HomeMy WebLinkAboutNAB Application Signed - reducedRenewable Energy Fund Round 14
Grant Application -Standard Form
Application Forms and Instructions
ALASKA
ENERG Y
AUT H OR ITY
This instruction page and the following grant application constitutes the Grant Application Form for
Round 14 of the Renewable Energy Fund (REF). A separate application form is available for
projects with a primary purpose of producing heat (see Request for Applications (RFA) Section
1.5). This is the standard form for all other projects , including projects that will produce heat and
electricity. An electronic version of the RFA and both application forms is available online at:
tip::, //wvv ~ I ( 10\i:.ll ' I rq'\VI I lp [ ./Grants I rci R ~nP\ I .-liP I lV. I I') 1~
REF -A ppllc~.
What follows are some basic information and instructions for this application :
• The Alaska Energy Authority (AEA) expects this application to be used as part of a two-year
solicitation cycle with an opt-out provision in the second year of the cycle.
• If you are applying for grants for more than one project, provide separate application forms for
each project.
• Multiple phases (e .g. final design, construction) for the same project may be submitted as one
application .
• If you are applying for grant funding for more than one phase of a project , provide milestones
and grant budget for each phase of the project (see Sections 3.1 and 3.2.2).
• In order to ensure that grants provide sufficient benefit to the public, AEA may limit
recommendations for grants to preliminary development phases in accordance with 3 Alaska
Administrative Code (ACC) 107.605(1).
• If some work has already been completed on your project and you are requesting funding for
an advanced phase, submit information sufficient to demonstrate that the preceding phases are
completed and funding for an advanced phase is warranted. Supporting documentation may
include, but is not limited to, reports, conceptual or final designs, models, photos, maps, proof
of site control, utility agreements, business and operation plans, power sale agreements,
relevant data sets, and other materials. Please provide a list of supporting documents in
Section 11 of this application and attach the doc uments to your application.
• If you have additional information or reports you would like the Authority to consider in
reviewing your application, e ither provide an electronic version of the document with your
submission or reference a web link where it can be downloaded or reviewed . Please provide a
list of additional information ; including any web links, in Section 12 of this application and attach
the documents to your application. For guidance on application best practices please refer to
the resource -specific Best Practices Checkli sts ; links to the checklists can be found in the
appendices list at the end of the accompanying REF Round 14 RFA.
• In the Section s below, please enter responses in the spaces provided . You may add additional
rows or space to the form to provide sufficient space for the information, or attach additional
sheets if needed .
• If you need assistance with your application, please contact AEA's Grants Coordinator by email
at ,, ' ""' ~ .-, 1 e 11 .g or by phone at (907) 771-3081.
AEA 23001 Page I of 45 1111 6/202 1
Renewable Energy Fund Round 14
Grant Application -Standard Form
REMINDER:
ALASKA
ENERGY
AUTHORITY
• AEA is subject to the Public Records Act AS 40.25, and materials submitted to AEA may be
subject to disclosure requirements under the act if no statutory exemptions apply.
• All applications received will be posted on the Authority web site after final recommendations
are made to the legislature. Please submit resumes as separate PDFs if the applicant would
like those excluded from the web posting of this application.
• In accordance with 3 AAC 107.630 (b) Applicants may request trade secrets or proprietary
company data be kept confidential subject to review and approval by AEA. If you want
information to be kept confidential the applicant must:
o Request the information be kept confidential.
o Clearly iden ti fy the information that is the trade secret or proprietary in their application .
o Receive concurrence from the Authority that the information will be kept confidential. If
the Authority determ ines it is not confidential , it will be treated as a public record in
accordance with AS 40.25 or returned to the applicant upon request.
AEA 2300 1 Page 2 of45 11/16/2021
Renewable Ener gy Fund Round 14
Grant Application -Standa rd F orm
SECTION 1-APPLICANT INFORMATION
ALASKA
ENERGY
AUTHORITY
Please specify the legal grantee that will own, operate, and maintain the project upon completi on .
I Name (Name of utility, IPP, local g overnment, or oth er g overnment entity)
I Northwest Arcti c Borough (NAB )
Tax ID # 92-0116661
Date of last financial statement audit: 6/30/2020
Mailing Address: Physical Address:
P .O . Bo x 1110 163 Lag oon St
Kotzebue , AK 99752 Kotzebue, AK 99 75 2
Telephone: Fax: Ema i l:
907-442-2 500 907-442 -2 93 0 imathia sso n@nwabor.org
I 1.1 Applicant Point of Contact I Grants Coordi nat or
Name: Ingemar Mathiasson T itle: Energy Manager
Mailing Address:
P.O. Box 1110
Kotzebue, AK 99752
Telephone: Fax: Email :
907-445-2 03 1 90 7 -442 -2930 im a thi asson@ nwabor.org
1.1.1 Appl icant Signatory Aut hority Contact Infor mati on
Name: Dickie Moto Title: Mayor
Mai l ing Address :
P.O. Box 1110
Kotzebue, AK 99752
Teleph one: Fax: Ema il:
9 07-442-8201 d moto@ nwa bo r .o rg
1.1.2 Applicant Alternate Points of Contact
Name Te l ephone: Fax: Email:
Erin Step he ns 90 7-442-822 1 907 -442 -2930 EStephen s@ nwabo r.org
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Renewable Energy Fund Round 14
Grant Application-Standard Form
ALASKA
ENERG Y
A UTHORI TY
1.2 Applicant Minimum Requirements
Please check as appropriate. If applicants do not meet the minimum requirements, the application
will be rejected.
11.2.1 Applicant Type
D An electric utility holding a certificate of publ ic convenience and necessity under AS 42.05
CPCN # , or
D An independent power producer in accordance with 3 AAC 107.695 (a) (1)
CPCN # , or
~ A local government, or
D A governmental entity (which includes tribal councils and housing authorities)
Add"f t 1 1ona mm1mum reqUiremen s
~ 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 govern ing authority. If the
applicant is a collaborative grouping , a formal approval from each participant's governing
authority is necessary. (In dicate 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
I 11 I I k I tit . " I •I D ,, I l ) I I" r,...., ...:
f t r d1 0 If ET I'll I 1 1J. (Any exceptions should be clearly noted and submitted with the
application .) (In dicate 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 beneficia ries. (Indicate yes by checking the box)
AEA 2300 1 Page 4 of45 11 /16/2021
Renewable Energy Fund Round 14
Grant Application -Standard Form
I SECTION 2 -PROJECT SUMMARY
2.1 Project Title
A LASKA
ENE RGY
AUTHORITY
Provide a 4 to 7 word title for your project. Type in the space below.
Design and Permitting for Solar PV and Battery Storage for Ambler, Kiana, Noorvik , and Selawik
I 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 Goot~, 1. ; 2 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 r ~ 1IS@nl l II II c 'lLOr by phone at (907) 771-
3081 .
Latitude Ambler-67.08816
Kiana -66.97164
Noorvik-66.83311
Selawik • 66.60088
[Other description of location]
Longitude -157.86581
-160.43651
-161.04077
-160.00472
The Villages of Ambler, Kiana, Noorvik , and Selawik are all located in the Northwest Arctic
Borough. Ambler, Kiana, and Noorvik are located along the banks of the Kobuk River. Selawik is
located at the mouth of the Selawik River. All four communities are located above the Arctic Circle.
The region experiences a transitional climate, characterized by long, cold winters and cool
summers. Temperatures range from -52 to 85 degrees Fahrenheit. Total precipitation averages
nine inches per year and average annual snowfall is forty seven inches.
2.2.2 Community benefiting-Name(s) of the community or communities that will be the
beneficiaries of the project.
The communities of Ambler, Kiana, Noorvik, and Selawik will benefit from this project that will
complete the design and permitting phase of this solar PV and Battery Storage project. Funding
requested here will bring the proposed projects to "shovel ready" status. Upon final construction,
the communities will have a more resilient energy infrastructure with capabilities of supplying their
community electricity needs at times without any diesel generation . This project will stabilize and
potentially lower the cost of energy production for the communities resulting in less out-migration
from community members that can no longer afford to live in their home. Stabilized energy cost can
also foster economic development opportunities . The projects will also build capacity in the
communities for project management and O&M skills for renewable energy systems. The Alaska
Village Electric Cooperative (AVEC), which is the electric utility for all four communities, will also
benefit from increased energy generation assets, improved reliability with less outages , less fuel
shipping needs, and enhanced local capacity.
2.3 Project Type
Please check as appropriate.
I 2.3.1 Renewable Resource Type
0 Wind D Biomass or Biofuels (excluding heat-only)
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Renewable Energy Fund Round 14
Grant Application-Standard Form
D Hydro, Including Run of River D Hydrokinetic
ALASKA
ENERGY
A UTHORITY
D Geothermal, Excluding Heat Pumps D Transmission of Renewable Energy
Solar Photovoltaic Storage of Renewable
lo Other (Describe) D Small Natural Gas
1 2.3.2 Proposed Grant Funded Phase(s) for this Request (Check all that apply)
Pre-Construction Constructi on
D Reconnaissance 181 Final Design and Permitting
D Feasibility and Conceptual Design D Construction
2.4 Project Description
Provide a brief, one-paragraph description of the proposed project.
The Northwest Arctic Borough (NAB) is requesting $590,000 for the Phase Ill Final Design and
Permitting for four high penetration distributed solar PV, Battery, and diesel hybrid systems for the
communities of Ambler, Kiana, Noorvik , and Selawik. The intent of this project is to leverage the
economies of scale for the design of the systems to significantly reduce the project development
costs and improve the project economics. The economies of scale will also be leveraged in the
future construction phase of the systems through equipment procurement and construction
contracts. Based on Hybrid Optimization for Multiple Energy Resources (HOMER) software
modeling and AEA's B/C Ratio model, when constructed these systems will displace about
102,099 gallons of imported diesel fuel annually and will result in about 3717 hours of diesels-off
operation in the communities, saving the communities about $486,152 during the 1st year of
operation . Lifetime savings for the project are estimated at $13,458,097. In addition to reducing the
cost of electrical generation, the installation of the batteries will dramatically increase the efficiency
and resilience of the power generation system by providing spinning reserve and significantly
reducing brown-outs and black-outs. This project will leverage the key learnings from other high
penetration systems operating and in development in the Northwest Arctic Borough, including
Kotzebue, Deering, Buckland, Shungnak, and Noatak.
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 project scope includes the design and permitting of the following components:
• Confirmation of recommended system sizing (PV, Battery, and Converters) from the HOMER
modeling based on most recent community production data, fuel costs, and expected capital
costs.
• Finalize solar array siting locations.
• Complete permitting applications.
• Develop RFP's for the procurement of Geotech and engineering design and if required,
geotechnical analysis.
• Perform geotechnical analysis on each siting location if required.
• Design Solar PV foundations.
AEA 23001 Page 6 of 45 11116/2021
Renewable Energy Fund Round 14
Grant A pplication-Standard Form
ALASKA
ENERG Y
AUTHORITY
• Designs for upgraded switchgear for Ambler, Kiana , Noorvik, Selawik in conjunction with
AVEC.
• Design Battery bui lding and foundation .
• Compl ete electrical and controls integration design including integration with the switchgea r in
the community power plants , includ ing a remote monitoring system to record data , evaluate
system performance , and aid in remote troubleshooting .
• IPP Ownership model, Business Plan , and Power Purchase Agreement.
• Matching local in-kind funds from the NAB and NANA will provide grant/project management,
technical support , and community outreach and engagement.
2 .6 Previous REF Applications for the Project
See Section 1.15 of the RFA for the maxi mum Qer Qroject cumulative grant award amount
Round Title of a pplication Application Did you Am o unt of REF
Submitted #,if known re ceive a grant awarded
grant? Y/N ($)
None
I SECTION 3 -Project Management, Development, and Operation
l 3.1 Schedule and Milestones
Please fill out the sc he dul e be low (or atta c h a similar s heet) for th e wo rk co ve re d by thi s funding
request. Be sure to identify ke y tas k s and decis ion points, inclu d in g go/no go decision s, in your
project al o ng wi th e stimated sta rt and end dates for ea c h of the mile stone s a nd tasks. Please
clearly identify the beginning and ending of all ph a ses (1. Re connai ss an ce, II. Feasibility and
Concept ual De s ign , Ill. Final Desig n and Permitting , and IV. Construction) of your proposed
project. See the RFA, Sec tions 2 .3-2.6 for the recomme nded mil es tones for e ach ph ase. Add
additional rows as needed .
Task Start End
# Milestones Tasks Date Date Deliverables
1.1 Gra nt Ag ree ment in • Sig ned Ag reement
pl ace 8/1/22 9/30/22
2.1 Co ntractor se lection • Develo p RFP for • RFP's with a detailed scope
and awa rd engineerin g of services based o n syste m
services , Geot ech , pe rformance need s.
and perm itting • Final sig ned co nt racts
technica l support
• Fo rm se lecti o n
co mmittee pe r N AB
reg ulati ons an d
se lect contract ors
• Award Contracts 10/1122 11/30/22
2 .2 Confirma tion of syste m • Co nfir m PV , Batte ry • Detailed Scope of work
compo nent sizi ng from and Conve rte r sizing
HOMER m odeli ng, site recomm endat io ns
contro l , an d develop fo r each community
RF P fo r Eng in eerin g based on most
recent AVE C 12/1/22 1 1/3 1/23
AEA 2300 1 Page 7 of 45 11/16/202 1
Renewable Energy Fund Round 14
Grant Application-Standard Form
production data , fuel
costs, and Capital
costs.
• Confirm solar array
sitinQ locations.
•
3.1 Final Design and • Provide technical
Permitting support and facilitate
community
involvement in the
design process.
• Develop Designs
and conduct design
reviews at 65% and
95%.
• Complete permit
applications -NAB
Title 9 Planning
Permit; FAA Glint &
Glare Review;
confirm wetlands
and floodplain
avoidance; NEC
compliance/PE,
critical habitat,
SHPO
• Final acceptance of
construction ready
designs
• stamps
3.2 Business Plan • Develop detailed
cost estimate and
fuel displacements
for each community
and conduct
economic analysis.
• Develop Ownership
model and PPA with
AVEC
4 .1 Grant Close-out • Prepare and submit
final reports
I 3.2 Budget
3.2.1 Funding Sources
•
•
•
•
•
•
2/1/23 10/31 /23
•
•
•
•
8/1/23 10/3 1/23
•
11 /1/23 12/31 /23
ALASKA
ENE RGY
AUT HO RI TY
Meetings notes from
community engagement
65% and 95% design review
notes
Final permit applications
Final acceptance letters
Construction-ready design
packages
Detailed Cost Estimates
Economic Analysis
PPA
Ownership model and O&M
plan
Submittal of final project
report and close-out
documentation
Indicate the funding sources for the phase(s) of the project applied for in this funding request.
Grant funds requested in this application $590,000
Cash match to be provideda $0
In-kind match to be provideda $34,000
Energy efficiency match _providedb $0
Total costs for project phase(s) covered in application (sum of $624,000
above)
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.
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Renewable Energy Fund Round 14
Grant Application-Standard Form
ALASKA
ENERGY
AUTHORITY
$17,756 of match will be provided by NAB in the form of in-kind for grants management , technical
support. and community outreach and engagement for involving community champions in the
design process . $16,244 in-kind match will also be provided by the NANA Regional Corporation
(NRC) Energy Program for technical support and the development of the Business Plan .
Both sources of match are already secured as both NAB and NRC have existing Energy Programs
and staff that will devote their time to this project. NRC 's Letter of Commitment is included in the
attachments. and NAB's commitment is in the Resolution . Additional funds would accelerate this
project if they were sufficient to consummate construction, but the overall approach here is to
aggregate/bundle projects to achieve economies of scale and cost savings, so a significant
amount of additional funds would be necessary at this design and permitting phase. Once the
projects are shovel ready-at the completion of this proposed phase of the project-then the
aggregated construction budget will be levera_g_ed for all four projects.
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.
NAB has 3 high penetration solar, battery, diesel hybrid systems in operation (Buckland, Deering ,
Shungnak) and has one system in the design and construction phase (Noatak). The NAB and
NANA have also contributed funds and expertise to the high penetratio n solar PV array in
Kotze bue . Based on this experience, we are confident in our cost estimates to complete the work.
however, the pandemic has complicated the supply chain of engineering services. If there is a
shortfall in funding, the communities will request additional funding through the NAB 's Village
Improvement Fund, and the NRC Energy Program has also committed to providing additional
resource s to fill any funding needs. The Village Improvement Fund is targeted for capital matching
funds exclusively for NAB communities and has been successfully leveraged for all of the above
projects and many others, resulting in the statewide leade rship around energy initiatives in the
NAB/NANA region .
3.2.3 Total Project Costs
Indicate the anticipated total cost by phase of the project (including all funding sources). Use actual
costs for completed phases. Indicate if the costs were actual or estimated.
Reconnaissance [Actual/Estimated] $0
Feasibility and Conceptual Design [Actual/Estimated} $ completed at no
cost by ANTHC and
DeerStone
Consulting -see
attachments
Final Design and Permitting [Actual/Estimated} $624,000
Construction [Actuai!Estimatedl $8,712,850
Total Project Costs (sum of above) Estimated $9,336,850 -
from HOMER
modeling
Metering/Tracking Equipment [not included in project Estimated $0
cost]
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 likel ihood of receipt of those funds.
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Renewable Energy Fund Round 14
Grant Application -Standard Form
• State and/or federal grants
• Loans, bonds , or other financing options
• Additional incentives (i.e. tax credits)
ALA SK A
ENERG Y
AUTHORITY
• Additional revenue streams (i.e. green tag sales or other renewable energy subsidies or
programs that might be available)
Funding for the construction of the high penetration solar, battery, diesel hybrid systems will be
required in future years. With the infusion of fund ing into Alaska from the Federal government,
NAB, NANA, and the communities will be pursuing funding through the USDA High Energy Cost
Grant Program , the Department of Energy-Indian Energy renewable energy programs, and the
Denali Commission . The regional team is also closely monitoring new funding opportunities
through the American Rescue Plan and any potential infrastructure funding . By bundling the
construction of four projects as a package, NAB will also be pursuing New Market Investment Tax
Credits that usually have a minimum project size of $5 million to participate in the program .
Bundling the projects will allow NAB to reach the minimum size. We have also enlisted the support
of Launch Alaska to assist with financing the full construction projects, which could take the form of
leveraging tax credits, angel or impact investors, green tag or carbon credit sales, and/or
conventional financing .
The Red Dog Mine contributes a Payment in Lieu of Taxes (PIL T) to the NAB annually, which
provides the majority of government revenue , including a recently created Village Improvement
Fund (VI F) that invests in infrastructure and community development initiatives to promote the
health and well-being of NAB residents and communities . VIF funds have been used in some
communities to develop clean energy infrastructure and we expect that Ambler, Kiana , Noorvik,
and Selawik will utilize VIF revenues to provide cost-share and leverage the construction of these
projects along with managing any cost overruns. NANA also periodically provides funds to
individual villages in the region that may be utilized as match for other construction funding of
capital projects.
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, Ill.
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
, 1 'L-. , \' u 1 ', J. or by phone at (907) 771-3081 .
Phase 3-Final Design and Permitting
Source of
Matching
Anticipated Grantee Funds:
RE-Fund Cash/In-Milestone or Task Completion Grant Funds Matching kind/Federal TOTALS
Date Funds Grants/Other
State
Grants/Other
(List milestones based on $ $ $ phase and type of p roject.
AEA 23001 Page 10 of45 11116/2021
Renewable Energy Fund Round 14
Grant Application -Standard Form
See Sections 2. 3 thr u 2. 6 of
the RFA)
Grant Agreement in place $
Contractor se lection and $10 ,000 award
Final Desiq n and Permittinq $533,456
Confirmation of system
component sizing fro m
HOMER mode ling , site control , $41 ,544
and develop RFP for
Engineering
Business Plan $
Grant C lose-out $5000
$
$
$
$
$
TOTALS $590 ,000
Budget Categories:
D ire ct L abor & Benefits $
Travel & Per Diem $
Equipme nt $
Materials & S upp li es $
Contractual Services $590 ,000
Construction Services $
Other $
TOTALS $590,000
3.2 .4 Cost Justification
$1000 In-kind
$6000 In-kind
$5000 In-kind
$3756 In-kind
$16,244 Other
$2000 In-kind
$
$
$
$
$
$34 ,000
$17 ,756
$
$
$
$
$
$16 ,244
$34 ,000
ALASKA
ENERGY
1\UTHORITY
$1000
$16 ,000
$538,456
$45 ,300
$18,244
$5000
$
$
$
$
$
$624 ,000
$
$
$
$
$
$
$
$624 ,000
Indicate the source(s) of the cost estimates used for the project budget, including costs for future
phases not included in this application.
The design costs estimate for this project was comp leted by the NAB project team based on recent
experience from the design and installations of the h igh penetration projects in Deering, Buckland,
Kotzebue , Shungnak , and Noatak, and with input from design and constructions partners on
previous projects including Hitachi (formerly ABB) and Ala s ka Native Renewable Industries.
Anticipating an eco nomy of scale with the design of four systems, we reduced the anticipated cost
of individual designs by about 30%. See the detailed capital budget in the Appendix.
I 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?
Progress will be measured based on a project charter with a timeline, milestones , and a
responsibility matrix to identify deficiencies before they impact project deliverables. We will also
have quarterly project meetings that include the AEA project manager to ensure tasks are being
performed according to the agreed-upon timeline and budget. The NAB Project Manager will
provide quarterly progress reports to NAB leadership and AEA that will detail the progress versus
plan and any remediation plans to address deficiencies . Our intent is to include the AEA project
manager as an active member of our design team to incorporate their knowledge and experience
in the successful project. NAB and NRC Energy Project Managers will be in regular contact with
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Grant Application-Standard Form
ALASKA
EN ERGY
A UTH ORITY
each other, the communities, and AVEC, as they already have activities in all the region 's
communities, and this will facilitate status monitoring
I 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 .
The NAB Finance Department consists of a treasurer, controller, accounting assistant, and
specialized contractor. The Finance Department utilizes Caselle accounting software . This is a
fund accounting platform that is used by over 1,200 municipal, county, and service districts
nationwide and is used to provide monthly financial reports to the Borough Assembly and track all
expenditures and revenues. The NAB undergoes a financial statement and single aud it annually.
Our Finance Department will manage all financial transactions associated with the grant and will be
responsible for monthly financial reporting to the NAB Mayor and Assembly and quarterly financial
reporting to AEA and other project partners. Current financial statements and other financial
information are available upon request. The NAB Finance Department is very familiar w ith state
and federal grants and manages millions of dollars annually.
In accordance with NAB policy, when a project is funded, an account and object account code is
created to track all materials and time related to that project. This is organized so that matching
and grant funds are properly accounted for. The grant agreement is reviewed in detail with the
accounting team at the beginning of the project to ensure that only eligible and reasonable costs
are billed to the grant.
From a procurement standpoint, NAB will select contractors following all NAB and federal
procurement rules, including those found in 7 CFR part 1709 and 2 CFR part 200. NAB will be
seeking contractors that have demonstrated success, expertise, and commitment to this type of
project in our region and its unique circumstances.
I 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.
Ingemar Mathiasson, NAB Energy Manager, works within the NAB 's Economic Development
Department. He will be the Project Manager and oversee all aspects of the project. He has
developed and managed renewable energy and energy efficiency projects in all 11 communities
within the Borough and has been the Project Manager for successful solar, battery, and diesel
hybrid systems in Buckland , Deering, Shungnak, and Noatak, along with biomass construction
project in Ambler. Mr. Mathiasson will also ensure community engagement and outreach in all
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villages . This will be coordinated with the Northwest Arctic Energy Steering Committee education
and outreach efforts for the region .
Mr. Mathiasson can be reached at 907-445-2031 and imathiasson@nwabor.org
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.
Angie Sturm has been the NAB Treasurer since 2016 . Ms. Sturm received her Bachelor of
Business Administration degree in Accounting and Management from the University of Alaska
Anchorage. Before accepting her position at the Borough , Angie was an Auditor for KPMG , LLP-
an international accounting firm with offices in An c horage . She will oversee all f inancial
transactions and financial reporting associated with this project, providing appropriate information
to AEA the NAB Assembly and Mayor.
I 4.1.3 Expertise and Resources
Describe the project team including the applicant, partners , and contra ctors.
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 c apacity to successfully select contra ctor s and manage complex
contracts .
Ingemar Mathiasson -NAB Energy Manager since 2009. Originally from Sweden , Mr. Ma t hia sson
has lived in Ala s ka since 1987. He built and live s in an off-the-grid homestead outside of Ambler,
complete with wind and solar power, batteries , and biomass for heating . He is a member of the
Board of Directors of the Renewable Energy Alaska Project (REAP) and has overseen more than
$15 million of renewable energy construction projects around the Borough in all 11 communities .
He will be the main Technical Contact on this project and will report to the NAB Economi c
Development Dire ctor and the Finance Department. He will manage the subcontractors and
coordinate communication with all project partners. Mr. Mathiasson will be the key contact for
design contractors and will lead the business plan development and community education and
outreach in all villages . Outreach work will be coordinated with the Northwest Arctic Energy
Steering Committee (NAESC) education and outreach efforts for the region . The NAESC is a
regional collaborative that has been leading the development of energy plans for more than 12
years in the NAB, guided by the goals of reducing energy costs and improving energy resilience as
the top priorities of the region .
Sonny Adams -NANA Regional Corporation (NRC) Director of Energy Programs . Mr. Adams has
been involved in all aspects of village energy development with NANA communities s ince 2007 . He
has served on the US Department of Energy "Indian Country Energy and Infrastructure Working
Group" and is currently managing the USDA HECG solar-wind-battery-diesel integration projects in
Buckland and Deering. Mr. Adams, a NANA shareholder originally from Kotzebue, has a Bachelor
of Science in Metallurgical and Materials Engineering from the University of Montana . He will
continue to lead NANA's contribution on this proposed initiative through collaboration with all
project stakeholders especially in relation to the IPP , training and techni ca l assistance , co mmunity
outreach and education , contractor support, and leadership within the NAESC.
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Brian Hirsch -DeerStone Consulting Founder and CEO . Dr. Hirsch worked in rural Alaska and
other remote locations on diesel-based renewable energy microgrids for over 25 years. Prior to
founding DeerStone, he served as an elected Board Member for Homer Electric Association, the
rural Electric Cooperative in his Alaska community; led the National Renewable Energy
Laboratory's Alaska Initiative for over six years; worked across Southeast Asia, Canada, lower 48
US, Mexico, and Central America ; and consulted for numerous non-profits and Tribal
organizations . He has a PhD in Natural Resources with a Master's Certification in Energy Analysis
and Policy from the University of Wisconsin-Madison and a bachelor's degree in
GovernmenUPolitical Science with three years of Electrical Engineering coursework from Cornell
University. DeerStone Consulting will continue to provide technical support to this project under
NRC. Project support will focus on the solar installation , battery and grid integration, and build ing
community capacity to manage projects in addition to developing the financial and organizational
structure for the IPP agreement.
Leah Lansdowne is a licensed Mechanical EIT, who completed her bachelor's in Mechanical
Engineering with a focus on renewable energy at the University of New Haven in Connecticut in
2019 and holds a prior bachelor's degree in Chemistry from Williams College . At DeerStone, she
has experience with microgrid controls , wind and solar productio n optimization , system
troubleshooting , telecommunications, the development of community energy action plans, and
system feasibility. Leah also has experience in reliability engineering , working with asset
management systems to develop and maintain maintenance records for the manufacturing facil ity
of a multinational pharmaceutical company in Bend , Oregon. She has also worked at municipal
utilities, includ ing the City of Bend Water Department, where she worked with water plant operators
to develop operational guides for the City water system . Her project management experience
includes lead ing a team of peers to design an air-filtration system for use in NASA spaceships . She
is proficient in Blue Mountain Regulatory Asset Manager (CMMS), Solidworks, and Hach WI MS.
Her previous professional endeavors include commercial fishing and natural building construction.
Engineering and Permitting support firms will be selected through a competitive procurement
process and will be selected based on their experience and technical expertise with s imilar projects
in remote Alaska . A scoring matrix will be developed during the procurement process , and the AEA
project manager will be invited to participate on the selection team .
4.2 Local Workforce
Describe how the project will use local labor or train a local labor workforce.
As with the recent solar PV projects that have been completed in NAB, local labor and capability
development will be a significant goal. The Shungnak high penetration solar and battery system
was constructed with a crew made up of about 90% local and Native members. We plan on
utilizing this experienced regional labor force on future construction proj ects and will actively train
additional crews in the solar PV installation skills .
Additionally, sustainability education and hands-on solar trainings will also be provided for
community members for future installation of the systems , in addition to the training provided to
locally hired laborers . This workforce training is already incorporated in other related projects we
are implementing including the upcoming Noatak high penetration solar PV and battery system.
Energy community champions have already been engaged in energy development through the
NAESC, and these champions will be engaged during the design process to e xpand their energy
education and provide community specific feedback on the designs . We will also use this project
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as an opportunity to recruit new energy champions and develop our next generation of NAB energy
leaders.
I SECTION 5-TECHNICAL FEASIBILITY
I 5.1 Resource Availability
5.1 .1 Assessment of Proposed Energy Resource
Describe the potential ex tent/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 des ign and permitting or construction projects , please provide feasibility
documents, des ign documents , and perm itt ing 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 Che cklist for additional
guidance .
The follow ing figure of Solar Insolation in Alaska was developed for the report "Solar Energy
Prospecting in Re mote Alaska -An Econo mic Analysis of So lar Photovoltaics in t he Last Frontier
State" by Paul Schwabe , National Renewable Energy Laboratory U.S. This report shows that the
Arctic and Interior regions of Alaska could e x pect high solar production predominantly from March
through August, with a steep drop off in the shoulder months and little to no product ion in the
winter. Most communities in the NAB a have an estimated value of 3.4 kWh/m2/Day for solar
insolation . Operating projects in Deering and Buckland are performing with a capacity factor of
almost 11%. Other e xisting solar PV projects in the region have affirmed the solar resource
availability and capacity factor value .
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> 4 .0
3.7) to 4.0
3.5 rc 3.75
1.!"> to 1S
3.0 IC 3.25
?.7 5 to 3.0
J 2.50 to 2.75
VS to 2.50
< 2.2 5
"
5.1.2 Alternatives to Proposed Energy Resource
:· ,,,
ALASKA
ENE RGY
AUTHORITY
"' 1 l , •trr
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.
Energy planning has been at the forefront of the NAESC's objectives during the last 10 years of its
existence. In that time , the region has installed many energy systems including heat recovery
systems, heat pumps, wind turbines , behind the meter solar systems , community scale solar and
battery systems, and wind, solar PV, battery, and diesel hybrid systems, along with develop ing the
first Power Purchase Agreement with AVEC. We have also focused on feas ibility studies of
interties between communities and potential hydroelectric projects . The region has been very
active in energy efficiency improvements. One of our key learnings is that solar PV is a good first
step for a community into operations and maintenance of renewable energy systems . It is the
easiest technology to maintain as the communities learn the requirements of operating and
maintaining energy systems along with partnering with incumbent utilities .
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1\UTHORI~Y
For this project, 8 different options were considered and evaluated based on our primary goals to
reduce the reliance on expensive diesel fuel and the costs of generating electricity in our
communities :
• Option 1: Do nothing
• Option 2 : Do minimum, Grid-tied Solar Power (up to utility limit)
• Option 3: Install a Solar Photovoltaic (PV) Array with a Battery Energy Storage System
• Option 4: Energy Efficiency
• Option 5: Biomass
• Option 6: Powerline lnterties between communities
• Option 7 : Wind Turbines
Option 1 was eliminated because doing nothing will not reduce our reliance on diesel. Option 2
was also eliminated because of our desire to achieve significant diesel re ductions and to work with
our partner AVEC and the utility limit with low penetration is only a minimal amount of renewable
production or fuel savings . Option 4 will continue to be a priority within our communities with a
focus on energy efficiency improvements for heating systems . Most impactful electrical energy
efficiency improvements have been completed in our communities. Regarding Option 5 , biomass
systems have been installed in Ambler and Kobuk, our two communities with good wood
resources . Feasibility studies for wood heating in other NAB communities have not resulted in
recommended systems. Options 6 and 7 are still under consideration for a future intertie between
Noorvik and Kiana that could be coupled with a wind system. This project is still in the pre-
feasibility stage and will not be ready for design and construction for many years . Wind turbines in
the other communities are a lso not viable at this time . A Solar PV, Battery, Diesel Hybrid System
was the most logical project for Ambler, Kiana , Noorvik, and Selawik community scale renewable
energy systems at this tim e, and combining the projects was determined to provide sign ificant
additional cost savings .
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 app ropriate
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
The following permits are required for a Solar PV installation:
• NAB Title 9 Planning Permit
• FAA Glint & Glare Review if potential interference with aviation traffic
• Analysis of wetlands and floodplain avoidance
• NEC compliance/PE stamps
• Consultation with State Historica l Preservation Office
• Critical Habitat avoidance
The permitting consultation s and applications will start as soon as the locatio ns of the PV arrays
are finalized . The permitting is expected to take 6 months to complete and is shown in the project
timeline . Contractors with appropriate expertise will be selected through a competitive RFP process
to lead the pursuit of these permits. NRC also has engineering subsidiaries who can help, in
AEA 2300 1 Page 17 of45 11 /16/20 21
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particular with the analysis of wetlands and floodplain avoidance , as they work on similar issues for
the Red Dog mine in the region.
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.
Preliminary sites were identified during the feasibility phase of the project and land ownership was
researched . Two to three locations were identified in each community that will meet the needs to
support the installation of solar arrays from a size , soil condition constructability, ownership,
location near power lines, r;ninimal obstruction, and permitting standpoints. It is expected that there
will be no additional site control needs for power line access. The site locations will be f inalized as
one of the first critical path tasks of the design phase of this project and will include public input into
the selection process. Because of Covid , the site selection has been delayed in terms of in-person
community meetings . All identified sites are owned by either NRC, individual City government for
the proposed project, or AVEC . All of these entities are supportive of the proposed project and
have submitted letters of support that will allow for site control of the eventual locations. Most of the
other solar PV projects in the region have utilized NRC lands.
j 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 c hallenging?
• How w i ll the project team reduce the risk of these tasks?
• What internal controls will be put in place to limit and deal with tec h nical risks?
See the "Common Planning Risks" section of the appropriate Best Practice Che ckl ist for additiona l
guidance.
NAB does not foresee any maj or technical risks for completing the Final Design and Permitting of
this project. The main technical aspects and potential challenges of final construction of these
projects will be considered in the design process and include: 1) Permafrost soils supporting
ground mounted racking for solar PV panels; 2) Integration of battery energy storage system ,
power conversion system for grid forming inverter, and system controls/dispatch ; and 3)
Challeng ing logistics in a remote location. All of these issues have been addressed and resolved in
similar projects in nearby communities, but each project has unique si te-specific c ircumstances. All
of the proposed equipment for this project is commercialized technology. Act ual systems for
consideration must be "flight proven" through s uccessful installations, ongoing co mmercial
performance in comparable field conditions , and covered by well established companies providing
commercial warranties .
To control these risks, the project team will conduct thorough geotechnical analysis of the s iting
locations to minimize impact to permafrost. The team will apply lessons learned from recent similar
installations and include extended commercialization technical support in vendor contracts to
assure that the integration control systems are optimized . The project team wi ll address the
challenging remote logistics by hiring ex perienced construction contractors and planning e xtra time
in the project schedule to allow for logistical issues .
Another technical risk in the past that has been successfully addressed is electrical integration of
new equipment into legacy infrastructure. This has been resolved with AVEC infrastructure through
upgraded switchgear and generator controls , and these lessons w ill be applied to the proj ects
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proposed here. Specifically, the solar PV and battery hybrid system recently installed in Shungnak,
and the one soon to be installed in Noatak, are designed to work with AVEC 's switchgear and
ComAp generator controllers , and any future microgrids will be required to be compatible with this
hardware and software . We have been particularly impressed with the performance of the Ageto
microgrid controller and its compatibility with AVEC 's switchgear and generator controls. We would
expect similar hardware and program software for future systems.
5.3 .2 Environmental Risk
Explain whether the follow ing 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 Practi ce Checklist for additional guidance.
• Threatened or endangered species
• Habitat issues
• Wetlands and other protected areas
• Archaeological and historical resources
• Land development constraints
• Telecommunications interference
• Aviation considerations
• Visual , aesthetics impacts
• Identify and describe other potential barriers
The initial environmental survey in the feasibility phase of the project did not identify any serious
concerns . Permit applications will be a deliverable of this project scope and will address the
following areas:
• Threatened or Endangered species· The U.S. Fish and Wildlife Service will be consulted to
ensure that the construction of the PV panels will have no harmful impact on threatened or
endangered species .
• Habitat issues-During the permitting process , the project team will consult with the required
agencies to avoid any impact to critical habitat, refuges , wilderness areas, and other
sanctuaries.
• Wetlands and other protected areas -The Corp of Engineers will be consulted on any need
for wetlands permits or remediation.
• Archaeological and historical resources -The State Historic Preservation Office will be
consulted for complia nce with the National Historic Preservation Act during the design process .
• Land development constraints -Site control will be a key deliverable of this project.
• Telecommunications interference-No potential issues identified . Any concerns will be
addressed in the project design.
• Aviation considerations -Consultation with the Federal Aviation Administration will be
required for a Determination of No Hazard to Air Traffi c.
• Visual, aesthetics impacts -Community meetings will be conducted to discuss visual impact
concerns for each location .
• No other potential barriers have been identified.
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 .
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5.4.1 Basic Operation of Existing Energy System
ALASKA
EN ERGY
.A UTH O RIT Y
Describe the basic operation of the existing energy system including : description of control system ;
spinning reserve needs and variability in generation (any high loads brought on quickly); and
current voltage, frequency, and outage issues across system. See the "Understanding the Existing
System" section of the appropriate Best Practice Checklist for additional guidance.
The existing diesel power plant in Ambler consists of three generators: a 363 kW Detroit Diesel
Series 60, a 271 kW Cummins K19G2, and a 397 kW Cummins K19G2. These generators were
installed in 2002 , 1993, and 1990 respectively. Aggregate generator efficiency in Ambler in 2020
was 12 .66 from the annual PCE report. The peak load in 2020 was 260 kW with an average load of
142 kW. Spinning reserve is provided by a second gen-set, and there are currently no voltage,
current, or recurring outage issues within Ambler.
The existing diesel power plant in Kiana consists of three generators: a 324 kW Detroit Diesel
Series 60, a 363 kW Detroit Diesel Series 60, and a 499 kW Cummins K19G2 . These generators
were installed in 2020, 2019, and 2000 respectively. Aggregate generator efficiency in Kiana in
2020 was 14.4 kWh/gal from the annual PCE report. The peak load in 2020 was 337 kW with an
average load of 194 kW . Spinning reserve is provided by a second gen-set, and there are currently
no voltage, current, or recurring outage issues within Kiana .
The existing diesel power plant in Noorvik consists of three generators: a 363 kW Detroit Diesel
Series 60, a 499 kW Cummins K19G2, and a 710 kW MTU. These generators were installed in
1997, 2016, and 2003 respectively . Aggregate generator efficiency in Noorvik in 2020 was 13.78
kWh/gal from the annual PCE report. The peak load in 2020 was 329 kW with an average load of
228 kW. Spinning reserve is provided by a second gen-set, and there are currently no voltage ,
current , or recurring outage issues within Noorvik. Noorvik also has a small 23 kW solar array
installed.
The existing diesel power plant in Selawik consists of three generators: a 499 kW Cummins QST, a
499 kW Cummins QSX, and 900 kW Cummins K38G4. These generators were installed in 2020,
2019, and 2014 respectively. Aggregate generator efficiency in Selawik in 2020 was 13.85 kWh/gal
from the annual PCE report. The peak load in 2020 was 612 kW with an average load of 319 kW.
Spinning reserve is provided by a second gen-set, and there are currently no voltage , current, or
recurring outage issues within Selawik .
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 e xtra
tables . If you have the data below in other formats , you can attach them to the application (see
Section 11 ).
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
Please refer to the attachment AVEC Fleet information for Ambler, Kiana, Noorvik, and
Selawik.
Is there operational heat recovery? (Y/N) If yes estimated
annual displaced heating fuel (gallons)
AEA 23001 Page 20 of 45
Yes-Noorvik -18,600 gal , Selawik-
9,200 gal, Ambler-8,800 gal, Kiana-
4,500 gal. There will be small impacts
11 /16/2021
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Grant Application-Standard Form
ALASKA
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y.,
5.4.2 .2 Existing Distribution System
d u ri ng the shoulder seasons t hat will
be quantified d u ring the design phase.
These projects are not expected to
have significant impacts to the heat
recovery systems because the
majority of diesel-off ti me will be
during the summer months.
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.
All four d istribu tion systems are very similar in the communities. Ambler, Kiana, Noorvik and Selawik
all generate at 496 V and step up to 7200 V for distribution .
The following information su mmaries the transform e rs in each community:
Ambler -switch 1: 3 ea 75kVA, switch 2: 3 ea 50kVA, switch 3: 3 ea 75 kVA
Kiana-switch 1: 3 ea 75kVA , switch 2: 3 ea 100 kVA, switch 3: direct 496V feed to waste treatment
plant
Noorvik-switch 1: 3 ea 100 kVA, switch 2: 3 ea 37 .5 kVA, 1 ea 100kVA listed as spare
Selawik -breaker 1: 3 ea 167kVA, breaker 2: 3 ea 167kV A, breaker 3: 3 ea 75kVA, 3 ea 100 kVA
at wind turbine site
5.4.2.3 Existl!!.g Thermal Generation Units _(jf a ol!_/icable to lfour project)
Generation Resource/ Design Make Model Average Year Hours
unit Fuel type capacity annual Installed
(MMBtu/hr) efficiency
N/R
5.4.2.4 O&M and replacement costs for Po w er Generation Thermal
exi sting u n its Generation
i. Annu al O&M cost for labor Pos tage stamp Rate -$140 ,000 per
Power Plant for Labor and non-
labor
ii. Annual O&M cost for non-labor See above
iii. Replacement schedule and cost for O il Change at 500 hrs-$140
ex isting un its Tune-up at 3000 hrs-$2400
Top end at 10,000 hrs -$8600
Overhaul at 20,000 hrs -$40-
55 ,000
Replacement at 100,000 hrs
See attachm ents for details
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I
. Use most recent year. Replace the section (Type 1 ), (Type 2), and (Type 3) with generation
sources ------------------------------------------
Ambl e r
Generatio Generatio Generatio Fuel Fuel
n (Diesel n(Type n(Type Consump Consump
Peak Minimum Month Genset) 2) 3) tion tion
Load Load
(kWh) (kWh) (kWh) (Diesel-[Other] Gallons)
January 137,457 9 ,540 212 162
February 123,478 8 ,803 260 163
March 129,271 9 ,245 244 14 8
April 104,075 7,684 215 131
May 83,241 6 ,515 207 105
June 79,176 6 ,283 176 93
July 68,919 5,553 158 89
August 84,054 6 ,658 190 98
September 88,150 6 ,697 124 109
October 99,546 7,150 223 122
November 120,6 54 8,398 241 136
December 134,688 17 ,6 29 220 154
Total 1 ,252,709 100,155
Kiana
Generatio Generatio Generatio Fuel Fuel
n (Diesel n(Type n(Type Consump Consump
Peak M inimum Month Genset) 2) 3) tion tion
Load Load
(kWh) (kWh) (kWh) (Diesel-[Other] Gallons)
January 189,494 14 ,252 329 228
February 164,673 12 ,740 282 208
March 159,942 12,111 245 185
April 135,549 10 ,886 215 163
May 106,340 7,737 177 135
June 107,615 7,854 166 129
July 100 ,225 7,451 187 107
August 114,121 8,293 172 134
September 122,230 8,887 280 153
October 139 ,240 10,099 273 15 7
November 160,493 11 ,029 337 192
December 183,6 56 3,138 265 21 8
Total 1,683,578 114,477
Noorvik
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Generatio Generatio Generatio Fuel
n (Diesel n (Solar n(Type Consump
Month Genset) PV) 3) tion
(kWh) (kWh) (kWh) (Diesel-
Gallons)
January 215,836 68 15,093
February 205,870 493 14,380
March 199,891 1,557 14,201
April 152,091 1,851 10,572
May 124,626 2,205 8,662
June 120 ,638 2 ,132 9,122
July 114,173 1,423 8 ,036
August 128,387 1,519 9 ,054
September 140,052 699 9,600
October 163,106 321 11 ,315
November 192,480 87 14,378
December 215,356 1 18,007
Total 1,972,506 142,420
Selawik
Generatio Generatio Generatio Fuel
n (Diesel n(Type n(Type Consump
Month Genset) 2) 3) tion
(kWh) (kWh) (kWh) (Diesel-
Gallons)
January 355676 25,179
February 326486 22,687
March 319556 22,977
April 246344 18,468
May 168962 12,682
June 152206 12,213
July 149014 11 ,359
August 185033 13,893
September 187692 14,090
October 230110 17,941
November 287380 20 ,397
December 295905 16,399
Total 2,904 ,36 4 208 ,285
5.4.3 Future Trends
Fuel
Consump
Peak tion
Load
[Other]
329
284
215
190
184
2 12
206
247
263
295
280
296
Fuel
Consump
Peak tion
Load
[Other]
612
563
565
421
277
265
290
259
322
457
451
486
ALASKA
ENER GY
,\UTHORITY
Minimum
Load
262
269
223
186
15 0
144
148
159
168
195
223
243
Minimum
Load
428
430
353
27 1
199
197
188
199
237
256
317
376
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.
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AU T HORITY
Population trends in the region have been relatively stable since the 201 0 census. The population of
Amber has increased by 1.55%, and the population of Kiana has increased by 7.48%. Selawik's
population was stable, and Noorvik's population decreased by 1.95%. Because of these population
trends , electric usage is not expected to change significantly. High energy costs have led to a focus
on energy conservation , and th is is not expected to change without significant reduction in energy
costs. While this project will slightly reduce rates, it is not expected to reduce rates enough to change
usage behaviors . As a result, significant load growth is not expected in any of the impacted
communities.
The NAB has been supporting the installation of heat pumps in residential and community buildings
throughout the region for the last 5 years . To be cost effective for consumers, these systems must
be managed so electrical usage stays within the 500 kWh per month PCE allotment.
Because of the ease of operations and maintenance of solar PV systems, high penetration solar PV,
when seasonally available, will continue to be the technology of choice for interior communities
without large hydroelectric or wind resources .
5.4.4 Proposed System Design
Provide the following information for the proposed renewable energy system :
• A description of renewable energy technology specific to proj ect 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 Pra ctice Checklist for additional
guidance.
The proposed project is a high penetration distributed solar-battery hybrid system that will be
connected to the local village electric grid . Each system will be sized to maximize the diesels-off
potential during the months of highest solar availability using HOMER software . The feasibility
modeling has identified the following PV array sizes for each community. The sizes of this
equipment will be optimized in the final design . Excess solar generation was not included in the
analysis.
Community Solar PV (Kw) Power Battery Energy
Conversion Storage (kWh)
System (kVA)
Ambler 390 500 384
Kiana 319 500 384
Noorvik 369 500 384
Selawik 430 750 384
The core component of each system will most likely be an ABB or Ageto supervisory microgrid
controller with power electronic inverters and controls, cou pled with a lithium-ion battery, that will
allow for periods of diesels-off operation when there is sufficient solar energy production and /or
adequate charge in the batteries to safely run the entire grid. In our case , this will most frequently
occur for hours at a time between April and August, when there is significant solar availability and
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the total system loads decrease because of warmer temperatures , less need for electric lighting ,
and the local schools close for summer.
An ABBe-mesh PowerStore is shown below . It is a compact and integrated platform with racks
that accommodate various battery manufacturers, a single temperature control , and fire
suppression package to reduce overall installation costs. For each community project, the system
grid controls for diesel generators, solar PV, batteries , and load feeder are controlled by this
system . This is a sample of what could be installed subject to competitive selection.
PowerStore•w Integrated 250/500
Leveraging experience with similar hybrid systems within our region and elsewhere around Alaska ,
this equipment is specifically designed for small isolated microgrids like that found in NAB. Over
the last several years, ABB and Ageto have provided similar "grid-forming" inverters with batteries
that allow for diesels-off operation in numerous remote microgrids around Alaska and elsewhere,
including in nearby Deering , Buckland and Shungnak. Kotzebue Electric Association has ABB
equipment in its powerhouse and local expertise and familiarity with the equipment for regional
support. Though the core power conversion technology is well proven, the supeNisory controllers
are continually improving their programming based on growing experience with micro-grids,
especially their expertise in remote locations across Alaska , Canada, and Australia. Fiber optic or
other digital communications will be utilized to insure proper integration and monitoring between
the solar, battery, and diesel generation assets.
5.4.4.1 Proposed Power Generation Units
Unit# Resource/ Design Make Model Expected Expected Expected
Fuel type capacity capacity life Availability
(kW) factor (years)
Ambler Solar 390 TBD TBD 11.2% 25 95%
Kiana Solar 297 TBD TBD 10.9% 25 95%
Noorvik Solar 358 TBD TBD 10.9% 25 95%
Selawik Solar 398 TBD TBD 10.8% 25 95%
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5.4.4.2 Pro~osed Thermal Generation Units (if a pl{cable) __
Generation Resource/ Design Make Model
unit Fuel type capacity
(MMBtu/hr)
N/A ·-
5.4.5 Basic Operation of Proposed Energy System
Expected
Average
annual
efficiency
ALASKA
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Expected
life
:
:
• 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 add itiona l
guidance .
The operation of these high penetration solar PV, battery, and diesel hybrid systems will be
controlled by a microgrid system integrator. The concept of "system integration" essentially
means overlaying new digital technology on top of a legacy islanded diesel grid and ensuring that
the diesel backbone is fully supported. This requires a supervisory controller to continually monitor
the entire system load to determine the optimal combination of solar PV, diesel generation , and
battery power necessary to meet the load with the least amount of diesel generation but also
ensure that the diesel generator, when running, is at least 30% loaded relative to its generation
capacity to provide grid stability and avoid wet stacking to protect the diesel generator. Other
operating constraints include maintaining battery state-of-charge (SOC) typically between 20-80 %
of total capacity, considering spinning reserve requirements on the diesel generator, and trying to
minimize curtailment of solar output. For example, in a community if the system load is 200 kW, the
smallest diesel is 315 kW, the solar PV is producing 180 kW and the batteries are 20% charged,
the supervisory controller would send a signal to turn on the 315 kW diesel generator to meet the
remaining 20 kW of system load but it would also need to run at higher than 20 kW output. In fact,
the diesel generator would have a low-load setpoint so it could not produ ce power at a rate less
than 94.5 kW (30% of its nameplate rating of 315 kW). The excess power, abo ve and beyond the
20 kW required to meet the system load, would go to charge the batteries. If the system load
stayed at 200 kW and the solar PV output stayed at 180 kW , once the batteries were charged to
80% of their capacity, then the supervisory controller would send a signal to turn off the diesel
generator and meet the entire system load with a combination of solar PV and battery output.
When the batteries dropped in charge, it would dispatch the diesel generator to meet the
difference.
It should be noted that the supervisory controller-the "brains" of the operation-does not di rectly
communicate with any of these generation assets , but rather rece ives inputs, and sends outputs, to
the solar inve rter, the diesel powerhouse switchgear and generator controls, and the battery
management system (BMS), and then these units control the generation assets. This requires
digital compatibility among all parts of the system and a pathway for all of the system components
to communicate d igitally, which can be done through fiber, ethernet, or wirelessly, depending on
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the circumstances . Typically, if the assets are located near each other, fiber or ethernet is
preferred , but in some cases , such as when wind turbines or solar PV arrays are relatively far from
the power plant, wireless communications are necessary. AVEC is in the process of updating the
diesel powerhouse switchgear and generator controls for all of their communities, which is an
essential requirement for proper digital communication and system control. We have been talking
c losely with AVEC to ensure that their new equipment will be digitally compatible with industry
leading power electronics , especially those that are already installed in the region such as SMA
and SolarEdge inverters and optimizers, Woodward easYgen and ComAp diesel generator
controls, Saft and BluePianet BMS's, and ABB and Ageto supervisory microgrid controllers.
5.4.3.1 Expected Capacity
Factor
10.8% to
11 .2%
5.4.5.2 Annual Electricity Production and Fuel Consum~tion (Proposed System) -AMBLER
Month Generation Generation Generation -JFuel Fuel Secondary Storage
(Proposed (Type 2) (Type 3) Consumption Consumption load (kWh)
System) (kWh) (kWh) (Diesel-[Other] (kWh)
(kWh) Gallons)
January 632 TBD in
February 6392 Design
··-
March 26412 Phase
April 51977
May 67863
June 73868
July 67863
August 47391
September 27273
October 12006
November 2324
December 0
Total 384001
5 .4.5.3 Annual Electricity Production and Fuel Consumption (Proposed System)-Kiana ··-Month Generation Generation Generation Fuel Fuel Secondary Storage
(Proposed (Type 2) (Type 3) Consumption Consumption load (kWh)
System) (kWh) (kWh) (Diesel-[Other] (kWh)
(kWh) Gallons)
January 483 TBD in
February 5055 Design
March 20169 Phase
April 38849
May 48058
June 53511
July 50470
August 35898
September 21199
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--=----:--Oct o b er 9071
November 1868
December 0
Total 284632
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--
~.4.5 .4 Annual Electricity Prod_uc!ion and Fuel Consumption (Pr~~sed System] -Noorvik
Mo nth Ge neration Generation Generation Fue l Fuel Secondary Storage
(Proposed (Type 2) (Type 3) Consumption Consumption load (kWh)
System) (kWh) (kWh) (Diesel-[Ot her] (kWh)
(kWhl Gallons)
January 578 TBD in
February 5951 Design
March 24159 Phase
April 46648
May 58607
June 64547
July 60572
August 43001
September 25394
October 10866
November 2125
December 0 -Total 342449 I
5.4.5.5 Annual Electri cit~ Production and Fuel Consumption (Prop osed S~stem) -Selawik
Month Gene ration Generation Generation Fuel Fuel Secondary Storage
(Proposed (Type 2) (Type 3) Consumption Consumption load (kWh)
System) (kWh) (kWh) (Diesel-[Other] (kWh)
(kWh) Gallons)
January 640 TBD in
February 6700 Design
March 26732 Phase
April 51491
May 63696
June 70924
July 66893
August 47 580
September 28097
October 12023
November 2476
December 0
Total 377253
I 5.4.6 Proposed System Operating and Ma intenance (O&M) Costs
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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.
$
I-0-'-I..L...:..plti....:.o-'-n-'2::..:....:.D....:.i'-'-e-'-s-'-e-'-l Q..._le.:...n;..;.e.:....:r....:.a:..:.ti:....:o...:..n....:.O.::....::....F.:....F _____ --l The O&M estimates were developed using the
For projects that will result in shutting down AEA 8/C ratio model. The table summarizes the
diesel generation please estimate: results for each community:
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.
Community Non-Estimated Annual
fuel Hours O&M
Savings Savin~s
Ambler $1500 2060 $20 ,489
Kiana $550 735 $6 ,870
Noorvik $550 729 $7,251
Selawik $145 19 3 $2,929
The non-fuel savings include the O&M savings
in the above table show the savings in diesel
replacement costs. This savings is calculated
using the diesels off hours, typical life of the
AVEC gensets (100 ,000 hrs .), and estimated
gen-set replacement cost ($75,000). See the
Replacement cost details in the Attachments .
The O&M Savings are pulled directly from
AEA's 8/C ratio model.
This application takes a slightly different
approach from the estimated O&M costs from
the AEA recommended rule of thumb of 2% of
capital cost for Solar PV projects. This 2% is
the same recommended estimate for wind
projects, and ex perience in NAB and other
regions of Alaska has shown that Solar PV
O&M costs are significantly less than wind
projects. For our estimates, we use 1% of the
battery capital cost for the battery system O&M .
Industry rule of thumb for Solar PV O&M costs
including panels and inverters and associated
equipment is $10-$20 per year per installed kW .
We used $20 per installed kW for a
conservative estimate. Please refer to the O&M
Costs in the attachments for full O&M
calculations .
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5.4.7 Fuel Costs
ALASKA
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Estimate annual cost for all applicable fuel(s) needed to run the proposed system (Year 1 of
operation)
Diesel Electricity
(Gallons)
Unit cost N/R
(!)
Annual
Units
Total
Annual
cost $) -
5.5 Performance and O&M Reporting
For construction projects only
5 .5.1 Metering Equipment
Propane Coal Wood Other
(Gallons) {Tons
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.
If this project proceeds to construction. each system will be designed with metering equ ipment that
will allow the operator to understand solar PV production , power flowing into and out of the battery,
and battery system station service including HVAC and battery round tri p efficiency. This metering
equipment is standard for all high penetration solar PV, ba ttery, diesel hybrid systems and will be
included in the cost of the construction phase of the project. Typical meters cost about $500 each.
5.5.2 O&M reporting
Please provide a short narrative about the methods that will be used to gather and store reliable
operations and maintenance data. including costs, to comply with the operations reporting
requirement identified in Section 3 .15 of the Request for Applications
If this project proceeds to construction, the following documentation will be collected on a monthly
basis by our finance depa rtment to understand the impac t of the solar PV/Battery systems once they
are operational :
•
•
•
kWh produced by the Solar PV
Diesel fuel usage in the power plant
Cost of diesel fuel //:
I
Battery round Trip Efficie ncy
Diesels-off hours
• Battery station service
• Maintenance and Material Costs
• AddWonallaborhouffi
This information will be repo rted annually to AEA in the required format.
I SECTION 6-ECONOMIC FEASIBILITY AND BENEF ITS
I 6 .1 Economic Feasibility
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I 6.1.1 Economic Benefit
Annual
Anticipated Diesel Fuel Displaced for Power Ambler-23,869
Generation (gallons) Kiana-21 ,979
Noorvik -26,223
Selawik-30,028
Anticipated Fuel Displaced for Heat
(gallons)
Total Fuel displaced (gallons) Ambler-23 ,869
Kiana-21,979
Noorvik -26,223
Selawik-30,028
Anticipated Diesel Fuel Displaced for Power YEAR 1
Generation ($) Ambler-$160,815
Kiana-$80,248
Noorvik -$93,880
Selawik -$107078
Anticipated Fuel Displaced for Heat($)
Anticipated Power Generation O&M Cost Ambler -$20,489
Savings Kiana -$6,870
Noorvik-$ 7,251
Selawik-$2 ,925
Anticipated Thermal Generation O&M Cost
Savings
Total Other costs savings (taxes, insurance, Ambler-$1500
etc.) Kiana-$550
Noorvik -$550
Selawik -$145
Total Fuel, O&M, and Other Cost Savings Ambler-$186,655
Kiana -$87,668
Noorvik-$101,681
Selawik-$110,148
6.1.2 Economic Benefit
ALASKA
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AUTHOR I f Y
Lifetime
Ambler-596,736
Kiana-549,482
Noorvik-655 ,568
Selawik-750,700
Ambler-596,736
Kiana-549,482
Noorvik -655,568
Selawik-750 ,700
Ambler-$4,436,909
Kiana -$2 ,287,029
Noorvik-$2,675 ,510
Selawik -$3,051653
Ambler-$512,225
Kiana-$171,750
Noorvik-$181,275
Selawik -$73,125
Ambler-$37 ,500
Kiana-$13,750
Noorvik-$13,750
Selawik-$3 ,625
Ambler-$4,986,645
Kiana-$2,472 ,518
Noorvik -$2,870,532
Selawik -$3 ,128,402
Explain the economic benefits of your project. Include direct cost savings and other economic
benefits, and how the people of Alaska will benefit from the project. Note that additional revenue
sources (such as tax credits or green tags) to pay for operations and/or financing, will not be
included as economic benefits of the project.
Where appropriate, describe the anticipated energy cost in the community, or whatever will be
affected by the project, over the life of the project. Explain how the forecast was developed and
provide year-by-year forecasts
The economic model used by AEA is available at ttttp s 1 w.akc 'r .1 · L I 2!..JL. c i • ' le-
no,G ra t t ,-____:_B~=or r,,..rl.l r r2 1 RE F ·J~ r:=t l io n. Thiseconomicmodelmaybe
used by applicants but is not required. The final benefit/cost ratio used will be derived from the
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AEA model to ensure a level playing field for all applicants. If used, please submit the model with
the application .
The economic modeling used for this application was the AEA B/C ratio model.
Potential annual fuel displacement (gallons and dollars) over the lifetime of the evaluated renewable
energy project: In total, the project will displace the equivalent of 102,099 gallons of diesel fuel for
electrical generation annually. The average price of fuel from the B/C ratio model was used for our
estimates and the 2024 cost was:
Ambler-$6 .74/gallon
Kiana -$3.65/gallon
Noorvik -$3 .58/gallon
Selawik -$3.57/gallon
Based on the output of the B/C ratio model, over the 25-year lifetime of the project, the project will
displace 2,552,486 gallons of diesel, with a lifetime cost savings of $13,458,097 million .
In the first year of operation , the renewable energy systems are expected to save the communi ties
more than $486 ,152 that will be used for utility operations and maintenance, savings for future
equipment replacements , operator and technical training, reduction in electric rates for commercial
and residential consumers.
The B/C ratio for each community is :
Ambler -1.24
Kiana - .63
Noorvik-.69
Selawik -. 71
Because of Ambler's high cost of diesel , the economics are positive . The other communities have
cha ll enging econom ics due to the relative ly low cost of diesel. This is a challenge that many remote
communities, especially AVEC communities, encounter when trying to justify the extremely high
construction costs for ren ewab le energy projects with fuel that is purchased in bulk for all their service
areas and tank farms that have been subsidized and are not accounted fo r in fue l costs. This is the
reason NAB is proposing to demonstrate the economies of scale th rough bundling for engineering ,
funding, procurement, and construction to make more renewable energy systems in remote
communities economica lly justified. For example, if we can achieve a 25 % to 30 % reduction in
project development and co nstruction costs through the economies of scale for Selawik, the B/C
ratios becomes posit ive. The economics of these projects are also very sensitive to fuel cost
increases.
The installation of battery energy storage systems are expected to have positive impacts o n the
operation of the diesel power plants, regardless of the renewable energy system . These benefits
include utilizing battery charge and discharge to maximize the fuel efficiency of the diesel engines
and reducing or eliminating brown-out and black-outs . A recent potential power outage in Shungnak
was avoided due to the battery providing time for the powerplant operators to troubleshoot a diesel
engine problem and restarting the system before an outage could occur. Unfortunately, the e conomi c
benefits of these other diesel engine benefits have not been quantified and the fuel efficiency controls
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have not been fine tuned . This work is a goal of the NAESC for their operating high penetration
systems .
The assumptions used in the B/C ratio analysis are:
Annual solar production and diesels off hours -values calculated in the HOMER modeling
feasibility studies .
Annual Renewable Energy O&M costs -1% of the battery capital cost for the battery system
O&M. Solar PV O&M costs including panels and inverters and associated equipment-$20 per year
per installed kW .
Installed PV capacities from HOMER modeling feasibility studies.
Diesel Generator O&M is based on the size of the generators in each community.
Displaced schedule component replacement cost savings due to diesels off is calculated
using actua l AVEC genset replacement costs and typical lifetime hours .
Project life of 25 years
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 inc lude:
• Low prices for diesel and/or heating oil
• Other projects developed in community
• Reductions in expected energy demand : Is there a risk of an insufficient market for energy
produ ced over the life of the project.
• Deferred and/or inadequate facility maintenance
• Other factors
Because NAB is only requesting Final Design and Permitting for these projects, the economic
analysis for ea ch community will be fine-tuned based on the capital costs from construction ready
des igns and current fuel prices.
The economic risks of the operation of these projects are also very low if the pre -con struction
economic analyses recommend project construction . The operating model used in NAB with an IPP
operating and maintaining the Solar PV and AVEC operating and maintaining the battery was put in
place to minimize ec onomic risks . The ease of operation of solar PV reduces the risk of operational
failure s due to inadequate maintenance from an IPP, and AVEC has a successful history of operating
and maintaining battery systems .
Be ca use the renewable energy is solar PV, there is no fuel cost that can create negative savings for
the communities. Low diesel costs will ex tend the payback of projects, but it is very un li kely that the
diese l prices w ill drop so low that there is not positive cash flow for these projects.
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 bri ef 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 .
N/A
I Renewable energy resource availability (kWh per month)
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Estimated direct sales to private sector businesses (kWh)
Revenue for displacing diesel generation for use at private sector businesses ($)
Estimated sales for use by the Alaskan public (kWh)
Revenue for displacing diesel generation for use by the Alaskan public($)
6.2 Other Public Benefit
ALASK A
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AUTHOR ITY
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.)
• 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
The primary goals of this project are to reduce the reliance on expensive diesel fuel and the costs
of generating electricity in our communities. Additional goals include increasing local and regional
capacity around energy security, establishing a platform for future energy innovation, reducing
risks associated with long distance marine-based fuel delivery, and mitigating and adapting to
climate change . Reducing reliance on diesel fuel through solar and battery systems will increase
our energy security, as will use of battery energy storage to provide additional generating assets.
Further, we intend to establish an Independent Power Producer (IPP) that will be managing the
s ystems and selling power to AVEC. This will increase our local a nd regional capacity for the
operations and maintenance of renewable energy systems and potentially support the
development of a regional energy services provider in partnership with the regional stakeholders .
This will ultimately result in lower costs and improved maintenance of community-owned
infrastructure.
We will be demonstrating the opportunities for economy of scale for renewable energy systems,
which, once established , can apply across Alaska . Due to the extremely high cost of construction
in remote Alaska , many renewable energy systems are financially cha llenged to achieve B/C ratios
of 1.0 or better making funding such as AEA's REF program difficult to acquire. Bundling multiple
projects might be an opportunity to reduce costs through multiple purchases and reduced
mobilization expenses. Battery, solar, and construction vendors have expressed interest in working
with NAB for cost reductions through scale, and our region has demonstrated the ability and
willingness to develop multiple projects and serve all communities in the region .
Implementing multiple projects in a remote region also is an enhanced workforce development
opportunity. If four so lar PV, battery, and diesel hybrid systems are constructed over multiple
years, stable, long-term region a l jobs will be developed, and crew members will have multiple
years to develop and use technical skills. This stable construction workforce will reduce
construction costs on future projects and the region will have a well -trained workforce.
New Market Ta x Credits are fund ing opportunities that have been available to many large projects
in the past, requiring between $5 million and $10 million minimum project sizes. Most projects in
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rural Alaska have not been eligible for these programs because the projects are just too small.
Bundling multiple renewable energy projects together could help meet the minimum size for
eligibility for New Market Tax Credits and open a new funding mechanism for rural communities .
As mentioned in the Economic Benefit section, utilizing the battery energy storage system to
reduce or eliminate brown-outs and black-outs and maximize the fuel efficiency of the operating
diesel engines is a goal of these hybrid systems and will be a focus for optimization in the coming
years .
Other public benefits include:
• Reduced electric rates for commercial customers that could be passed to community members
through lower prices .
• Reduced electric rates for commercial customers could lead to economic development such as
opening a restaurant.
• Extension of the distribution system to the solar PV arrays will help facilitate new housing
development in the future .
• Leverage opportunities for future construction with "outside ," i.e., federal support that would
otherwise not be brought into the communities.
• Maintained leadership within the state for the NAB/NANA region , and ongoing recognition of
state leadership within the global clean energy community focused on remote microgrids.
• Continued innovation , both technically and financially, that could ultimately be replicated at
scale across Alaska.
SECTION 7 -SUSTAINABILITY
Describe your plan for operating the completed project so that it will be susta inable 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
The business and operations plan will be developed during this phase of the project and will inform
the project sustainability. In a previous collaborative project between NAB and AVEC in Shungnak,
the solar PV system supported the establishment of a community-based Independent Power
Producer that sells power to AVEC. The battery and supervisory controller are operated and
maintained by AVEC because AVEC is responsible for the dispatch of the entire power generating
system. The AVEC maintenance organization supports these installations and has an extensive
staff of skilled mechanics and technicians. AVEC has proven over many years that they can
successfully maintain complex equipment and controls. By partnering with AVEC , all parties have
an ongoing interest in maintaining the system, reducing fuel use and system costs , and developing
a trained workforce . The NAB and NANA are also supporting the community-based IPP through
technical support of their own staff and hired contractors , thus reducing costs to the community,
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and chron icling lessons learned for continual system optimization and improvement with each new
project. This spans design, construction, 0 & M, local training, and financial management for long
term sustainability.
The AVEC/IPP example will most likely be the model proposed for the management structure of
the four communities addressed in this application . The Solar PV IPP will employ one part-time
technician from the local community to operate and maintain the PV system. The solar technician
in each community will be involved in the design of the solar PV, battery and diesel hybrid systems
and will be included on the construction crews . Their training will consist of involvement in
designing and building the system from a greenfield site. The operations and maintenance
requirements will also be thoroughly detailed in O&M manuals that will be deliverables of the
construction phase. These manuals will detail the periodic inspections and maintenance activities
for required daily inspections forms and initial spare parts will be included in the equipment
purchases. Commissioning will also include vendor specific training from the suppliers' technical
support teams . The IPP leadership and AVEC operators will conduct monthly meetings to verify
that all required O&M and data tracking expectations are taking place.
With 4 operating systems and potentially f ive more systems in development, the NAESC will form
an operators ' network subcommittee to discuss operational and maintenance best practi ces and
issues and expand technician capacity and support within the region. This w ill be further supported
by the NAB and NANA Energy Programs.
7 .1.2 Fi nancial Susta inability
• 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.
For each community, detailed capita l costs estimates based on actual vendor equipment and
construction quotes will be developed from the construction ready designs that result from this
project. Economic Analyses will be conducted with these cap ital costs and the latest fuel costs to
determine if a project should move forward to construction or if there is a better use for the capital
investment.
NRC a nd NAB have w o rked with c on s ultants t o develop a rate sett ing c al c u lator that take s into
account a Power Purchase Agreement (PPA) with utilities. This tool accounts for all annual
operations and maintenance costs and estimates the impact to PCE reimbursements to the
utilities. This tool will be used to develop rates for PPA's with AVEC to assure that the IPP, the
utility, and the rate payers benefit from the project. AVEC will continue to utilize their successful
revenue collection process with the ir rate payers, so non-payment is not an issue.
All of these details will be addressed in the business plan deliverable of this project.
7.1 .2.1 Revenue Sources
Briefly explain what if any effect your project will have on e lectrical rates in the proposed benefit
area over the life of the project. If there is expected to be multiple rates for electricity, such as a
separate rate for intermittent heat, explain what the rates will be and how they will be determined
Collect sufficient revenue to cover operational and capital costs
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• What is the expected cost-ba sed rate (as consistent with RFA requirements)
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• If you expect to have multiple rate classes, such as ex cess e lectricity 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 ex cess electricity for heat).
• Annual customer revenue sufficient to cover costs
• Additional incentives (i.e . ta x credits)
• Additional revenue streams (i.e . green tag sales or other renewable energy subsidies or
programs that might be available)
If these projects move into the commercialization phase , it will be because they stabilize and
potentially provide a slight reduction in rates to utility commercial customers . The rates will be set
in the PPA negotiations with AVEC during the deve lopment of the business plan , and there is
commitment from all parties that the projects w ill not move forward to construction unless the
benefits of the projects are shared between the IPP , the util ity , and the rate payers.
Th is project is not expected to resu lt in mu ltiple rate c lasses, additional incentives, or additional
revenue streams.
7.1.2.2 Power Purchase/Sale
The power purchase/sale informati on should include the following:
• Identification of potential power buyer( s )/custome r( 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 c ustome rs .
NAB has recently partnered with AVEC on a very sim il ar project to what is proposed in this
appl ication . An IPP owned by the Nati ve V illage of Shungna k and supported by NAB has entered
into a PPA with AVEC for a solar PV, battery , and diesel hybrid system . The IPP operates and
maintains the Solar PV array, and AVEC o perates and maintains the battery system .
AVEC has provided a letter of support indicating that they are interested in developing PPA's for
future projects in the NAB. AVEC has also been actively involved in th is appl ication development.
The potential power purchase/sales p ri ces will be deve loped through the business plan process
and will be based on AVEC displaced fuels costs. In general , the renewable generation will be
priced at the avoided fuel cost for AVEC minus O&M cost s and other system encumbrances that
AVEC will n eed to cover as a result of the renewable asset inter-connected to AVEC's generation
and d istribution system . This will ensure fairly distributed benefits to all stakeholders in the
community .
I 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 w ith
work once your grant is approved .
Speci fically address your progress towards or read iness to begin , at a minimum , the follow ing :
• The phase(s) that must be completed prior to beginn ing the phase(s ) proposed in this application
• The phase(s ) proposed in this appl ica ti on
• Obta ining all necessary permits
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• Securing land access and use for the project
• Procuring all necessary equipment and materials
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AUTHOR ITY
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.
The development of these projects for Ambler, Kiana , Noorvik, and Selawik have followed the
traditional renewable energy project development process. A sola r resource assessment for Alaska
was conducted by the National Renewable Energy Lab in 2016 to provide a basic framework for
solar PV feasibility studies. We also have excellent solar PV production data for all communities in
the NAB/NANA region, including the four communities included in this proposal, from solar PV
installations installed at the communities' water treatment plants, which were a pre-cursor to this
proposed project and other solar PV systems throughout the region. Based on this production data,
we have detailed understanding of the reliability and performance of solar PV, but site-specific
projects at community scale will have different economics, and this project is designed to
determine these variables. As well, we now have experience with several village-scale installations
in other nearby communities, so most residents are exposed to the technology and very interested
in developing it for their own communities. The NAESC energy education process that has
occurred for over a decade has also contributed to widespread community readiness , which is why
we are now actively considering multiple projects at once, in attempts to reduce costs and
systematize the initiatives.
NAB and the Northwest Arctic Energy Steering Committee conducted community outreach and
educational activities to support the development of regional and community energy plans. Solar
PV and battery systems were high priorities. This application is an outgrowth of these efforts .
Feasibility studies through the Alaska Native Tribal Health Consortium were conducted for each
community, addressing optimum sizing of the solar PV arrays , battery and converters and
performing a basic economic viability analysis . The feasibility studies showed that the systems
could result in significant diesel savings and diesel-off operation , but the economics of the projects
in Kiana, Noorvik, and Selawik are challenging when implemented as single stand-alone efforts. As
a result, the project team is proposing the bundling of these four projects to improve the economics
of the projects throug h cost savings related to economies of scale for bulk purchases and
contracts.
We are requesting Final Design and Permitting in this application to understand the cost savings
opportunities with economies of scale . Site Selection will be finalized in this phase , and NRC has
expressed interest in providing land for the solar arrays. Permitting will also take place during this
phase of the project.
Once the designs are complete and the economic evaluations are complete, the NAB , AVEC and
the communities will make a determination if the projects should move forward to construction .
Grant funding, loans, and other funding mechanisms will be pursued to complete the funding
packages .
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. Invo ices for work completed,
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4 . Photos of the work performed, and/or
ALASKA
ENERGY
1\LJTHGRI fY
5 . Any other available verification such as scopes of work, technical drawings, and payroll for
work completed internally.
Our region, led by NAB , has been focused on energy efficiency measure since the early 2000's .
The NAB School District has completed large LED lighting upgrades throughout the local schools.
The small local stores have been encouraged to carry LED bulbs in stock-a rarity in rural Alaska .
AVEC has aggressively constructed heat recovery systems in all NAB utilities including Ambler,
Kiana , Noorvik, and Selawik which has increased the heat rejection rate from some of its
generators to facilitate the expansion of the heat recovery systems. All of the above demonstrate
our commitment for energy sovereignty and our capability for successful project planning and
implementation .
Ambler installed a heat recovery system and completed audits and winterization upgrades in its
water treatment plant along with whole house weatherization recently completed in preparation of
residential heat pump installations.
Kiana was a participant in the Remote Alaska Communities Energy Efficiency (RACEE) program
through the Department of Energy and implemented energy efficiency measures
(EEMs) to eight community buildings, including the youth center, City Industrial Arts classroom ,
school, clinic, tribal office, city office, city shop & warm storage, city administrative building ,
and fire house. The EEMs included: replacing old , inefficient lightbulbs with light emitting
diodes (LEOs) both inside and outside all eight buildings; installing motion light sensors to
optimize electricity usage when spaces are unoccupied; air sealing all building envelopes to
insulate against heat loss; programming automatic setback thermostats to adjust heating when
outside temperatures peak and plummet; and lastly, retro-commissioning of the school to
ensure that all mechanical systems are again functioning as designed . Kiana also implemented
energy efficiency measures and installed a waste heat recovery system on their water treatment
plant. The energy efficiency measures included installation of LED lights , heat add controls with
modulating valves , updated boiler controls , air sealing, and programmable thermostats . The local
water treatment plant operators participated in this process and were trained on efficient system
operations.
Noorvik was also a participant in the RACEE program and performed energy efficiency audits on
three community buildings and investigated the expans ion of heat recovery system. Unfortunately,
the heat recovery expansion was determined not financially viable at the 65% design phase .
Through the Village Energy Efficiency Program (VEEP), one community building completed
extensively weatherization upgrades and the heat recovery system to the Water Treatment Plant
was optimized .
Selawik's energy efficiency work has been focused on the water and sewer system that freezes up
annually. Through the VEEP program , there has been significant progress on repairing leaks in the
vacuum system , adding insulation to the above ground piping , replacing aging and poorly sized
pumps, and optimizing heat trace on the piping . Additional work is still required and ANTHC is
seeping capital projects for additional major repairs .
As well , throughout the region , NANA contributed about $2 million to energy efficiency initiatives
through the Energy Wise program with RurAL CAP from 2010-2013 with meaningful impact, saving
fuel and improving quality of life for shareholders and residents in all 11 communities.
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Grant Application -Standa rd Form
SECTION 9 -LOCAL SUPPORT AND OPPOSITION
ALASK A
ENE RGY
AUTHORI TY
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 .
Because of the education and outreach work that has been completed by the NAESC in the last 12
years, communities and regional entities are very engaged in the energy development process.
Active participation in the NAESC and Letters of Support have been submitted by the following
partners:
NAB Resolution
NANA Regional Corporation
Alaska Village Electric Cooperative
City of Ambler
City of Selawik
Maniilaq Association
Launch Alaska
Bundling these projects is a high priority and does not engender any opposition that we are aware
of throughout the region.
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 .
The NAB's annual general fund appropriation is approximately $23 million, of which,80% of the
revenue ($18 . 7 million) is derived from the PIL T agreement with the Red Dog Mine . The PIL Tis
negotiated every 5-10 years while the mine is in operation . The NAB has received federal grant
funds in the past, all of which were successfully administered and closed out and is the recipient of
several current grants from the state of Alaska, mostly having to do with public safety. All grants
are compliant , and reporting is being conducted by the appropriate administrators and Finance
Department. As well, because of the VIF account, the NAB is in a similar position to AEA in that we
administer community grants and require careful accounting from our grant recipients, and we are
accountable to all the communities and Red Dog for providing the support. This has required
careful financial management. Currently, the NAB is not receiving any direct federal funding but we
are helping the City of Ambler manage their USDA HECG Biomass Facility project and we are
about to manage a $2 million US DOE Indian Energy solar PV and battery construction grant for
the community of Noatak. The NAB also maintains an active SAM registration.
The following AEA grants have been award to the NAB in the last 12 years:
Recipient Grant Program
NAB REF
AEA 23001
Project
Wind Farms for
Buckland
Deering and
Page 40 o f 45
Funding Amount
$10,738,438
Year Awarded
2009
11 /16/2021
Renewable Energy Fund Round 14
Grant Application -Standard Form
Noorvik-
2195377
NAB REF Upper Kobuk
Biomass-
7040028
NAB EETF Testing of the
Eocycle EO
25/12 Tilt-Up
Wind Turbine in
Kotzebue , Alaska
7310071
$185,867
$284,843
ALASKA
ENE RGY
AUTHORITY
2012
2013
One of the strengths of energy development in the Northwest Arctic Borough is the diverse
collaboration among stakeholders within the communities as well as numerous supporting
organizations and service providers outside the communities. The NAB and NRC are co -sponsors
of the Northwest Arctic Energy Steering Committee (NAESC ), a collaboration of energy leaders
representing all the communities of the NAB . This organization has been instrumental in the
development of renewable energy systems in the region, resulting in an innovative and diverse
portfolio of successful projects . Our experience with federal funded assistance agreements shows
that our assembled project team has the breadth and depth of knowledge to successfully
implement this proposed solar PV and battery storage design and permitting project. The following
table summarizes some of the many state and federal grants received by members of our project
team .
Recipient Grant Program Project Amount Year Awarded
NAB USDA-High Ambler Bi o mass $700,000 2019
Energy Cost
Native Village of EPA-DERA Deering Diesel $418 ,180 2021
Deering Engine
Replacements
Native Village of EPA -DERA Buckland Diesel $485,423 2020
Buckland Engine
Replacements
Native Village of BIA -Tribal Utility Capacity $99 ,000 2019
Kiana Energy Development
Deve lopment and IPP
Capacity Formation
NANA Regional BIA-Tribal Regional Energy $100 ,000 2018
Corporation Energy Support
Development Organization
Capacity Formation
NAB AEA REF Wind Turbines in $10 .7 million 2009
Buckland and
Deering
NANA Regional DOE -Indian Solar PV in $1 million 2017
Corporation Energy Kotzebue ,
AEA 23 00 1 P a ge 41 of 45 11 /16/2021
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Buckland, and
Deering
NANA Regional USDA-HECG Battery Energy
Corporation Storage in
Buckland and
Deering
NANA Regional DOE -Indian Regional
Corporation Energy Technical
Support
NAB USDA-HECG Solar PV and
Battery in
Shungnak
NAB DOE -Indian Noatak Solar PV
Energy and Battery
City of Kobuk AEA-REF Biomass Heating
City of Ambler AEA-REF Ambler Heat
Recovery
$1 .6 million
$500 ,000
$2 .1 million
$2 million
$401,87 3
$435 ,000
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/\UTH0RITY
2016
2016
2021
2021
2011
2009
The NAB's Co mprehensive Eco nomic Development Strategy and energy plann ing activities a re
encapsulated in a detailed energy plan found on our website at: Northwest Arctic Borough
Comprehensive Eco nomic Development Strategy -Jl,l l1 r ,. -
! t ' f 1[ r•!< 1, j l I J j•l rr. r • I , 1 . ') f
SECTION 11 -LIST OF SUPPORTI NG DOCUMENTATION FOR PRIOR PHASES
In the space below, please provide a list of additional documents attached to support completion of
prior phases .
Please see the follow ing doc uments in t he Attachments:
Re connaissance -Solar Energy Prospec ting in Remote Alaska-An Economic Ana lys is of Solar
Photov oltaics in the Last Frontier State" by Paul Schwabe , Nationa l Renewab le Energy Laboratory
U.S.·
Proje ct Feasibility Reports for:
Ambler
Kiana
Noorvik
Shungnak
SECTION 12-LIST OF ADD IT IONAL DOCUMENTAT ION SUBM ITTED FOR CONSIDERATIO N
In the space below , please provide a list of additional information submitted for consideration .
Detailed Capital Budget
AVEC Fleet Summary
Solar and Battery O&M Cal culations
Diesels Off Replacement Costs
AVEC Maintenance Schedul e
B/C ratio models
Team Resumes
AEA 2300 1 Page 4 2 of45 11/1 6/20 21
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Grant Application -Standard Form
I SECTION 13 -AUTHORIZED SIGNERS FORM
Community/Grantee Name: Northwest Arctic Borough
Regular Election is held: First Tuesday of November
every 3 years . Next election is in 2024.
I Authorized Grant Signer(s):
Printed Name Title
Date:
-1\ \ 5\202 L\
Term
ALASKA
ENERG Y
AUTHORITY
Signature
Dickie Mota Mayor 2021-2024 C-?._ ;.:: fXl1
I authorize the above person(s) to sign Grant Documents:
Must be authorized b the hi hest rankin or anization/communit /munici
Printed Name Title Term
Dickie Mota Mayor 2021-2024
I Grantee Contact Information:
Mailing Address: P.O . Box 1110
Kotzebue , AK 99752
Phone Number: 907-442-2500
Fax Number: 907-442-2930
Email Address: imathiasson@nwabor.org
Federal Tax ID #: Tax ID # 92·0116661
Please submit an updated form whenever there is a change to the above information.
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SECTION 14-ADDITIONAL DOCUMENTATION AND CERTIFICATION
ALASKA
EN ERGY
f\UTHORITY
SUBMIT THE FOLL OWING DOCUMENTS WITH YOUR APPLICATION:
A. Contact information and resumes of Applicant's Project Manager, Project Accountant (s),
key staff, partners, consu ltants, and suppliers per application form Section 3.1, 3.4 and
3.6.
Applicants are asked to provide resumes submitted with appli cations in separate electronic
documents if the individuals do not want their resumes posted to the project web si te.
B . Letters or resolutions demonstrating l ocal support per appl ication f orm Section 9.
stat
C. For projects involving heat: Most recent invoice demonstrating the cost of heating fuel
for the building(s) impacted by the project.
D. Governing Body Resolution or other formal acti on taken by t he applicant's governing
body or management per RFA Section 1.4 that:
• Commits the o r ganization to provide the matching resources f o r project at the match
amounts indicated in the application.
• Authorizes the individual who signs the appl ication has the authority to commit the
o r ganization to the obligations under the grant.
• Provides as point of contact to represe nt the applicant f o r purposes of this
application.
• Certifies the applicant is in compliance with applicable federa l, state, and l ocal, l aws
inc ludin g existing credit and f ederal tax obligations.
E. An electr oni c versi on of the entire application on CD or other electronic media, per RFA
Section 1. 7.
F. CERTIFICATION
The undersigned certifies that this appli cation for a renewable energy grant is truthful
and correct, and that the applicant is in compliance with, and will continue to compl y
with, all federal and state laws includ ing existing credit and federal tax obligati ons and
that they can indeed commit the entity to these obligations.
Print Name Dickie Moto
Signature a /-~-~ D/1/1
Title Mayor
Date /~6/zc
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