HomeMy WebLinkAboutUpper Tanana Area Intertie GrantApplication5 Final
August 23, 2011
Alaska Energy Authority
Attn: Butch White, Grants Administrator
AEA 12-001 Renewable Energy Grant Application
813 West Northern Lights Blvd
Anchorage, AK 99503
RE: Upper Tanana Area Intertie Grant Application
AEA 12-001 Renewable Energy Grant Application Round V
Dear AEA:
Enclosed in response to RFA AEA 12-001 Renewable Energy Grant Application
Round V program, is an application requesting funding for the Upper Tanana Area
Intertie. Enclosed with this letter are two hard copies and one CD with the document in
PDF format.
Enclosed as per the RFA,
o Grant Application Form
o Cost Worksheet (included in Section 10 – Appendices)
o Grant Budget (included in Section 10 – Appendices)
o Grant Budget Form Instructions
o Other pertinent information
If you have any questions, please call either Glen Martin (Resource Assessment &
Permits) 360-385-1733 x122, or Bob Grimm (President) 360-385-1733 x120.
Sincerely,
Glen D. Martin
Resource Assessment & Permits
Enc. (as stated)
Renewable Energy Fund Round 5
Grant Application
AEA 12-001 Application Page 1 of 23 7/1/2011
Application Forms and Instructions
The following forms and instructions are provided to assist you in preparing your application for
a Renewable Energy Fund Grant. An electronic version of the Request for Applications (RFA)
and the forms are available online at: http://www.akenergyauthority.org
Grant Application
Form
GrantApp5.doc Application form in MS Word that includes an outline of
information required to submit a complete application.
Applicants should use the form to assure all information is
provided and attach additional information as required.
Application Cost
Worksheet
Costworksheet
5.doc
Summary of Cost information that should be addressed by
applicants in preparing their application.
Grant Budget
Form
GrantBudget5.
doc
A detailed grant budget that includes a breakdown of costs by
milestone and a summary of funds available and requested to
complete the work for which funds are being requested.
Grant Budget
Form Instructions
GrantBudgetIn
structions5.doc
Instructions for completing the above grant budget form.
Authorized
Signers Form
Authorized
signers
form5.doc
Form indicating who is authorized to sign the grant, finance
reports and progress reports and provides grantee information.
If you are applying for grants for more than one project, provide separate application
forms for each project.
Multiple phases 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 completion of each phase.
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 satisfied and funding for an advanced phase is warranted.
If you have additional information or reports you would like the Authority to consider in
reviewing your application, either provide an electronic version of the document with
your submission or reference a web link where it can be downloaded or reviewed.
REMINDER:
Alaska Energy Authority is subject to the Public Records Act AS 40.25, and materials
submitted to the Authority 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.
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 the
Authority. If you want information is to be kept confidential the applicant must:
o Request the information be kept confidential.
o Clearly identify the information that is the trade secret or proprietary in their
application.
o Receive concurrence from the Authority that the information will be kept
confidential. If the Authority determines it is not confidential it will be treated as a
public record in accordance with AS 40.25 or returned to the applicant upon
request.
Renewable Energy Fund
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SECTION 1 – APPLICANT INFORMATION
Name (Name of utility, IPP, or government entity submitting proposal)
ALASKA POWER COMPANY (APC) (a subsidiary of Alaska Power & Telephone Company (AP&T))
Type of Entity: Utility Fiscal Year End: December 31
Tax ID # 92-0153693 Tax Status: For-profit or non-profit ( check one)
Mailing Address
P.O. Box 3222
Port Townsend, WA 98368
Physical Address
193 Otto Street
Port Townsend, WA 98368
Telephone Fax
360-385-1733 360-385-7538
Email
glen.m@aptalaska.com
1.1 APPLICANT POINT OF CONTACT / GRANTS MANAGER
Name
Glen Martin
Title
Grant Writer and Permitting/Licensing Manager
Mailing Address
c/o Alaska Power Company, P.O. Box 3222, Port Townsend, WA 98368
Telephone Fax
360-385-1733 360-385-7538
Email
glen.m@aptalaska.com
Mailing Address
P.O. Box 3222
Port Townsend, WA 98368
Physical Address
193 Otto Street
Port Townsend, WA 98368
1.2 APPLICANT MINIMUM REQUIREMENTS
Please check as appropriate. If you do not to meet the minimum applicant requirements, your
application will be rejected.
1.2.1 As an Applicant, we are: (put an X in the appropriate box)
X An electric utility holding a certificate of public convenience and necessity under AS
42.05, or
An independent power producer in accordance with 3 AAC 107.695 (a) (1), or
A local government, or
A governmental entity (which includes tribal councils and housing authorities);
Yes
1.2.2. Attached to this application is formal approval and endorsement for its project by
its board of directors, executive management, or other governing authority. If the
applicant is a collaborative grouping, a formal approval from each participant’s
governing authority is necessary. (Indicate Yes or No in the box )
Yes
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.
Yes
1.2.4. If awarded the grant, we can comply with all terms and conditions of the attached
grant form. (Any exceptions should be clearly noted and submitted with the
application.)
Yes
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.
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SECTION 2 – PROJECT SUMMARY
This is intended to be no more than a 1-2 page overview of your project.
2.1 Project Title – (Provide a 4 to 5 word title for your project)
Upper Tanana Area Intertie Project
2.2 Project Location –
Include the physical location of your project and name(s) of the community or communities that will
benefit from your project.
The communities of Slana, Chistochina, and Mentasta Lake are located on the Tok Cutoff of the
Glenn Highway, south of Tok. Tok is located on the Alaska Highway, where the Tok Cutoff ends.
The communities of Northway, Northway Junction, and Northway Village are located southeast
of Tok on the Alaska Highway. This project would connect these communities with Tok.
2.3 PROJECT TYPE
Put X in boxes as appropriate
2.3.1 Renewable Resource Type
Wind Biomass or Biofuels
Hydro, including run of river X Transmission of Renewable Energy
Geothermal, including Heat Pumps Small Natural Gas
Heat Recovery from existing sources Hydrokinetic
Solar Storage of Renewable
Other (Describe)
2.3.2 Proposed Grant Funded Phase(s) for this Request (Check all that apply)
Reconnaissance X Design and Permitting
Feasibility X Construction and Commissioning
Conceptual Design
2.4 PROJECT DESCRIPTION
Provide a brief one paragraph description of your proposed project.
The Project is to interconnect communities reliant on diesel generation to Tok where a
renewable energy project will be constructed in the next 3-4 years. By beginning the
interconnection during the summer of 2012, completion of the distribution lines will coincide
closely with the startup of the renewable energy project. There would be two stages for this
project:
Stage 1: Would consist of a 25 mile 34.5 kV distribution line on wood pole structures to Tok from
the APC closed grid that currently connects Slana, Chistochina, and Mentasta. These
communities are on the Tok Cutoff of the Glenn Hwy, south of Tok.
Stage 2: Would consist of a 40 mile 34.5 kV distribution line on wood pole structures to Tok from
the APC closed grid that currently connects Northway, Northway Junction, and Northway
Village. These communities are located southeast of Tok along the Alaska Highway.
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2.5 PROJECT BENEFIT
Briefly discuss the financial and public benefits that will result from this project, (such as reduced fuel
costs, lower energy costs, etc.)
A major benefit of this project is the reduction in cost of electricity to the consumers in all six
communities who presently pay approximately:
Slana, Chistochina, Mentasta = $0.6892/kWh (before the PCE is applied). Their electric
rate would be reduced to Tok’s rate of $0.5142/kWh (before the PCE is applied), a 25.4%
savings.
Northway, Northway Junction, Northway Village = $0.7006/kWh (before the PCE is
applied). Their electric rates would be reduced to Tok’s rate of $0.5142/kWh (before the
PCE is applied), a 26.5% savings.
There are a total of six communities that will benefit from this project in Alaska1: Chistochina
(pop. 93), Slana (pop. 124), Mentasta Lake (pop. 142), Northway (pop. 95), Northway Junction
(pop. 72), and Northway Village (pop. 107), shown in Figures 1 and 2 in the Appendices. APC
presently sells power for $0.5142/kWh in Tok and to other communities connected to Tok’s
closed grid. APC also provides centralized electric service to the communities of Chistochina,
Slana, Mentasta (which had a 58 mile intertie completed in 2011) and to Northway, Northway
Junction, and Northway Village; all of which have higher rates because of their isolation. If they
can be connected to Tok’s grid, their rates can be significantly reduced. Additional savings will
occur once the renewable energy project for the Tok grid is constructed, which is expected to be
completed before or around the same time as these interties.
APC will also benefit by reducing the amount of diesel fuel purchased and combusted (emitting
green house gases (GHG) and particulate matter) and O&M expenses for its various separate
diesel plants for two reasons:
1. because the Tok power plant has more efficient diesel generators
2. because the renewable energy project will reduce or eliminate the use of diesel
generation.
Having these communities connect as soon as possible will allow APC to dramatically reduce its
diesel use as soon as renewable energy is available. When renewable energy becomes the
energy source in the near future, all the community rates will go down further and be more
stable, eliminating the fluctuation of diesel generation on their rates.
Of the six communities, Slana, Mentasta Lake, Northway, and Northway Village are considered
distressed communities by the Denali Commission. This project would provide much needed
economic benefits to these communities by lowering their electric rates. Slana presently has the
diesel plant to operate the Slana-Chistochina-Mentasta grid and Northway Junction has the
diesel plant for Northway, Northway Junction, and Northway Village. These two energy markets
will have less air pollution, both green house gases (GHG) and particulate matter, with the
interconnection to the Tok grid.
Savings to the consumer is a measurement of the public benefit from this action. At present there
are more than 143 homes, businesses, and government facilities in the Northway communities
with individual consumers in between, many of whom are self-generating. In addition,
centralized electric service will facilitate economic development along this section (40 miles) of
1 All populations numbers are based on the 2000 U.S. Census.
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the Alaska Highway, including residential construction on currently undeveloped lots, and will
provide more disposable income for APC customers. The same is true for Chistochina, Slana,
and Mentasta Lake, where there are a total of 341 homes plus businesses, and government
buildings.
Project Benefits/Outcomes
Reduction of energy costs from $0.6892/kWh and $0.7006/kWh respectively to Tok’s
rate of $0.5142/kWh with additional savings once the renewable energy project is
brought on line;
Will be in position to benefit from the renewable energy project if brought on line later
than completion of the interties;
Greater service reliability because primary and backup generation equipment will be
easily accessed in Tok while eliminating emissions and noise;
Public safety may be improved if refueling does not have to take place on icy winter
roads, which could cause an accident and prevent fuel from reaching the community,
which in-turn may shut down the generation plant and leave them without electricity;
Public school could reopen closed teaching positions and purchase new books with
reduced electric rates;
More disposable income for community members and local city governments;
Economic development due to less expensive electricity;
2.6 PROJECT BUDGET OVERVIEW
Briefly discuss the amount of funds needed, the anticipated sources of funds, and the nature and source
of other contributions to the project.
The total cost of the Project is estimated to be $9,546,005. APC proposes to immediately go to
Phase III: Final Design and Permitting, followed by Phase IV: Construction. Because the
distribution lines will follow highways and their associated right-of-way (ROW), a feasibility
analysis is not necessary. Design is fairly straight forward for distribution lines, which APC has
significant experience with designing and constructing, minimizing the need for a conceptual
design (conceptual design is actually included with this application). Part of the Phase II is a
resource assessment and environmental studies, however, because the distribution line will
primarily be in the existing highway ROW, impacts have already occurred from clearing for the
highway and streams are easily spanned to avoid impacts to riparian habitat. During Phase III,
communications with the ADOT, COE, ADF&G, and USF&WS will take place to ensure no
impacts will occur to the environment (or find a mitigation if there will be) and to obtain the
appropriate permits for construction (only the ADOT ROW permit and possibly a COE permit
will be needed).
Phase III: APC requests with this application grant funding of $126,400 which is 80% of the
estimated costs of Phases III ($158,000). APC will provide $31,600 in matching funds (20%
match) from its normal operating funds.
Phase IV: APC also requests with this application grant funding of $7,510,404, which is 80% of
the estimated costs of Phase IV. APC will provide $1,877,601 in matching funds (20% match)
from its normal operating funds.
The total estimated costs for each phase, including construction, are shown below:
Phase III: Final Design and Permitting ....................................................$158,000
Phase IV: Construction.......................................................................... $9,388,005
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Total....................................................................................................... $9,546,005
2.7 COST AND BENEFIT SUMARY
Include a summary of grant request and your project’s total costs and benefits below.
Grant Costs
(Summary of funds requested)
2.7.1 Grant Funds Requested in this application. $7,636,804
2.7.2 Other Funds to be provided (Project match) $1,909,201
2.7.3 Total Grant Costs (sum of 2.7.1 and 2.7.2) $9,546,005
Project Costs & Benefits
(Summary of total project costs including work to date and future cost estimates to get to a fully
operational project)
2.7.4 Total Project Cost (Summary from Cost Worksheet
including estimates through construction)
$9,546,005
2.7.5 Estimated Direct Financial Benefit (Savings) $
2.7.6 Other Public Benefit (If you can calculate the benefit in
terms of dollars please provide that number here and
explain how you calculated that number in your application
(Section 5.)
$153,896 (Annual PCE
savings)
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SECTION 3 – PROJECT MANAGEMENT PLAN
Describe who will be responsible for managing the project and provide a plan for successfully
completing the project within the scope, schedule and budget proposed in the application.
3.1 Project Manager
Tell us who will be managing the project for the Grantee and include contact information, a
resume and references for the manager(s). 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.
Vern Neitzer, APC’s Chief Engineer, will be the Project Manager. Mr. Neitzer is located in Skagway
near the Project location, and has extensive experience in managing both renewable and fossil
fuel energy development. Greg Mickelson, APC’s VP of Power Operations, will be the
Construction Manager. Mr. Mickelson oversees operations of APC’s Tok office/plant and has
extensive experience with renewable and fossil fuel energy development as well as hundreds of
miles of distribution line installation. Resumes for Mr. Neitzer and Mr. Mickelson are included
in Section 10.
3.2 Project Schedule
Include a schedule for the proposed work that will be funded by this grant. (You may include a
chart or table attachment with a summary of dates below.)
A bar schedule of the expected design, permitting, and construction sequence is provided in
Section 10. The following summarizes key activities and dates of the schedule:
Phase III: Permitting and Final Design:
Materials Cost Analysis..................................................................... July 2012
Survey right-of-way............................................................................July-August 2012
Environmental Analysis for Stage 1 (Agency Review)....................... October 2012
Environmental Analysis for Stage 2 (Agency Review)....................... October 2012
Final Design completed................................................................... December 2012
Phase IV: Construction: 2013 –2017:
Order Materials.............................................................................. December 2012
Flag right-of-way (Stage 1: Mentasta to Tok)............................... March-April 2013
Clear right-of-way........................................................................... March-May 2013
Construction (Stage 1: Mentasta to Tok)..................... April 2013 – November 2015
Flag right-of-way (Stage 2: Northway to Tetlin Junction)............. April-May 2014
Clear right-of-way........................................................................... April-June 2014
Construction begins (Stage 2: Northway to Tetlin Junction).......... May 2014 -
November 2017
Final Construction Report to AEA.................................................... December 2017
3.3 Project Milestones
Define key tasks and decision points in your project and a schedule for achieving them. The
Milestones must also be included on your budget worksheet to demonstrate how you propose to
manage the project cash flow. (See Section 2 of the RFA or the Budget Form.)
Phase III Milestones:
Survey of ROW’s completed (stage 1 & 2)
Environmental Analysis (Agency Review)
Final Design completed
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Phase IV Milestones:
Materials ordered
ROW flagged for Stage 1
ROW cleared for Stage 1
Construction of Stage 1 starts
ROW flagged for Stage 2
ROW cleared for Stage 2
Construction of Phase 2 begins
Construction of Stage 1 is complete
Construction of Stage 2 is complete
Final Construction Report issued
3.4 Project Resources
Describe the personnel, contractors, equipment, and services you will use to accomplish the
project. Include any partnerships or commitments with other entities you have or anticipate will
be needed to complete your project. Describe any existing contracts and the selection process
you may use for major equipment purchases or contracts. Include brief resumes and references
for known, key personnel, contractors, and suppliers as an attachment to your application.
Key APC involved in the project development and their roles will be:
Greg Mickelson, Project Manager
John Harvey, Construction Manager
Bob Berreth, Electrical Design
Vern Neitzer, Senior Engineer
Glen Martin, Resource Assessment and Permits
Phase III: Permitting & Final Design
A review of the environment for ADF&G, USF&WS, COE, and SHPO will be conducted by APC
personnel to identify streams to be crossed and any potential raptor nest sites. SHPO will
provide comments on cultural resources and the need for a survey (in a previous review for the
Northway intertie they found a survey was not necessary). Fish survey may be required; however
potential impacts can be mitigated by spanning all water bodies.
Only an Alaska DOT ROW permit with some minor private property agreements are anticipated
(necessary permits and property rights will be part of this phase). COE permit may be required
if poles must be placed in wetlands, i.e. muskeg.
Final design will utilize data collected from the ROW survey in Phase III.
Phase IV: Construction
APC personnel will flag the ROW
Clearing the ROW: Local contractor will be used
APC personnel will bore the holes for pole placement, place the poles, string the
conductor, and energize the system.
APC permitting specialist will conduct the environmental assessment and agency review for
permitting; contractors for any fish and archaeological surveys would be hired.
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APC will prepare the final design documents in-house using its staff civil, mechanical, and
electrical engineers, who all have extensive experience in distribution line development along
with renewable energy development. These engineers have designed and built hundreds of miles
of line in Alaska.
3.5 Project Communications
Discuss how you plan to monitor the project and keep the Authority informed of the status.
During Phases III & IV, APC proposes to provide quarterly reports to AEA regarding the status
of the work and use of the grant funds. APC has provided similar reports to AEA and other
grant funding agencies in the past several years on other projects, and has established the
necessary procedures for producing the reports expeditiously.
3.6 Project Risk
Discuss potential problems and how you would address them.
Site Control – APC does not yet have Alaska DOT right-of-way (ROW) approval for placement
of distribution lines, poles and other appurtenances. A small amount of private land may also be
needed for the ROW. We will work with state agencies, local government, and private land
owners, as needed, during the Phase III assessment to negotiate leases, easements, or sales.
Inclement Weather – Working conditions in the Alaskan interior are very harsh during the
winter. The proposed schedule assumes there will be no work during certain portions of the
winter when temperatures become too cold; otherwise, construction will take advantage of the
frozen ground, because of less environmental impacts, to access lands for pole placement
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SECTION 4 – PROJECT DESCRIPTION AND TASKS
Tell us what the project is and how you will meet the requirements outlined in Section 2 of
the RFA.
The level of information will vary according to phase(s) of the project you propose to
undertake with grant funds.
If you are applying for grant funding for more than one phase of a project provide a
plan and grant budget form for completion of each phase.
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 satisfied and funding for an advanced phase is warranted.
4.1 Proposed Energy Resource
Describe the potential extent/amount of the energy resource that is available.
Discuss 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.
Proposed Energy Resource: For this project, APC will install a 34.5 kV three-phase distribution
line to get six communities that currently rely on diesel generation connected to Tok, which is the
energy hub for the area and where a renewable energy resource will soon be constructed.
APC currently supplies diesel generated electricity from Tok to Tanacross, Dot Lake, and Tetlin.
APC currently is conducting a feasibility analysis for a biomass renewable energy project in or
near Tok. As a part of that feasibility analysis will be a determination as to whether the Yerrick
Creek Hydroelectric Project would benefit the area more; it is also possible both could be
developed. Either renewable energy project could be in operation by as early as 2014-2015.2
Connecting these additional communities to the Tok grid in a timely manner will help them
benefit from a renewable resource as early as possible. It is not a question of if, but of when will
renewable energy come to the Tok grid.
APC has been pursuing a renewable energy project for the last several years 20 miles west of Tok
at Yerrick Creek, having most permits either in hand, or almost ready to be issued to us. The
installed capacity for the Yerrick Creek Hydroelectric Project is proposed to be 1.5MW. The
hydro project is expected to meet the full load only part of the year, but otherwise be
supplemented by diesel generation. The biomass project is expected to initially be 2MW and can
be scalable in 2MW increments to up to 10MW. The feasibility analysis mentioned above will
look at the load added by these two other energy markets from the Tok Cutoff and Alaska
Highways as well as which renewable resource should be developed.
Pros: Compared to the current diesel generation for each local grid, connecting to the Tok grid
will have the following immediate advantages:
• electric rates for customers will immediately go down;
• when the renewable resource is constructed, whether biomass or hydro, or both, their
electric rates will go down an additional amount;
• there would be savings to the states PCE program;
• O&M would be reduced, saving APC money, because fewer diesel plants would be in
operation with the intertie;
• less diesel fuel would be purchased, saving APC money;
• fewer hazardous substances;
2 Will be reliant upon the AEA Renewable Energy Grant Funding cycle to get the necessary funds.
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• fewer particulate matter emissions and GHG emissions;
Cons: There are currently no other solutions for these communities; to remain on their isolated
diesel power plants means:
higher electric rates;
potential for spills;
air pollution, etc.
4.2 Existing Energy System
4.2.1 Basic configuration of Existing Energy System
Briefly discuss the basic configuration of the existing energy system. Include information about
the number, size, age, efficiency, and type of generation.
Existing Power Generation for Slana, Chistochina, and Mentasta grid:
There are 3 gensets in the Slana diesel power plant and 2 gensets in the Chistochina diesel power
plant as follows:
Slana Power Plant (main power plant)
Unit #1 = CAT Model C9, 344kVA, 275kW, in service Oct. 2010
Unit #2 = CAT Model C9, 344kVA, 275kW, in service July 2011
Unit #3 = John Deere Model 610AF010, 180kW
Chistochina Power Plant (on standby as backup generation)
Unit #1 = John Deere Model 6068TF250, 110 kW
Unit #2 = John Deere Model 6068TF250, 110 kW
Mentasta Power Plant (on standby as backup generation)
Unit #1 = John Deere Model 6068TF250, 115 kW, in service Sept. 2009
Unit #2A = John Deere Model 6068TF250, 110 kW,
Unit #3A = John Deere Model 6068TF250, 110 kW, in service 2008
The community of Chistochina was intertied with the community of Slana in 2010 with a 34.5 kV
distribution line. Chistochina was an existing APC customer, but Slana also wanted to be an
APC customer for better reliance than the small ADOT generator that only supplied a small part
of the community. APC then completed a 34.5kV intertie to the community of Mentasta Lake in
July 2011. Mentasta Lake was also already served by APC with its own diesel generation plant.
Annual sales for fiscal year 2010 were 1,120,285kWh for the Slana, Chistochina, and Mentasta
energy market. Total annual diesel generation for these three communities was about 105,000
gallons. Slana is now the power plant hub for these communities, being in between them both
and with slightly better fuel efficient generators, with the other diesel plants in Chistochina and
Mentasta Lake left in standby mode. This has provided the opportunity to improve service and
reduce electric rates by combining all three communities and bringing many who were off-the-
grid onto the grid. Winter outages can make accessing the Slana power plant on the Tok Cutoff
difficult. The end of the distribution line is still 25 miles short of Tok.
Existing Power Generation for Northway, Northway Junction, and Northway Village grid:
There are 3 gensets in the Northway Junction diesel power plant as follows:
Northway Junction Power Plant:
Unit #1 = CAT Model 3412, 330kW
Unit #2 = CAT Model 3456, 300kW, in service Nov. 2006
Unit #3 = CAT Model 3456, 400kW, in service Oct. 2007
The Northway Junction power plant supplies electricity to all three Northway communities:
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Northway, Northway Junction, and Northway Village. Annual sales for fiscal year 2010 were
1,221,516kWh for the Northway, Northway Junction, and Northway Village energy market. Total
annual diesel generation for these three communities was about 97,000 gallons. Winter outages
can make accessing this power plant difficult on the Alaska Highway. The end of the distribution
line is still 40 miles short of Tok.
There are 6 gensets in the Tok diesel power plant that presently supplies electricity to four
communities, as follows:
Unit #3 = CAT Model D3516, 1320 kW, Purchased / Installed 1999
Unit #4 = CAT/KATO Model 3516, 1135 kW, Purchased / Installed 1989
Unit #5 = CAT/KATO Model 3516, 1135 kW, Purchased / Installed 1995
Unit #7 = CAT Model C175-16, 1800 kW, Installed 2007 (is on loan from CAT as a test unit)
Unit #8 = CAT/KATO Model D3508, 440 kW, Purchased / Installed 1985
Unit #9 = CAT/KATO Model 3512C, 1050 kW, Purchased / Installation in progress 2008
4.2.2 Existing Energy Resources Used
Briefly discuss your understanding of the existing energy resources. Include a brief discussion of
any impact the project may have on existing energy infrastructure and resources.
This distribution line extension project will reduce the use of two diesel generation plants and the
frequency of their maintenance, including overhauls and replacement. The diesel generators that
would be affected are all owned and operated by APC in both the Slana and Northway Junction
power plants. In addition, the transmission and distribution grids connecting each group of
communities are also owned and operated by APC. The Project will eventually lead to reduced
reliance on fossil fuels as a renewable energy project is constructed in the near future. Once
these communities are intertied to Tok, their diesel generators will be placed on standby mod to
only be used during outages or maintenance.
4.2.3 Existing Energy Market
Discuss existing energy use and its market. Discuss impacts your project may have on energy
customers.
The existing energy market includes the communities of Slana, Chistochina, Mentasta in one
market (Slana providing the electricity), the communities of Northway, Northway Junction, and
Northway Village in another market (Northway Junction providing the electricity), that would
connect to the Tok energy market that currently consists of the communities of Tok, Dot Lake,
Tanacross, and Tetlin (Tok provides the electricity). In the near future, APC plans to construct a
renewable energy resource (hydropower and/or biomass) to supply renewable energy to the Tok
energy market. Connecting the other two energy markets to Tok will allow them to share the
renewable energy resource and lower their electric rates. APC currently owns all the power
plants, distribution and distribution lines in all three energy markets.
Impacts the project would have on the energy customers would be to reduce their electric rates,
reduce local air emissions, generator noise pollution, and the potential for fuel spills. The
project would also reduce fuel costs and operation and maintenance costs for APC by putting the
Slana and Northway Junction power plants on standby status as backup generation. The local
diesel retailer will have fewer profits from the sale of diesel as our use is reduced.
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4.3 Proposed System
Include information necessary to describe the system you are intending to develop and address
potential system design, land ownership, permits, and environmental issues.
4.3.1 System Design
Provide the following information for the proposed renewable energy system:
A description of renewable energy technology specific to project location
Optimum installed capacity
Anticipated capacity factor
Anticipated annual generation
Anticipated barriers
Basic integration concept
Delivery methods
Renewable energy technology specific to location – APC has been investigating the development
of a conventional run-of-river hydroelectric project at Yerrick Creek, which is west of Tok on the
Alaska Highway. APC has conducted all the environmental studies and geotechnical evaluations
and is in negotiations with a private land owner to complete the access control needed to develop
the project. APC is also conducting a feasibility analysis of a biomass project that would be
located in or near Tok. This feasibility analysis will analyze both the feasibility of biomass and
whether biomass or hydropower will best meet the needs of the Upper Tanana Area. If it is
determined that only one of these renewable energy resources is feasible, or the best choice, that
is the project APC will pursue. However, it is also possible that both methods could be considered
feasible and therefore the renewable energy for the Upper Tanana Area may be a mix of the two.
The feasibility analysis is expected to be completed by the end of 2011.
The installed capacity for the Yerrick Creek Hydroelectric Project is proposed to be 1.5MW. The
hydro project is expected to meet the full load only part of the year, but otherwise be
supplemented by diesel generation.
The biomass project is expected to initially be 2MW and can be scalable in 2MW increments to up
to 10MW. The feasibility analysis mentioned above will look at the load added by these two other
energy markets from the Tok Cutoff and Alaska Highways.
By connecting these two energy markets to the Tok grid over the next 5 years, they will be on line
about the same time as a renewable energy project will come on line, ensuring that everyone
benefits from lower rates as early as possible. The Upper Tanana Area can benefit from these
renewable energy projects and from the grid extensions APC has implemented and is also
proposing in this application, by making it possible for additional line extensions in the future to
either get out to other grids with renewable energy, or for other grids to connect to APC’s
extensive grid. The continued interconnection of the Upper Tanana Area communities will benefit
a larger percentage of the population and in the long term make the area more livable and
economically viable in these difficult times.
4.3.2 Land Ownership
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.
APC does not expect any problems with obtaining the necessary permits and easements because
the Native organizations and private land owners (who currently have only home generation and
look forward to this intertie) who will benefit from less expensive electrical rates; APC has a good
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working relationship with local Native organizations. ADOT is a willing partner in
accommodating our line extensions and their assistance in the past has been greatly appreciated.
4.3.3 Permits
Provide the following information as it may relate to permitting and how you intend to address
outstanding permit issues.
List of applicable permits
Anticipated permitting timeline
Identify and discussion of potential barriers
Applicable Permits:
Alaska DOT – ROW Permit
COE 404 Certification (possibly)
ADF&G Habitat Permit (maybe)
SHPO approval
No other permits are anticipated.
4.3.4 Environmental
Address whether the following environmental and land use issues apply, and if so how they will
be addressed:
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 discuss other potential barriers
TES species – would be transient in the project area; because the project will either be in
the ADOT ROW or adjacent to it, disturbance has already occurred and the projects
disturbance will be significantly less. Poles would be spaced every 300 feet, minimizing
terrestrial impacts with limited clearing of vegetation being in or adjacent to the highway
ROW. This area has forest along the highways so that the poles and conductor will not be
viewed as primary perching habitat.
Habitat Issues – there are no known habitat issues; considering that the project is within
or adjacent to a highway, and the poles would be placed away from any riparian habitat,
impacts to habitat would be insignificant. A review of the project by ADF&G and
USF&WS will determine if there are habitat issues and how they can be mitigated.
Wetlands and other protected areas – no protected areas occur along the highways;
wetlands do exist along portions of the highways and can be avoided with the 300 foot
spacing of the poles, but a review will take place during Phase III to make sure a COE
permit isn’t needed.
Archaeological and Historical Resources – Because pole placement would be every 300
feet with only an 18-inch diameter disturbance, the impact from poles is minimal. The
highway ROW would be used as much as possible where disturbance has already occurred
to the route taken for the distribution line, minimizing the potential to disturb cultural and
historic resources. SHPO will have an opportunity to review the project to make their own
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determination during Phase III. If they determine a cultural resource survey is necessary,
one will be done.
Land Development Constraints – A potential constraint are Alaskan Native Lands, but
being within the ADOT ROW should prevent this from being a barrier. Private property
owners will welcome access to electricity, which many property owners do not have in the
distribution line free areas that the project would pass through. They would become
customers where presently they may rely on self generation or have no electricity.
Connecting to the APC grid will also require that their electrical wiring but up to grade,
which may improve household safety; a side benefit to connecting to a utilities grid.
Telecommunications Interference – The voltage to be used on these distribution lines, 34.5
kV, is below the voltage where interference can occur. APC places their 34.5 kV
distribution line next to AP&T telephone lines throughout the AP&T service area, and no
interference occurs.
Aviation considerations – The distribution line will be placed on poles that are 40-50 feet
in height, well below where aircraft should be flying. In addition, the distribution line will
be near a highway and will also be primarily passing through forests. Near Tok the Slana,
Chistochina, Mentasta intertie will come close to an airport, but is 0.5 to1.0 miles from the
field. This should not be a hazard to aircraft at that distance and also because the
highway runs parallel to the airport where the distribution line will be located; highways
and power lines are frequently linked so that it would be common for a pilot to be looking
for power lines if near the highway. The intertie from Northway communities will not be
close to any airport.
Visual and Aesthetic Impacts – For the area, wood poles structures with cables on them
are typical; this project will use the same methods and materials as previous distribution
lines in the area. Being adjacent to the highway, primarily within the highway ROW, and
also being in or adjacent to forest most of the time, the distribution line ROW has already
been disturbed and the trees will prevent viewing from any significant distance (the trees
will generally be taller than the poles). There should not be any significant impact to
visuals or aesthetics in an otherwise already disturbed corridor.
Identify and Discuss other potential Barriers – No other barriers are known to exist at this
time. Phase III will determine if there are barriers.
4.4 Proposed New System Costs and Projected Revenues
(Total Estimated Costs and Projected Revenues)
The level of cost information provided will vary according to the phase of funding requested and
any previous work the applicant may have done on the project. Applicants must reference the
source of their cost data. For example: Applicants Records or Analysis, Industry Standards,
Consultant or Manufacturer’s estimates.
4.4.1 Project Development Cost
Provide detailed project cost information based on your current knowledge and understanding of
the project. Cost information should include the following:
Total anticipated project cost, and cost for this phase
Requested grant funding
Applicant matching funds – loans, capital contributions, in-kind
Identification of other funding sources
Projected capital cost of proposed renewable energy system
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Projected development cost of proposed renewable energy system
Anticipated Project costs:
Phase I........................................... $0
Phase II .................................... $0
Phase III............................. $158,000
Phase IV ........................ $9,388,005
Total .............................. $9,546,005
Requesting Grant Funds for Phase III and Phase IV: $7,636,804
Matching Funds for Phase III and Phase IV: $1,909,201 (20%)
Grant Funds Breakdown:
Phase III: $126,400 (80% of total cost for Phase III)
Phase III Matching Funds: $31,600 (20% of total cost for Phase III)
Other Funding Sources: Other funding sources have not been identified at this time. APC will
provide the $31,600 in matching funds for Phase III from its normal operating funds.
Phase IV: $7,510,404 (80% of total cost for Phase IV)
Phase IV Matching Funds: $1,877,601 (20% of total cost for Phase IV)
Other Funding Sources: Other funding sources have not been identified at this time. APC will
provide the $1,877,601 in matching funds for Phase IV from its normal operating funds.
Projected Capital Cost of Renewable Energy System: $9,388,005 (assumed to be the cost of
Phase IV Construction)
Projected Development Cost of Proposed Renewable Energy System: $9,546,005 (assumed to be
the sum of Phase III, and IV costs).
These estimated costs, reflect the applicant’s knowledge and experience at building distribution
lines.
Phase III: Project Costs for Final Design & Permitting
Survey of ROW’s completed........................................................................... $2,000
Archaeological Survey(s)...............................................................................$100,000
Environmental Analysis & Agency Review.................................................... $50,000
Final Design Engineering............................................................................. $6,000
Total For Phase III: ................................................................................. $158,000
Phase IV: Project Costs for Construction
The construction phase will have two sub-phases, Stage 1: Mentasta to Tok; Stage 2: Northway to
Tok.
Stage 1: Mentasta to Tok (25-Miles) Construction
Materials (include freight) $1078150
Exempt Materials (materials x 25%) 270151.75
Labor 386375
Fringe Benefits (Labor x 55%) 212506.25
Vehicle Expense Heavy (56.1%) 216756.38
Vehicle Expense light (18.7%) 0
Contract/Other 625000
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2788939.38
G & A overhead (total x 13.5%) 376838.46
Subtotal $3,165,777.84
10%
Contingency 316823
Total $3,482,600.84
$0.00
Grand Total $3,482,600.00
Stage 2: Northway to Tok (40-Miles) Construction
Materials (include freight) $1952423.00
Exempt Materials (materials x 25%) 488190
Labor 691325
Fringe Benefits (Labor x 55%) 380229
Vehicle Expense Heavy (56.1%) 387833
Vehicle Expense light (18.7%) 0
Contract/Other 830,000
4730000.00
G & A overhead (total x 13.5%) 638550
Subtotal $5,368,550.00
10%
Contingency $536,855.00
Total $5,905,405.00
$0.00
Grand Total $5,905,405.00
Total Construction Costs for both Interties
Total Stage 1:................................................................................... $3,482,600.00
Total Stage 2:.................................................................................+ $5,905,405.00
Total For Phase IV:......................................................................... $9,388,005.00
4.4.2 Project Operating and Maintenance Costs
Include anticipated O&M costs for new facilities constructed and how these would be funded by
the applicant.
(Note: Operational costs are not eligible for grant funds however grantees are required to meet
ongoing reporting requirements for the purpose of reporting impacts of projects on the
communities they serve.)
The O&M cost for the Project is estimated to be approximately $25,000 per year. APC is not
requesting grant funding for O&M costs.
4.4.3 Power Purchase/Sale
The power purchase/sale information should include the following:
Identification of potential power buyer(s)/customer(s)
Potential power purchase/sales price - at a minimum indicate a price range
Proposed rate of return from grant-funded project
APC is developing this project to supply renewable power to APC’s Tok Cutoff customers (Slana,
Chistochina, Mentasta) and the Alaska Highway communities of Northway, Northway Junction,
and Northway Village. APC expects that the rates to its commercial and residential customers
will decrease with their interconnection to Tok and are expected to fall further when a renewable
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resource is constructed in the next 3-4 years. APC projects that sales of electricity will increase
because of customers picked up along both routes that are presently unserved and are self
generating. The present rate for the Tok Cutoff communities is $0.6892/kWh and the Northway
communities is $0.7006/kWh. These rates will go down to Tok’s present rate of $0.5142/kWh.
Once the renewable energy project is in operation, all communities rates are likely to fall to
additional lows.
4.4.4 Project Cost Worksheet
Complete the cost worksheet form which provides summary information that will be considered in
evaluating the project.
Please see the attached Cost Worksheet.
SECTION 5– PROJECT BENEFIT
Explain the economic and public benefits of your project. Include direct cost savings, and
how the people of Alaska will benefit from the project.
The benefits information should include the following:
Potential annual fuel displacement (gal and $) over the lifetime of the evaluated renewable
energy project
Anticipated annual revenue (based on i.e. a Proposed Power Purchase Agreement price,
RCA tariff, or cost based rate)
Potential additional annual incentives (i.e. tax credits)
Potential additional annual revenue streams (i.e. green tag sales or other renewable
energy subsidies or programs that might be available)
Discuss the non-economic public benefits to Alaskans over the lifetime of the project
Potential annual fuel displacement: With these six communities intertied to the Tok grid, the
renewable energy project to be built in the next 3-4 years will off-set approximately 202,091
gallons of diesel fuel annually (based on 2010 fuel use). Over a 50 year period the Project could
potentially save 10,104,550 gallons of diesel fuel, at present rates of use. APC’s most recent
purchase of diesel fuel for the:
Northway power plant (July 2, 2011) was $3.88/gal.
Slana power plant (July 27, 2011) was $3.75/gal.
APC’s economic analysis assumes that fuel prices will escalate at 6.0% per year3 for the next 50
years, which results in an average fuel price of $96.10/gal by 2061. This is based on an analysis
conducted for SE Alaska by the SEIRP Advisory Work Group on future fuel costs. We have
assumed that since SE Alaska expects a 6.0% per year cost increase, the Tok area can probably
expect the same or similar increases.
Anticipated annual revenue: Revenues will change for three reasons:
1) as the result of additional customers that would be brought onto the grid that are currently
unserved between each energy market, i.e. Mentasta (where the current grid ends) to Tok, or
Northway to Tok;
2) reduced income from lower electric rates to our customers;
3) lower O&M for these remote power plants, which will be placed on standby status, saving APC
3 Based on the SEIRP Advisory Work Group Fuel Prices Analysis; a copy of the analysis is enclosed.
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financial resources, including reduced frequency of maintenance on trucks, less use of gas, less
overtime, etc.
A positive return to the State would occur from reduced PCE Program funds needed for these
communities. Since the PCE rate will convert to the Tok energy market PCE rate for both
interties, the savings for each energy market will be:
Slana = $58,991/annually (based on 2010 sales and on Tok’s PCE rate)
Northway = $62,750/annually (based on 2010 sales and on Tok’s PCE rate)
Total annual savings to the PCE Program = $153,896
As mentioned earlier, efficiency for APC will improve with this intertie because fewer man-hours will
be needed to maintain service to this area, including a reduction in overtime. Other efficiencies
relate to reduced hours of vehicle and equipment use for maintaining these power plants.
Maintenance of the Northway Junction or Slana power plants (which will go to standby mode) will be
a benefit of this intertie. The Northway Junction power plant has an energy efficiency of
12.93kWh/gal of fuel. The cost of fuel for Northway Junction at the last purchase on July 2, 2011,
was $3.88/gal. The Slana power plant has an energy efficiency of 12.78kWh/gal. The cost of fuel
for Slana at the last purchase on July 27, 2011, was $3.75/gal. Once connected to Tok, the
efficiency will improve to 14.53kWh per gallon of fuel. The cost of fuel for Tok at the last purchase
was $3.96/gal; but this was for low sulfur fuel which is more expensive.
In FY 2010, the combined sales of electricity for the Slana and Northway grids were 2,341,801
kWh. Besides improving efficiency, safety for APC’s personnel will improve by reducing the
frequency they must drive to Northway and Slana on the icy winter roads to inspect and maintain the
generation plants.
We must consider the fact that this project also benefits the residents of the Northway communities
and Tok Cutoff communities as well as future residents along both highway systems with
significant energy cost savings. Lower electric rates will also encourage commercial development
along the Alaska Highway, which will potentially contribute to more jobs and more disposable
income. This is our primary purpose in applying for the grant, to reduce their rates by connecting
them to a renewable energy resource for the electricity needs rather than potential savings to
APC.
Additional savings will occur when the renewable energy project comes on line.
Potential additional annual incentives: Not estimated.
Potential additional revenue streams: Not estimated.
Non-economic public benefits to Alaskans: A main non-economic benefit of the Project is the
reduction of emissions from diesel generation by remote power plants that once supplied by a
renewable energy resource in 3-4 years will have no air emissions, store less fuel, and reduce the
potential for spills to occur from transporting and the transference of the fuel. The more
immediate non-economic benefit is the Tok power plant has more efficient diesel generators than
the remote power plants, improving air quality for the area. The future renewable energy project
would reduce the equivalent of about 2,021 tons of CO2 and particulate matter into the air per
year; will also reduce NOx emissions into the air by about 50.5 tons per year. These
environmental benefits will improve the environment in the Upper Tanana Area, providing a non-
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economic benefit to the people of Alaska.
Other benefits: In the short term the local economy would benefit due to local hire for
construction labor, materials for construction, and lease or rental of equipment. In the long term,
APC may need to hire more linemen to maintain the system, which could either be local hire or
bringing in someone from outside who will contribute their income to the local community
through taxes, purchases, and rent or homeownership.
Public safety will be enhanced with a system that is in full compliance with the National Electric
Safety Code and other standards, forcing self-generation homes to bring their electrical wiring
and circuitry up to code. The environment will be improved as small, less efficient generators are
replaced with central station service from Tok where in the near future renewable energy will
replace the diesel generation. Air emissions will also be significantly reduced (essentially
eliminated) at Northway and Slana, which will also reduce noise to zero. The potential for spills
from regularly transporting fuel and filling the storage tank will also be significantly reduced. The
potential for power to be lost to these communities because of weather or the road preventing the
delivery of fuel or servicing of the generation facility will be eliminated if this intertie goes through.
Presently, if the fuel truck had an accident, or was unable to get to the community for long periods of
time, the community could end up without electricity. The same goes for providing service by APC.
Road and weather conditions in the winter have periodically prevented access to Northway and
Slana. It is only a matter of time before the right conditions meet to make this a reality, and then they
will be without heat or light during sub-zero temperatures.
The public school systems will benefit from lower rates by being able to reopen previously closed
teaching positions and ordering of new books that have previously been cut from the budget in order
to pay electric bills. This will in turn improve the education system that may improve the local
economy if these young people become entrepreneurs and start new businesses, with the end result of
keeping more of them in their respective community.
By reducing the cost of electricity to these communities the cost to the PCE program will also be
reduced by approximately $153,896 annually, at the current PCE rate and FY 2010 sales. This is
important because as most states of the nation are struggling with budget deficits right now, so is
the State of Alaska. This rate reduction to these six communities will benefit the State of Alaska in
general. Additional savings will occur to the PCE Program once the renewable energy project is
on line.
It is also expected that with the generation facilities and personnel in Tok, the service reliability will
improve for all six communities because only the distribution line will provide an outage point from
Tok south (rather than a whole power plant at a remote site).
SECTION 6– SUSTAINABILITY
Discuss your plan for operating the completed project so that it will be sustainable.
Include at a minimum:
Proposed business structure(s) and concepts that may be considered.
How you propose to finance the maintenance and operations for the life of the project
Identification of operational issues that could arise.
A description of operational costs including on-going support for any back-up or existing
systems that may be require to continue operation
Commitment to reporting the savings and benefits
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APC generates electricity with hydroelectric and diesel power plants throughout Alaska, presently
serving 25 communities, as shown in the attached map “Service Areas”. APC’s experience in
Alaska goes back to 1957. APC has staff certified as electrical, civil, and mechanical engineers.
APC’s engineers are responsible for the designing, ordering materials, and construction of power
plants, turbines, generators, switchgear, SCADA networks, distribution lines, etc. APC’s facilities
are well maintained and our operations and construction personnel are among the best in the
industry. We have a consistent history of excellent performance in reliability, customer service,
and a reputation for being a low cost provider of electric service.
APC operates and maintains all of the existing power plants and transmission and distribution
lines in the three energy markets affected by this proposed Project, Tok, Slana, and Northway.
AP&T, APC parent company, owns and operates six hydroelectric projects in Southeast Alaska;
four of which were built by AP&T.
APC proposes to use these funds for final design, permitting, and construction to fully complete an
intertie between Tok and Northway Junction and Tok and Slana.
The current company structure is sustainable as a power utility, with revenues from ratepayers
covering fuel costs, O&M and regulated profit structure. As a regulated utility, AP&T is already
required to report its revenues, O&M and power generation fuel costs.
Savings and benefits will be directly experienced by the utility ratepayers.
SECTION 7 – READINESS & COMPLIANCE WITH OTHER GRANTS
Discuss what you have done to prepare for this award and how quickly you intend to proceed
with work once your grant is approved.
Tell us what you may have already accomplished on the project to date and identify other grants
that may have been previously awarded for this project and the degree you have been able to
meet the requirements of previous grants.
Several of APC’s projects have been funded by grants, demonstrating significant grant
administration experience by APC. APC, and the parent company AP&T, are familiar with and
have successfully obtained AEA funding in the past, and has regularly successfully met funding
requirements and reports.
SECTION 8– LOCAL SUPORT
Discuss what local support or possible opposition there may be regarding your project. Include
letters of support from the community that would benefit from this project.
This project enjoys support in the Northway communities and Tok Cutoff communities because
their rates will go down. Residences that are off either grid between these energy markets and
Tok will be able to connect to this centralized electric service, providing less expensive electricity
than they are able to self-generate.
No opposition is known or anticipated at this time.
SECTION 9 – GRANT BUDGET
Tell us how much you want in grant funds Include any investments to date and funding sources,
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how much is being requested in grant funds, and additional investments you will make as an
applicant.
Include an estimate of budget costs by milestones using the form – GrantBudget5.doc
Total Project Costs: $9,546,005 (total for Phases III, and IV)
Investments to date and funding sources: AP&T has spent on a minor amount to date for
conceptual design.
Amount requested in grant funds: $7,636,804 (80% of estimated costs for Phases III, and IV)
Additional investment by AP&T: AP&T will provide matching funding equaling 20% of the total
cost of Phases III and IV ($1,909,201). This matching amount will be paid from AP&T’s general
operations funds.
I Renewable Energy Fund ALASKA
ENERGY AUTHORITY Grant Application Round 5
SECTION 10 -ADDITIONAL DOCUMENTATION AND CERTIFICATION
SUBMIT THE FOLLOWING DOCUMENTS WITH YOUR APPLICATION:
A. Contact information, resumes of Applicant's Project Manager, key staff, partners,
consultants, and suppliers per application form Section 3.1 and 3.4. Applicants
are asked to separate resumes submitted with applications, if the individuals do
not want their resumes posted.
B. Cost Worksheet per application form Section 4.4.4.
C. Grant Budget Form per application form Section 9.
D. Letters demonstrating local support per application form Section 8.
E. An electronic version of the entire application on CD per RFA Section 1.7.
F. Authorized Signers Form.
G. Governing Body Resolution or other formal action taken by the applicant's
governing body or management per RFA Section 1.4 that:
Commits the organization to provide the matching resources for project at the
match amounts indicated in the application.
Authorizes the individual who signs the application has the authority to
commit the organization to the obligations under the grant.
Provides as point of contact to represent the applicant for purposes of this
application.
Certifies the applicant is in compliance with applicable federal, state, and local,
laws including existing credit and federal tax obligations.
H. CERTIFICATION
The undersigned certifies that this application for a renewable energy grant is truthful
and correct, and that the applicant is in compliance with, and will continue to comply
with, all federal and state laws including existing credit and federal tax obligations and
that they can indeed commit the entity to these obligations.
Print Name
Signature
Title
Date
AEA 12-001 Grant Application Page 23 of 23 7/111 2011
UPPER TANANA AREA INTERTIE
APPENDICES
TABLE OF CONTENTS
1. Certificate of Public Convenience & Necessity
2. Corporate Resolution
3. Authorized Signers
4. Project Maps
5. Project Drawings – Typical Pole Structures
6. Project Schedule
7. Resume’s
8. AP&T (& APC) Service Area Map
9. Cost Worksheet
10. Grant Budget Form
11. Electronic Version Certification
CERTIFICATE OF PUBLIC
CONVENIENCE & NECESSITY
CORPORATE RESOLUTION
AUTHORIZED SIGNERS
Grant Documents Authorized Signers
Pl ease cl earl y p rint or ty pe all sections of this form.
Co m muni ty/Grantee Nam e : AL A SKA POWER COMPANY
Reg ul a r E lection is he ld: An nu a ll y I Date : A nnu al E lecti o n =M ay 2011
Autho rized G rant Si
P rin ted Name Title Te rm
Rob ert S. Grim m CEO / Preside nt
Gl en D. Martin
I autho rize the above person(s) to sign Grant Do cu me nts:
(H ighest ranki ng organization/com mu nity/m un icipal official)
Prin te d Name Title T e rm
Robert S. Grimm CEO / President Pe rmane nt
Gran tee Contact Inform ation:
Mailing Address: P .O. Box 3222
P ho ne Number: 360-385 -1733 x120
Fax Number: 360-385 -753 8
E-mai l Address: bob.g@aptalaska.com
Fisc a l Year E nd: December 31
Entity T~_e _(For-pro fi t or non-profit status): For Profit
Fe deral T ax ID #: 92-0 153693
Please s u bmit an updated form whenever there is a change to the abo ve information.
Pl ea se return the original completed for m to:
Al aska Energy Authority
813 W . Northern Lights Blv d.
AlASKAAnchorage, AK 9950 3 ENERGY AUTHORITYAttn: Butc h White, G rants Ad mini strator
H:\GRANTSIAEA Round V Ren ewable Energy Grants\GrantDocumentsAutho ri zedSignersS.doc
PROJECT MAPS
PROJECT DRAWINGS – TYPICAL POLE STRUCTURES
PROJECT SCHEDULE
PHASE III: Permitting & Final DesignMaterials Cost AnalysisSurvey Right-of-WayEnvironmental AnalysisFinal DesignPHASE IV: Construction 2013-2015Phase 1 - Mentasta to TokOrder MaterialsFlag Right-of-WayClear Right-of-WayConstruction of Phase 1Completion of Phase 1 ConstructionPHASE IV: Construction 2014 - 2017Phase 2 - Northway to TokFlag Right-of-WayClear Right-of-WayConstruction of Phase 2Completion of Phase 2 ConstructionFinal Report to AEAQ3 Q4 Q120122013Q2 Q3 Q4 Q1Q420162017Q1 Q2Q1 Q2 Q3Q22015Q3 Q4Q4Q3Q1 Q2Q1 Q2UPPER TANANA AREA INTERTIE PROJECTDESIGN AND CONSTRUCTION SCHEDULE2014Q3 Q42018Q1 Q2Q3 Q4
RESUME’S
APC & AP&T SERVICE AREA MAP
COST WORKSHEET
Renewable Energy Fund Round 5
Project Cost/Benefit Worksheet
RFA AEA12-001 Application Cost Worksheet Page 1 7-1-11
Please note that some fields might not be applicable for all technologies or all project
phases. The level of information detail varies according to phase requirements.
1. Renewable Energy Source
The Applicant should demonstrate that the renewable energy resource is available on a
sustainable basis.
Annual average resource availability. To Be Determined Through Feasibility Analysis for
Biomass or Hydropower as mentioned in the grant
application.
Unit depends on project type (e.g. windspeed, hydropower output, biomasss fuel)
2. Existing Energy Generation and Usage
a) Basic configuration (if system is part of the Railbelt 1 grid, leave this section blank)
i. Number of generators/boilers/other Northway/Slana Energy Markets (11 diesel
generators) + Tok (6 diesel generators)
ii. Rated capacity of generators/boilers/other Slana = 275kW, 275kW, 180kW
Chistochina = 110kW, 110kW
Mentasta = 115kW, 110kW, 110kW
Northway = 330kW, 300kW, 400kW
Tok = 1320kW, 1135kW, 1135kW, 1800kW,
440kW, 1030kW
iii. Generator/boilers/other type
iv. Age of generators/boilers/other
v. Efficiency of generators/boilers/other
b) Annual O&M cost (if system is part of the Railbelt grid, leave this section blank)
i. Annual O&M cost for labor
ii. Annual O&M cost for non-labor
c) Annual electricity production and fuel usage (fill in as applicable) (if system is part of the
Railbelt grid, leave this section blank)
i. Electricity [kWh] Sales (FY 2010):
Slana / Chistochina / Mentasta = 1,120,285kWh;
Northway = 1,221,516kWh;
Tok = 9,834,077kWh
ii. Fuel usage
Diesel [gal] Diesel used (2010)
Slana / Chistochina / Mentasta = 105,043 gal.;
Northway = 97,048 gal.;
Tok = 780,879 gal.
Other
iii. Peak Load Slana = January 186kWh, July 149kWh; Chistochina = January 0kWh, July
1 The Railbelt grid connects all customers of Chugach Electric Association, Homer Electric Association, Golden Valley Electric
Association, the City of Seward Electric Department, Matanuska Electric Association and Anchorage Municipal Light and Power.
Renewable Energy Fund Round 5
Project Cost/Benefit Worksheet
RFA AEA12-001 Application Cost Worksheet Page 2 7-1-11
18kWh; Mentasta = January – 83kWh, July 65kWh; Northway = January –
235kWh, July 166kWh; Tok = January – 1,745kWh, July 1,440kWh
iv. Average Load
v. Minimum Load
vi. Efficiency
vii. Future trends
d) Annual heating fuel usage (fill in as applicable)
i. Diesel [gal or MMBtu]
ii. Electricity [kWh]
iii. Propane [gal or MMBtu]
iv. Coal [tons or MMBtu]
v. Wood [cords, green tons, dry tons]
vi. Other
3. Proposed System Design Capacity and Fuel Usage
(Include any projections for continued use of non-renewable fuels)
a) Proposed renewable capacity
(Wind, Hydro, Biomass, other)
[kW or MMBtu/hr]
Currently, the Yerrick Creek Hydropower Project capacity
is to be 1,500 kW; the Tok Biomass Project capacity is to
initially be 2,000 kW, but can grow in 2,000 kW increments
up to 10,000 kW. Expected completion of one or both
projects in 3-4 years.
b) Proposed annual electricity or heat production (fill in as applicable)
i. Electricity [kWh]
ii. Heat [MMBtu]
c) Proposed annual fuel usage (fill in as applicable)
i. Propane [gal or MMBtu]
ii. Coal [tons or MMBtu]
iii. Wood [cords, green tons, dry tons]
iv. Other
4. Project Cost
a) Total capital cost of new system $9,388,005
b) Development cost $9,546,005
c) Annual O&M cost of new system
d) Annual fuel cost
5. Project Benefits
a) Amount of fuel displaced for
i. Electricity 202,091 gallons of diesel fuel annually (based on 2010 fuel use) once a
renewable energy project comes on line in 2-3 years
Renewable Energy Fund Round 5
Project Cost/Benefit Worksheet
RFA AEA12-001 Application Cost Worksheet Page 3 7-1-11
ii. Heat
iii. Transportation
b) Current price of displaced fuel Slana Energy Market = $0.6892/kWh
Northway Energy Market = $0.7006/kWh
c) Other economic benefits PCE Program will save $153,896 annually once
intertied with Tok; this is before the renewable energy
project is connected, which will provide further savings.
d) Alaska public benefits Savings to PCE Program and reduced air emissions
and noise in two communities – Slana and Northway
6. Power Purchase/Sales Price
a) Price for power purchase/sale APC owns all electrical infrastructure in the three
energy markets and is developing this intertie.
7. Project Analysis
a) Basic Economic Analysis
Project benefit/cost ratio
Payback (years)
ALASKA POWER TELEPHONE COMPANY
2011 PROJECT WORKORDER WORKSHEET'
W.O.#
Location: Tok Person Responsible for project Greg
Project Name:
Description:
NO FIBER
Planning Schedule:
Materials Order Date:
Project Start Date:
Estimated Project Sign Off Date For Completion:
Procedure Questions:Load For Exempt Materials Yes x No
Load For Vehicle Expense Yes x No
Budget Amounts:
Materials (include freight)$1078150
Exempt Materials (materials x 25%)270151.75
Labor 386375
Fringe Benefits (Labor x 55%)212506.25
Vehicle Expense Heavy (56.1%)216756.38
Vehicle Expense light (18.7%)0
Contract/Other 625000
2788939.38
G & A overhead (total x 13.5%)376838.46
Subtotal 3,165,777.84$
10% Contingency 316823
Total 3,482,600.84$
$0.00
Grand Total 3,482,600.84$
Approvals (initial date):
Property Manager:
Mentasta/Tok Intertie
Construct 25 miles of new 34.5kv line from Tok area to Broken Bridge on south
road.
Page 1
[BLANK PAGE]
ALASKA POWER TELEPHONE COMPANY
2011 PROJECT WORKORDER WORKSHEET'
W.O.#
Location: Person Responsible for project Greg
Project Name:
Description:
Planning Schedule:
Materials Order Date:
Project Start Date:
Estimated Project Sign Off Date For Completion:
Procedure Questions:Load For Exempt Materials Yes x No
Load For Vehicle Expense Yes x No
Budget Amounts:
Materials (include freight) $ 1952423.00
Exempt Materials (materials x 25%) 488190
Labor 691325
Fringe Benefits (Labor x 55%) 380229
Vehicle Expense Heavy (56.1%) 387833
Vehicle Expense light (18.7%) 0
Contract/Other 830,000
4730000.00
G & A overhead (total x 13.5%) 638550
Subtotal 5,368,550.00$
10% Contingency 536,855.00$
Total 5,905,405.00$
$0.00
Grand Total 5,905,405.00$
Approvals (initial date):
Property Manager:
Northway/Tok Intertie
Construct 37 miles of new 3 phase 34.5kv transmission line and 3 miles of re-build
existing 24.9 to 34.5kv.
Page 1
GRANT BUDGET FORM
GRANT BUDGET FORM FOR PHASE III
Renewable Energy Fund Grant Round V Grant Budget Form 7-1-11 Upper Tanana Area Intertie Phase III - Milestones Anticipated Completion Date RE- Fund Grant Funds Grantee Matching Funds Source of Matching Funds: Cash/In-kind/Federal Grants/Other State Grants/Other TOTALS Survey of ROW’s completed July 2012 $1,600 $400 $2,000 Archaeological Surveys September 2012 $80,000 $20,000 $100,000 Environmental Analysis (ADF&G, COE, & USF&WS review) October 2012 $40,000 $10,000 $50,000 Final Design completed December 2012 $4,800 $1,200 $6,000 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ TOTALS $126,400 $31,600 $158,000 Budget Categories: Direct Labor & Benefits $12,800 $3,200 $16,000 Travel & Per Diem $1,600 $400 $2,000 Equipment $ $ $ Materials & Supplies $ $ $ Contractual Services $112,000 $28,000 $140,000 Construction Services $ $ $ Other $ $ $ TOTALS $126,400 $31,600 $158,000 Applications should include a separate worksheet for each project phase (Reconnaissance, Feasibility, Design and Permitting, and Construction)- Add additional pages as needed
GRANT BUDGET FORM FOR PHASE IV – STAGE 1
MENTASTA TO TOK
Renewable Energy Fund Grant Round V Grant Budget Form 7-1-11 Upper Tanana Area Intertie Tok Cutoff MP 91 to Tok Milestone or Task Phase IV – Milestones 2012-2015 Anticipated Completion Date RE- Fund Grant Funds Grantee Matching Funds Source of Matching Funds: Cash/In-kind/Federal Grants/Other State Grants/Other TOTALS Order Materials December 2012 $1,076,600.00 $269,150.00 $1,345,750.00 Flag right-of-way (Stage 1: Mentasta to Tok March – April 2013 $ 20,000.00 $ 5,000.00 $ 25,000.00 Clear right-of-way March – May 2013 $120,000.00 $ 30,000.00 $150,000.00 Construction begins (Stage 1: Mentasta [MP 91] to Tok) April 2013 – Nov. 2015 $1,569,480.00 $ 392,370.00 $1,961,850.00 $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ $ TOTALS $2,786,080.00 $ 696,520.00 $3,482,600.00 Budget Categories: Direct Labor & Fringe Benefits [Labor x 55%] $480,000.00 $120,000.00 $600,000.00 Travel & Per Diem $ $ $ Equipment [Vehicle Expense Heavy (56.1%)] $176,000.00 $44,000.00 $220,000.00 Materials [Materials & Exempt Materials (materials x 25%)] $1,075,200.00 $268,800.00 $1,344,000.00 Contractual Services $500,000 $125,000.00 $625,000 G & A Overhead (total x 13.5%) $301,600.00 $75,400.00 $377,000.00 10% Contingency $253,280.00 $63,320.00 $316,600 TOTALS $2,786,080.00 $696,520.00 $3,482,600 Applications should include a separate worksheet for each project phase (Reconnaissance, Feasibility, Design and Permitting, and Construction)- Add additional pages as needed
GRANT BUDGET FORM FOR PHASE IV – STAGE 2
NORTHWAY JUNCTION TO TETLIN JUNCTION
Renewable Energy Fund Grant Round V Grant Budget Form 7-1-11 Upper Tanana Area Intertie Northway to Tok Milestone or Task Phase IV – Milestones 2013-2017 Anticipated Completion Date RE- Fund Grant Funds Grantee Matching Funds Source of Matching Funds: Cash/In-kind/Federal Grants/Other State Grants/Other TOTALS Order Materials December 2012 $1,600,000.00 $ 400,000.00 $2,000,000 Flag right-of-way (Phase 2: Northway to Tetlin Junction) April – May 2014 $28,000.00 $ 7,000.00 $ 35,000 Clear right-of-way April – June 2014 $224,000.00 $ 56,000.00 $280,000 Construction begins (Phase 2: Northway to Tetlin Junction) May 2014 – Nov. 2017 $2,856,324 $ 714,081.00 $3,570,405 Final Report December 2017 $ 16,000.00 $ 4,000.00 $20,000 $ $ $ $ $ $ December 2017 $ $ $ $ $ $ $ $ TOTALS $4,724,324.00 $1,181,081.00 $5,905,405 Budget Categories: Direct Labor & Fringe Benefits [Labor x 55%] $857,600.00 $214,400.00 $1,072,000 Travel & Per Diem $ $ $ Equipment [Vehicle Expense Heavy (56.1%)] $310,400.00 $77,600.00 $388,000 Materials [Materials & Exempt Materials (materials x 25%)] $1,952,000.00 $488,000.00 $2,440,000 Contractual Services $664,000.00 $166,000.00 $830,000 G & A Overhead (total x 13.5%) $510,840.00 $127,710.00 $638,550 10% Contingency $429,484.00 $107,371.00 $536,855 TOTALS $4,724,324.00 $1,181,081.00 $5,905,405 Applications should include a separate worksheet for each project phase (Reconnaissance, Feasibility, Design and Permitting, and Construction)- Add additional pages as needed
RFA AEA12‐001 Grant Budget Instructions Page 1 of 5 7‐1‐11
Renewable Energy Fund Round 5
Grant Budget Instructions
NOTICE TO GRANTEES
Reimbursement to a Grantee under this program is on a cost reimbursable basis. In
accordance with the terms of the grant a Grantee is required to submit certified requests
for reimbursements that document commitments and expenditures and demonstrate
meeting milestones identified in the grant.
A proposed reimbursement schedule tied to completion of milestones must be identified
in the applicant’s proposal. The Alaska Energy Authority (“AEA” or “Authority”) will not
approve a reimbursement schedule that does not reflect costs or commitments tied to
the accomplishment of milestones identified in the grant. The final reimbursement
schedule is subject to negotiation and will be incorporated into the grant agreement.
The Authority may authorize a percentage of grant funds, up to 20% depending on the
type of grant, as an advance reimbursement at the startup of the grant.
The Authority may also withhold up to 20% of the total grant subject to completion of the
project and submission of final reports and other documentation that may be required by
the grant.
A Grantee is required to account for and document all expenditures of grant and
matching funds including documentation of expenditures on any advanced
reimbursement. All requests for reimbursement are subject to audit by the Authority.
The Grantee is also required to comply with 2.AAC.45.010, the State Single Audit
regulations.
1. Budget Form
Information concerning the proposed grant budget needs to be provided on the Grant Budget
Form. The Grantee must tie their budget request to the proposed milestones they propose in
their application. Examples of milestones for each project phase are included with the budget
form and in Section 2 of the RFA.
For the purposes of determining potential cash-flow and a reimbursement schedule Grantees
should use the form to identify the proposed date that the milestone would be met, the
anticipated amount of grant funds to be expended to meet that milestone, and the amount and
type of matching resources they intend to apply to that milestone.
The bottom part of the form includes the allowable Budget Categories and is intended to be a
summary of types of cost for each phase of the grant.
2. Allowable Costs
Allowable costs for a grant include all reasonable and ordinary costs for direct labor and
benefits, travel, equipment, supplies, contractual services, construction services, and other
direct costs identified that are necessary for and incurred as a direct result of the project.
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Grant Budget Instructions Renewable Energy Fund Round 5
A cost is reasonable and ordinary if, in its nature or amount, it does not exceed that which would
be incurred by a prudent person under the circumstances prevailing at the time the decision was
made to incur the costs.
Allowable costs under this grant include all reasonable and ordinary costs for direct labor &
benefits, travel, equipment, supplies, contractual services, construction services, and other
direct costs identified and approved in the Project budget that are necessary for and incurred as
a direct result of the Project and are consistent with the requirements of the grant agreement.
A cost is reasonable and ordinary if, in its nature and amount, it does not exceed that which
would be incurred by a prudent person under the circumstances prevailing at the time the
decision was made to incur the costs.
Allowable costs are only those costs that are directly related to activities authorized by the Grant
Agreement and necessary for the Project. The categories of costs and additional limits or
restrictions are listed below:
a. Direct Labor & Benefits
Include salaries, wages, and employee benefits of the Grantee’s employees for that portion
of those costs attributable to the time actually devoted by each employee to, and necessary
for the Project. Direct labor costs do not include bonuses, stock options, other payments
above base compensation and employee benefits, severance payments or other termination
allowances paid to the Grantee’s employees.
b. Travel, Meals, or Per Diem
Include reasonable travel expenses necessary for the Project. These include necessary
transportation and meal expenses or per diem of Grantee employees for which expenses
the employees are reimbursed under the Grantee’s standard written operating practice for
travel and per diem or the current State of Alaska Administrative Manual for employee
travel.
c. Equipment
Include costs of acquiring, transporting, leasing, installing, operating, and maintaining
equipment necessary for the Project, including sales and use taxes. Equipment owned by
the Grantee is to be charged to the project at the monthly rates contained in the Data Quest
Blue Book. The rates for equipment owned by the Grantee for less than a month’s duration
are to be computed on an hourly charge determined by dividing the monthly rate by 176.
Equipment rented by the Grantee can be charged to the grant at actual invoiced charge
rates, subject to a maximum amount equal to the hourly rates contained in the Data Quest
Blue Book. The Authority’s Project Manager must approve all equipment charge rates to be
used by the Grantee. The Data Quest Blue Book is available to the AEA Project Managers
and grantees may contact them for current allowable rates.
Subject to prior approval of the Authority’s Project Manager, costs or expenses necessary to
repair or replace equipment damage or losses incurred in performance of work under the
grant may be allowed. However, damage or losses that result from the Grantee’s
RFA AEA12‐001 Grant Budget Instructions Page 3 of 5 7‐1‐11
Grant Budget Instructions Renewable Energy Fund Round 5
employees, officer’s, or contractor’s gross negligence, willful misconduct, or criminal conduct
will not be allowed.
d. Materials and Supplies
Include costs of material, office expenses, communications, computers, and supplies
purchased or leased by the Grantee necessary for the Project.
e. Contractual services
Include the Grantee’s cost of contract services necessary for the Project. Services may
include costs of contract feasibility studies, project management services, engineering and
design, environmental studies, field studies, and surveys for the project as well as costs
incurred to comply with ecological, environmental, and health and safety laws.
f. Construction Services
For construction projects this includes the Grantee’s cost for construction contracts, labor,
equipment, materials, insurance, bonding, and transportation necessary for the Project.
Work performed by the Grantee’s employees during construction may be budgeted under
direct labor and benefits. Contracted project management or engineering may be budgeted
under contractual services and major equipment purchases made by the Grantee may be
budgeted under equipment.
g. Other Direct Costs In addition to the above the following expenses necessary for the
Project may be allowed.
Net insurance premiums paid for insurance required for the grant Project;
Costs of permits and licenses for the grant Project;
Non-litigation legal costs for the Project directly relating to the activities; in this
paragraph, “non-litigation legal costs” includes expenses for the Grantee’s legal staff and
outside legal counsel performing non-litigation legal services;
Office lease/rental payments;
Other direct costs for the Project directly relating to the activities and identified in the
grant documents; and/or
Land or other real property or reasonable and ordinary costs related to interests in land
including easements, right-of-ways, or other defined interests.
3. Specific Expenditures not allowed
Ineligible expenditures include costs for overhead, lobbying, entertainment , alcohol, litigation,
payments for civil or criminal restitution, judgments, interest on judgments, penalties, fines,
costs not necessary for and directly related to the grant Project, or any costs incurred before the
beginning date of the grant as indicated on the signature page.
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Grant Budget Instructions Renewable Energy Fund Round 5
Overhead costs described in this section include:
salaries, wages, applicable employee benefits, and business-related expenses of the
Grantee’s employees performing functions not directly related to the grant Project;
office and other expenses not directly related to the grant Project; and
costs and expenses of administration, accounting, human resources, training, property
and income taxes, entertainment, self-insurance, and warehousing.
4. Match and Cost Sharing
If the Applicant is providing a match, it is should be detailed either as a specific dollar amount or
as a percentage of the total project budget. The type and amount of matching contributions
should be discussed in the application under section two.
Cost sharing or matching is that portion of the Project costs not borne by the Authority. The
Authority will accept all contributions, including cash and in-kind, as part of the Applicants‟ cost
sharing or matching when such contributions meet the following criteria:
Are provided for in the Project budget;
Are verifiable from the Applicant’s records;
Third party costing sharing contributions are verifiable (with a letter of intent or similar
document);
Are not included as contributions for another state or federally assisted project or
program (i.e., the same funds cannot be counted as match for more than one program);
Are necessary and reasonable for proper and efficient accomplishment of the Project or
program objectives;
Are allowable costs;
Are not paid by the State or federal government under another award, except for
authorized by the State or federal statute to be used for cost sharing or matching;
Must be incurred within the grant eligible time period.
Any match proposed with the application will be required in the Grant award and the Grantee
will be required to document the use of the proposed matching funds or in-kind contributions
with their request for reimbursement.
Previous Renewable Energy Fund grants will not be counted as match.
5. Valuing In-Kind Support as Match
If the Applicant chooses to use in-kind support as some; or, its entire match, the values of those
contributions will be reviewed by the Authority at the time the budget is approved. The values will
be determined as follows:
The value of real property will be the current fair market value as determined by an
independent third party or a valuation that is mutually agreed to by the Authority and the
Applicant and approved in the grant budget.
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Grant Budget Instructions Renewable Energy Fund Round 5
The value assessed to Applicant equipment or supplies will not exceed the approved
equipment rates or fair market value of the supplies at the time the grant is approved or
amended.
Equipment usage will be valued based on approved usage rates that are determined in
accordance with the item „c.‟ above. Rates paid will not exceed the fair market value of
the equipment if purchased.
Rates for donated personal services will be based on rates paid for similar work and skill
level in the recipient’s organization. If the required skills are not found in the recipient
organization, rates will be based on rates paid for similar work in the labor market.
Fringe benefits that are reasonable, allowable, and allocable may be included in the
valuation.
Transportation and lodging provided by the Applicant for non-local labor will not exceed
the commercial rates that may be available within the community or region.
6. Grant Disbursements
Applicants are reminded that they must request disbursement of grant funds in the form and
format required by the Authority with appropriate back-up documentation and certifications.
This format will be provided by the Authority.
The back-up documentation must demonstrate the total costs incurred are allowable, and reflect
the amount being billed. Documentation must include:
A summary of direct labor costs supported by timesheets or other valid time record to
document proof of payment.
Travel and per diem reimbursement documentation.
Contractor or vendor payment requests.
Invoices.
Payment of grant funds will be subject to the Applicant complying with its matching contribution
requirements of the proposed grant.
Payment of grant funds will be made by AEA to the Grantee within 30 days of receipt of a
properly completed, supported, and certified Reimbursement Request.
ELECTRONIC VERSION ENCLOSED - CERTIFICATION
ELECTRONIC VERSION ENCLOSED – CERTIFICATION
This is to certify that one electronic version of this grant application on a CD was
included with the two hard copies.
Respectfully,
Glen D. Martin
Resource Assessment, Permitting, Grant Writing
Date: August 22, 2011