HomeMy WebLinkAboutCity of Ouzinkie AEA 15003 REF Grant Application
Hydro Alaska Energy Authority – AEA 15003
Renewable Energy Grant Application
H
CITY OF OUZINKIE
City of Ouzinkie
ALASKA ENERGY AUTHORITY – AEA 15003 RENEWABLE ENERGY
GRANT APPLICATION
APPLICATION CONTENTS
AEA APPLICATION – SECTION 1 THROUGH 9
AUTHORIZED SIGNERS – SECTION 10
ADDITIONAL DOCUMENTATION AND CERTIFICATION – SECTION 11
RESUMES
LETTERS OF SUPPORT
GOVERNING BODY RESOLUTION
FEASIBILITY STUDY
Renewable Energy Fund Round VIII
Grant Application - Standard Form
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Application Forms and Instructions
This instruction page and the following grant application constitutes the Grant Application Form for
Round VIII of the Renewable Energy Fund. A separate application form is available for projects
with a primary purpose of producing heat (see 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
Request for Applications (RFA) and both application forms is available online at:
http://www.akenergyauthority.org/REFund8.html.
If you need technical assistance filling out this application, please contact Shawn Calfa, the
Alaska Energy Authority Grants Administrator at (907) 771-3031 or at scalfa@aidea.org.
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 each phase of the project.
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 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.
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.
In the sections below, please enter responses in the spaces provided, often under the
section heading. You may add additional rows or space to the form to provide sufficient
space for the information, or attach additional sheets if needed.
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 333 (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.
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SECTION 1 – APPLICANT INFORMATION
Name (Name of utility, IPP, or government entity submitting proposal)
City of Ouzinkie
Type of Entity: Fiscal Year End:
Local Government June 30
Tax ID # 92-0035750
Tax Status: ☐ For-profit ☐ Non-profit ☒ Government (check one)
Date of last financial statement audit:2/5/2014
Mailing Address: Physical Address:
PO Box 109 3rd and C Street Box 109
Ouzinkie, Alaska 99644 Ouzinkie, Alaska 99644
Telephone: Fax: Email:
(907) 680-2209 (907) 680-2223 cityofouzinkie@ouzinkie.org
1.1 APPLICANT POINT OF CONTACT / GRANTS MANAGER
Name: Eric Hanssen, P.E. Title: Sr. Engineering Project Manager
Mailing Address:
Alaska Native Tribal Health Consortium
Division of Environmental Health & Engineering
Rural Energy Program
3900 Ambassador Drive, Suite 301
Anchorage, Alaska 99507
Telephone: Fax: Email:
(907) 729-3620 (907) 729-4090 echanssen@anthc.org
1.1.1 APPLICANT ALTERNATE POINTS OF CONTACT
Name Telephone: Fax: Email:
Suzanne Wolf – Energy Program (907) 729-4065 (907) 729-3571 swolf@anthc.org
Heather Dongoski – Grant Specialist (907) 729-3049 (907) 729-3049 hdongoski@anthc.org
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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)
☐ 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)
1.2 APPLICANT MINIMUM REQUIREMENTS (continued)
Please check as appropriate.
☒ 1.2.2 Attached to this application is formal approval and endorsement for the project by the
applicant’s board of directors, executive management, or other governing authority. If the
applicant is a collaborative grouping, a formal approval from each participant’s governing
authority is necessary. (Indicate 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 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
http://www.akenergyauthority.org/REFund8.html. (Any exceptions should be clearly noted
and submitted with the application.) (Indicate by checking the box)
☒ 1.2.5 We intend to own and operate any project that may be constructed with grant funds for
the benefit of the general public. If no please describe the nature of the project and who will
be the primary beneficiaries. (Indicate yes by checking the box)
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SECTION 2 – PROJECT SUMMARY
This section is intended to be no more than a 2-3 page overview of your project.
2.1 Project Title – (Provide a 4 to 7 word title for your project). Type in space below.
Ouzinkie Hydroelectric Power 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 in the subsections below.
2.2.1 Location of Project – Latitude and longitude, street address, or community name.
Latitude and longitude coordinates may be obtained from Google Maps by finding you project’s
location on the map and then right clicking with the mouse and selecting “What is here? The
coordinates will be displayed in the Google search window above the map in a format as follows:
61.195676.-149.898663. If you would like assistance obtaining this information please contact
AEA at 907-771-3031.
57.925879,-152.502766
2.2.2 Community benefiting – Name(s) of the community or communities that will be the
beneficiaries of the project.
Ouzinkie, Alaska
2.3 PROJECT TYPE
Put X in boxes as appropriate
2.3.1 Renewable Resource Type
☐ Wind ☐ Biomass or Biofuels (excluding heat-only)
☒ Hydro, Including Run of River ☐ Hydrokinetic
☐ Geothermal, Excluding Heat Pumps ☐ Transmission of Renewable Energy
☐ Solar Photovoltaic ☐ Storage of Renewable
☐ Other (Describe) ☐ Small Natural Gas
2.3.2 Proposed Grant Funded Phase(s) for this Request (Check all that apply)
Pre-Construction Construction
☐ Reconnaissance ☒ Final Design and Permitting
☐ Feasibility and Conceptual Design ☒ Construction
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2.4 PROJECT DESCRIPTION
Provide a brief one paragraph description of the proposed project.
Ouizinkie formerly had a makeshift hydroelectric operation that had served the village for many
years. However, the dam failed in the fall of 2013 even while a new project was being planned to
replace the dam. Since the new dam construction has begun, Ouzinkie has been without
hydroelectric power. Engineering review of the legacy penstock and power plant strongly
recommended against trying to put the 30 year old pipeline (non-pressure rated sewer pipe) into
service. The proposed project in Ouzinkie will work to install new hydroelectric capacity in
conjunction with the recent new dam construction. A new 5100’ 20 inch HDPE penstock will be
installed to provide water for use in a new Ossberger 150 KW hydroelectric turbine. The turbine is
to operate efficiently at flow rates from 2 cfs to 10 cfs. The penstock will also supply water for the
community water system, ensuring access to clean water for the community replacing the backup
supply source since the dam failure.
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, local jobs created, etc.)
The proposed project will benefit the community by reducing fuel expenses at the power utility by
$171,422 per year, through avoided diesel generator use. The project is anticipated to supply the
community with 475,750 KWH per year through hydroelectric production. This in turn reduces run
time on the diesel generators, extending the equipment’s lifespan, and reduces C02 emissions in
the community from diesel generation. Additionally, there is potential that the benefit may improve
in the future as the precipitation trends have been increasing and the long term projections indicate
that this trend will continue.
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 requested grant funding is $2,516,385. The total anticipated project cost is $2,541,549,
including ANTHC’s in-kind contribution for project and program management services. $99,400 is
needed for design; $2,416,985 is needed for construction. ANTHC will provide an in-kind match of
1% in the form of project and program management services.
In section 2.7.10 – Additional performance monitoring equipment expenses of $15,000 will be
covered under an Environmental Protection Agency project that ANTHC was awarded to install
remote monitoring systems in select rural communities.
2.7 COST AND BENEFIT SUMMARY
Include a summary of grant request and your project’s total costs and benefits below.
Costs for the Current Phase Covered by this Grant
(Summary of funds requested)
2.7.1 Grant Funds Requested in this application $ 2,516,385
2.7.2 Cash match to be provided $ 0
2.7.3 In-kind match to be provided $ 25,164
2.7.4 Other grant funds to be provided $ 0
2.7.5 Total Costs for Requested Phase of Project (sum of 2.7.1 through 2.7.4) $ 2,541,549
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Other items for consideration
2.7.6 Other grant applications not yet approved $ 0
Project Costs & Benefits
(Summary of total project costs including work to date and future cost estimates to get to a fully
operational project)
2.7.7 Total Project Cost
Summary from Cost Worksheet, Section 4.4.4, including
estimates through construction.
$ 2,541,549
2.7.8 Additional Performance Monitoring Equipment not
covered by the project but required for the Grant
Only applicable to construction phase projects
$ 15,000
2.7.9 Estimated Direct Financial Benefit (Savings)
The economic model used by AEA is available at
www.akenergyauthority.org/REFund8.html. This economic
model may be used by applicants but is not required. Other
economic models developed by the applicant may be used,
however the final benefit/cost ratio used will be derived from
the AEA model to ensure a level playing field for all
applicants.
$ 171,422 Annually
2.7.10 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 Section 5 below.
$ Supply of lower cost
energy to non PCE
commercial users
improving the business
climate.
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). In the electronic submittal, please submit resumes as separate
PDFs if the applicant would like those excluded from the web posting of this application. 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.
Alaska Native Tribal Health Consortium (ANTHC) is a statewide non-profit health services
organization, formed by congress in 1997 to assume the roles and duties of the Indian Health
Service (IHS) in Alaska. ANTHC is the largest tribal self-governance entity in the United States,
with over 1,900 employees and an annual operating budget in excess of $475M. Approximately
31% of this funding is from a compact agreement with IHS. Approximately 25% of the operating
revenue originates from other federal and state grants and contracts. ANTHC has a 16-year history
of clean audits, conducted by an independent accounting firm in accordance with the Single Audit
Act.
ANTHC Sanitation Facilities Senior Engineering Project Manager Mike Roberts, P.E. has been with
ANTHC since 2008. As a senior engineering project manager in the sanitation facilities
department, he oversees project development, design, and construction of projects supporting the
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sanitation and energy needs for 17 remote communities throughout Alaska. During his time with
ANTHC, Mike has served as both a sanitation facilities project manager and as the safety program
coordinator, responsible for managing the construction safety program for construction operations
throughout the state. Prior to joining ANTHC, Mike served eight years on active duty in the US Air
Force as a Bioenvironmental Engineer in Panama City, FL, Dayton, OH, and San Antonio, TX. He
holds a Bachelors of Science in Environmental Engineering from the US Air Force Academy in
Colorado Springs, CO, and a Master’s of Science in Environmental Engineering from the Air Force
Institute of Technology in Dayton, OH.
3.2 Project Schedule and Milestones
Please fill out the schedule below. Be sure to identify key tasks and decision points in in your
project along with estimated start and end dates for each of the milestones and tasks. Please
clearly identify the beginning and ending of all phases of your proposed project.
Please fill out form provided below. You may add additional rows as needed.
The Milestones noted below, are based on a typical construction season. If the project is awarded, before it is
executed, updated and realistic milestones will be completed by ANTHC and provided to AEA.
Milestones Tasks Start Date End Date
Conduct Kickoff Meeting 11/1/2015 11/1/2015
65% design w/cost estimate 11/1/2015 1/1/2016
Final Design documents 1/1/2016 2/1/2016
Pre-construction meeting 2/1/2016 3/1/2016
Construction 5/1/2016 7/1/2017
Commissioning 7/1/2017 9/1/2017
Final Inspection and follow-up 9/1/2017 10/1/2017
Project closeout 10/1/2017 12/31/2017
Project management throughout (ANTHC in-kind) 11/1/2015 12/31/2017
1.) Project Planning
2.) Construction
3.) Project Closeout
4.) Project Management and Match Activities
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3.3 Project Resources
Describe the personnel, contractors, personnel or firms, 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.
ANTHC DEHE provides design and construction services for rural Alaskan communities
infrastructure projects and is able to employ either typical contract or force account construction
services to complete the project. DEHE has successfully partnered and worked with the City of
Grayling on sanitation and health facilities design and construction projects. The ANTHC will
administer and be responsible for executing the proposed installation project. ANTHC will enter
into a cooperative project agreement (CPA) with the City of Grayling, to implement the project, if it
is awarded.
The project manager will be supported in the design of the project by John Warren, Director of
Engineering at ANTHC, Chong Park, ANTHC Lead Mechanical Engineer, and Dave Reed, ANTHC
Lead Electrical Engineer. To the extent possible, local labor will be used during construction.
ANTHC will use its purchasing and contracting resources for material procurement and delivery.
Resumes of potential alternate resources and key personnel are attached to this application.
3.4 Project Communications
Discuss how you plan to monitor the project and keep the Authority informed of the status. Please
provide an alternative contact person and their contact information.
Written project progress reports will be provided to the AEA project manager as required by the
grant. Meetings will be conducted by ANTHC, the Village, and AEA to discuss the status of the
project. Regular coordination meetings will be held between AEA and ANTHC regarding all
projects.
3.5 Project Risk
Discuss potential problems and how you would address them.
In general there are no technological or financial risks identified for this project. A major piece of
this overall project, the construction of the new dam has gone quite well. To construct the new
dam, improved access was developed which will benefit the installation of the penstock. Installing
a 20 inch HDPE penstock from the new Ouzinkie dam to the powerhouse could result in some
challenges primarily pertaining to poor weather and unanticipated discoveries during burial of the
pipe. These potential risks are not considered significant.
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3.6 Project Accountant(s)
Tell us who will be performing the accounting of this Project for the Grantee and include contact
information, a resume and references for the project accountant(s). In the electronic submittal,
please submit resumes as separate PDFs if the applicant would like those excluded from the web
posting of this application. If the applicant does not have a project accountant indicate how you
intend to solicit project management support.
The City of Ouzinkie will use the accounting resources of ANTHC. ANTHC’s Division of
Environmental Health accounting department is led by the Construction Controller, Diane Chris.
The Construction Finance Department is comprised of 10 staff that handle all DEHE’s accounting
functions. A Senior Accountant has been designated to support any ANTHC Grant awards
including AEA financial reporting. Key Staff resumes are included in this application.
3.7 Financial Accounting System
Discuss the accounting system that will be used to account for project costs and whom will be the
primary user of the accounting system.
The project finances will be kept in Spectrum construction job cost accounting software used by
ANTHC. The software accounts expenditures by phase code and cost types. Purchasing,
contracting, and accounting are the primary users of the system with the information always
available to the Project Team.
3.8 Financial Management Controls
Discuss 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 Renewable Energy Fund Grant Program.
The City of Ouzinkie will enter into a cooperative project agreement (CPA) with ANTHC to
implement the project as well as financial management. ANTHC’s cost controls have been
implemented to comply with OMB cost control principles and requirements of all state and federal
grants. ANTHC has a 16-year history of clean audits, conducted by an independent accounting
firm in accordance with the Single Audit Act. ANTHC will provide records and accounting records
available to state and federal auditors on request.
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ECTION 4 – PROJECT DESCRIPTION AND TASKS
The level of information will vary according to phase(s) of the project you propose to undertake
with grant funds.
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. For pre-construction applications, describe
the resource to the extent known. For design and permitting or construction projects, please
provide feasibility documents, design documents, and permitting documents (if applicable) as
attachments to this application.
The appendices of the attached feasibility study detail the assessments of the resource. Various
penstock flow rates were examined with consideration to river flow levels. The power output and
operation time also vary with the supply flow rate from the penstock. Below is a high level
summary of this:
Q_Penstock
cfs
V_penstock
fps
H_net
(ft)
P_supplied
to Turbine,
KW
Power
output
KW
Days of
operation
3.3 1.96 228 64.4 50 286
3.8 2.24 227 73.3 57 250
5.0 2.96 226 96.7 77 189
5.7 3.35 224 108.5 87 167
7.6 4.47 222 143.4 119 125
8.6 5.03 218 158.4 133 111
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.
The City of Ouzinkie’s electrical utility currently generates electricity from a 60 KW, a 100 KW, and
a 190 KW diesel generator. The City’s electrical utility has in the past generated electricity from a
mixture of diesel and hydroelectric sources, but those were decommissioned with the dam failure.
The utility owns three diesel generators, a 60 KW generator, a 100 kW generator, and a 190 kW
generator. The decommissioned hydroelectric generator had a maximum capacity of 125 kW.
The production of the various generators varies greatly by month. In general, the more hydro-
electric power that was produced, the less the larger generators are used (see Figure 6, Appendix
A of the feasibility study.
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.
Currently Ouzinkie utilizes diesel fuel for electrical generation. The location of the new turbine
would be directly adjacent to diesel power generation, providing for ease of access and easy
integration of controls. Operation of the largest diesel generators should decrease while
hydroelectricity provides a significant portion (sometimes as much as 100%) of the base
community load.
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4.2.3 Existing Energy Market
Discuss existing energy use and its market. Discuss impacts your project may have on energy
customers.
The average usage per month in Ouzinkie is 73,930 KWH with demand peaking in the winter.
Currently residential makes up 45% of the yearly electrical load, commercial users make up about
36% of the load, and governmental users make up 19% of the load. The primary impact of
reducing fuel usage, and thus operating costs for the power utility, will likely primarily reduce state
PCE reimbursement. However, non-PCE eligible customers, such as commercial facilities, could
potentially see a reduction in their electrical rate. More details are available in the feasibility study.
4.3 Proposed System
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
A 5100’ HDPE butt fused penstock will be installed from the new Mahoona Dam to the site of
the existing Ouzinkie power plant. The existing structure next to the Ouzinkie powerhouse
will house the Ossberger 150 kW two celled turbine and generator set. The 150 KW
Ossberger turbine generator operates at 81.4% efficiency and can allow for operation of
either turbine at 75 KW when flow from the Mahoona lake dam is low.
At maximum capacity the Ossberger turbine can produce 150 kW of power, occasionally
carrying 100% of the community of Ouzinkie’s electric load.
Anticipated capacity factor : 64%
Anticipated annual generation of this project is 475,750 KWH
Anticipated barriers: None. Environmental and permitting barriers were addressed in
construction of the dam.
Basic integration concept: Integration with the diesel plant as a hybrid operation. The
hydroelectric is to make up the base electrical production with the diesel generators
providing peak demands.
Delivery methods: Existing electrical distribution infrastructure.
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.
The penstock and power house are to be on Ouzinkie Corporation land.
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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 discuss potential barriers
Permits for the existing dam construction include:
SWPPP
Endangered Species Section 7 concurrence
SHPO concurrence
USACE NWP
ADF&G Fish Habitat not required per agency correspondence
DNR Water Rights (existing, in place per DNR)
The same permits are expected to be required for this project. Federal Energy Regulatory
Commission (FERC) licensing is not required as the entire project is on native owned lands.
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
ANTHC will consider all potential environmental concerns associated with this project. ANTHC has
extensive experience using the comprehensive Indian Health Service (IHS) environmental review
procedures for conducting environmental analysis of all health and sanitation facilities projects in
all stages of development, as outlined in the IHS environmental review Manual issued in January
2007.
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: Applicant’s 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
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Identification of other funding sources
Projected capital cost of proposed renewable energy system
Projected development cost of proposed renewable energy system
Total anticipated project cost for design/construction of this project is $2,541,549
Requested grant funding is $ 2,516,385
ANTHC will contribute matching project and program management funds of 1% or $ 25,164
The Mahoona Lake dam was constructed with funding from ANTHC and the State of Alaska
Project development costs of the Ouzinkie Hydroelectric Turbine and penstock are $100,394
for design and permitting of the project.
Projected capital cost of proposed renewable energy system is $ 2,441,155 which includes
construction and project management.
In section 2.7.10 – Additional performance monitoring equipment expenses of $15,000 will be
covered under an Environmental Protection Agency project that ANTHC was awarded to install
remote monitoring systems in select rural communities.
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.)
Operating and Maintenance costs for the proposed hydroelectric system in Ouzinkie will likely
decrease operating costs overall for the power utility. Hydroelectric plants of this size are notable
for their low operation and maintenance cost. Reduced run time on the diesel generators will
reduce maintenance requirements of those. The new road to the new dam will allow for ease of
access in case of problems with the intake or any sensors required for the hydroelectric turbine.
Operations and maintenance costs will be paid for out of electrical bill collection.
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
Rates will be adjusted as is required by the regulatory commission. In addition, future fish
processing, ferry terminal and a commercial greenhouse is planned.
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4.4.4 Project Cost Worksheet
Complete the cost worksheet form which provides summary information that will be considered in
evaluating the project.
Please fill out the form provided below.
Renewable Energy Source
The Applicant should demonstrate that the renewable energy resource is available on a
sustainable basis.
Annual average resource availability. 3.68 CFS
Unit depends on project type (e.g. windspeed, hydropower output, biomass fuel)
Existing Energy Generation and Usage
a) Basic configuration (if system is part of the Railbelt1 grid, leave this section blank)
i. Number of generators/boilers/other 3 Diesel Generators
ii. Rated capacity of generators/boilers/other 60, 100, 190 kW
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 $75,000
ii. Annual O&M cost for non-labor $270,000
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] 887,164
ii. Fuel usage
Diesel [gal] 67,439
Other
iii. Peak Load 175 KW
iv. Average Load 90 kW
v. Minimum Load 80 kW
vi. Efficiency
vii. Future trends Some growth expected. See 4.4.3
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
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 VIII
Grant Application - Standard Form
AEA 15003 Page 15 of 22 7/2/14
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]
150 kW Hydroelectric
b) Proposed annual electricity or heat production (fill in as applicable)
i. Electricity [kWh] 475,750 kWh
ii. Heat [MMBtu] 0
c) Proposed annual fuel usage (fill in as applicable)
i. Propane [gal or MMBtu]
ii. Coal [tons or MMBtu]
iii. Wood or pellets [cords, green tons,
dry tons]
iv. Other
Project Cost
a) Total capital cost of new system $ 2,441,155
b) Development cost $ 100,394
c) Annual O&M cost of new system $2,000 per year based on past experience.
d) Annual fuel cost $148,240 (residual fuel cost for diesel)
Project Benefits
a) Amount of fuel displaced for
i. Electricity $171,422 (36,164 gal of diesel displaced)
ii. Heat
iii. Transportation
b) Current price of displaced fuel $4.74
c) Other economic benefits $ 10,000 Reduced operating cost @ water treatment plant
d) Alaska public benefits Raw water supply to the water treatment plant currently
operating with back-up supply, Reduced C02 Emissions
Power Purchase/Sales Price
a) Price for power purchase/sale
Project Analysis
a) Basic Economic Analysis
Project benefit/cost ratio
Payback (years) 14.5 years
Renewable Energy Fund Round VIII
Grant Application - Standard Form
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4.4.5 Impact on Rates
Briefly explain what if any effect your project will have on electrical rates in the proposed benefit
area. If the is for a PCE eligible utility please discuss what the expected impact would be for both
pre and post PCE.
Ouzinkie had existed with partial hydropower for roughly 30 years. However, this was a makeshift
set up including a wooden dam, sewer pipe used as penstock and the hydroelectric turbine. Since
the dam failed in 2013, Ouzinkie has been without hydroelectricity and has seen the cost of power
approximately double. Furthermore, Ouzinkie has been strongly advised by professional
engineers and consultants not to attempt to make use of the 30 year old sewer pipe for a penstock
with a new hydroelectric system so this problem will continue. Building a penstock and hydro plant
and putting it on-line will greatly reduce the cost of diesel operations by 54 % over current diesel
operations and some years will be more. This should save PCE subsidies as well as provide lower
rates for non-PCE commercial users.
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 (gallons and dollars) 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
The annual projected diesel fuel to be displaced is estimated at 36,164 gallons per year. At the
current rate paid for fuel, this amounts to an annual savings of $ 171,422. This will lower the
electricity cost, provide a sustainable power source, reduce run time of electric generators, and
reduce emissions normally created from power production.
5.1 Public Benefit for Projects with Private Sector Sales
Projects that include sales of power to private sector businesses (sawmills, cruise ships, mines,
etc.), please provide a brief description of the direct and indirect public benefits derived from the
project as well as the private sector benefits and complete the table below. See section 1.6 in the
Request for Applications for more information.
Renewable energy resource availability (kWh per month) 39,646 kWh
Estimated sales (kWh)
Revenue for displacing diesel generation for use at
private sector businesses ($)
Estimated sales (kWh) 39,646 kWh/month
Revenue for displacing diesel generation for use by the
Alaskan public ($)
$171,422 annually
Renewable Energy Fund Round VIII
Grant Application - Standard Form
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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
City employees will conduct periodic maintenance such as cleaning intake screens, monitoring
water levels and production numbers, troubleshooting reported problems etc. Specialized
contractors will be engaged when specialty work is required on the actual turbine. Project
constructed infrastructure maintenance will be financed out of electrical rate collections from
existing and future customers in Ouzinkie. Rates should eventually decrease from the increased
hydroelectric production.
Integration of existing diesel generation will need to be appropriately controlled to ensure proper
switch gear operation and to minimize power distribution disruptions.
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.
Presently final design efforts are planned for the winter of 2015. Shortly thereafter materials will be
ordered and shipped to the community so that construction can commence in the summer of 2016.
The design for the penstock has already been completed to the 65% level as part of previous
design effort on the new dam in Ouzinkie. This effort was funded by the Alaska Native Tribal
Health Consortium. The new dam is nearing completion as of September 2014, and was funded by
the Alaska Legislature. The new dam in Ouzinkie will increase the amount of water available for
storage in Mahoona Lake from the levels of the failed wooden dam.
SECTION 8 – LOCAL SUPPORT AND OPPOSITION
Discuss local support and opposition, known or anticipated, for the project. Include letters of
support or other documentation of local support from the community that would benefit from this
project. The Documentation of support must be dated within one year of the RFA date of July 2,
2014
The City of Ouzinkie is submitting the grant application. ANTHC has provided match for the project
as well as a letter of support. The Ouzinkie Native Corporation, Native Village of Ouzinkie, and
Kodiak Island Borough have all written letters of support to this project. There is no known
opposition to this project.
Renewable Energy Fund Round VIII
Grant Application - Standard Form
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SECTION 9 – GRANT BUDGET
Tell us how much you are seeking in grant funds. Include any investments to date and funding
sources, how much is being requested in grant funds, and additional investments you will make as
an applicant.
9.1 Funding sources and Financial Commitment
Provide a narrative summary regarding funding source and your financial commitment to the
project
The cost estimates presented in the table below represent the anticipated costs of the proposed
system, taking into account recent design and construction costs of similar projects. Large
financial risks are associated with construction work in rural Alaska. Expenses for potential
changes in site conditions, unknown or unforeseen issues, and logistics have been incorporated
into these costs. ANTHC’s match may actually work out to be much higher than shown, as this
work may be performed at ANTHC’s billing rate and may exceed the hours anticipated.
Any excess time/value of the project management in-kind match does not replace other financial
cost elements of this project. The anticipated dates of completion are assumed based on the
likelihood of funding, other ongoing work in the city, and other heat recovery work going on around
the state.
9.2 Cost Estimate for Metering Equipment
Please provide a short narrative, and cost estimate, identifying the metering equipment, and its
related use to comply with the operations reporting requirement identified in Section 3.15 of the
Request for Applications.
It is proposed to specify and install electrical metering equipment that can be used to feed AEA’s
remote monitoring system. Installation of this equipment would greatly simplify the reporting
requirements, of at least the operational and performance data. Specific equipment selection and
specification will be in cooperation with AEA to insure reporting needs are met.
Renewable Energy Fund Round VIII
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Applications MUST include a separate worksheet for each project phase that was identified in
section 2.3.2 of this application, (I. Reconnaissance, II. Feasibility and Conceptual Design, III. Final
Design and Permitting, and IV. Construction and Commissioning). Please use the tables provided
below to detail your proposed project’s budget. Be sure to use one table for each phase of your
project.
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 at 907-771-3031 or by emailing the Grants
Administrator, Shawn Calfa, at scalfa@aidea.org.
DESIGN PHASE
Milestone or Task
Anticipated
Completion
Date
RE- Fund
Grant
Funds
Grantee
Matching
Source of
Matching Funds:
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
TOTALS
(List milestones based on
phase and type of project. See
Milestone list below. )
Project Management Throughout $500 $994
In-kind 1%
ANTHC
project/program
management
$1,494
Conduct Kickoff Meeting $10,000 $10,000
65% design w/cost estimate $70,000 $70,000
Final Design documents $18,899 $18,899
TOTALS $99,400 $994 $100,393
Budget Categories:
Direct Labor & Benefits $0
Travel & Per Diem $0
Equipment
Materials & Supplies
Contractual Services * $99,400 $994 $100,394
Construction Services
Other
TOTALS $99,400 $994 $100,394
Renewable Energy Fund Round VIII
Grant Application - Standard Form
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CONSTRUCTION PHASE
Milestone or Task
Anticipated
Completion
Date
RE- Fund
Grant
Funds
Grantee
Matching
Source of
Matching Funds:
Cash/In-
kind/Federal
Grants/Other State
Grants/Other
TOTALS
(List milestones based on phase
and type of project. See Milestone
list below. )
Project Management Throughout $24,170
In-kind ANTHC
project/program
management
$24,170
Pre-construction meeting $10,000
Construction $2,250,000 $2,250,000
Commissioning $40,000 $40,000
Final Inspection and follow-up $106,985 $106,985
Project Closeout $10,000 $10,000
$2,416,985 $24,170 $2,431,155
Budget Categories:
Direct Labor & Benefits
Travel & Per Diem $0
Equipment
Materials & Supplies $0
Contractual Services * $2,416,985 $24,170 $2,431,155
Construction Services
Other
TOTALS $2,416,985 $24,170 $2,431,155
City of Ouzinkie
LETTERS OF SUPPORT
City of Ouzinkie
GOVERNERING BODY
RESOLUTION
1
TABLE OF CONTENTS
BACKGROUND ........................................................................................................................................ 2
EXISTING ELECTRICAL SYSTEM ........................................................................................................ 3
SYSTEM DEFICIENCIES ......................................................................................................................... 4
ANALYSIS OF ALTERNATIVES ............................................................................................................ 5
CONCLUSIONS......................................................................................................................................... 7
APPENDICIES:
Appendix A – Electrical System Data
Appendix B – Hydro-Electric Data
Appendix C – Cost Estimates
Appendix D – Conceptual Design
2
BACKGROUND
The decommissioned existing hydro-electric system in Ouzinkie was constructed in 1986 by a
private contractor to sell low cost electricity to the community. The dam was a composite wood,
steel, concrete and rock fill structure that was used to increase the water storage capacity of
Mahoona Lake and to divert water to the 125kW hydro-electric turbine. The penstock was
constructed using thin walled plastic sewer pipe and the turbine was housed in a shipping
container to reduce construction costs. The system has served the community well for almost 30
years until the dam failure in the fall of 2013. The turbine consumed about seven (7) cubic feet
per second (cfs) of water when operating at full capacity and requires approximately five (5)
acre-feet of water to produce about 1000 kW of electrical power. Ownership of the dam,
penstock and hydro-electric turbine was transferred to the City of Ouzinkie (City) in 1993.
On June 10, 2011 the State of Alaska, Department of Natural Resources, Dam Safety and
Construction Unit conducted a field inspection of the Mahoona Dam. The field inspection report
for the site visit noted concerns about the structural integrity of the wooden supports and
degradation of the dam face.
Prior to June 2011, a private engineering contractor had been retained by the City to conduct
periodic safety inspections of the Mahoona Lake dam. On September 15, 2011, the engineering
contractor inspected the Mahoona Lake dam subsequent to a significant rainfall event that caused
some flooding in the community. The dam spillway had become clogged with debris and the
dam filled to a water level above the normal operating point. The event stressed the wooden
supports resulting in additional damage to the already compromised wooden structure. On
September 27, 2011 a letter was issued by the contactor to the City noting that “the structure has
been further evaluated and confirmed to be deteriorated to the point where operation at full
reservoir level is unwise”
In early 2012 ANTHC partnered with the City to complete the design of a new dam and to
pursue funding to replace the deteriorating dam. The design incorporated some of the structural
elements of the existing dam in order to reduce construction costs. Because of the seismic risk in
the area and the amount of water impounded by the dam, the new facility was designed
conservatively as a concrete faced rock fill (CFR) dam. ANTHC’s cost proposal for the new
CFR dam was approximately 60% lower than a competing cost proposal the City received from a
private contractor.
In early 2013 the city was successful in obtaining funding from the State of Alaska to build the
3
new dam. Construction was scheduled to begin in April 2014. In mid-March 2013 a breach
formed in the old dam. The breach was caused by a tree stump that had floated up to the dam and
punched a hole through the rotted wooden face. Because of the dam breach, the construction
scheduled was accelerated. Completion of the new dam is scheduled for September 2014.
EXISTING ELECTRICAL SYSTEM
The City’s total electrical consumption over a two year period is illustrated in Figure 1 in
Appendix A. Figure 1 indicates that electrical consumptions peaks in the middle of the winter,
and is lowest in the summer. The variation in demand is likely due to lower lighting and heating
demands in every sector of the community, as well as a large drop-off due to the reduced usage
of the school during the summer.
The City’s electrical consumption can be broken down in to three categories, residential,
commercial, and governmental. These are based on power cost equalization (PCE) definitions.
Residential is entirely homeowners, who are eligible for power cost subsidies up to 500 kWh per
month. Commercial users are businesses and some state and federally funded facilities which are
not eligible for PCE (including the school). Governmental facilities are primarily city owned
facilities, but also include the health clinic.
The largest consumer of electricity in the community is residential (see Figure 2, Appendix A).
Residential also has the lowest variation in consumption. Commercial is the second largest, but
has significantly more variation in consumption, primarily due to the school being significantly
lower in the summer. Governmental consumption fluctuates largely due to the electrical usage of
street and harbor lighting, but makes up the smallest portion of electrical consumption overall for
the community.
Over the course of the year, residential makes up 45% of electrical consumption, commercial
36%, and governmental 19% (See Figures 3, 4 and 5 in Appendix A). This however is
substantially different seasonally. (Summer defined as June, July August. Winter defined as the
rest of the year)
While electrical consumption rises across all sectors during the winter, the increase in
governmental and commercial facilities is far greater.
Sector Active Meters Average Monthly Consumption (kWh)
Residential 90 288.97
Commercial 23 907.18
Governmental 15 752.13
4
While residential makes up the primary electrical consumption base, the largest single users are
primarily governmental and commercial users.
Electrical Generation
The City’s electrical utility has in the past generated electricity from a mixture of diesel and
hydro-electric sources. The utility owns three diesel generators, a 60 KW generator, a 100 kW
generator, and a 190 kW generator. The decrepit existing hydro-electric generator has a
maximum capacity of 125 kW.
The production of the various generators varies greatly by month. In general, the more hydro-
electric power that is produced, the less the larger generators are used (see Figure 6, Appendix
A).
The old Hydro-electric production varied from producing 40,000 kWh at max capacity, to
producing 0 kWh. Hydro-electric production is the primary variable in determining how much
diesel generation capacity is used (see Figure 7, Appendix A). In recent years the hydro-
electricity has been shut down as much as 30% of the time, with future shut downs expected to
increase based on the turbine/generator set installed in 1988 reaching the end of its useful life
Hydro-electric power on average made up 28% of the electrical production with the old turbine
and generator in the community. Line losses average 9% and did not vary based on the primary
source of electrical generation (see Figure 8, Appendix A).
Hydro-electric Capacity
If Hydro-electric power could produce at its 40,000 kWh/month max regularly, it would meet
50% of the winter time load of the community, and 75% of the summer time load.
To be able to meet the communities current electrical demands 100% with hydro-electric power.
Hydro-electric production would have to be increased to 55,000 kWh/month in the summer and
72,000 kWh/month in the winter. However, the amount of water from the watershed is not
sufficient to support this all of the time.
Residential electrical consumption dips in the summer on the whole. This effect is mitigated by
the presence of some seasonal residents who are typically fairly large users. The decline in
consumption is unfortunately minimized due to the increase in residents (see Figure 9, Appendix
A).
SYSTEM DEFICIENCIES
The existing turbine is aging and requires constant maintenance to keep it operating. Even with
diligent maintenance, the City of Ouzinkie reports that the system was down for repairs or
5
waiting on parts on average 30% of the time each year. The existing turbine is also not properly
sized to take full advantage of the limited watershed that feeds Mahoonah Lake.
The existing turbine is oversized and operating inefficiently during the majority of the year when
flows from the watershed cannot support operating the turbine at full capacity. From the
precipitation vs. flow rate analysis (see Figure 2, Appendix B), it can be noted that operating the
turbine at full capacity can only occur for a limited number of days each year after a significant
storm event. The system can operate at full capacity on average only 5% of the year and at
approximately 40% of its capacity or less over more than 55% of the time each year (Alaska
Climate Summaries, 1973-2006).
The bottom line is that the hydro-electric turbine is oversized for the watershed and needs better
controls to take advantage of equalizing heavy precipitation events. Ideally all water entering the
lake would flow through the penstock and not over the dam spillway. A turbine system that is
capable of operating efficiently at both high and low flow rates will increase the amount of
power that can be produced from water flowing down the penstock. Preventing water loss over
the spillway by using a control system with a sound operating strategy, that considers the
hydraulics of the watershed, will maximize the amount of power that can be produced by the
system. Finally, a new system that is not plagued with breakdowns will ensure the turbine is
available to operate when the water resource is available. From the previous discussion on
hydro-electric capacity, it should be noted that a properly designed and operated hydro-electric
facility can substantially reduce the City’s reliance on diesel electric power.
Water is sourced from Mahoona lake to supply the hydro-electric turbines using 5100’ of 18”
and 21” diameter PVC penstock. The penstock was constructed in the 1980’s using non-pressure
rated PVC sewer pipe meeting ASTM F679, ASTM F679 is only suitable for non-pressure
drainage of sewer and surface water. The pipe was poorly covered during construction and has
jacked and been pushed through time. Exposed pipe can be crushed by falling trees. Though the
transmission line has performed adequately, it is not rated for the pressurized water currenty
flowing through the pipeline and is at extremely high risk of failure.
A new penstock is essential and required to operate hydroelectric power in the community. This
transmission line is also the communities’ only source of water for their community water
system. Ensuring a stable supply of water to the community is critical for maintain access to
clean water for the community of Ouzinkie.
ANALYSIS OF ALTERNATIVES
In order to more effectively provide electrical power, the hydro-electric turbine should be a two-
celled 150 kW Ossberger turbine/generator set. The Ossberger turbine will generate a partial load
6
of its specified 150 kW by opening or closing the guide vane positions via the lake water level
controller. The current peak load is approximately 175 kW, which primarily occurs during the
winter. During the majority of the time, the Ossberger turbine will provide 75 kW of hydro-
electric supplementary power through either turbine. With this configuration, the efficiency of
the City’s power system can be optimized if a new 120 kW diesel generator is also installed.
However, the installation of a new diesel generator is not part of this project but should be
considered in the future.
Ouzinkie’s historic precipitation information is shown in Figure 1, Appendix B.
Due to the limited size of the watershed, the City cannot rely on hydro-electricity to provide
100% of the community’s electrical demands at a sustained level. However, it should be noted
that the amount of water passing through the hydro-electric turbine can occasionally be reduced
(see Figure 2, Appendix B). For example, when electrical demand is lower, the amount of water
passing through the turbine can be reduced resulting in water conservation and lower electrical
power production. The water flow rate through the turbine will be approximately 2.5-5 cfs. The
corresponding electricity generated from the aforementioned flow rate would be approximately
25,000-58,000 kWh (see Figure 3, Appendix B).
During higher precipitation, the hydro-electric power can run on full capacity at 150 kW without
utilizing a diesel generator.
During lower-than-average precipitation, the hydro-electric power needs to run on partial
capacity (approximately 75 kW) of the full capacity of 150 kW by utilizing either one of the
proposed turbine/generator sets in conjunction with a 120 kW diesel generator.
The turbine/generator analyses were performed as follows:
1. Ossberger Turbine (150KW): Install a new turbine/generator in the old hydro-electric
turbine/generator facility adjacent to the Ouzinkie power plant.
2. Quote from Hydropower Turbine Systems (HTS) Inc: $250,000 with existing switchgear
3. The technical data given by HTS indicates that the turbine’s peak mechanical efficiency
is approximately 81.4%. The estimated range of turbine efficiency for the new turbine is
an estimated 75% (lower flow rate) to 83% (higher flow rate).
4. Over the course of the year this turbine would generate 475,750 KWH of electricity.
Based on 2011 PCE data, Ouzinkie’s exsiting diesel generation has a KWH/gallon of fuel
efficiency of on average 13.155. 475,750 KWH would displace 36,151 gallons of fuel at
$4.74 per gallon for a total project benefit of $171,422.
A new penstock of 5,100 ft needs to be installed using 24” HDPE, SDR 15.5, butt fused
connections. This pipe is rated for water pressure application and has excellent freeze/thaw
characteristics. Proper installation practices should be followed to provide an adequate bury
7
depth below the frost line and for protection of the pipe. Other upgrades would include air relief
stations along the pipeline, a bypass line at the hydro plant, proper main line valves at the upper
and lower ends of the line, and adequate pressure relief in case of a line surge.
A construction cost estimate is attached for the construction costs of a new penstock. 65%
Design, including surveying for the new penstock has been completed with funding from the
State of Alaska for the Mahoona dam replacement. Completing design of the penstock would
require minimal effort.
CONCLUSIONS
Estimated construction costs include materials, equipment, freight, labor, design, construction
management, training and startup and testing. Cost was estimated based on recent project
experience.
All work at the hydro-electric turbine buildings, construction of the penstock, along with design
and construction management/administration for the complete project, is included in the Base
Project cost. Incremental costs for overhead and freight are estimated individually (refer to
attached cost estimates located in Appendix C).
The monthly electricity costs saved with the Ossberger turbine and penstock are illustrated in
Figure 4, Appendix B. The estimated annual community savings from generating hydro-electric
power in conjunction with existing diesel generation, is $171,422. . Based on the ratio of the
project cost to savings, the estimated simple payback is 14.5 years.
If this proposal is granted through the State of Alaska Renewable Energy Fund Grant Program in
the Round VIII, construction money for this project will be available in 2 years. With a 2 year
escalation rate of 3%, the respective estimated project cost in 2016 is $2,516,385.
APPENDIX A
ELECTRICAL SYSTEM DATA
APPENDIX B
HYDRO-ELECTRIC DATA
010,00020,00030,00040,00050,00060,00070,00080,00090,000100,000May June July Aug Sept Oct Nov Dec Jan Feb March AprilElectricity (KWh)MonthRequired Electricity VS Available ElectricityMonthly Electrical Power Requirement (2012, from John W)Monthly Electric Power Generated (2011, PCE Data)Future Monthly Available Electricity from a new Hydroelectric Turbine
05,00010,00015,00020,00025,000May June July Aug Sept Oct Nov Dec Jan Feb March AprilTotal Fuel Cost Saving (Dollars)MonthTotal Fuel Cost Saving with New Hydroelectric Turbine Total fuel Cost Saving with New Turbine
APPENDIX C
COST ESTIMATES
Ouzinkie Cost Estimate for Hydro-Electric ProjectQty Rate 134 126 117 115 127 126 85 108 35 35 35 Labor Civil 400 8 50.050,000$ Site Visit 6 1,100.00$ 6,600$ Mechanical 80 8 10.09,600$ Site Visit 2 1,100.00$ 2,200$ Electrical 240 8 30.028,800$ Site Visit 2 1,100.00$ 2,200$ DesignTotal hours 1151.3 300.0 1421.3 75.1 155.0 5.0 44.0 711.3 2736.0 10.0 20.0MobilizationEquipment Shipping 1 1 1.0 1 12,510$ Misc equip a1 10,000.00$ 20,000$ 20,000.00$ Camp set up 1 1 1.0 2 1 34,900$ -$ -$ Shop Set up 0.0-$ -$ -$ Takeoffs 1 1 1.0 56,700$ Support Mat1 10,000.00$ 10,000$ 10,000.00$ Training 0.01-$ -$ -$ Materials Receiving and Inventory 1 1 1.0 1 0.2 0.5 0.5 0.2 34,055$ -$ -$ Set up Materials Storage/Yard 1 1 1.0 1 2 0.2 45,250$ -$ -$ Expediting to Const Site 1 1 1.0 3 3 69,630$ -$ -$ Dam Safety ReviewDam Safety 1 20,000.00$ 20,000$ 20,000.00$ -$ -$ -$ Penstock ConstructionLine clearing / grubbing 5100 300 18.0 1 2 0.1 174,610$ Excavation 5100 500 10.8 1 1 0.1 1 247,574$ HD PE Pipe 5100 104.29$ 531,900$ 63,828$ 595,728.00$ Bedding materials 2500 300 8.3 1 1 0.1 1 339,625$ Bedding 2500 25.00$ 62,500$ 7,500$ 70,000.00$ Pipe Installation 5100 300 18.0 1 2 0.1 1 3106,650$ seeding 5100 5.29$ 27,000$ 3,240$ 30,240.00$ Backfill and seeding 5100 300 18.0 1 1 0.1 1 385,590$ Fittings 1 25,000.00$ 25,000$ 3,000$ 28,000.00$ Connection to New Dam 1 0.2 5.0 1 1 1 323,200$ Air Relief 5 5,000.00$ 25,000$ 3,000$ 28,000.00$ Connection to Hydro building 1 0.2 5.0 1 1 1 323,200$ Fuel/Parts 1 40,000.00$ 40,000$ 4,800$ 44,800.00$ Install Air Relief Valves 5 1 5.0 1 2 1 329,050$ Equipment 11 100,000.00$ 100,000$ 12,000$ 112,000.00$ -$ -$ -$ -$ -$ -$ Module 1 1 1.0 1 1 3 1 14,170$ Module 1 -$ -$ -$ Generator installation 1.0 1 2 2 15,910$ Generator 1 250,000.00$ 250,000$ 30,000$ 280,000.00$ Electrical Controls 1 1 1.0 1 15 1525,640$ Elect Contro1 50,000.00$ 50,000$ 6,000$ 56,000.00$ -$ -$ -$ -$ Literature and References 1 1 1.0 56,300$ Publishing 4 500.00$ 2,000$ 240$ 2,240.00$ Startup and Training 2 1 2.0 1 10 229,280$ -$ -$ -$ -$ -$ -$ -$ -$ Preliminary Clean Up 0.0-$ -$ -$ -$ Final Inspection Punch List 1 1 1.0 1 1 23,300$ -$ -$ -$ Final Clean Up 2 1 2.0 0.5 22,740$ -$ -$ -$ -$ -$ -$ -$ -$ Pack Up and Crate 1 1 1.0 5 5 2 1017,750$ Shipping - D1 50,000.00$ -$ -$ Shipping / Equipment 1 1 1.0 1 1 23,210$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ -$ Financial Close out/ Auditing 1 1 1.0 11,260$ Printing 1 500.00$ 500$ 500.00$ As builting 1 1 1.0 1 12,600$ Audit 1 15,000.00$ 15,000$ 15,000.00$ -$ -$ -$ Fixed estimate @ 120 /hr.Fixed estimate @ 120 /hr.Assumptions: No. Cost EaFinalStartup and CommissioningJob Clean Up/ Final Inspection*NoteEngineerTotal CostDe-MobeELEMENTElectricianGenerator Module DesignProduction Rate88,400$ *NoteLocalLabor Local OperatorDays(60hr. Week)Fixed estimate @ 120 /hr.MATERIALS5,400 foot Penstock, 150 kW Ossberger Turbine MechanicItemLABORTotalSuperOperatorMaterials+ FreightFreightPlumberLocal PlumberCrew Leadshipping
Ouzinkie Cost Estimate for Hydro-Electric Project564,704$ 1,178,900$ M+F total 1,312,508.00$ 664,104$ 1,877,212$ 1,976,612$ 2,516,385$ 174,000$ Total 2,516,385$ 14.5 yrsAll + contingency, 2 year Escalation @ 3% Estimated annual savings Labor + Materials + FreightTotal MatTotal LaborLabor + Mat + Frgt + Design- Construction team is mobilized and on site for adjacent project. - Trenching with associated project was not included, but availability of equipment, mechanics and operators was for purposes of mobilization and staging.- Civil site visit as part of adjacent project.Superintendant will split time with adjacent work.- Power plant is mostly configure and equiped.- System control can be accomplished w/o a panel.- Crew leader functions will be accomplished by Superentendant, or in lieu of Super.- De-mobilization not required due to adjacent project.With DesignSimple Payback
APPENDIX D
CONCEPTUAL DESIGN
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Ouzinkie
Summary of Engineering Report (John Warren).
Annual power consumption = 620,000 KWH
Power plant record: 4.2 acre-ft to 5.3 acre-ft to produce 1000 KW.
Water required = 620,000 x 5.0 acre-ft/ 1000 KW = 3100 acre-ft (annual)
Annual domestic water required = 70 ac-ft
Total Annual Water Required for Ouzinkie = 3170 ac-ft
Water required for annual hydropower at the current level.
Annual hydropower generation = 381,392 KWH (aveage of three years)
Average hydropower consumption = 43.5 Kw
Estimated water waste for waste pipe and spillway losses = 15%
Required water storage =5.0 ac-ft/1000KW x 381,392 KWH/yr x 1.15 = 2193 ac-ft
Coefficient of water available for productive use: C = 2193/3760 = 0.6
Current watershed = 148 ac-ft
Average annual rainfall: 61 in - 84 in
Water storage @ 61" = 2730 acre-ft
Water Storage @ 84" = 3760 acre-ft
Approximately 60% of water falling on the watershed is available at the end of the penstock for productive use.
(C_max = 0.85)
With C =0.6 net water used for productive use after deducting all losses such
as evaporation, ground seepage
Available water for productive use @ 61" = 2730 acre-ft x 0.6 = 1640 ac-ft
Available water for productive use@ 84" = 3760 acre-ft x 0.6 = 2260 ac-ft
Water shortfall = 1530 to 910 ac-ft (48% to 29% of the water demand)
% of diesel power generation over total electrical power demand = 38% (average of three years)
Analysis with Data provided in Ouzinkie Engineering Report by John Warren.
applied to cal power output
Eff increase = 0.05 respective increases for one new turbine (eff(e) +0.05) and two new (eff(e)+0.1)
Eff = 0.7 0.8 (Range of overall efficiency in operation)
Q_max = 9 cfs
watershed = 148 ac-ft (current water storage capacity)
watershed = 183 ac-ft (approximately 25% increase of water storage capacity by raising one foot above the existing spillway)
Net Head = 220 ft w/ New Dam (@ 9cfs)
230 ft w/ New Dam (@ 5cfs)
1 acre = 43560 ft^2
Penstock Dia =17.25 in
1 sq mile = 640 ac
Avg Annual Rainfall =61"
Annual water available = 2730 ac-ft (drainage basin of 0.84 square miles)
Currently, estimated water waste =15%(through waste pipe and spillway losses)
Annual water available = 3380 ac-ft (drainage basin of 1.04 square miles)
(previously estimated 0.84 sq. miles is
re-evaluated to be 1.04)
Estimated water waste in future =5%(through waste pipe and spillway losses)
Correction Factor =0.60 (reasonable range: 50-70%)
Fuel Costs =$4.74
W/ exsting turbine +Old Dam
Q_Penstock
cfs
V_penstock
fps H_net (ft)
P_supplie
d to
Turbine,
KW
Power
output
KW
Days of
operation
3.5 2.16 228 67.6 50 224
4 2.46 227 77.0 57 196
5.3 3.27 226 101.5 77 148
6 3.70 224 113.9 87 130
8 4.93 222 150.6 119 98
9 5.55 218 166.3 133 87
W/ Osseburger turbine (150KW)
Q_Penstock
cfs
V_penstock
fps H_net (ft)
P_supplie
d to
Turbine,
KW
Power
output
KW
Days of
operation
3.3 1.96 228 64.4 50 286
3.8 2.24 227 73.3 57 250
5.0 2.96 226 96.7 77 189
5.7 3.35 224 108.5 87 167
7.6 4.47 222 143.4 119 125
8.6 5.03 218 158.4 133 111
W/ two smaller turbines (60KW)+ New Dam
Q_Penstock
cfs
V_penstock
fps H_net (ft)
P_supplie
d to
Turbine,
KW
Power
output
KW
Current
days of
operation
3.2 1.86 228 61.4 50 301
3.6 2.13 227 69.8 57 263
4.8 2.82 226 92.1 77 198
5.4 3.19 224 103.3 87 175
7.3 4.26 222 136.6 119 131
8.2 4.79 218 150.9 133 117
Monthly power requirements (KWh), 2010, Hydroelectric 1999
May June July August September October November December January February March April Total
64,000 63,000 63,000 62,000 73,000 71,000 75,000 81,000 81,000 85,000 70,000 75,000 863,000
With growth rate of 1.4%
Monthly power requirements (KWh), 2012, Hydroelectric 1999
May June July August September October November December January February March April Total
65,792 64,764 64,764 63,736 75,044 72,988 77,100 83,268 83,268 87,380 71,960 77,100 887,164
Monthly power requirements (KWh), 2011, PCE data
May June July August September October November December January February March April Total
56,577 50,591 47,794 51,734 59,259 59,104 62,228 68,768 70,064 68,991 62,547 70,945 728,602 Diesel
38,504 38,564 11,570 7,796 56,189 35,516 30,861 21,790 29,790 28,636 2,246 21,944 323,406 Hydro
Monthly fuel costs & efficiencies, 2011, PCE data
May June July August September October November December January February March April Avg/Total
11.46 15.07 14.34 12.14 13.60 10.99 10.87 13.31 15.26 13.22 11.33 16.27 13.16 Fuel Eff (Kwh/gal)
2,278 1,817 1,621 1,789 2,464 3,400 2,893 2,962 1,854 1,957 2,375 2,429 27,839 Costs (1)
2,984 2,381 2,118 2,334 3,239 4,476 3,800 3,901 2,431 2,562 3,112 3,199 36,538 Costs (2)
Current Available Electricity from Hydroelectric (KW )
May June July August September October November December January February March April Average
38.5 41.8 33.9 31.4 51.9 56.4 48.5 59.7 41.9 42.1 39.7 61.8 45.7 1981-2010
43.1 38.1 28.5 30.9 55.4 57.1 46.8 52.2 39.1 39.8 37.5 54.0 43.6 1971-2000
37.8 34.0 25.8 35.3 49.4 49.0 42.2 46.5 36.2 35.4 29.0 48.1 39.1 1961-1990
Future Available Electricity from Hydroelectric (KW ) w/ One 150 KW
May June July August September October November December January February March April Average
45.9 49.8 40.4 37.6 61.8 67.0 57.8 70.9 50.0 50.2 47.4 73.4 54.3 1981-2010
51.3 45.5 34.2 36.9 65.9 67.9 55.8 62.0 46.6 47.5 44.8 64.2 51.9 1971-2000
45.1 40.6 30.9 42.2 58.8 58.3 50.2 55.3 43.2 42.4 34.8 57.3 46.6 1961-1990
Current Available Electricity from Hydroelectric (KWh)
May June July August September October November December January February March April Total
28,611 30,103 25,191 23,370 37,397 41,998 34,950 44,431 31,210 28,290 29,558 44,525 399,633 1981-2010
32,064 27,455 21,217 22,977 39,913 42,514 33,732 38,811 29,109 26,738 27,914 38,884 381,329 1971-2000
28,113 24,482 19,174 26,278 35,560 36,464 30,354 34,586 26,921 23,805 21,607 34,645 341,989 1961-1990
Future Available Electricity from Hydroelectric (KWh) w/ one 150 KW
May June July August September October November December January February March April Total
34,119 35,878 30,094 27,951 44,467 49,882 41,585 52,748 37,179 33,750 35,235 52,863 475,750 1981-2010
38,184 32,761 25,418 27,490 47,430 50,490 40,151 46,129 34,706 31,923 33,299 46,218 454,198 1971-2000
33,534 29,261 23,015 31,373 42,304 43,364 36,174 41,154 32,131 28,469 25,877 41,226 407,882 1961-1990
Future Available Electricity from Hydroelectric (KW ) w/ two smaller turbines (60KW)
May June July August September October November December January February March April Average
30,041 31,608 26,450 24,538 39,267 44,097 36,697 46,652 32,771 29,705 31,036 46,751 34,968 1981-2010
33,667 28,828 22,278 24,126 41,908 44,640 35,418 40,752 30,565 28,075 29,310 40,828 33,366 1971-2000
29,519 25,706 20,133 27,591 37,338 38,287 31,872 36,315 28,268 24,995 22,688 36,377 29,924 1961-1990
Future Available Electricity from Hydroelectric (KWh) w/ two smaller turbines (60KW)
May June July August September October November December January February March April Total
35,825 37,672 31,599 29,349 46,691 52,376 43,664 55,385 39,038 35,437 36,996 55,506 499,538 1981-2010
40,093 34,399 26,689 28,864 49,801 53,014 42,158 48,435 36,441 33,519 34,964 48,529 476,908 1971-2000
35,210 30,724 24,165 32,942 44,419 45,533 37,982 43,211 33,738 29,893 27,171 43,287 428,276 1961-1990
Ouzinkie
Summary of Engineering Report (John Warren).
Annual power consumption = 620,000 KWH
Power plant record: 4.2 acre-ft to 5.3 acre-ft to produce 1000 KW.
Water required = 620,000 x 5.0 acre-ft/ 1000 KW = 3100 acre-ft (annual)
Annual domestic water required = 70 ac-ft
Total Annual Water Required for Ouzinkie = 3170 ac-ft
Water required for annual hydropower at the current level.
Annual hydropower generation = 381,392 KWH (aveage of three years)
Average hydropower consumption = 43.5 Kw
Estimated water waste for waste pipe and spillway losses = 15%
Required water storage =5.0 ac-ft/1000KW x 381,392 KWH/yr x 1.15 = 2193 ac-ft
Coefficient of water available for productive use: C = 2193/3760 = 0.6
Current watershed = 148 ac-ft
Average annual rainfall: 61 in - 84 in
Water storage @ 61" = 2730 acre-ft
Water Storage @ 84" = 3760 acre-ft
Approximately 60% of water falling on the watershed is available at the end of the penstock for productive use.
(C_max = 0.85)
With C =0.6 net water used for productive use after deducting all losses such
as evaporation, ground seepage
Available water for productive use @ 61" = 2730 acre-ft x 0.6 = 1640 ac-ft
Available water for productive use@ 84" = 3760 acre-ft x 0.6 = 2260 ac-ft
Water shortfall = 1530 to 910 ac-ft (48% to 29% of the water demand)
% of diesel power generation over total electrical power demand = 38% (average of three years)
Analysis with Data provided in Ouzinkie Engineering Report by John Warren.
applied to cal power output
Eff increase = 0.05 respective increases for one new turbine (eff(e) +0.05) and two new (eff(e)+0.1)
Eff = 0.7 0.8 (Range of overall efficiency in operation)
Q_max = 9 cfs
watershed = 148 ac-ft (current water storage capacity)
watershed = 183 ac-ft (approximately 25% increase of water storage capacity by raising one foot above the existing spillway)
Net Head = 220 ft w/ New Dam (@ 9cfs)
230 ft w/ New Dam (@ 5cfs)
1 acre = 43560 ft^2
Penstock Dia =17.25 in
1 sq mile = 640 ac
Avg Annual Rainfall =61"
Annual water available = 2730 ac-ft (drainage basin of 0.84 square miles)
Currently, estimated water waste =15%(through waste pipe and spillway losses)
Annual water available = 3380 ac-ft (drainage basin of 1.04 square miles)
(previously estimated 0.84 sq. miles is
re-evaluated to be 1.04)
Estimated water waste in future =5%(through waste pipe and spillway losses)
Correction Factor =0.60 (reasonable range: 50-70%)
Fuel Costs =$4.74
W/ exsting turbine +Old Dam
Q_Penstock
cfs
V_penstock
fps H_net (ft)
P_supplie
d to
Turbine,
KW
Power
output
KW
Days of
operation
3.5 2.16 228 67.6 50 224
4 2.46 227 77.0 57 196
5.3 3.27 226 101.5 77 148
6 3.70 224 113.9 87 130
8 4.93 222 150.6 119 98
9 5.55 218 166.3 133 87
W/ Osseburger turbine (150KW)
Q_Penstock
cfs
V_penstock
fps H_net (ft)
P_supplie
d to
Turbine,
KW
Power
output
KW
Days of
operation
3.3 1.96 228 64.4 50 286
3.8 2.24 227 73.3 57 250
5.0 2.96 226 96.7 77 189
5.7 3.35 224 108.5 87 167
7.6 4.47 222 143.4 119 125
8.6 5.03 218 158.4 133 111
W/ two smaller turbines (60KW)+ New Dam
Q_Penstock
cfs
V_penstock
fps H_net (ft)
P_supplie
d to
Turbine,
KW
Power
output
KW
Current
days of
operation
3.2 1.86 228 61.4 50 301
3.6 2.13 227 69.8 57 263
4.8 2.82 226 92.1 77 198
5.4 3.19 224 103.3 87 175
7.3 4.26 222 136.6 119 131
8.2 4.79 218 150.9 133 117