longitude -159.7686 West
Holy Cross is located in Interior Alaska on the west bank of Ghost Creek Slough off the Yukon
River. It is 40 miles northwest of Aniak and 420 miles southwest of Fairbanks.
2.2.2 Community benefiting – Name(s) of the community or communities that will be the
beneficiaries of the project.
The project will benefit the entire community of Holy Cross, Alaska (population of approximately
178 as of 2010 Census).
2.3 Project Type
Please check as appropriate.
2.3.1 Renewable Resource Type
☐ Wind ☐ Biomass or Biofuels (excluding heat-only)
☐ Hydro, Including Run of River ☐ Hydrokinetic
☐ Geothermal, Excluding Heat Pumps ☐ Transmission of Renewable Energy
☒ Solar Photovoltaic ☒ Storage of Renewable
☐ Other (Describe) ☐ Small Natural Gas
2.3.2 Proposed Grant Funded Phase(s) for this Request (Check all that apply)
Pre-Construction Construction
☐ Reconnaissance ☐ Final Design and Permitting
☒ Feasibility and Conceptual Design ☐ Construction
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2.4 Project Description
Provide a brief, one-paragraph description of the proposed project.
Alaska Village Electric Cooperative, Inc. (AVEC) is requesting $135,000 through an Alaska Energy
Authority (AEA) Renewable Energy Fund (REF) grant to conduct a feasibility study for local solar
energy and battery storage potential in Holy Cross, Alaska. The proposed project involves
analyzing solar data, examining potential location alternatives, and creating a conceptual design
for local solar energy and battery storage. Like many communities in Alaska, Holy Cross
experiences high and unstable energy costs. The community depends on diesel fuel to power the
three local generators responsible for all available energy in Holy Cross. Solar energy has proven
a viable energy resource through projects in the similar communities of Eagle and Kaltag.
Dependent on the results of the proposed feasibility study, AVEC would secure funding to prepare
a final design, complete permitting, and develop solar energy in Holy Cross.
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.
The AEA REF grant funds will be used to conduct a solar feasibility study in Holy Cross, and if
funded by AEA, this effort will be supplemented by AVEC contributions. In order to assess the
potential of solar energy and battery storage in Holy Cross, AVEC proposes a study of the
available solar resource. The study would include determining a location most suited for a solar
project, examining the best technology to fit the needs of the community, and identifying any
needed upgrades to existing facilities. The project would investigate available battery storage
technologies for solar energy, sizing and cost benefits for the community, including impact on
existing heat recovery. A conceptual design report (CDR) will be created based on the outcome of
these efforts.
Following successful completion of the proposed feasibility study and conceptual design, AVEC will
seek appropriate fund resources to implement solar energy in Holy Cross. AVEC intends to
prepare a final design, complete permitting, and construct solar infrastructure in Holy Cross to be
online as soon as 2025.
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
($)
N/A
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Grant Application – Standard Form
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SECTION 3 – Project Management, Development, and Operation
3.1 Schedule and Milestones
Please fill out the schedule below (or attach a similar sheet) for the work covered by this funding
request. Be sure to identify key tasks and decision points, including go/no go decisions, in your
project along with estimated start and end dates for each of the milestones and tasks. Please
clearly identify the beginning and ending of all phases (I. Reconnaissance, II. Feasibility and
Conceptual Design, III. Final Design and Permitting, and IV. Construction) of your proposed
project. See the RFA, Sections 2.3-2.6 for the recommended milestones for each phase. Add
additional rows as needed.
Task
# Milestones Tasks
Start
Date
End
Date Deliverables
1 Project scoping
and contractor
solicitation
AVEC will select contractor(s)
for the solar feasibility
investigations and conceptual
design immediately following
AEA’s authorization to proceed.
Aug 1,
2022
Aug 15,
2022
Contractor
Agreements
2 Resource
identification and
detailed resource
analysis
AVEC will complete a solar
resource report using available
solar energy data and other
sources of information as
determined by consultations with
knowledgeable experts.
Sep 31,
2022
Sep 31,
2023
Solar
Resource
Analysis
Report
3 Identification of
land and
regulatory issues
AVEC will identify site
alternatives for constructing
solar infrastructure and initiate
negotiations of permanent site
control for a proposed photo
voltaic (PV) array system and
storage battery in consultation
with local municipal and tribal
governments, if needed.
Sep 1,
2022
Aug 1,
2023
List of
potential
solar sites
4 Permitting and
environmental
analysis
AVEC will research and conduct
consultations with agencies to
determine needed
environmental permits for project
construction.
Sep 1,
2022
Aug 1,
2023
List of
needed
environment
al permits
and
consultation
5 Detailed analysis
of current cost of
energy and future
market
Based on AVEC records and
available community plans,
AVEC will conduct an analysis of
existing and future energy costs
and markets. AVEC will host a
community meeting to collect
input on potential future energy
markets, information collected
will be incorporated into the
CDR.
Feb 1,
2022
Aug 31,
2023
Existing and
Future
Energy
Costs and
Markets
Analysis
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6 Assessment of
alternatives
AVEC will review solar PV
systems, battery storage
systems, layouts, and locations
to determine a recommended
location and PV system best
suited for local conditions and
the community.
May 1,
2022
Sep 30,
2023
Addressed in
CDR
7 CDR and costs
estimate
AVEC will examine various PV
technologies and battery storage
systems to determine the best
suited system to fit the lower
energy demand in Holy Cross. A
conceptual design and cost
estimate would be prepared
using information gathered from
the solar resource analysis.
Sep 1,
2023
Nov 1,
2023
CDR and
cost estimate
8 Detailed
economic and
financial analyses
AVEC will conduct an economic
and financial analysis to
examine potential final design
and construction costs,
operating and maintenance
costs, user rates, and other
fiscal components. This analysis
will be evaluated in the CDR.
Jun 1,
2023
Sep 1,
2023
Economic
and Financial
Analysis
9 Conceptual
business and
operations plan
As a utility cooperative, AVEC
has business and operation
plans currently in place for the
cooperative as a whole.
Operating and business plans
may be updated to include solar
energy and battery storage.
Jun 1,
2023
Oct 31,
2023
Updated
Conceptual
Business
and
Operations
Plan
10 Final report and
recommendations
AVEC will combine all of the
memoranda and reports written
for the project in a final report for
submission to AEA. The Final
CDR to include the following
information:
• Solar Resource Analysis
• Site Control Agreements
• Existing and Future Energy
Costs and Markets Analysis
• Economic and Financial
Analysis
• Conceptual Business and
Operations Plan
• CDR and Cost Estimate,
including panel evaluation
• Needed environmental
permits and consultations
Sep 15,
2023
Dec 31,
2023
Final CDR
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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 $135,000
Cash match to be provideda $15,000
In-kind match to be provideda $0
Energy efficiency match providedb $0
Total costs for project phase(s) covered in application (sum of
above)
$150,000
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.
AVEC commits a 10% cash contribution of the total cost of the Holy Cross Solar Energy Feasibility
Study Project should it receive AEA funding, totaling $15,000.
a Attach documentation for proof (see Section 1.18 of the Request for Applications)
b See Section 8.2 of this application and Section 1.18 of the RFA for requirements for Energy Efficiency
Match.
3.2.2 Cost Overruns
Describe the plan to cover potential cost increases or shortfalls in funding.
AVEC does not anticipate any cost increases or shortfalls in funding, basing the project budget off
of years of experience conducting feasibility studies for comparable communities in Alaska. Should
the project experience a funding issue, AVEC will seek additional funding sources or allocate a
larger cash contribution to the effort.
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 Estimated $0
Feasibility and Conceptual Design Estimated $150,000
Final Design and Permitting Estimated $100,000
Construction Estimated $750,000
Total Project Costs (sum of above) Estimated $1,000,000
Metering/Tracking Equipment [not included in project
cost]
Estimated
(pending results of
feasibility study)
$400-1,000
3.2.4 Funding Subsequent Phases
If subsequent phases are required beyond the phases being applied for in this application,
describe the anticipated sources of funding and the likelihood of receipt of those funds.
• State and/or federal grants
• Loans, bonds, or other financing options
• Additional incentives (i.e. tax credits)
• Additional revenue streams (i.e. green tag sales or other renewable energy subsidies or
programs that might be available)
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Following successful competition of the Holy Cross Solar Energy and Battery Storage Feasibility
Study and assuming solar energy integrated with battery storage proves a viable local energy
resource, AVEC intends to proceed with final design and project construction. The proposed
feasibility study and concept design report will be used to determine a recommended PV system
and subsequent costs, and AVEC anticipates that final design of a solar energy with battery
storage system in Holy Cross to be about $100,000 and construction to be about $750,000, for a
total capital cost of approximately $1,000,000. It is possible that the funding for this work could
come from upcoming federal infrastructure funding, a subsequent application to AEA REF grant,
USDA Rural Utility Service program, or another state or federal grant program. AVEC intends to
provide a 10% cash match for the final design and construction phases of a Holy Cross solar
energy system with battery storage.
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3.2.3 Budget Forms
Applications MUST include a separate worksheet for each project phase that was identified in
Section 2.3.2 of this application — I. Reconnaissance, II. Feasibility and Conceptual Design, III.
Final Design and Permitting, and IV. Construction. Please use the tables provided below to detail
your proposed project’s total budget. Be sure to use one table for each phase of your project, and
delete any unnecessary tables. The milestones and tasks should match those listed in 3.1 above.
If you have any question regarding how to prepare these tables or if you need assistance preparing
the application please feel free to contact AEA’s Grants Coordinator by email at
grants@akenergyauthority.org or by phone at (907) 771-3081.
Phase 2 — Feasibility and Conceptual Design
Milestone or Task
Anticipated
Completion
Date
RE- Fund
Grant
Funds
Grantee
Matching
Funds
Source of
Matching
Funds:
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
TOTALS
(List milestones based on
phase and type of project. See
Sections 2.3 thru 2.6 of the
RFA )
$ $ $
1. Project scoping and
contractor solicitation Aug 15, 2022 $1,350 $150 Cash $1,500
2. Resource identification and
detailed resource analysis Sep 31, 2023 $9,000 $1,000 Cash $10,000
3. Identification of land and
regulatory issues Aug 1, 2023 $5,400 $600 Cash $6,000
4. Permitting and
environmental analysis Aug 1, 2023 $9,000 $1,000 Cash $10,000
5. Detailed analysis of current
cost of energy and future
market
Aug 31, 2023 $5,400 $600 Cash $6,000
6. Assessment of alternatives Sep 30, 2023 $6,750 $750 Cash $7,500
7. CDR and costs estimate Nov 1, 2023 $81,000 $9,000 Cash $90,000
8. Detailed economic and
financial analyses Sep 1, 2023 $9,000 $1,000 Cash $10,000
9. Conceptual business and
operations plan Oct 31, 2023 $2,700 $300 Cash $3,000
10. Final report and
recommendations Dec 31, 2023 $5,400 $600 Cash $6,000
TOTALS $135,000 $15,000 $150,000
Budget Categories:
Direct Labor & Benefits $15,300 $1,700 Cash $17,000
Travel & Per Diem $15,300 $1,700 Cash $17,000
Equipment $15,300 $1,700 -- $17,000
Materials & Supplies $0 $0 --
Contractual Services $89,100 $9,900 Cash $99,000
Construction Services $0 $0 --
Other $0 $0 Cash
TOTALS $135,000 $15,000 $150,000
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3.2.4 Cost Justification
Indicate the source(s) of the cost estimates used for the project budget, including costs for future
phases not included in this application.
AVEC based the proposed project budget for this grant application on past experience successfully
completing solar resource feasibility study in Kaltag and projects completed by others in similar
locations in the state and based on the NREL solar potential for Holy Cross.
The purpose of this effort is to determine solar energy viability and the power system best suited to
harvest solar energy with battery storage. Once the location and PV array system are determined,
the next phase of this project would be final design and construction. Although it is difficult to
determine without an assessment of the resource and infrastructure what would be needed, AVEC
expects that final design and construction would cost approximately $1,000,000. It is possible that
the funding for this work could come from upcoming infrastructure funding through an application to
AEA’s Renewable Energy Fund program, USDA Rural Utility Service program, or another state or
federal grant program.
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?
AVEC has systems in place to accomplish reporting requirements successfully. AVEC has
received funding and successfully administered grants from AEA, Denali Commission, US
Department of Agriculture, and US Department of Energy, completing more than 100 major
projects in its service area over the last 20 years.
The project will be managed out of AVEC’s Projects Development Department. For financial
reporting, the Projects Development Department’s accountant, supported by the Administrative
Services Department, will prepare financial reports. The accountant will be responsible for ensuring
that vendor invoices and internal labor charges are documented in accordance with AEA
guidelines and are included with financial reports. AVEC has sophisticated systems in place for
accounting, payables, financial reporting, and capitalization of assets in accordance with the State
of Alaska’s guidelines.
AVEC will require that monthly written progress reports be provided with each invoice submitted
from primary contractor(s). The progress reports will include a summary of tasks completed, issues
or problems experienced, upcoming tasks, and contractor’s needs from AVEC. Project progress
reports will be collected, combined, and supplemented as necessary and forwarded as one
package to the AEA project manager each quarter.
Because AVEC is responsible to its member communities and a board of directors, staying on
schedule and within budget is essential. This project will result in an analysis and
recommendations for clean, renewable energy from a solar array with battery storage. Holy Cross
residents are very interested in this project because their energy costs can be a large portion of
their budgets. AVEC member communities expect status updates on village projects, including
when and what work will occur, who will be involved, and when it will be completed. Community
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members are also able to contact AVEC’s CEO and Board of Directors directly if they have an
inquiry or concern about a project.
An independent auditor’s report on compliance for each major federal program and report on
internal control over compliance required by Title 2 CFR 200 (Uniform Guidance) for AVEC in 2020
did not identify any deficiencies in internal control the auditor considered to be a material
weakness. In addition, the independent auditor’s report on compliance with aspects of contractual
agreements and regulatory requirements for AVEC in 2020 stated that nothing indicated AVEC
failed to comply with the terms, covenants, provisions, or conditions of loans, grants, and security
instruments as specified in 7 CFR part 1773. A copy of AVEC’s audit is available upon request.
Quarterly meetings will occur between AVEC and AEA to discuss the status of all projects funded
through the AEA Renewable Energy Grants program. Individual project meetings will be held, as
required or requested by AEA.
Forest Button will be responsible for tracking progress of project communications, and Onya Stein,
may be contacted as an alternative manager.
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.
AVEC’s accounting system consists of software, procedures, and controls driven by the daily
inputs and other actions of competent employees throughout the organization. The software is
comprised of a comprehensive suite of Daffron-brand modules including accounting
(payables/payroll/general ledger), work orders, purchase orders, customer service and billing, and
warehouse/inventory. Some ancillary functions are accomplished on spreadsheets with data
downloaded from the various Daffron modules.
Procedures and controls include but are not limited to adequate separation of duties, manager-
level approval of all expenditures, CEO-level approval of all major expenditures, a formal
purchasing system (including purchase orders) for acquisition of materials and components, and a
formal contracting system for acquisition of contractual services (consultants, construction
contractors, etc.). Accounts payable are processed and recorded by the AVEC Accounting
Department, all expenditures are coded to budget categories and assigned to appropriate work
orders. The Projects Development and Key Accounts Department, particularly its Project Manager,
and Senior Accountant are primarily responsible for all grant reporting.
AVEC’s team, with years of experience and knowledge of managing AEA-funded project costs and
grant reimbursements, has a system in place for ensuring that only costs that are reasonable,
ordinary, and necessary are charged to a project, and that only costs that are eligible are submitted
for reimbursement. First, AVEC’s Project Manager (PM) is responsible for determining whether
costs are appropriate and acceptable. The PM reviews all invoices from contractors and vendors
and all in-house labor and equipment charges. Second, the Projects Development and Key
Accounts Department Manager (DM) reviews costs associated with outsourced services, including
consultant and contractor invoices, to ensure that the charges are reasonable. The DM also
reviews his department’s staff labor charges (timesheets) to the project. Third, the Operations and
Engineering Department Managers review all in-house labor (timesheets) and expense reports for
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their respective departments to make sure that the charges are acceptable. Finally, the Projects
Development and Key Accounts Department Senior Accountant, while preparing AEA financial
reports and reimbursement requests, provides a review of both outsourced and in-house charges
to determine whether they are allowable costs.
AVEC has systems in place to keep unacceptable overhead costs from being charged to and
reimbursed through the REF Grant Fund Program. Upon project initiation, an AVEC work order
number is created to track all project labor and expenses. AVEC staff and contractors reference
this number on all timesheets and invoices when working on the project, ensuring that project costs
are known. Purchase orders are universally used to establish spending limits for purchases of
materials, which are then monitored by the Accounting Department through the enterprise
accounting system. Task orders and contracts are universally used to establish spending limits for
purchases of contractual services, which are then monitored by the Projects Development and Key
Accounts Department utilizing spreadsheets. Direct labor expenses (gross payroll) are tracked
separately from overhead costs including employee benefits and payroll taxes. Once labor hours
have been calculated, overhead including employee benefits and payroll taxes are applied in a
separate transaction on the work order.
AVEC and AEA have an agreed rate cap for employer costs of payroll, consisting only of employee
benefits and payroll taxes. AVEC can ensure that only allowable costs would be requested for
reimbursement because the direct labor and indirect/overhead costs are separate transactions
(and thus the indirect/overhead amounts can be easily omitted from reimbursement), and because
the allowable rate has been established and agreed upon (and thus can be easily included for
reimbursement).
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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.
Forest Button is the Project Manager and has served as manager of the Projects Development
Department for AVEC since 2016 where he leads a team focused on stabilizing the cost of energy
in rural Alaskan villages through improved power plant efficiency, renewable power generation,
wind to heat, recovered heat, and interties between villages.
Previously, Mr. Button worked as a project manager under contract to AVEC. He was responsible
for the management of the design and construction of capital projects and has 25 years of
experience managing construction projects throughout Alaska. Mr. Button has a degree in Mining
Engineering from the University of Alaska, Fairbanks.
4.1.2 Project Accountant
Indicate who will be performing the accounting of this project for the grantee. If the applicant does
not have a project accountant indicate how you intend to solicit financial accounting support.
Rebecca Lopez is the Chief Financial Officer at AVEC, which includes the Accounting Department,
Purchasing, IT, and Human Resources. Ms. Lopez has more than 8 years of experience in the
Alaska electric utility industry. She joined AVEC in 2021. She is responsible for all administrative
and financial records including preparing grant reports, Regulatory Commission of Alaska rate
filings, financial forecasts, budgets and PCE, as well as overseeing the day-to-day office
operations.
4.1.3 Expertise and Resources
Describe the project team including the applicant, partners, and contractors.
For each member of the project team, indicate:
• the milestones/tasks in 3.1 they will be responsible for;
• the knowledge, skills, and experience that will be used to successfully deliver the tasks;
• how time and other resource conflicts will be managed to successfully complete the task.
If contractors have not been selected to complete the work, provide reviewers with sufficient detail
to understand the applicant’s capacity to successfully select contractors and manage complex
contracts.
AVEC would use a project management approach that has been used to successfully design and
construct renewable energy projects throughout rural Alaska: a team of AVEC staff and external
consultants.
AVEC staff and their role on this project includes:
• William R. Stamm, President and Chief Executive Officer, would act as Project
Executive and will maintain ultimate program and financial authority.
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• Forest Button, Manager, Community Development and Key Accounts, would lead the
project management team consisting of AVEC staff, consultants, and contractors. Together
with the Assistant Project Manager, Forest would provide coordination of solar data
analysis, conceptual design, and permitting. The group’s resources include a project
coordinator, accountant, project/construction manager (PM/CM), and a community liaison.
Mr. Button will be responsible for managing all the project milestones listed in Section 3.1.
He will also be responsible for reporting directly to AEA on the status of the project.
• Onya Stein, Assistant Project Manager, will assist on all milestones of the project. In
particular, she will be responsible for managing the consultant team. Onya would ensure
that all milestones and tasks are completed. Specifically, she would be responsible for
selecting, coordinating, and managing the solar resource specialist, engineers, and
permitting consultants and ensuring that their deliverables are on time and within budget.
• Daniel Allis, Manager of Operations, would provide oversight and input in planning for
construction, distribution, and solar energy generation components of the project.
Specifically, he would provide input on analysis of current cost (milestone 5); the
assessment of alternatives (milestone 6); the CDR (milestone 7); and the final report
(milestone 10).
• Darren Westby, Manager of Engineering, would provide technical assistance and
information on the existing power system and possible issues and project study needs.
Specifically, Darren would provide input on the detailed resource analysis (milestone 2);
analysis of current cost (milestone 5); the assessment of alternatives (milestone 6); the
CDR (milestone 7); and the final report (milestone 10).
• Rebecca Lopez, Chief Financial Officer, would assist with questions arising out of the
economic and financial analysis (milestone 8) and the business and operations plan
(milestone 9). In addition, related to grant management, she would provide support in
accounting, payables, financial reporting, and capitalization of assets in accordance with
AEA guidelines.
• Anna Sattler, Community Liaison, would communicate directly with Holy Cross residents
to ensure that the community is informed. Specifically, Anna would assist by working with
the community on identification of land issues (milestone 3); assessment of alternatives
(milestone 6); and relaying information and recommendations from the CDR (milestone 7
and 10)
Contractors for this project would include:
• Solar Resource Consultant. AVEC would seek a consultant best suited for assisting with
this effort based on experience in Alaska. This consultant would:
- Draft the solar resource report (milestone 2)
• Engineering consultant: AVEC would select and employ an engineering consultant who
would:
- Provide an analysis of current cost of energy and future market (milestone 5)
- Draft an assessment of alternatives (milestone 6)
- Prepare the CDR and cost estimates (milestone 7)
- Document economic and financial aspects (milestone 8)
- Draft a business and operations plan (milestone 9)
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• Environmental Consultant: AVEC currently has an on-call contract with Solstice Alaska
Consulting, Inc. for environmental permitting. It is likely that Solstice would work on this
project. Robin Reich’s (Solstice’s president) resume is attached (see Tab A). Solstice
would:
- Consult with agencies
- Document permit needs for future solar project (milestone 3)
Selection Process for Contractors: The engineering consultant selection would be based upon
technical competencies, past performance, written proposal quality, cost, and general consensus
from an internal AVEC technical steering committee. The selection of the consultant would occur in
strict conformity with AVEC’s procurement policies, and conformance with OMB circulars.
Resumes for key staff, partners, and consultants can be found attached in Tab A.
4.2 Local Workforce
Describe how the project will use local labor or train a local labor workforce.
AVEC uses local labor whenever possible in both daily operations and special projects;
recognizing that local labor is good for its customers’ families. Local wages circulate, often multiple
times, within the community thereby benefitting the community as a whole. AVEC project
managers also know there are tasks that are more competently done by local folks; for example,
equipment operators, bear guards, bird monitors, and four-wheeler drivers.
For this feasibility effort, it is expected that local labor could assist with some aspects of the project
including helping to determine a suitable solar location and, if needed, resource analysis.
Local labor saves money within special project budgets as demonstrated in comparing budgets
with local labor wages against imported labor wages, travel, and per diem. This is true for not only
AVEC’s own projects but also for its contractors. Therefore, assuming the proposed solar feasibility
study shows solar to be a viable resource in Holy Cross, AVEC could include local hire language in
the construction bid documents and contract.
AVEC has included the following language in bid documents in the past:
“Local Labor and Local Firms Participation Goal: The participation goal for this project has
been established as a percentage of the total dollar amount awarded to the successful bidder in
the amount of 20% to local labor and local firms. The successful bidder shall provide the Owner
documentation to demonstrate compliance with this goal. If this goal cannot be reached and good
faith efforts were demonstrated through documentation to the Owner, the Owner has the right to
issue a variance to this section.”
“Use of Local Labor and Local Firms: To the maximum extent practicable, Contractor shall
accomplish the Project using local labor and Alaska firms.”
In most AVEC communities, the power plant operators are employees of their city government.
Through a contract process, AVEC reimburses the city for the wages and fringe benefits of the
power plant operators. During project feasibility, design, and construction phases, plant operators
provide necessary assistance; typically, with tasks like bird monitoring, taking photographs,
changing sim cards, hosting and assisting engineers and others coming into the community for
project work.
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AVEC is very proud of its training program wherein power plant operators are trained by an
itinerant training supervisor who travels continuously to AVEC communities and works one-on-one
with the operators as needed and throughout the year.
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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” section of the appropriate Best Practice Checklist for additional
guidance.
AVEC completed a preliminary review of the solar potential in Holy Cross. According to the
National Renewable Energy Laboratory (NREL) PVWatts Calculator tool, a 200 kilowatt (kW) solar
array system in Holy Cross has the potential to produce 166,034 kilowatt hours (kWh) annually
(CF=9.5%). The proposed feasibility study will identify a PV system location and method of
operation to maximize the renewable capacity factor while maintaining power quality for the
community.
Additionally, based on existing knowledge and solar feasibility studies conducted for comparable
communities in similar Alaskan locations, it is assumed Holy Cross has conditions appropriate for a
viable solar PV system. Given the preliminary nature of the proposed feasibility study, a more
definitive determination of solar as resource in Holy Cross would be achieved by this effort.
The University of Alaska Fairbanks operates a pilot solar PV test site through the Alaska Center on
Energy and Power. Given their experience with measuring solar in interior Alaska, AVEC will
consult with ACEP on solar energy systems while conducting the proposed planning and analysis.
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.
Solar energy has proven a viable energy resource in multiple communities with similar
environmental and climate conditions, including Fairbanks, Kotzebue, Kaltag, and Eagle. Diesel
fuel is the primary source of energy, which is expensive. Other alternative energy resources (wind,
hydroelectric and geothermal) are not anticipated to be as cost effective or viable as solar energy
with battery storage in Holy Cross. The wind resource is low; there are no geothermal opportunities
nearby, and hydroelectric power opportunities don’t exist because of the landscape and unsuitable
waterbodies.
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
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No permits are expected to be required for the proposed feasibility/ design phase on this project,
but AVEC will work with consultants to determine what permits may be needed for construction.
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.
AVEC expects to place the solar infrastructure adjacent to the AVEC power plant. The proximity to
the facility and the existing fence will help protect the potential solar array and allow for easier
energy incorporation into the existing system and operations and maintenance. If the proposed
feasibility study proves that solar energy is a viable resource in Holy Cross in a different location,
AVEC will consult with local municipal, corporation, and tribal entities in Holy Cross to select a site
and to obtain site control of a PV array location. A letter of non-objection will be sought from the
corporation or city, depending on location. Starting with a community meeting, AVEC’s community
liaison will lead the effort to gain site control. Since the major landholders support the project (see
attached letters of support in Tab B), and since AVEC expects to use its existing site, site control is
not expected to be an obstacle.
5.3 Project Technical & Environmental Risk
5.3.1 Technical Risk
Describe potential technical risks and how you would address them.
• Which tasks are expected to be most challenging?
• How will the project team reduce the risk of these tasks?
• What internal controls will be put in place to limit and deal with technical risks?
See the “Common Planning Risks” section of the appropriate Best Practice Checklist for additional
guidance.
The feasibility effort will help to identify and overcome the few technical risks that might be
expected with the implementation of a solar and battery storage project in Holy Cross. Some initial
challenges that AVEC will overcome could be:
System Upgrades: Holy Cross currently has a single-phase distribution system and switchgear.
Single-phase to three-phase conversion at the power plant with automated generation switchgear
along with other improvements may be needed prior to installation of any renewables. During the
feasibility study, AVEC will identify needed improvements and their costs. AVEC will then address
those needs before installation of a PV array with battery storage.
Site Control/Access: Sometimes site control for the placement of solar sites is difficult; however,
because AVEC expects to use their existing power plant location, gaining site control may not be
needed.
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
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• Archaeological and historical resources
• Land development constraints
• Telecommunications interference
• Aviation considerations
• Visual, aesthetics impacts
• Identify and describe other potential barriers
During the final design and permitting phases, once the solar project is better scoped, AVEC would
work with agencies to address the following potential environmental issues:
Threatened or endangered species: The U.S. Fish and Wildlife Service would be consulted to
ensure that installation of the solar project would have no effect on threatened or endangered
species. If clearing is required for the installation of the panels, it would be timed to avoid impacts
to migratory birds in compliance with the Migratory Bird Treaty Act.
Habitat issues: Because the array would be installed next to the power plant, habitat issues are
not expected.
Wetlands and other protected areas: Although not expected, if the solar project is placed in
designated wetlands, a U.S. Army Corps of Engineers’ wetlands permit would be needed.
Archaeological and historical resources: Compliance with the National Historic Preservation Act
and consultation with the State Historic Preservation Officer would be conducted prior to
installation of the solar panels.
Land Development Constraints: Land development constraints are not expected, since the array
would most likely be installed on AVEC land. AVEC will work with the landowners to obtain site
control if another location proves more suitable.
Telecommunications Interference: The solar project would be located so as not to interfere with
current telecommunication services.
Aviation Considerations: The solar project location would be selected based on airspace
availability and limitations to meet the FAA’s Notice Criteria, and a no-hazard determination would
be sought from the FAA as soon as a project location has been finalized.
Visual Impacts: AVEC will conduct community meetings to discuss visual impacts and how they
could be mitigated.
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
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current voltage, frequency, and outage issues across system. See the “Understanding the Existing
System” section of the appropriate Best Practice Checklist for additional guidance.
The existing power generation system in Holy Cross consists of 3 diesel generators in a single
phase 120/240V electrical system: two Detroit Diesel Series 60 and one Cummins LTA10.
The plant operator selects which engine to run and manually controls which engine(s) are on line.
The most efficient available engine is used to meet the load. Individual generator efficiency is not
tracked, but the aggregate diesel generator efficiency in 2020 was 13.01 kilo-watt hours per gallon
(kWh/gallon).
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 generator, Detroit Diesel Series 60 D3 1200 RPM, 207 kW, 50kW min, Electronic
Fuel Injection, KT Generator model 6P4-1363, Simplex control panel, Basler APR63-5 voltage
regulator and APM301 paralleling module, GAC genset controls w/ EAM104 speed control, 9,117
hours, installed 2019.
Unit 2: Diesel generator, Detroit Diesel Series 60 K4 1200 RPM, 236 kW, 50kW min, Electronic
Fuel Injection, KT Generator model 6P4-1050, Controlled Power control panel, Basler APR63-5
voltage regulator and APM301 paralleling module, GAC genset controls w/ EAM104 speed
control, 22,774 hours, installed 2017.
Unit 3: Diesel generator, Cummins LTA10, 1800RPM, 250kW, 50kW min, Mechanical Fuel
Injection, KT Generator model 4P3-1475, Controlled Power control panel, Basler APR 63-5
voltage regulator and APM301 paralleling module, GAC genset controls w/ 5210 speed control,
2,089 hours, installed 2019.
5.4.2.2 Existing Distribution System
Describe the basic elements of the distribution system. Include the capacity of the step-up
transformer at the powerhouse, the distribution voltage(s) across the community, any transmission
voltages, and other elements that will be affected by the proposed project.
The Holy Cross power plant generates single phase 120/240V, there are three 50kVA transformers
(one on each switch) and one direct feed from the bottom switch. Part of the feasibility study will
focus on the ability to integrate renewables on smaller single-phase systems or whether a voltage
conversion is recommended.
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, to the water treatment plant.
Estimated at 2,699 gal displaced.
5.4.2.3 O&M and replacement costs for
existing units
Power Generation Thermal Generation
i. Annual O&M cost for labor $28,000
ii. Annual O&M cost for non-labor
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5.4.2.4 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 Generatio
n (Diesel)
(kWh)
Generation
(Type 2)
(kWh)
Fuel
Consumption
(Diesel-
Gallons)
Fuel
Consumption
[Other]
Peak
Load
Minimum
Load
(Assumed
3/4 of
average
load)
January 61,744 N/A 4,966 N/A 100.0 62.2
February 51,730 3,776 82.0 55.7
March 53,612 3,972 80.0 54.0
April 45,058 3,437 74.0 46.9
May 40,098 3,123 66.0 40.4
June 45,505 3,549 72.0 47.4
July 44,838 3,442 82.0 45.2
August 45,447 3,764 81.0 45.8
September 41,574 3,261 77.0 43.3
October 47,004 3,589 81.0 47.4
November 55,036 4,132 85.0 57.3
December 58,568 4,367 85.0 59.0
Total 590,214 45,378 Average 80.4 50.4
5.4.3 Future Trends
Describe the anticipated energy demand in the community, or whatever will be affected by the
project, over the life of the project. Explain how the forecast was developed and provide year by
year forecasts. As appropriate, include expected changes to energy demand, peak load, seasonal
variations, etc. that will affect the project.
According to U.S. Census data, Holy Cross’s population has fluctuated from 178 to 227 community
members over the past 20 years. The 2019 estimated population of Holy Cross was 220 people.
Diesel energy costs in Holy Cross are high. Power costs for residences and community facilities are
subsidized through Alaska’s Power Cost Equalization (PCE) program. For 2020, the average
household monthly cost of power before the PCE was $179, with the PCE subsidy the average
household monthly cost was $128.
Currently, major projects and increases in population are not planned or expected in Holy Cross.
However, as more parts of rural Alaska become connected with better internet service, energy
demand and peak load could moderately increase in the foreseeable future due to more electronics
use. In addition, the community is always looking to bring new businesses and opportunities. Since
energy demand is expected to rise in the future, solar energy development could be used to reduce
the cost of energy and offset energy production from diesel fuel.
Stabilizing the cost of energy provides various economics benefits to community, including reducing
household energy costs, allowing commercial entities to pass along savings to residents, and
increasing available funds to invest in improved community and social service. These economic
iii. Replacement schedule and cost for
existing units
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benefits will reduce outmigration of individuals in response to excessive utility costs energy costs
and ensure a consistent local energy market.
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.
Renewable energy technology: AVEC plans to conduct a feasibility analysis, resource
assessment, and conceptual design to assess the possibility of using solar power with battery
storage in Holy Cross. Solar generation and energy storage components are becoming available
from a wider number of reliable sources. In every deployment the integration of intermittent
generation to the energy grid is a key component to a successful project. The existing Holy Cross
generation and distribution system is small, single phase and manually operated. This feasibility
study is intended to determine if a solar PV project could be properly integrated in to the existing
power system and what modifications would be required to have a meaningful impact on diesel
consumption.
Proposed capacity/capacity determination: The purpose of this work is to gather background
information to plan a future alternative energy facility. Anticipated capacity and generation would
be examined for various PV array and battery storage systems, secondary load options, and
control schemes. It is expected that a 200 kW solar array could be implemented and integrated
with energy storage sized with a 200 kWhbattery.
Based on the NREL PVWatts Calculator tool, a 200 kW solar array system in Holy Cross has the
potential to produce 166,034 kilowatt hours (kWh) annually (CF=9.5%). The proposed feasibility
study will identify whether a PV system near the existing power plant would be a viable location
The study will also determine battery and inverter sizes and the method of operation to maximize
the renewable capacity factor while maintaining power quality for the community. Finally, the study
would determine distribution and power plant upgrades that would be needed prior to the
installation of a solar array and battery storage.
Integration plan: Solar infrastructure would need to interconnect with the existing diesel power
plant. Depending on the complexity of the proposed system, the diesel generators would continue
running at minimum levels, or be allowed to go diesel-off (estimated to be 1,500 hours annually).
Conceptual design, to be completed as a part of this project, would detail how power from a solar
array system would be integrated into the existing system in Holy Cross.
Civil infrastructure: Assuming solar energy proves a viable resource in Holy Cross, civil
infrastructure access to and foundations for solar panels will be included in subsequent final design
and construction phases of the project.
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Backup/supplemental system: The existing power plant with diesel fuel generators and the
existing power distribution system will be maintained to provide for the full power needs of the
community.
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 Solar 200 TBD TBD 9.5%
(NREL
model)
25 166,034
kWh/year
(NREL
model)
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
N/A
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.
A solar energy system in Holy Cross will be designed to supplement the existing diesel generators.
When the solar resource is high (summer), the power plant would be designed to be able to run
with diesels off when integrated with a battery storage system. The existing diesel system will
remain in operation at a lower capacity to supplement solar energy online in the winter and when
the solar resource is low. It is anticipated that to make solar generation the primary energy source
during periods of prolonged sun exposure would require an energy storage system and planned
upgrades to the existing diesel generation and distribution systems. Batteries and inverters will be
analyzed to determine the best size and operations.
The proposed feasibility study will determine the optimal solar PV array and battery storage system
design and operation regimen.
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The intent of the proposed system is to lower the power generated by diesel generation and will
effectively lower the heat output of the diesel generators. The heat recovery system in Holy Cross
currently displaces nearly all the heating needs of the water treatment plant and City Hall. Heat
demands are highest in the winter and solar output is highest in the summer; therefore, the impacts
to the existing recovered heat system may be minimal. The feasibility study will compare system
loads, heat demand, and projected solar generation considering the overall impact on recovered
heat.
The anticipated effect of the proposed system is lower diesel fuel use for electrical power generation.
Also, power generator use in Holy Cross would be decreased, thereby decreasing generator
operations and maintenance costs, enabling generators to last longer and need fewer overhauls.
5.4.3.1 Expected Capacity Factor 9.5% (from NREL calculator)
5.4.5.2 Annual Electricity Production and Fuel Consumption (Proposed System)
Month Generation
(Proposed
System:
Solar PV,
from NREL)
(kWh)
Generation
(Type 2:
Diesel)
(kWh)
Generation
(Type 3)
(kWh)
Fuel
Consumption
(Diesel-
Gallons)
Assume
13kW/gal
Fuel
Consumption
[Other]
Secondary
load
(kWh)
Stora
ge
(kWh)
January 4,740 57,004 NA 4,385 NA NA TBD
February 5,046 46,684 3,591
March 14,968 38,644 2,973
April 16,427 28,631 2,202
May 26,473 13,625 1,048
June 28,181 17,324 1,333
July 21,493 23,345 1,796
August 18,700 26,747 2,057
September 12,507 29,067 2,236
October 8,499 38,505 2,962
November 3,848 51,188 3,938
December 5,153 53,415 4,109
Total 166,035 424,179 32,629
5.4.5.3 Annual Heating Fuel Consumption (Proposed System)
Month Diesel
(Gallons)
Electricity Propane
(Gallons)
Coal
(Tons)
Wood
(Cords,
green tons,
dry tons)
Other
January N/A
February
March
April
May
June
July
August
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September
October
November
December
Total
5.4.6 Proposed System Operating and Maintenance (O&M) Costs
O&M costs can be estimated in two ways for the standard application. Most proposed renewable
energy projects will fall under Option 1 because the new resource will not allow for diesel
generation to be turned off. Some projects may allow for diesel generation to be turned off for
periods of time; these projects should choose Option 2 for estimating O&M.
Option 1: Diesel generation ON
For projects that do not result in shutting down
diesel generation there is assumed to be no
impact on the base case O&M. Please indicate
the estimated annual O&M cost associated with
the proposed renewable project.
For the purpose of this analysis, $30/kW is
assumed.
NREL estimates a solar array’s O&M cost is
estimated a $0.02/W which equates to
$20/kW. The Northwest Arctic Borough uses
$30/kW based on their experience with solar
projects.
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. $10,514 (First year)
2. Hours diesel OFF/year: 1,500
3. $6,000
5.4.7 Fuel Costs
Estimate annual cost for all applicable fuel(s) needed to run the proposed system (Year 1 of
operation - 2025)
Diesel
(Gallons)
Electricity Propane
(Gallons)
Coal
(Tons)
Wood
Other
Unit cost
($) $4.33 NA NA NA NA NA
Annual
Units
32,629 gals
(see Table
5.4.5.2)
Total
Annual
cost ($)
$141,284
5.5 Performance and O&M Reporting
For construction projects only
5.5.1 Metering Equipment
Please provide a short narrative, and cost estimate, identifying the metering equipment that will be
used to comply with the operations reporting requirement identified in Section 3.15 of the Request
for Applications.
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Because this project involves feasibility and conceptual design work only, no meter would be
installed. AVEC installs meters on all renewable projects and will install a meter panel for this solar
energy project. Metering equipment specifications and costs would be determined during the
proposed conceptual design work and subsequent final design project phases.
5.5.2 O&M reporting
Please provide a short narrative about the methods that will be used to gather and store reliable
operations and maintenance data, including costs, to comply with the operations reporting
requirement identified in Section 3.15 of the Request for Applications
No O&M costs are anticipated during the feasibility phase of this project. If solar energy proves
feasible, their maintenance would be funded by AVEC’s general operating costs.
SECTION 6 – ECONOMIC FEASIBILITY AND BENEFITS
6.1 Economic Feasibility
6.1.1 Economic Benefit
Annual Lifetime
Anticipated Diesel Fuel Displaced for Power
Generation (gallons)
12,772 (Assuming
166,035 kWh
produced from
renewables, and 13
kWh per gallon
efficiency according to
AVEC.)
319,300
Anticipated Fuel Displaced for Heat
(gallons) 0 0
Total Fuel displaced (gallons) 12,772 319,300
Anticipated Diesel Fuel Displaced for Power
Generation ($)
$55,302 (Assuming
fuel cost of $4.33 in
2025)
$1,484,745 (Using average
fuel cost from 2025-2049 is
$4.65)
Anticipated Fuel Displaced for Heat ($) 0 0
Anticipated Power Generation O&M Cost
Savings 0 0
Anticipated Thermal Generation O&M Cost
Savings n/a n/a
Total Other costs savings (taxes, insurance,
etc.) 0 0
Total Fuel, O&M, and Other Cost Savings $55,302 $1,484,745
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.
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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 https://www.akenergyauthority.org/What-We-
Do/Grants-Loans/Renewable-Energy-Fund/2021-REF-Application. This economic model may be
used by applicants but is not required. The final benefit/cost ratio used will be derived from the
AEA model to ensure a level playing field for all applicants. If used, please submit the model with
the application.
The primary financial benefit from this project would be to determine whether solar is a suitable
resource to provide power to Holy Cross and, if appropriate, to prepare a conceptual design of a
solar facility with battery storage.
Assuming the installation of a 200-kW capacity system, it could produce 166,034 kWh annually.
The possible displacement of diesel fuel used for power generation in Holy Cross could be
approximately 12,772 gallons per year. Using AEA’s community fuel oil price projections, this
project could save $55,302 during the first year of operation. Over the 25-year life of the project,
the estimated savings would be $1,484,745.
Holy Cross qualifies for Alaska’s power cost equalization program, providing economic assistance
to communities with high energy costs and subsidized energy rates up to 500 kWh. The average
annual price for residential electricity in Holy Cross without PCE is $0.52 per kilowatt hour (kWh) as
of December 2021. The price per kWh in Holy Cross can be compared to the “extremely high” cost
benchmark established by U.S. Rural Utilities Service (RUS) of $0.3627/kWh or can be compared
to Anchorage’s average cost of $0.1348/kWh. The residents of Holy Cross would benefit from this
project as it would help mitigate the volatile energy costs found in rural Alaska.
Immediate savings from this project will directly benefit AVEC and reduce Holy Cross’s
dependence on the PCE program. Un-subsidized energy costs are expected to decrease for
residents and commercial entities in Holy Cross, providing immediate savings. Reduced energy
costs for non-PCE community institutions may allow for increased or improved community or social
services. Similarly, reduced energy costs for other non-PCE commercial energy customers such as
stores might result in savings to residents.
The Holy Cross Community Development plan identified the high cost of energy as a barrier to
economic development for the community. This project would help meet the goals of the
community plan. Stabilizing the rising costs of energy production by incorporating solar would ease
the burden felt by the residents and allow for progress in community goals.
Sources: Holy Cross 2018-2021 Community Plan, Alaska Community Database
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
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• Reductions in expected energy demand: Is there a risk of an insufficient market for energy
produced over the life of the project.
• Deferred and/or inadequate facility maintenance
• Other factors
Economic risks from this project are primarily from the high startup costs, and economic viability is
dependent on successful implementation and operation of solar energy infrastructure over a 25-year
lifetime. Pilot projects and larger scale solar energy installations in interior Alaska, including in Kaltag,
Kotzebue, Eagle, Fairbanks, and Willow, have proven solar projects in similar locations to be
economically viable.
Although Holy Cross has a small population, it is stable and isn’t expected to drop substantially in
the near future. Electricity demand will remain and could increase if energy costs drop or if new
opportunities arise.
AEA projections suggest the cost of fuel in Holy Cross will increase for the foreseeable future,
suggesting costs for continued dependence on diesel powered electricity in Holy Cross could
become prohibitive. With implementation of solar energy, energy costs will likely decrease and help
to ensure a stable population in Holy Cross and a reliable energy market.
Success of this project is dependent on maintenance of the existing energy infrastructure and the
distribution system and the new solar array. AVEC has a complete and thorough process for tracking
and maintaining energy infrastructure in all 58 communities the cooperative serves.
6.1.4 Public Benefit for Projects with Direct Private Sector Sales
For projects that include direct sales of power to private sector businesses (sawmills, cruise ships,
mines, etc.), please provide a brief description of the direct and indirect public benefits derived from
the project as well as the private sector benefits and complete the table below. See Section 1.6 in
the Request for Applications for more information.
Not applicable to this project.
Renewable energy resource availability (kWh per month) NA
Estimated direct sales to private sector businesses (kWh) NA
Revenue for displacing diesel generation for use at private sector businesses ($) NA
Estimated sales for use by the Alaskan public (kWh) NA
Revenue for displacing diesel generation for use by the Alaskan public ($) NA
6.2 Other Public Benefit
Describe the non-economic public benefits to Alaskans over the lifetime of the project. For the
purpose of evaluating this criterion, public benefits are those benefits that would be considered
unique to a given project and not generic to any renewable resource. For example, decreased
greenhouse gas emission, stable pricing of fuel source, won’t be considered under this category.
Some examples of other public benefits include:
• The project will result in developing infrastructure (roads, trails, pipes, power lines, etc.) that can
be used for other purposes
• The project will result in a direct long-term increase in jobs (operating, supplying fuel, etc.)
• The project will solve other problems for the community (waste disposal, food security, etc.)
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• 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
Implementing solar energy supports the Holy Cross Community Plan goal to “support the local
environment.” Implementing solar infrastructure and reducing dependency on diesel powered
electricity will reduce the potential for fuel spills or contamination, improve air quality, and decrease
reliance on fossil fuels.
Data from this project will provide important information regarding solar resources in rural Alaska to
be applied in future projects.
Incorporating solar energy into the community power system will help stabilize costs associated
with emergency medical service (EMS) provided in a health clinic by a health aide.
Like all of Alaska, Holy Cross is subject to long periods of darkness. Even in the winter, solar
power could help supplement the cost of outside safety and security lighting of homes, roads
(streetlights), the airport runway, and other locations.
A battery storage system would provide a back-up source of power in the event of a power plant
outage during the entire year to improve system reliability.
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 scheduled maintenance is performed
As a local utility that has been in operation since 1968, AVEC is completely able to finance,
operate, and maintain this project for the design life. AVEC has capacity and experience to operate
this project. AVEC has operating renewable energy projects throughout the state and is familiar
with planning, constructing, operating, and maintaining solar systems. See section 10 for a
complete discussion of AVEC’s success with similar or related long-term operations.
AVEC has a large and geographically diverse staff capable of operating and maintaining energy
infrastructure. AVEC follows established and proven protocols for training existing and future
employees to operate and maintain diesel and renewable generation facilities. Throughout AVEC’s
time as a leading energy cooperative, AVEC has had success with training and onboarding of
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renewable infrastructure projects in Alaska. See section 4 for a detailed discussion of key personal
assigned to ensure successful completion of this project.
AVEC will use tracking protocols already in practice to track necessary tasks associated with the
proposed feasibility study and CDR, along with any subsequent project phases.
Should solar power prove a viable resource in Holy Cross and AVEC successfully implements
solar energy infrastructure, the solar array system would be incorporated into AVEC’s established
and proven power plant operation and maintenance system. Local plant operators would provide
daily servicing. AVEC technicians would continue to provide periodic preventative or corrective
maintenance and would be supported by AVEC headquarters staff, purchasing, and warehousing.
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.
The capital costs of the proposed solar array in Holy Cross would be determined through the
feasibility study and associated CDR. Solar experts and engineers would prepare a cost estimate
for installation of a suitable array.
The costs of operations and maintenance of the proposed project would be determined by through
the feasibility study. Currently, the estimated annual O&M for this project is $6,000 based on NREL
guidance and Northwest Arctic Borough costs. All AVEC facilities O&M costs are funded through
ongoing energy sales.
AVEC has well established and proven processes in place to account for setting rates, ensuring
revenue is collected, and maintaining financial sustainability of infrastructure over their operational
lives.
Rates are inclusive of a kWh charge, a fuel charge, a flat customer charge fee, sale tax (in some
communities), and a demand charge (if service billed on a demand meter). Many residential and
community facilities receive a PCE deduction for up to 500kWh per month. As a recipient of PCE,
AVEC’s rates are reviewed and approved by the Regulatory Commission of Alaska. When
renewable energy is added to an existing diesel generation system, AVEC determines the cost of
electricity based lower fuel use for generation and the cost of operating the new renewable energy
system.
AVEC ensures that bills are collected through monthly billing and easy payment options (mail,
online, over the phone, autopay, by credit card, etc.). AVEC helps customers obtain financial
assistance when needed. As a last resort, AVEC can disconnect customers for nonpayment.
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
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Collect sufficient revenue to cover operational and capital costs
• What is the expected cost-based rate (as consistent with RFA requirements)
• If you expect to have multiple rate classes, such as excess electricity for heat, explain what
those rates are expected to be and how those rates account for the costs of delivering the
energy (see AEA’s white paper on excess electricity for heat).
• Annual customer revenue sufficient to cover costs
• Additional incentives (i.e., tax credits)
• Additional revenue streams (i.e., green tag sales or other renewable energy subsidies or
programs that might be available)
Given that this project is in the conceptual design stage, revenue and incentives are unknown. Tax
credits are not expected to be beneficial to the project due to AVEC’s status as a non-profit entity.
Nonetheless, in addition to saving the direct cost of fuel, AVEC could sell green tags from the
project.
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.
Identification of potential power buyer(s)/customer(s): AVEC, the existing electric utility serving
Holy Cross, is a member-owned cooperative electric utility and typically owns and maintains the
generation, fuel storage, and distribution facilities in the villages it serves. No power purchase or
sales agreements would be needed for this project.
Holy Cross has approximately 100 households and a health clinic, city office, school, and water
treatment plant which purchase power from AVEC. At this point in project development, the
potential power price and rate of return on the project is unknown.
Potential power purchase/sales price: At this point in project development, the potential power
price and rate of return on the project is unknown. Work done under this grant would determine this
information.
SECTION 8 – PROJECT READINESS
8.1 Project Preparation
Describe what you have done to prepare for this award and how quickly you intend to proceed with
work once your grant is approved.
Specifically address your progress towards or readiness to begin, at a minimum, the following:
• The phase(s) that must be completed prior to beginning the phase(s) proposed in this application
• The phase(s) proposed in this application
• Obtaining all necessary permits
• Securing land access and use for the project
• Procuring all necessary equipment and materials
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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.
Once funding is known to be secured, AVEC would seek contractors to help complete the
feasibility level work.
AVEC has already identified a potential location for the solar array and battery storage system
adjacent to the existing power plant. Site control selection is secure and Holy Cross residents are
engaged and ready to work on this important community project and are prepared to work with
AVEC on land agreements if the proposed location is not feasible.
While the solar resource analysis is ongoing, other task items would be conducted in the first
winter, including analysis of current cost of energy and future market, and the economic and
financial analyses. Once the solar study is completed, conceptual design would occur.
With the solar analysis and site selection in hand, completion of the CDR would be seamless.
No other grants have been secured for this work in the past.
8.2 Demand- or Supply-Side Efficiency Upgrades
If you have invested in energy efficiency projects that will have a positive impact on the proposed
project, and have chosen to not include them in the economic analysis, applicants should provide
as much documentation as possible including:
1. Explain how it will improve the success of the RE project
2. Energy efficiency pre and post audit reports, or other appropriate analysis,
3. Invoices for work completed,
4. Photos of the work performed, and/or
5. Any other available verification such as scopes of work, technical drawings, and payroll for
work completed internally.
Not applicable to this project.
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 November 16, 2021. Please note that
letters of support from legislators will not count toward this criterion.
The community is committed to moving this project forward and fully supports evaluating solar
energy as a viable option for sustainable energy infrastructure in the community. Letters of support
for this project have been received from the City of Holy Cross, Holy Cross Village, Deloycheet,
Incorporated, Tanana Chiefs Conference, Interior Regional Housing Authority, and the Iditarod
Area School District. Letters of support can be found under Tab B.
SECTION 10 – COMPLIANCE WITH OTHER AWARDS
Identify other grants that may have been previously awarded to the Applicant by AEA for this or
any other project. Describe the degree you have been able to meet the requirements of previous
grants including project deadlines, reporting, and information requests.
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AVEC has been providing electrical services to rural, isolated, and economically-disadvantaged
Alaskan communities since 1968. The Cooperative began with three communities and a very small
staff, and has steadily grown to the impressive non-profit organization it is today, with 58-member
villages. AVEC started out with loans from the USDA RUS, and became a Denali Commission
partner in 2001. AVEC now has over 90 employees. There are generation technicians, linemen,
managers, engineers, expediters, and others in its central office in Anchorage, and plant operators
within member communities. With the signatures on this application, AVEC certifies that it is a
legally incorporated, non-profit entity eligible to receive federal grant funding for the proposed
project. Documentation of incorporation is available upon request.
AVEC has the largest geographic service area of any retail electric cooperative in the world. It has
demonstrated non-stop dedication to bringing stable and efficient sources of electricity to homes,
schools, clinics, water and sewer systems, businesses, and communications infrastructure in its
member villages. AVEC operates 170 diesel generators throughout its service area and purchases
over 8 million gallons of fuel annually. The generators produce electric power for member
communities, running a cumulative total of more than 400,000 hours per year. In 2020, AVEC
generated 121 million kWh in power sales.
Each of AVEC’s 58 villages conducts an annual village meeting for the express purpose of electing
a delegate to represent their community at AVEC’s Annual Cooperative Meeting held in Anchorage
each March. At the Annual Meeting, the delegates discuss AVEC business and elect members to
serve on the seven-member board of directors. AVEC and the local governments operate as a
partnership. Under operating agreements with all member communities, local control is exercised.
The village governments hire the plant operators and oversee the day-to-day operation of power
generation plants.
The AVEC Board of Directors and staff are committed to the on-going effort of increasing the
efficiencies and effectiveness of power-producing facilities and distribution lines in all member
villages. They believe that by improving the power generation and distribution in each community,
they are helping to improve the future of all impacted residents.
Since 2000, AVEC has reliably and responsibly spent over $299 million of grant funds and $37
million of AVEC’s own matching contributions to construct over 120 major projects. This includes
36 bulk fuel tank farm upgrades or replacements, 19 new diesel-fired power plants, 7 standby
backup power plants, 22 (grant funded or AVEC funded) recovered heat systems, 14 wind farms
(32 total wind turbines), 8 village-to-village interties, 1 photovoltaic (PV) solar array, and 33 other
generation and distribution upgrades. Funding for these projects has come from the Denali
Commission ($225 million), the Alaska Energy Authority ($38 million), USDA RUS direct awards
($14 million), USDE Office of Indian Energy ($4 million), and other grants ($18 million).
AVEC has been awarded over 39 AEA grants, details for these grants are attached in Tab G.
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.
Not applicable.
SECTION 12 – LIST OF ADDITIONAL DOCUMENTATION SUBMITTED FOR CONSIDERATION
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In the space below, please provide a list of additional information submitted for consideration.
Tab A – Resumes
Tab B – Letters of Support
Tab C – Heat
Tab D – Authority
Tab E – Electronic Application
Tab F – Certification
Tab G – Additional Materials (REF Round 14 Economic Evaluation Model; AVEC AEA Grant
Summary)
Tab A
Resumes
Tab B
Letters of Support
December 30, 2021 William R. Stamm, President & CEO Alaska Village Electric Cooperative, Inc. (AVEC) 4831 Eagle Street Anchorage, AK 99503 Re: Letter of Support for the Holy Cross Solar/Battery Reconnaissance and Feasibility Study REF Grant Application Dear Mr. Stamm, Doyon, Ltd understands that AVEC is seeking Alaska Energy Authority (AEA) Renewable Energy Fund (REF) grant funding for a solar/battery energy reconnaissance analysis and feasibility study in Holy Cross, AK. We believe this project is very important to the community of Holy Cross and would like to offer our support. The work will include assessing the potential photovoltaic (PV) capacity with battery storage in Holy Cross, with an exact size to be determined by the study. If the proposed analysis shows that solar energy is a viable energy resource in Holy Cross, AVEC could seek funding to prepare a final design, obtain permits and deploy a PV array and battery storage system. Doyon, Ltd. fully supports this study, as it will help determine if solar power has scalable potential in Holy Cross. A solar power generation system would be an economic benefit in our community of approximately 176 people currently experiencing high and unstable power costs. AVEC is welcome to include this letter in the grant application package. Sincerely, Aaron M. Schutt, President & CEO
122 1st Avenue
Fairbanks, AK 99701
907-452-8251
www.tananachiefs.org
January 10th 2022
Alaska Energy Authority
Renewable Energy Fund
813 West Northern Lights Blvd.
Anchorage, AK 99503
RE: AVEC application for Solar Photovoltaic and Battery Construction
Dear Alaska Energy Authority:
Please accept this letter of support from Tanana Chiefs Conference (TCC) regarding the Alaska
Village Electric Cooperative’s application to Round 14 of the AEA Renewable Energy Fund for
design of a solar photovoltaic (PV) and battery hybrid system. The type of system AVEC is
proposing has already proved economically and technically feasible in the community of Shungnak
and would result in substantial fuel and cost savings for the community as well as provide a
replicable model for other villages to follow.
TCC has worked extensively with the community in Holy Cross on extensive energy efficiency
upgrades through the US Department of Energy’s Remote Alaskan Communities Energy
Efficiency (RACEE) program, a solar energy projects, and heat recovery project to bring waste
heat from the AVEC plant to supply the Holy Cross water/sewer building and city office. The
AEA REF project described here is a logical and necessary progression of the past energy
improvements being made by the community to enhance energy security and save diesel fuel.
Tanana Chiefs Conference is the inter-tribal consortium representing 37 federally recognized tribes
across Alaska’s interior. For the past 40 years, TCC has been a voice advocating for the
priorities of interior villages and providing essential technical assistance to implement
communities’ visions. Our program has significant and specialized experience working with
rural energy projects in this region including assisting communities with several EPA DERA
projects and solar PV design-builds over the past 8 years. With this letter we commit to working
collaboratively with AVEC on the design process to ensure that any design can also be utilized
in other TCC villages that are part of the AVEC system.
Holy Cross is setting the standard in rural Alaska for cooperation among stakeholders as well as
innovative energy projects that improve the local economy, enhance energy security and resiliency.
As such, we strongly support this project.
Sincerely,
Dave Messier
TCC Rural Energy Coordinator
Dave.pm@tananachiefs.org
December 28, 2021
William R. Stamm, President and CEO
Alaska Village Electric Cooperative, Inc. (AVEC)
4831 Eagle Street
Anchorage, AK 99503
Re: Letter of Support for the Holy Cross Solar/Battery Reconnaissance and Feasibility Study REF
Grant Application
Dear Mr. Stamm,
The Iditarod Area School District understands that AVEC is seeking Alaska Energy Authority
(AEA) Renewable Energy Fund (REF) grant funding for a solar/battery energy reconnaissance
analysis and feasibility study in Holy Cross, AK. We believe this project is very important to the
community of Holy Cross and would like to offer our support. The work will include assessing
the potential photovoltaic (PV) capacity with battery storage in Holy Cross, with an exact size to
be determined by the study. If the proposed analysis shows that solar energy is a viable energy
resource in Holy Cross, AVEC could seek funding to prepare a final design, obtain permits and
deploy a PV array and battery storage system.
The Iditarod Area School District fully supports this study, as it will help determine if solar
power has scalable potential in Holy Cross. A solar power generation system would be an
economic benefit in our community of approximately 176 people currently experiencing high
and unstable power costs. AVEC is welcome to include this letter in the grant application
package.
Sincerely,
Helen Cheek
Superintendent
Iditarod Area School District
Anvik
Grayling
McGrath
Holy Cross
Iditarod Distance Learning Center
Nikolai
Shageluk
Takotna
Iditarod Area School District
PO Box 90
90 Chinana Road
McGrath, Alaska 99627
907.524.1221
Tab C
Heat Project Information
No information provided in this section.
Not applicable to this project.
Tab D
Authority
Tab E
Electronic Application
Application was submitted electronically.
Not applicable to this project.
Tab F
Certification
Tab G
Additional Materials
‐ AVEC AEA Grant Summary
‐ Evaluation Model
Grant # /
Application #No.Description Notes Year Funded
Grant #2195244 Wind Turbine Foundation Design & Testing Project (DC project 27D Toksook Bay)Completed successfully; facilities now in service.2005 AES
Grant #2195281 Chevak Wind Farm Project (DC project 29E)Completed successfully; facilities now in service.2007 AES
Grant #2195412 Ambler Solar PV Construction Failed early feasibility evaluation, returned bulk of funds.2008 RD1
Grant #2195432 Bethel Wind Farm Completed successfully; facilities now in service.2008 RD1
Grant #2195413 Cosmos Hills Hydro Feasibility Completed successfully; feasibility only.2008 RD1
Grant #2195384 Mekoryuk Wind Farm Construction Completed successfully; facilities now in service.2008 RD1
Grant #2195431 Old Harbor Hydroelectric Final Design Completed successfully (design). FERC licensure in place.2008 RD1
Grant #2195383 Quinhagak Wind Farm Construction Completed successfully; facilities now in service.2008 RD1
Grant #2195385 Toksook Bay Wind Farm Expansion Construction Completed successfully; facilities now in service.2008 RD1
Grant #2195463 Shaktoolik Wind Construction Completed successfully; facilities now in service.2009 RD2
Grant #2195464 Teller Wind Analysis Completed successfully; feasibility only.2009 RD2
Grant #2195468 Emmonak/Alakanuk Wind Design and Construction Completed successfully; facilities now in service.2009 RD2
Grant #7030006 New Stuyahok Wind Analysis Completed successfully; feasibility only.2009 RD2
Grant #7030016 Kivalina Wind-Intertie Feasibility Analysis & Conceptual Design Completed successfully; feasibility only.2010 RD3
Grant #7040008 Stebbins Wind Feasibility Completed successfully; feasibility only.2011 RD4
Grant #7040014 Old Harbor Hydroelectric Project Completed successfully (design). FERC licensure in place.2011 RD4
Grant #7040017 St. Mary's/ Pitka's Point Wind Design and Construction Completed successfully; facilities now in service.2011 RD4
Grant #7040019 Eek Wind Feasibility Completed successfully; feasibility only.2011 RD4
Grant #7040021 Marshall Wind Feasibility Study Completed successfully; feasibility only.2011 RD4
Grant #7040022 Scammon Bay Wind Feasibility Completed successfully; feasibility only.2011 RD4
Grant #7040030 Selawik Hybrid Wind Diesel System Turbine Upgrade Assessment Completed successfully; feasibility only.2011 RD4
Grant #7040049 Kaltag Solar Construction Completed successfully; facilities now in service.2011 RD4
Grant #7040052 Koyuk Wind Feasibility Study Community declined to participate. Returned funding.2011 RD4
Grant #7040053 Elim Wind Feasibility Study Completed successfully; feasibility only.2011 RD4
Grant #7050870 Surplus Wind Energy Recovery for Mekoryuk Water System Heat Completed successfully; facilities now in service.2012 RD5
Grant #7050871 Shaktoolik Surplus Wind Energy Recovery for Water System Heat Completed successfully; facilities now in service.2012 RD5
Grant #7050875 Surplus Wind Energy Recovery for Chevak Water System Heat Completed successfully; facilities now in service.2012 RD5
Grant #7050876 Surplus Wind Energy Recovery for Gambell Water System Heat Completed successfully; facilities now in service.2012 RD5
Grant #7060939 Stebbins Heat Recovery Project Completed successfully; facilities now in service.2013 RD6
Grant #7071067 Mountain Village Wind Feasibility and Conceptual Design Completed successfully; feasibility only.2014 RD7
Grant #7071068 Stebbins St. Michael Wind Energy Final Design and Permitting Completed successfully; final design and permitting.2014 RD7
Grant #7081118 Bethel Power Plant Heat Recovery Assessment & Conceptual Design Completed successfully; feasibility and coceptual design.2015 RD8
Grant #7091223 Shishmaref Wind Energy Feasibility and CDR In progress. 2018 RD9
Grant #7091224 Mountain Village-St. Mary's Wind Intertie Project Completed successfully; facilities constructed. 2018 RD9
Grant #7110056 Togiak RPSU Completed successfully; facilities now in service.2017
Grant #7110082 Anvik DERA Replace Engine Position 3 Completed successfully; new engine commissioned and on-line.2019
Grant #7210025 Holy Cross BFU Completed successfully; facilities now in service.2017
Grant #7310305 Grid Bridging System Research and Development In progress.2019
Application #13002 Goodnews Bay Wind Energy Feasibility & Conceptual Design Project Currently waiting for AEA's authorization to proceed.2020 RD13
Application #13003 Kotlik Wind Energy Feasibility & Conceptual Design Project Currently waiting for AEA's authorization to proceed.2020 RD13
Renewable Energy Fund Economic Benefit-Cost Analysis Model
Project Description
Community
Nearest Fuel Community
Region
RE Technology
Project ID
Applicant Name
Project Title
Results
NPV Benefits $948,210.52
NPV Capital Costs $945,989
B/C Ratio 1.00
NPV Net Benefit $29,774
Performance Unit Value
Displaced Electricity kWh per year 166,035
Displaced Electricity total lifetime kWh 4,150,875
Displaced Petroleum Fuel gallons per year 11,451
Displaced Petroleum Fuel total lifetime gallons 286,267
Displaced Natural Gas MCF per year -
Displaced Natural Gas total lifetime MCF -
Avoided CO2 tonnes per year 116
Avoided CO2 total lifetime tonnes 2,906
Proposed System Unit Value
Capital Costs $1,000,000$
Project Start year 2025
Project Life years 25
Displaced Electric kWh per year 166,035
Displaced Heat gallons displaced per year
Renewable Generation O&M (Electric)$ per year 6,000
Renewable Generation O&M (Heat)$ per year
Diesels OFF time Hours per year 1,500
Electric Capacity kW 200
Electric Capacity Factor %9%
Heating Capacity Btu/hr
Heating Capacity Factor %#DIV/0!
Total Other Public Benefit 2021$ (Total over the life of the project)0
Base System
Size of impacted engines (select from list)$/hr
Diesel Generator O&M 60-150kW 7.01$
Applicant's Diesel Generator Efficiency kWh per gallon 13
Total current annual diesel generation kWh/gallon
590,241 kWh (2020) 14.50
NOTICE: By default, this sheet is locked. If you need to unlock the sheet go to 'Review' in ribbon bar, select
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Holy Cross
Holy Cross
Rural
Solar PV
Alaska Village Electric Cooperative, Inc.
Holy Cross Solar Array
Diesel Generation Efficiency
Annual Cost Savings Units
Entered Value Project Capital Cost $ per year
CALCULATION Electric Cost Savings $ per year
CALCULATION Heating Cost Savings $ per year
Entered Value Other Public Benefits $ per year
CALCULATION Total Cost Savings $ per year
CALCULATION Net Benefit $ per year
Cumulative Cost
Electric Units
Enter Value if generation changes Renewable Generation kWh per year
Entered Value Renewable scheduled replacement(s) (Electric) $ per year
REFERENCE: Cell D34 Renewable O&M (Electric)$ per year
Entered Value Renewable Electric Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Biomass)green tons
Entered Value Renewable Fuel Cost $ per unit
CALCULATION Total Renewable Fuel Cost (Electric)$ per year
Proposed Generation Cost (Electric)$ per year
REFERENCE: Cell D32 Displaced Fossil Fuel Generation kWh per year
REFERENCE: Worksheet 'Diesel Fuel
Prices'Displaced Fuel Price $ per gallon
Enter Value if Diesels are OFF Displaced Scheduled component replacement(s) $ per year
CALCULATION Displaced O&M $ per year
CALCULATION Displaced Fuel Use gallons per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Generation Displaced Cost $ per year
Heating Units
Entered Value Renewable scheduled replacement(s)$ per year
REFERENCE: Cell D35 Renewable Heat O&M $ per year
Entered Value Renewable Heat Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Heat)green tons/kWh/etc.
Entered Value Renewable Fuel Cost (Heat)$ per unit
CALCULATION Total Renewable Fuel Cost (Heat)$ per year
CALCULATION Proposed Generation Cost (Heat)$ per year
REFERENCE: Cell D33 Displaced Fossil Fuel Use gallons per year
Entered Value Displaced Fossil Fuel Price $ per gallon
Entered Value Displaced Scheduled component replacement(s) $ per year
Entered Value Displaced O&M $ per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Heating Displaced Cost $ per year
Base
Proposed
Base
Proposed
4 5 6 7 8
2021 2022 2023 2024 2025
120,000$ 880,000$
-$ -$ -$ -$ 54,089$
-$ -$ -$ -$ -$
-$ -$ -$ -$ 54,089$
-$ -$ (120,000)$ (880,000)$ 54,089$
120,000 1,000,000 945,911
2021 2022 2023 2024 2025
----166,035
-$ -$ -$ -$ 6,000$
3.50$
-$ -$ -$ -$ -$
-$ -$ -$ -$ 6,000$
----166,035
3.97$ 4.03$ 4.14$ 4.22$ 4.33$
-$ -$ -$ -$ -$
-$ -$ -$ -$ 10,515$
----11,451
-$ -$ -$ -$ 49,575$
-$ -$ -$ -$ 60,089$
2021 2022 2023 2024 2025
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-----
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
Annual Cost Savings Units
Entered Value Project Capital Cost $ per year
CALCULATION Electric Cost Savings $ per year
CALCULATION Heating Cost Savings $ per year
Entered Value Other Public Benefits $ per year
CALCULATION Total Cost Savings $ per year
CALCULATION Net Benefit $ per year
Cumulative Cost
Electric Units
Enter Value if generation changes Renewable Generation kWh per year
Entered Value Renewable scheduled replacement(s) (Electric) $ per year
REFERENCE: Cell D34 Renewable O&M (Electric)$ per year
Entered Value Renewable Electric Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Biomass)green tons
Entered Value Renewable Fuel Cost $ per unit
CALCULATION Total Renewable Fuel Cost (Electric)$ per year
Proposed Generation Cost (Electric)$ per year
REFERENCE: Cell D32 Displaced Fossil Fuel Generation kWh per year
REFERENCE: Worksheet 'Diesel Fuel
Prices'Displaced Fuel Price $ per gallon
Enter Value if Diesels are OFF Displaced Scheduled component replacement(s) $ per year
CALCULATION Displaced O&M $ per year
CALCULATION Displaced Fuel Use gallons per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Generation Displaced Cost $ per year
Heating Units
Entered Value Renewable scheduled replacement(s)$ per year
REFERENCE: Cell D35 Renewable Heat O&M $ per year
Entered Value Renewable Heat Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Heat)green tons/kWh/etc.
Entered Value Renewable Fuel Cost (Heat)$ per unit
CALCULATION Total Renewable Fuel Cost (Heat)$ per year
CALCULATION Proposed Generation Cost (Heat)$ per year
REFERENCE: Cell D33 Displaced Fossil Fuel Use gallons per year
Entered Value Displaced Fossil Fuel Price $ per gallon
Entered Value Displaced Scheduled component replacement(s) $ per year
Entered Value Displaced O&M $ per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Heating Displaced Cost $ per year
Base
Proposed
Base
Proposed
9 10 11 12 13
2026 2027 2028 2029 2030
55,092$ 55,819$ 56,505$ 57,151$ 57,759$
-$ -$ -$ -$ -$
55,092$ 55,819$ 56,505$ 57,151$ 57,759$
55,092$ 55,819$ 56,505$ 57,151$ 57,759$
890,818 835,000 778,495 721,343 663,584
2026 2027 2028 2029 2030
166,035 166,035 166,035 166,035 166,035
6,000$ 6,000$ 6,000$ 6,000$ 6,000$
-$ -$ -$ -$ -$
6,000$ 6,000$ 6,000$ 6,000$ 6,000$
166,035 166,035 166,035 166,035 166,035
4.42$ 4.48$ 4.54$ 4.60$ 4.65$
-$ -$ -$ -$
10,515$ 10,515$ 10,515$ 10,515$ 10,515$
11,451 11,451 11,451 11,451 11,451
50,578$ 51,304$ 51,990$ 52,637$ 53,245$
61,092$ 61,819$ 62,505$ 63,151$ 63,759$
2026 2027 2028 2029 2030
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-----
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
Annual Cost Savings Units
Entered Value Project Capital Cost $ per year
CALCULATION Electric Cost Savings $ per year
CALCULATION Heating Cost Savings $ per year
Entered Value Other Public Benefits $ per year
CALCULATION Total Cost Savings $ per year
CALCULATION Net Benefit $ per year
Cumulative Cost
Electric Units
Enter Value if generation changes Renewable Generation kWh per year
Entered Value Renewable scheduled replacement(s) (Electric) $ per year
REFERENCE: Cell D34 Renewable O&M (Electric)$ per year
Entered Value Renewable Electric Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Biomass)green tons
Entered Value Renewable Fuel Cost $ per unit
CALCULATION Total Renewable Fuel Cost (Electric)$ per year
Proposed Generation Cost (Electric)$ per year
REFERENCE: Cell D32 Displaced Fossil Fuel Generation kWh per year
REFERENCE: Worksheet 'Diesel Fuel
Prices'Displaced Fuel Price $ per gallon
Enter Value if Diesels are OFF Displaced Scheduled component replacement(s) $ per year
CALCULATION Displaced O&M $ per year
CALCULATION Displaced Fuel Use gallons per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Generation Displaced Cost $ per year
Heating Units
Entered Value Renewable scheduled replacement(s)$ per year
REFERENCE: Cell D35 Renewable Heat O&M $ per year
Entered Value Renewable Heat Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Heat)green tons/kWh/etc.
Entered Value Renewable Fuel Cost (Heat)$ per unit
CALCULATION Total Renewable Fuel Cost (Heat)$ per year
CALCULATION Proposed Generation Cost (Heat)$ per year
REFERENCE: Cell D33 Displaced Fossil Fuel Use gallons per year
Entered Value Displaced Fossil Fuel Price $ per gallon
Entered Value Displaced Scheduled component replacement(s) $ per year
Entered Value Displaced O&M $ per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Heating Displaced Cost $ per year
Base
Proposed
Base
Proposed
14 15 16 17 18
2031 2032 2033 2034 2035
58,329$ 58,861$ 59,356$ 59,815$ 60,238$
-$ -$ -$ -$ -$
58,329$ 58,861$ 59,356$ 59,815$ 60,238$
58,329$ 58,861$ 59,356$ 59,815$ 60,238$
605,256 546,395 487,039 427,225 366,987
2031 2032 2033 2034 2035
166,035 166,035 166,035 166,035 166,035
6,000$ 6,000$ 6,000$ 6,000$ 6,000$
-$ -$ -$ -$ -$
6,000$ 6,000$ 6,000$ 6,000$ 6,000$
166,035 166,035 166,035 166,035 166,035
4.70$ 4.75$ 4.79$ 4.83$ 4.87$
-$ -$ -$ -$
10,515$ 10,515$ 10,515$ 10,515$ 10,515$
11,451 11,451 11,451 11,451 11,451
53,814$ 54,346$ 54,841$ 55,300$ 55,723$
64,329$ 64,861$ 65,356$ 65,815$ 66,238$
2031 2032 2033 2034 2035
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-----
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
Annual Cost Savings Units
Entered Value Project Capital Cost $ per year
CALCULATION Electric Cost Savings $ per year
CALCULATION Heating Cost Savings $ per year
Entered Value Other Public Benefits $ per year
CALCULATION Total Cost Savings $ per year
CALCULATION Net Benefit $ per year
Cumulative Cost
Electric Units
Enter Value if generation changes Renewable Generation kWh per year
Entered Value Renewable scheduled replacement(s) (Electric) $ per year
REFERENCE: Cell D34 Renewable O&M (Electric)$ per year
Entered Value Renewable Electric Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Biomass)green tons
Entered Value Renewable Fuel Cost $ per unit
CALCULATION Total Renewable Fuel Cost (Electric)$ per year
Proposed Generation Cost (Electric)$ per year
REFERENCE: Cell D32 Displaced Fossil Fuel Generation kWh per year
REFERENCE: Worksheet 'Diesel Fuel
Prices'Displaced Fuel Price $ per gallon
Enter Value if Diesels are OFF Displaced Scheduled component replacement(s) $ per year
CALCULATION Displaced O&M $ per year
CALCULATION Displaced Fuel Use gallons per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Generation Displaced Cost $ per year
Heating Units
Entered Value Renewable scheduled replacement(s)$ per year
REFERENCE: Cell D35 Renewable Heat O&M $ per year
Entered Value Renewable Heat Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Heat)green tons/kWh/etc.
Entered Value Renewable Fuel Cost (Heat)$ per unit
CALCULATION Total Renewable Fuel Cost (Heat)$ per year
CALCULATION Proposed Generation Cost (Heat)$ per year
REFERENCE: Cell D33 Displaced Fossil Fuel Use gallons per year
Entered Value Displaced Fossil Fuel Price $ per gallon
Entered Value Displaced Scheduled component replacement(s) $ per year
Entered Value Displaced O&M $ per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Heating Displaced Cost $ per year
Base
Proposed
Base
Proposed
19 20 21 22 23
2036 2037 2038 2039 2040
60,625$ 60,978$ 61,295$ 61,579$ 61,828$
-$ -$ -$ -$ -$
60,625$ 60,978$ 61,295$ 61,579$ 61,828$
60,625$ 60,978$ 61,295$ 61,579$ 61,828$
306,362 245,385 184,089 122,511 60,683
2036 2037 2038 2039 2040
166,035 166,035 166,035 166,035 166,035
6,000$ 6,000$ 6,000$ 6,000$ 6,000$
-$ -$ -$ -$ -$
6,000$ 6,000$ 6,000$ 6,000$ 6,000$
166,035 166,035 166,035 166,035 166,035
4.90$ 4.93$ 4.96$ 4.98$ 5.01$
-$ -$ -$ -$ -$
10,515$ 10,515$ 10,515$ 10,515$ 10,515$
11,451 11,451 11,451 11,451 11,451
56,111$ 56,463$ 56,781$ 57,064$ 57,313$
66,625$ 66,978$ 67,295$ 67,579$ 67,828$
2036 2037 2038 2039 2040
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-----
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
Annual Cost Savings Units
Entered Value Project Capital Cost $ per year
CALCULATION Electric Cost Savings $ per year
CALCULATION Heating Cost Savings $ per year
Entered Value Other Public Benefits $ per year
CALCULATION Total Cost Savings $ per year
CALCULATION Net Benefit $ per year
Cumulative Cost
Electric Units
Enter Value if generation changes Renewable Generation kWh per year
Entered Value Renewable scheduled replacement(s) (Electric) $ per year
REFERENCE: Cell D34 Renewable O&M (Electric)$ per year
Entered Value Renewable Electric Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Biomass)green tons
Entered Value Renewable Fuel Cost $ per unit
CALCULATION Total Renewable Fuel Cost (Electric)$ per year
Proposed Generation Cost (Electric)$ per year
REFERENCE: Cell D32 Displaced Fossil Fuel Generation kWh per year
REFERENCE: Worksheet 'Diesel Fuel
Prices'Displaced Fuel Price $ per gallon
Enter Value if Diesels are OFF Displaced Scheduled component replacement(s) $ per year
CALCULATION Displaced O&M $ per year
CALCULATION Displaced Fuel Use gallons per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Generation Displaced Cost $ per year
Heating Units
Entered Value Renewable scheduled replacement(s)$ per year
REFERENCE: Cell D35 Renewable Heat O&M $ per year
Entered Value Renewable Heat Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Heat)green tons/kWh/etc.
Entered Value Renewable Fuel Cost (Heat)$ per unit
CALCULATION Total Renewable Fuel Cost (Heat)$ per year
CALCULATION Proposed Generation Cost (Heat)$ per year
REFERENCE: Cell D33 Displaced Fossil Fuel Use gallons per year
Entered Value Displaced Fossil Fuel Price $ per gallon
Entered Value Displaced Scheduled component replacement(s) $ per year
Entered Value Displaced O&M $ per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Heating Displaced Cost $ per year
Base
Proposed
Base
Proposed
24 25 26 27 28
2041 2042 2043 2044 2045
62,043$ 62,225$ 62,373$ 62,488$ 62,488$
-$ -$ -$ -$ -$
62,043$ 62,225$ 62,373$ 62,488$ 62,488$
62,043$ 62,225$ 62,373$ 62,488$ 62,488$
-1,361 -63,586 -125,959 -188,447 -250,934
2041 2042 2043 2044 2045
166,035 166,035 166,035 166,035 166,035
6,000$ 6,000$ 6,000$ 6,000$ 6,000$
-$ -$ -$ -$ -$
6,000$ 6,000$ 6,000$ 6,000$ 6,000$
166,035 166,035 166,035 166,035 166,035
5.02$ 5.04$ 5.05$ 5.06$ 5.06$
-$ -$ -$ -$ -$
10,515$ 10,515$ 10,515$ 10,515$ 10,515$
11,451 11,451 11,451 11,451 11,451
57,529$ 57,710$ 57,859$ 57,973$ 57,973$
68,043$ 68,225$ 68,373$ 68,488$ 68,488$
2041 2042 2043 2044 2045
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-----
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
Annual Cost Savings Units
Entered Value Project Capital Cost $ per year
CALCULATION Electric Cost Savings $ per year
CALCULATION Heating Cost Savings $ per year
Entered Value Other Public Benefits $ per year
CALCULATION Total Cost Savings $ per year
CALCULATION Net Benefit $ per year
Cumulative Cost
Electric Units
Enter Value if generation changes Renewable Generation kWh per year
Entered Value Renewable scheduled replacement(s) (Electric) $ per year
REFERENCE: Cell D34 Renewable O&M (Electric)$ per year
Entered Value Renewable Electric Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Biomass)green tons
Entered Value Renewable Fuel Cost $ per unit
CALCULATION Total Renewable Fuel Cost (Electric)$ per year
Proposed Generation Cost (Electric)$ per year
REFERENCE: Cell D32 Displaced Fossil Fuel Generation kWh per year
REFERENCE: Worksheet 'Diesel Fuel
Prices'Displaced Fuel Price $ per gallon
Enter Value if Diesels are OFF Displaced Scheduled component replacement(s) $ per year
CALCULATION Displaced O&M $ per year
CALCULATION Displaced Fuel Use gallons per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Generation Displaced Cost $ per year
Heating Units
Entered Value Renewable scheduled replacement(s)$ per year
REFERENCE: Cell D35 Renewable Heat O&M $ per year
Entered Value Renewable Heat Other costs $ per year
Entered Value Renewable Fuel Use Quantity (Heat)green tons/kWh/etc.
Entered Value Renewable Fuel Cost (Heat)$ per unit
CALCULATION Total Renewable Fuel Cost (Heat)$ per year
CALCULATION Proposed Generation Cost (Heat)$ per year
REFERENCE: Cell D33 Displaced Fossil Fuel Use gallons per year
Entered Value Displaced Fossil Fuel Price $ per gallon
Entered Value Displaced Scheduled component replacement(s) $ per year
Entered Value Displaced O&M $ per year
CALCULATION Displaced Fuel Cost $ per year
CALCULATION Base Heating Displaced Cost $ per year
Base
Proposed
Base
Proposed
29 30 31 32 33
2046 2047 2048 2049 2050
62,488$ 62,488$ 62,488$ 62,488$ -$
-$ -$ -$ -$ -$
62,488$ 62,488$ 62,488$ 62,488$ -$
62,488$ 62,488$ 62,488$ 62,488$ -$
-313,422 -375,910 -438,398 -500,886
2046 2047 2048 2049 2050
166,035 166,035 166,035 166,035 -
6,000$ 6,000$ 6,000$ 6,000$ -$
-$ -$ -$ -$ -$
6,000$ 6,000$ 6,000$ 6,000$ -$
166,035 166,035 166,035 166,035 -
5.06$ 5.06$ 5.06$ 5.06$ 5.06$
-$ -$ -$ -$ -$
10,515$ 10,515$ 10,515$ 10,515$ -$
11,451 11,451 11,451 11,451 -
57,973$ 57,973$ 57,973$ 57,973$ -$
68,488$ 68,488$ 68,488$ 68,488$ -$
2046 2047 2048 2049 2050
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$
-----
-$ -$ -$ -$ -$
-$ -$ -$ -$ -$