HomeMy WebLinkAboutTanana Alternative Energy Assessment App
Renewable Energy Fund
Grant Application
AEA 09-004 Grant Application Page 1 of 14 9/2/2008
Application Forms and Instructions
The following forms and instructions are provided for 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/RE_Fund.html
The following application forms are required to be submitted for a grant recommendation:
Grant Application
Form
GrantApp.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.doc Summary of Cost information that should be addressed
by applicants in preparing their application.
Grant Budget
Form
GrantBudget.xls A detailed grant budget that includes a breakdown of
costs by task and a summary of funds available and
requested to complete the work for which funds are being
requested.
Grant Budget
Form Instructions
GrantBudgetInstr.pdf Instructions for completing the above grant budget form.
• 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 a plan
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.
Renewable Energy Fund
Grant Application
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SECTION 1 – APPLICANT INFORMATION
Name (Name of utility, IPP, or government entity submitting proposal)
Tanana Power Co., Inc
Type of Entity:
Corporation
Mailing Address
6270 E Beechcraft Rd Wasilla, AK 99654
Physical Address
6270 E Beechcraft Rd Wasilla, AK 99654
Telephone
907-745-5363
Fax
907-745-5362
Email
katy@yukontel.com
1.1 APPLICANT POINT OF CONTACT
Name
Don Eller
Title
President
Mailing Address
6270 E Beechcraft Rd Wasilla, AK 99654
Telephone
907-745-5363
Fax
907-745-5362
Email
nalaska@yukontel.com
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, 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 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.)
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Grant Application
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SECTION 2 – PROJECT SUMMARY
Provide a brief 1-2 page overview of your project.
2.1 PROJECT TYPE
Describe the type of project you are proposing, (Reconnaissance; Resource Assessment/
Feasibility Analysis/Conceptual Design; Final Design and Permitting; and/or Construction) as
well as the kind of renewable energy you intend to use. Refer to Section 1.5 of RFA.
This project is a feasibility analysis of the numerous alternative energy resources in and around Tanana,
Alaska including Wind, Geothermal, Kinetic Hydro and Traditional Hydro. The results of the feasibility
analysis will be used to determine which alternative energy resource or combination of resources would
be the most cost effective to serve the community of Tanana, Alaska.
2.2 PROJECT DESCRIPTION
Provide a one paragraph description of your project. At a minimum include the project location,
communities to be served, and who will be involved in the grant project.
The Tanana area is blessed with a multitude of possible alternative energy resources including:
1) Wind Energy at is T. 5 N., R. 21 W. Sec. 10 located approximately 10 miles from downtown Tanana
proper.
2) Wind Energy at T. 4 N., R 20 W. This resource was eliminated as a possible because of transmission
line costs from the site to Tanana. The transmission line would have to cross the Yukon River.
3) Wind and Kinetic Hydro at T. 6 N., R 17 W. commonly referred to as “The Rapids”. This has both
wind and water energy available however transmission line costs from The Rapids to Tanana, given the
terrain, would be very costly.
4) Geothermal at Little Melozitna Hot Springs (65.459, 153.312). There has been cursory analysis done
on this resource using chalcedony geo-thermometer methods by Kolker. These results are encouraging.
However, the magnitude of the resource needs to be defined better to determine if it would be
economically prudent to develop.
5) Traditional Hydro at Jackson Creek located at T. 5 N., R. 21 W. and T. 6 N., R 21 W. The project has
been studied before by the APA in the 1980s. Information regarding the study can be found in
“Reconnaissance Study of Energy Requirements and Alternatives for Tanana” Report Summary.
6) Kinetic Hydro Energy production using the Yukon River at Tanana using drag turbines.
Grant funds would be used to do engineering assessments of resources 4 and 5 with the contributed funds
and in kind resources of Tanana Power and the community of Tanana devoted to quantifying the
resources 1 and 6.
The ultimate goal being to determine “the best” resource to develop of the community to meet the
community of Tanana’s long term energy needs most cost effectively.
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2.3 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. Include a project cost summary that includes an estimated total cost
through construction.
The search for possible alternative energy resources to provide sustainable low cost electricity to Tanana
started long before the State of Alaska made grant money available for projects. Tanana Power has
invested a tremendous amount of sweat equity and finances to develop a kinetic hydro conversion system
which is appropriate for village application along the Yukon River. Pictures are included as Attachment
2.3.1 to show the progress on this front.
The Tanana Tribal Council has generously supplied a NRG 30 M metrological tower for studying the
wind at T. 5 N., R. 21 W. Sec. 10 which Tanana Power has installed and fitted with wind monitoring
sensors. Tanana Power will be working with V3 Energy to the data processing from the wind monitoring
system.
This project will examine four different possible alternative resources around Tanana to determine the
“best” project to pursue for providing lower cost sustainable electricity to the consumers of Tanana
Power.
2.4 PROJECT BENEFIT
Briefly discuss the financial benefits that will result from this project, including an estimate of economic
benefits (such as reduced fuel costs) and a description of other benefits to the Alaskan public.
The purpose of this project is to acquire knowledge regarding alternative energy projects in and around
Tanana. The project will quantify the magnitude and engineering viability of alternative energy
development of four different resources in the Tanana area: Wind, Kinetic Hydro, Traditional Hydro and
Geothermal. As a result of the acquired knowledge the best alternative energy solution using current
technology for Tanana will be known. This Knowledge will then be used to pursue a sustainable cost
effective energy for Tanana.
As an additional benefit the wind and kinetic hydro data and information collected will become part of the
public domain for all to use.
2.5 PROJECT COST AND BENEFIT SUMARY
Include a summary of your project’s total costs and benefits below.
2.5.1 Total Project Cost
(Including estimates through construction.)
$ 393298.50
2.5.2 Grant Funds Requested in this application. $ 303060.00
2.5.3 Other Funds to be provided (Project match) $ 90238.50
2.5.4 Total Grant Costs (sum of 2.5.2 and 2.5.3) $ 393298.50
2.5.5 Estimated Benefit (Savings) $ N/A
2.5.6 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.)
$ N/A
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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 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.
This project will be operated by 3 key personnel members; Donald Eller, Ralph Eller, and Kelly Carlisle.
Ralph Eller, Plant Manager and Vice President, will be directly involved and doing most of the labor
himself. Kelly Carlisle, Field Tech., will assist with some of the labor and technical design of the project.
Don Eller, President, will oversee the project and assist with the technical design and financial
management. Mark Foster, a vendor, will assist Tanana Power by doing a peer review of the completed
project.
Enclosed as Attachment 3.1.1, 3.1.2 and 3.1.3, are resumes for the key personnel responsible for all grant
work. Also enclosed as Attachment 3.1.4 is a resume for vendor Mark Foster, and as Attachment 3.1.5 is
the Organization/Personnel structure for Tanana Power for those involved in the grant process.
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.)
The object of this project is to determine which alternative energy resource in or around Tanana would
make the most economic sense to develop, ultimately lowering the cost of power to the consumer.
Given the nature of Alaska the ever changing Seasons and the weather should be the drivers for tasks and
decision points rather than arbitrary dates. Enclosed as Attachment 3.2.1 is a timeline based on Alaskan
seasons and while these are broad in nature and subject to change based on the year every effort will be
made to keep the time table, remaining accountable to the State of Alaska for funds provided.
3.3 Project Milestones
Define key tasks and decision points in your project and a schedule for achieving them.
The goal of this project to determine the “best” or most cost effective alternative energy resource from the
community of Tanana with the ultimate goal of lowering the consumer cost of electricity through the
development of the “best” alternative resource. Therefore it will be necessary to have enough information
to determine the “best” alternative before November of 2009 to maximize funding chances.
The wind component of the project is well on its way. The critical wind item will be to have the data
correlated and a report as to its potential and costs before November 2009.
The kinetic hydro energy component of this project has to critical Milestones, the first being the
integration of the turbine with the gearing and generation system. The logistic and for this are taking
place right now. The second milestone will be generating the first KWH of energy which goes into the
grid and is used by customers. The second milestone will be driven by when the river is free of ice and
drift.
The traditional hydro component of this project has two significant milestones: 1) getting the stream
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measuring in place. 2) Generation of the interim report allowing comparison against other alternatives.
The geothermal component of this project has one milestone which is the generation of the interim report
allowing comparison against other alternatives.
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.
Tanana Power is unique among many rural electrical utilities. Tanana Power is privately owned and has
been since it was started. The community of Tanana has had commercial electricity available since the
late sixties. As a result of being in business over 40 years TPC has refined its operation to a science.
Because Tanana Power has been in business so long it also has a tremendous amount or resources
available. Heavy equipment on site includes 3 yard font end loader, dump trucks, bull dozers, ladder
truck, light crane, track auger and semi tractors to high light a few items. Access and use of these items
will be supplied at no cost to the grant for use in this project.
While Tanana Power has numerous equipment resources available on sight, the resources of greatest
value are the relationships with vendors, suppliers and quality people both within and outside its
organization. Since PolarConsult and V3 Energy are new contractors numerous phone calls were made to
known contacts within the power industry that had either worked directly with the contractor or had
firsthand knowledge of their work. After an intensive vetting process PolarConsult and V3 Energy were
chosen.
The proposal from PolarConsult is attached. The work to be done by V3 Energy will be the data
processing of the wind monitoring information and report generation from this information.
The value of Tanana Power employees and employees of associated companies cannot be overstated.
While none of are experts in any one field our abilities acquired from a lifetime of doing make up for any
lack of formal academic training. Simply stated, we get it done and we get it done right, on time and on
budget.
Tanana Power is working with Jim Norman of ABS Alaska to take the energy generated by the drag
turbine it has developed and converting the energy to electricity so that it can be integrated with the
existing distribution system. The components required are a gearing mechanism to take the energy
generated by the paddle wheel so that it will power a generator. The En Current generation system which
takes the energy from the water then converts the energy to wild AC and then use electronics to filter and
clean up the AC power so that it can be supplied to the community grid.
3.5 Project Communications
Discuss how you plan to monitor the project and keep the Authority informed of the status.
All formal communications regarding the project will be sent from Tanana Power’s administrative office.
At a minimum quarterly progress and financial reports will be submitted to AEA for review. If issues
arise that significantly impact the working being done under this grant, AEA will be notified as soon a
possible. If at any time AEA wanted to make an onsite visit to see what was actually happening on the
ground Tanana Power would happily accommodate them.
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3.6 Project Risk
Discuss potential problems and how you would address them.
What is the risk of gaining knowledge? That the knowledge gained will not be applied or used. That will
not be the case in this study since the results of study are to be used to select the best alternative to
provide the lowest cost energy to Tanana Power’s customers.
There is always a chance that a land holder might have a change of heart. Take for example the wind
monitoring, Doyon has issued TPC a land use permit with the understanding that the long term goal is to
develop the wind resource at the site should it be economic. It is possible that Doyon could have a
change of heart but I believe the chances of this are small. In all the work I have done with Doyon their
motto has been, “if the local population desires the project then it has the support of Doyon.” TPC has
tried to keep the community of Tanana informed and involved in resource selection process, this is one of
the reasons why development of wind energy on Mission Hill is not on the short list, and it is culturally
unacceptable to the community of Tanana.
Risks for this project as a whole are small. We are trying to find good information to chart the future
energy course for the community of Tanana.
The permitting process with regard to both Jackson Creek Hydro and Melozi Hot Springs would be of
immediate concerns to most, when looking at project development. Land ownership directly impacts the
permitting process, if the project is on or crosses Federal land the Federal process must be used.
Fortunately the Jackson Creek Hydro does not involve any Federal land so would not involve the FERC
permitting process but would fall under the much less arduous State permitting process.
Penstock icing issues are of concern as well. Attached is a good report on Frazil ice concerns. Icing is of
concern but can be dealt with by proper design. In talking with two different entities about icing, one an
Alaskan company with numerous hydro plants operating in Alaska and the other in Canada responsible
for operations of numerous dam that must remain operation at – 40 C, both indicated that while icing is a
concern, the concern can be addressed by proper design and operational practices.
It should be noted that no administrative charges have been added to grant costs. Tanana Power does not
view the grants as a revenue stream to be used to offset administrative costs. All grant administrative
costs are absorbed by Tanana Power internally. Labor costs of Tanana Power included in the grant are at
a loaded labor rate; IE the labor costs are inclusive of benefits, taxes and other costs associated directly
with the hourly costs of the employee.
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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 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 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.
Four different types of alternative energies are to be studied. Geothermal and traditional hydro resource
both has the capability of generating all the electrical needs for the community of Tanana year round. The
kinetic hydro and wind resources are unknown with regard to magnitude. However the “best” choice will
be determined by which alternative will generate the lowest cost of power for the consumer.
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.
Since 1991, Tanana Power Co., has used economic dispatch as the method to control its engines. The
wide range in demand makes economic dispatch a very good method of economizing on fuel. In 2005
peak load ranged from 280 kW during the winter months to 90 kW during off peak hours in the summer.
Since demand has a direct relationship to weather it is important to prepare for loads higher than 280 kW.
When running a comparison of the last 5 years, the summer loads range between 90 kW and 180 kW while
winter loads are between 150 kW and 300 kW.
Engines are dispatched based on their efficiency. Every engine has a load range were kwh/gal is the
highest for the given range. The demand dispatch software is then programmed to operate the engine with
the best fuel economy for the given load range. Engine parameters are also integrated in the demand
dispatch software so that the engines are not overloaded.
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.
Tanana’s electrical needs and a portion of its heating needs are supplied by diesel internal combustion
engines controlled by a demand dispatch PLC control system. This automation process has significantly
lowered fuel usage by matching the most efficient generator to the load. Based on fuel efficiency
information TPC has introduced the Detroit Diesel Series engine into its generation system with positive
results for fuel efficiency. It should also be noted that Tanana Power typically only runs standard #2 diesel
during the summer and fall months and then #2 -15 diesel throughout the winter. To use #2 -15 during the
winter no heating of the fuel is required just proper design and operation of the day tank filling system.
The use of #2 fuels year round significantly increases fuel efficiency.
The control system will work well with any developed alternative energy resource and the existing
generation system would work well as a standby. The extensive transmission network significantly
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reduce the length of transmission lines required to bring an developed alternative energy resource to
market.
4.2.3 Existing Energy Market
Discuss existing energy use and its market. Discuss impacts your project may have on energy
customers.
The electrical energy demand in Tanana is roughly 60% commercial and 40% residential for the
approximate 1.25 Mwh consumed annually. While electric energy cost in Tanana are significantly less
than surrounding villages, electric energy costs are of significant concern to the residents. Electrical
energy costs affect all aspects of life from prices paid at the store and Laundromat for goods and services,
to the school budget.
Given the public policy decision to promote alternative energy development and the significant and
uncertain costs associated with diesel electric power generation it is Tanana Power’s desire to follow the
state’s public policy decision while providing stable low cost electricity.
Enclosed as Attachment 4.2.3 - Tanana Power Revenue Breakdown 2006-2008.
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
Upon completion of the feasibility study enough data will have been collected to determine the best source
of alternative generation. Using the data collected a system design will be created to maximize the
resources potential.
By November of 2009 Tanana Power expects to have collected enough data to determine the best
alternative energy source and begin the development phase of an alternative energy project.
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.
There are no potential land ownership issues. Tanana power has worked closely with the community to
gain their approval for the feasibility studies. There will be a land lease entered into with the state of
Alaska for possible geothermal testing near the Little Melozitna Hot Springs. The state will issue a land
lease on a yearly basis until the project is completed and possibly a permanent lease if geothermal will be a
viable and cost effective form of generation for Tanana, AK.
Federal land surrounds the hot springs themselves. However through contact with the BLM and FERC it
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has been determined that no Federal Permitting or land use contracts will be required at a federal level and
that small alternative power projects are only licensed by the state.
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
There will be no new permits needed to establish the feasibility studies.
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
There are no foreseen environmental or land use issues.
4.4 Proposed New System Costs (Total Estimated Costs and proposed 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
• Projected development cost of proposed renewable energy system
Upon completion of the feasibility studies Tanana Power intends to develop the most cost effective
resource. At that time detailed information on projected cost and return will be available based on the
method of generation chosen.
See the enclosed Grant Budget.
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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.
• Total anticipated project cost for this phase
• Requested grant funding
During this phase of the project there will be minimal operating and maintenance costs.
See the enclosed Detailed Budget for specific costs associated with the feasibility study.
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
Tanana Power Co., Inc. already generates and distributes power to Tanana AK. The purpose of this
Feasibility study will be to determine the best method of generation to provide the most cost effective
power to its residents. Projected rate of return and generation costs will be determined based on the most
cost effective form of generation concluded with the feasibility study.
4.4.4 Cost Worksheet
Complete the cost worksheet form which provides summary information that will be considered
in evaluating the project.
The cost worksheet is enclosed.
4.4.5 Business Plan
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.
The results of the feasibility analysis will be used to determine which alternative energy resource or
combination of resources would be the most cost effective to serve the community of Tanana Alaska.
Once the best resource has been determined Tanana Power will go ahead with developing the resource
and projected cost and savings will be done at that time. The new operations will be conducted in the
same manner as existing operations using Ralph Eller as the plant manager, with another full time tech.
to assist in the maintenance of the operations.
4.4.6 Analysis and Recommendations
Provide information about the economic analysis and the proposed project. Discuss your
recommendation for additional project development work.
An intensive vetting process was gone through before arriving at the short list of possible alternative
energy projects for Tanana. The vetting process included high level economic and cost analysis, land
ownership review, local and cultural concerns and review of resource potential verses demand based on
existing information. There is large variation in cost data. For example costs for transmission line
construction range from $100,000 to $500,000 per mile so a figure of $250,000 was used in the high level
economic analysis. There are no projects included in this feasibility study that cannot pass the “common
sense” test ( is this project actually feasible based on all available information) and does the project pass
the economic test being able to produce electricity for the community of Tanana at or below $0.30 per
kwh.
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The object of this grant is to arrive at recommendations for development. The information generated in
depth study of the resource and the cost it will take to develop. A peer review will then occur of the
information with economic analysis to determine which resources it would be prudent to develop.
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 avoided cost of ownership)
• 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
Currently Tanana Power burns roughly 100,000 gallons of fuel annually to meet the community of
Tanana’s electrical needs. The current generation efficiency is roughly 13.5 kwh/gallon. This compares
with utilities 3 to 5 times the size of Tanana Power. So this year, fuel was $4.06 gal, in fuel costs alone
$0.30 out of every kwh sold go to pay for the fuel to produce it. The fuel cost per KWH varies with the
price of fuel. At Tanana Powers efficiency with fuel at $3 per gallon the fuel cost per KWH would be
$0.22. It is desired based on the results of this study to create an alternative energy project that would
generate electricity at or below the fuel costs per KWH. A lofty goal, but very obtainable.
This project will identify the alternative energy project costs and engineering challenges in much greater
detail than a reconnaissance study allowing resources to be directed at the “best” course of action in the
future for the community of Tanana.
Being hands on and liking to get things done, it goes against my nature to request funds for yet another
study. However, given the capital required to develop an alternative energy project it is also the most
prudent course of action at this time, removing uncertain as to engineering difficulties, resources potential
and developing detailed costs to avoid many of the issues which arise which cause budget over runs and
even project failure. Tanana Power did not wait for the State of Alaska to make grant funds available to
start pursuing alternative energy projects, the pictures supplied within this grant application demonstrate
Tanana Power’s commitment to pursuing low cost energy alternatives long before the possibility of grant
money became available.
Enclosed as Attachment 4.2.1 are the Fuel Statistics from 2006-2008
SECTION 6 – GRANT BUDGET
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Tell us how much your total project costs. Include any investments to date and funding sources,
how much is requested in grant funds, and additional investments you will make as an
applicant.
Include an estimate of budget costs by tasks using the form - GrantBudget.xls
Tanana Power has already invested many man hours and funds into the exploration of alternative power.
With the construction of a Paddle Wheel and exploration into Wind Generation we have already begun
collecting data to determine the best possible source of alternative generation. With the approval and full
support of the community Tanana Power is dedicated to reducing the cost of consumer power to the
residents, an essential effort to keep the village way of life sustainable for its inhabitants.
The total cost of the feasibility study is expected to be $393298.50. We are requesting $303060.00 of
grant funding to continue our research. Enclosed is a detailed budget of the projected Project Costs and
Monies already dedicated to the project.
Renewable Energy Fund
Grant Application
AEA 09-004 Grant Application Page 14 of 14 9/3/2008
SECTION 7 – ADDITIONAL DOCUMENTATION AND CERTIFICATION
SUBMIT THE FOLLOWING DOCUMENTS WITH YOUR APPLICATION:
A. Resumes of Applicant’s Project Manager, key staff, partners, consultants, and
suppliers per application form Section 3.1 and 3.4
B. Cost Worksheet per application form Section 4.4.4
C. Grant Budget Form per application form Section 6.
D. An electronic version of the entire application per RFA Section 1.6
E. Governing Body Resolution per RFA Section 1.4
Enclose a copy of the resolution or other formal action taken by the applicant’s
governing body or management that:
- authorizes this application for project funding at the match amounts indicated in
the application
- authorizes the individual named as point of contact to represent the applicant for
purposes of this application
- states the applicant is in compliance with all federal state, and local, laws
including existing credit and federal tax obligations.
F. CERTIFICATION
The undersigned certifies that this application for a renewable energy grant is truthful
and correct, and that the applicant is in compliance with, and will continue to comply
with, all federal and state laws including existing credit and federal tax obligations.
Print Name
Signature
Title
Date
Alaska Energy Authority ‐ Renewable Energy FundBUDGET INFORMATIONBUDGET SUMMARY: Tanana Power Co., Inc.Milestone or Task Federal Funds State FundsLocal Match Funds (Cash)Local Match Funds (In‐Kind)Other FundsTOTALS1 Wind $7,500.00 $22,203.40 $29,703.402 Kinetic Hydro $30,000.00 $43,035.10 $73,035.103 Traditional Hydro $215,360.00$215,360.004 Geothermal $45,200.00$45,200.005 Info Processing /Peer Review$5,000.00$5,000.006 Overall Project Management $25,000.00 $25,000.00Milestone # or Task #BUDGET CATAGORIES:1 Wind 2 Kinetic Hydro 3 Traditional Hydro 4 Geothermal5 Info Processing /Peer Review6 Overall Project Management TOTALSDirect Labor and Benefits $9,838.40 $26,906.73 $59,560.00 $3,200.00 $25,000.00 $124,505.13Travel, Meals, or Per Diem $60,000.00 $60,000.00Equipment $9,165.00 $25,328.37 $42,000.00 $76,493.37Supplies $1,000.00 $20,000.00$21,000.00Contractual Services $7,500.00 $40,000.00 $40,000.00 $5,000.00 $92,500.00Construction Services$0.00Other Direct Costs $2,200.00$800.00$13,800.00$2,000.00$18,800.00TOTAL DIRECT CHARGES$29,703.40 $73,035.10 $215,360.00 $45,200.00 $5,000.00 $25,000.00RFA AEA09‐004 Budget Form
Detailed Budget
Wind
2 Snow Machines Wet for 5 days @ $100/day 1,000.00$
1 Snow Machines/ATV Wet for 12 days @ $100/day 1,200.00$
Data processing and report generation by V3 Energy, LLC 7,500.00$
Tanana Tribal Council
NRG Systems 30M Tower approximate current value. 6,000.00$
Total Wind Project Feasiliblity Costs 29,703.40$
Community Contributed Funds 22,203.40$
Requested funds to be supplied by grant 7,500.00$
Kinetic Hydro
Tanana Power Contribution
Material and supplies for Water Wheel construction 12,128.37$
Loaded Labor Costs for construction 16,906.73$
Gear system to take torque of wheel into high RPM (Est) 10,000.00$
TotalKinetic Hydro Fesability $ 98,035.10
Community Contributed Funds 43,035.10$
Requested funds to be supplied by grant 30,000.00$
Boat for moving platform to production site and removal
$200/day wet (Insallation 1 day removal 1 day for 2 years) $ 800.00
Generator and control electronics (Est) Vendor En
Current/ABS Alaska $ 20,000.00
Estimated labor required to be set up for turn key power
production $ 10,000.00
Monthly data acquisition and tower saftey check 12 man days
@ loaded Labor rate of 55.90/hr $ 5,366.40
Initial research for tower location including talking to locals
about the possible wind resources and coordination with land
holders
Equipment required for putting in and removing drag turbine
from river to storage 8 hours @ $200/hr for 966 Loader, Semi
truck and Line truck (2X for two years) $ 3,200.00
Tanana Power Contributions Symphonie Logger and Sensors 3,165.00$
10 man days for Tower install and logistics Loaded labor rate
55.90/hour $ 4,472.00
Miscellaneous Supplies‐ Anchoring system, Ground wire, tools $ 1,000.00
Traditional Hydro
2 Snow Machines Wet for 14 days @ $100/day 2,800.00$
Gage Installation
Transporation 55,000.00$
Equipment 40,000.00$
Labor 45,000.00$
Other Expenses 10,000.00$
Gage Removal
Transporation 5,000.00$
Equipment 2,000.00$
Labor 12,000.00$
Other Expenses 1,000.00$
Preliminary Design 10,000.00$
Cost Estimate 15,000.00$
Report 15,000.00$
Total Traditional Hydro Feasiblity Costs 215,360.00$
Community Contributed Funds ‐$
Requested funds to be supplied by grant 215,360.00$
Geothermal
Cost Estimate 20,000.00$
Feasibility 20,000.00$
Trail Clearing and providing access 3,200.00$
20/hr including own chainsaw 20 man days
2 Snow Machines Wet for 10 days @ $100/day 2,000.00$
Total Traditional Hydro Feasiblity Costs 45,200.00$
Community Contributed Funds ‐$
Requested funds to be supplied by grant 45,200.00$
Overall Project
Total Project
Total Project Costs 393,298.50$
Grant funds requested in this application 298,060.00$
Other Funds to be provided 95,238.50$
Total Grant Costs 393,298.50$
$ 25,000.00
Project coordination and Management Tanana Power (in kind
contribution)
Trail Clearing and providing access 20/hr including own
chainsaw 16 man days $ 2,560.00
Data and information processing and peer review with
economic modeling MAFA (Mark Foster) $ 5,000.00
Renewable Energy Fund
RFA AEA 09-004 Application Cost Worksheet revised 9/26/08 Page 1
Application Cost Worksheet
Please note that some fields might not be applicable for all technologies or all project
phases. 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.
Unit depends on project type (e.g. windspeed, hydropower output, biomasss fuel)
2. Existing Energy Generation
a) Basic configuration (if system is part of the Railbelt1 grid, leave this section blank)
i. Number of generators/boilers/other 4
ii. Rated capacity of generators/boilers/other 1.3MW
iii. Generator/boilers/other type Detroit Diesel and Caterpillar
iv. Age of generators/boilers/other 2yrs/3yrs/+15yrs/+15yrs
v. Efficiency of generators/boilers/other 13.5 KW/Gal
b) Annual O&M cost (if system is part of the Railbelt grid, leave this section blank)
i. Annual O&M cost for labor $2236.00
ii. Annual O&M cost for non-labor $1700.00
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] 1250000 (Approx)
ii. Fuel usage
Diesel [gal] 92000 (Approx)
Other ----
iii. Peak Load 275 KW
iv. Average Load 135.5 KW
v. Minimum Load 179 KW
vi. Efficiency 13.5 KW/Gal
vii. Future trends
d) Annual heating fuel usage (fill in as applicable)
i. Diesel [gal or MMBtu]
ii. Electricity [kWh]
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
RFA AEA 09-004 Application Cost Worksheet revised 9/26/08 Page 2
iii. Propane [gal or MMBtu]
iv. Coal [tons or MMBtu]
v. Wood [cords, green tons, dry tons]
vi. Other
3. Proposed System Design
a) Installed capacity ----------------
b) Annual renewable electricity generation
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 ---------------------
4. Project Cost
a) Total capital cost of new system ------------------------
b) Development cost ------------------------
c) Annual O&M cost of new system ------------------------
d) Annual fuel cost -------------------------
5. Project Benefits
a) Amount of fuel displaced for
i. Electricity -------------------------------
ii. Heat -------------------------------
iii. Transportation -------------------------------
b) Price of displaced fuel ---------------------------
c) Other economic benefits --------------------------
d) Amount of Alaska public benefits ---------------------------
6. Power Purchase/Sales Price
a) Price for power purchase/sale ----------------------------
Renewable Energy Fund
RFA AEA 09-004 Application Cost Worksheet revised 9/26/08 Page 3
7. Project Analysis
a) Basic Economic Analysis
Project benefit/cost ratio -----------------------------------
Payback ------------------------------------
ATTACHMENT 2.3.1
Paddle Wheel Construction
ATTACHMENT 2.3.1 CONT.
Water Paddle Construction
ATTACHMENT 2.3.1 CONT.
Paddle Wheel
ATTACHMENT 2.3.1 CONT.
Paddle Wheel Construction
ATTACHMENT 2.3.2
Summer Site for the Wind Generation Project
ATTACHMENT 2.3.2 CONT.
Wind Generation
ATTACHMENT 2.3.2 CONT.
Wind Generation
ATTACHMENT 3.1.1
Manager-Don Eller, Tanana Power Co. Inc
Donald B. Eller was brought up in the public utility industry and since 1979, Don Eller has
assisted in the installation of aerial and buried cable as well as many other functions associated
with a telephone and electric company. He is familiar with most aspects of both cable and
telephone outside plant, the Redcom MDX Switch, has been involved in the installation and
upgrading of two complete Redcom systems, designed, built and maintains the three broadband
systems/ISPs currently in operation.
In 1985, Don Eller received a Bachelor of Science in Civil Engineering (emphasis on finite
element analysis of structures) from the University of Colorado, in Boulder. In the years
following, he served in the Peace Corps as a water resource engineer in Thailand where he had
the responsibility of working with Thai Nationals to determine and resolve water related
problems. Through this experience Don was able to see firsthand the complicated issues
involved in rural development.
After returning from Thailand, Don Eller obtained his MBA from Alaska Pacific University in
1991, while working for YTC. He served as the graduate member of the Alaska Pacific
University student government and as a member of the Alaska Commission on Post Secondary
Education.
Don Eller spear headed the generator automation system for Tanana Power Co. Inc. Tanana
Power Co. Inc. generates and distributes power to 180 customers. The switch gear automation
project consisted of automating the starting and stopping and phasing in large diesel electric
generators based on community demand for electricity. Included in this project was automation
of valves, control of generators, automated fueling and video surveillance. This project has lead
to an increase of 13% in efficiency for electricity production in Tanana as well as removed the
necessity for having an employee on site full time. At the core of the system lies a managed high
speed network passing information in real time between program logic controllers, sensors,
actuators, and computers. The network of this system must work flawlessly and be very secure.
This project was completed and has remained operational since 1997. We currently can log in
from anywhere in the world and perform maintenance and monitoring as necessary.
Don Eller has spoken numerous times nationally regarding VoIP and Broadband networks. He
has spoken numerous times within the state on automated control systems. While it may seem
that Broadband network and automated control systems are different, in reality they are very
similar. Mr. Eller's vast experience in the field of networks allow him to work on an automated
control system such as Tanana Power's and then work on the broad band network which connects
the automated control system to the rest of the world. Mr. Eller has installed wireless, cable and
DSL broadband systems.
Mr. Eller's back ground in project management as well as his long term experience in getting
projects done, on time and on budget in rural Alaska make him a strategist member of the
Tanana Power team involved in this project.
ATTACHMENT 3.1.2
Plant Manager-Ralph Eller, Tanana Power Company Inc.
Growing up the son of small business owners in bush Alaska, Ralph was exposed to the
operations of Tanana Power Co. at an early age. Cliff Eller (his father), had a very young
lineman’s helper while extending the village’s power lines to serve more customers, and Ralph
worked for the company ever since.
His bachelor of science degree from Northern Michigan University in Electronics Technology
(with a minor in Business) has served him well when installing and programming the PLC-
controlled automated fueling, cooling, and generator control systems that Tanana Power
currently uses to provide the best fuel efficiency to its customers. Most of his education though,
has been through hands-on experience gained in his 16 years working at the plant in Tanana.
In the position of Plant Manager, he is responsible for what happens with the electricity in
Tanana. In his tenure at TPC, he has replaced seven generators; this entailed welding cooling
and exhausts systems, plumbing in fuel lines, and wiring the generators as well as the electrical
controls to the engines. He has overhauled four diesel generators that were used for power
production. He designed and built a new cooling system in the plant which cut down the cooling-
related problems and reduced the electrical consumption of the fan motors. He has designed and
built underground and aerial distribution systems to upgrade the facilities that were in place. He
is also in charge of the operation of the Bulk Fuel Storage Plant, which was constructed in 2002.
He is in charge of placing all of the fuel orders, take delivery of, and distributed the majority of
diesel that comes to Tanana.
ATTACHMENT 3.1.3
Kelly Carlisle-Operations Tech
Kelly Carlisle, like most of those involved with Tanana Power has a very diverse background
and skill set. Kelly attended Alaska Methodist University for years studying History. He
worked in the escrow department of First National Bank of Anchorage and was directory of the
Anchorage Recycling Center until running his own fishing business for 18 years.
While working for with Tanana Power, Kelly has been involved in the Water Wheel and Wind
Generation projects. He is also a technician for Tanana Powers affiliate companies Yukon
Telephone and Supervision Inc. where he is included in all phases of both cable and telephone
outside plant installation and maintenance. Kelly’s ability to acquire information and calmly
process it has made him into a first –rate central office and head-end tech.
ATTACHMENT 3.1.5
Don
Eller
Chelle
Sommerville
Ralph
Eller
Kelly
Carlisle
Operations
Accounting
Don
Eller
Ralph
Eller
Management/Ownership
Operations/Accounting
Current Status Spring 2009 (ending April 30, 2009) Summer 2009 (ending July 31, 2009) Fall 2009 (ending October 30, 2009) Winter 2010 (Ending January 31, 2010)Wind Permission to use land Monthly collection of dataReport on wind resource with Demob of tower and clean upTower In Place Collecting Data Monthly collection of data Economic analysis for development potentialKinetic Hydro Floating platform constructed Integration of turbine with Deployment of turbine generating Report on viablity of resource withTested and refined for one season generation system electricity and putting the electricty Economic analysis for development potentialcommunity grid.Traditional Hydro All previous work reviewed Installation of stream Interm Report on viablity of resource with Full Report on viablity of resource withProposal from PolarConsult gauging system Engineering field work Economic analysis for development potential Economic analysis for development potentialGeothermal All previous work reviewedInterm Report on viablity of resource with Full Report on viablity of resource withProposal from PolarConsult Start feasiblity report Economic analysis for development potential Economic analysis for development potentialOverallSelection most attactive cost effectiveAlternative and apply to fully fund designand construction.ATTACHMENT 3.2.1
TANANA POWER COMPANY, INC,KWH GENERATED - ATTACHMENT CFUEL & KWH STATISTICSGALLONS VALUE OF GAL CURRENT TOTAL KWH KWH GENMONTH YEAR CONSUMED CONSUMED FUEL COST GENERATED PER GAL.JANUARY 2006 10,136.0 24,721.70 2.4390 143,000 14.108129FEBRUARY 2006 8,401.0 20,490.04 2.4390 117,250 13.956672MARCH 2006 9,087.0 22,163.19 2.4390 127,200 13.998019APRIL 2006 7,925.0 19,329.08 2.4390 105,375 13.296530MAY 2006 7,099.0 17,314.46 2.4390 92,825 13.075785JUNE 2006 6,909.0 20,653.07 2.9893 91,610 13.259517JULY 2006 6,835.0 20,431.87 2.9893 90,255 13.204828AUGUST 2006 7,820.0 24,140.34 3.0870 94,928 12.139130SEPTEMBER 2006 7,279.0 22,470.27 3.0870 96,705 13.285479OCTOBER 2006 8,764.0 27,054.47 3.0870 122,035 13.924578NOVEMBER 2006 10,762.0 33,222.29 3.0870 151,740 14.099610DECEMBER 2006 10,546.0 32,555.50 3.0870 146,245 13.867343TOTALS101,563.0 284,546.29 1,379,168 13.579433 13.517968ATTACHMENT 4.2.1
TANANA POWER COMPANY, INC,KWH GENERATED - ATTACHMENT CFUEL & KWH STATISTICSGALLONS VALUE OF GAL CURRENT TOTAL KWH KWH GENMONTH YEAR CONSUMED CONSUMED FUEL COST GENERATED PER GAL.JANUARY 2007 10,096.0 31,166.35 3.0870 150,700 14.926704FEBRUARY 2007 9,272.0 28,622.66 3.0870 128,070 13.812554MARCH 2007 10,774.0 33,259.34 3.0870 146,100 13.560423APRIL 2007 8,577.0 26,477.20 3.0870 116,200 13.547861MAY 2007 7,446.0 22,985.80 3.0870 97,340 13.072791JUNE 2007 5,852.0 18,065.12 3.0870 81,860 13.988380JULY 2007 5,648.0 17,435.38 3.0870 80,220 14.203258AUGUST 2007 5,617.0 15,545.05 2.7675 78,650 14.002136SEPTEMBER 2007 6,859.0 18,982.28 2.7675 97,480 14.211984OCTOBER 2007 8,840.0 24,464.70 2.7675 117,370 13.277149NOVEMBER 2007 8,330.0 23,053.28 2.7675 116,240 13.954382DECEMBER 2007 10,037.0 27,777.40 2.7675 140,080 13.956361TOTALS97,348.0 287,834.56 1,350,310 13.870958 13.876165ATTACHMENT 4.2.1 CONT.
TANANA POWER COMPANY, INC.KWH GENERATED - ATTACHMENT CFUEL & KWH STATISTICSGALLONS VALUE OF GAL CURRENT TOTAL KWH KWH GENMONTH YEAR CONSUMED CONSUMED FUEL COST GENERATED PER GAL.JANUARY 2008 9,964.0 27,575.37 2.7675 136,760 13.725411FEBRUARY 2008 9,465.0 26,194.39 2.7675 122,008 12.890438MARCH 2008 9,501.0 26,294.02 2.7675 114,277 12.027892APRIL 2008 7,883.0 21,816.20 2.7675 98,675 12.517443MAY 2008 6,685.0 18,500.74 2.7675 86,980 13.011219JUNE 2008 5,269.0 14,581.96 2.7675 75,585 14.345227JULY 2008 5,775.0 15,982.31 2.7675 79,437 13.755325AUGUST 2008 5,707.0 23,141.89 4.0550 80,238 14.059576SEPTEMBER 2008 6,141.0 24,901.76 4.0550 86,125 14.024589OCTOBER 2008 7,897.0 32,022.34 4.0550 106,250 13.454476NOVEMBER 2007 8,330.0 23,053.28 2.7675 116,240 13.954382DECEMBER 2007 10,037.0 27,777.40 2.7675 140,080 13.956361TOTALS92,654.0 281,841.63 1,242,655 13.411779 13.476862ATTACHMENT 4.2.1 CONT.
TANANA POWER CO., INC.2006 REVENUE BREAKDOWNTOTAL % OF COMM % OF RES % OF ST. LITE % OF COMM COMM RES RES ST. LITE ST. LITE R CMONTH KWH TOTAL KWH TOTAL KWH TOTAL KWH TOTAL TOTAL ENERGY SURCHRGE ENERGY SURCHRGE ENERGY SURCHG KWHPEAK DEMANDJANUARY 132458 100% 81,463 61.50% 49,523 37.39% 1472 1.11%MONTH ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST MONTH KWHFEBRUARY 107765 100% 69,179 64.19% 37,114 34.44% 1472 1.37% JANUARY $0.00 $0.00 $0.00 JAN = 259.0MARCH 116698 100% 72,859 62.43% 42,367 36.30% 1472 1.26% FEBRUARY $0.00 $0.00 $0.00 FEB = 260.10APRIL 97242 100% 61,646 63.39% 34,124 35.09% 1472 1.51% MARCH $0.00 $0.00 $0.00 MAR = 236.30MAY 85385 100% 53,532 62.69% 30,381 35.58% 1472 1.72% APRIL $0.00 $0.00 $0.00 APR = 187.30JUNE 84713 100% 50,772 59.93% 32,469 38.33% 1472 1.74% MAY $0.00 $0.00 $0.00 MAY = 204.30JULY 83184 100% 47077 56.59% 34635 41.64% 1472 1.77% JUNE $0.00 $0.00 $0.00 JUN = 217.00AUGUST 76950 100% 41,315 53.69% 34,163 44.40% 1472 1.91% JULY -$341.86 -$302.28 -$39.58 $0.00 $0.00 -540 JUL = 199.00SEPTEMBER 84043 100% 47,398 56.40% 35,173 41.85% 1472 1.75% AUGUST -$1,778.32 -$928.34 -$316.23 -$442.06 -$91.69 $0.00 $0.00 -467 -2,200 AUG = 202.00OCTOBER 112062 100% 67,818 60.52% 42,772 38.17% 1472 1.31% SEPTEMBER $0.00 $0.00 $0.00 SEPT = 215.00NOVEMBER 140729 100% 88,557 62.93% 50,636 35.98% 1536 1.09% OCTOBER -$1,348.01 -$1,035.63 -$312.38 $0.00 $0.00 -553 -3,090 OCT = 245.00DECEMBER 134972 100% 85,079 63.03% 48,421 35.87% 1472 1.09% NOVEMBER -$223.23 -$189.07 -$34.16 $0.00 $0.00 -405 NOV = 300.00ADJUSTMENTS -7255 100% -5,695 78.50% -1,560 21.50% 0.00% DECEMBER -$34.16 -$34.16 $0.00 $0.00 DEC = 297.00TOTAL 1248946 100% 761000 60.93% 470218 37.65% 17728 1.42% TOTAL -$3,725.58 -$2,153.04 -$316.23 -$1,125.04 -$131.27 $0.00 $0.00 -1,560 -5,695 (LESS SURCHARGE BILLED &ADJUSTMENTS) TOTAL # COMM RES ST LITETOTAL % OF COMM % OF RES % OF ST. LITE % OF TOTAL COMM RES ST. LITE MONTH CUST. CUST. CUST. CUST.MONTH $$$ TOTAL $$$ TOTAL $$$ TOTAL $$$ TOTAL MONTH $$$ $$$ $$$ $$$JANUARY 177 20 156 1JANUARY 66,233.25$ 100.00% 37,892.20$ 57.21% 27,505.81$ 41.53% 835.24$ 1.26% JANUARY $84,818.29 $49,322.18 $34,454.34 $1,041.77 FEBRUARY 173 20 152 1FEBRUARY 54,213.98$ 100.00% 32,320.89$ 59.62% 21,057.85$ 38.84% 835.24$ 1.54% FEBRUARY $65,832.02 $39,779.03 $25,059.06 $993.93 MARCH 174 20 153 1 MARCH 58,551.34$ 100.00% 33,985.31$ 58.04% 23,730.79$ 40.53% 835.24$ 1.43% MARCH $71,132.42 $41,840.19 $28,298.30 $993.93 APRIL 173 20 152 1APRIL 49,378.81$ 100.00% 29,002.09$ 58.73% 19,541.48$ 39.57% 835.24$ 1.69% APRIL $59,862.39 $35,648.07 $23,220.39 $993.93 MAY 177 20 156 1MAY 43,688.51$ 100.00% 25,329.93$ 57.98% 17,523.34$ 40.11% 835.24$ 1.91% MAY $49,948.04 $29,254.31 $19,750.58 $943.15 JUNE 180 20 159 1JUNE 43,584.98$ 100.00% 24,154.63$ 55.42% 18,595.11$ 42.66% 835.24$ 1.92% JUNE $49,795.21 $27,876.67 $20,975.39 $943.15 JULY 181 20 160 1JULY 43,171.98$ 100.00% 22,386.90$ 51.86% 19,949.84$ 46.21% 835.24$ 1.93% JULY $47,710.13 $24,593.49 $22,173.49 $943.15 AUGUST 187 21 165 1AUGUST 41,626.54$ 100.00% 20,934.49$ 50.29% 19,856.81$ 47.70% 835.24$ 2.01% AUGUST $53,819.57 $27,907.73 $24,842.69 $1,069.15 SEPTEMBER 183 20 162 1SEPTEMBER 43,549.40$ 100.00% 22,575.16$ 51.84% 20,139.00$ 46.24% 835.24$ 1.92% SEPTEMBER $55,863.90 $29,071.53 $25,723.22 $1,069.15 OCTOBER 188 21 166 1OCTOBER 56,639.48$ 100.00% 31,739.84$ 56.04% 24,064.40$ 42.49% 835.24$ 1.47% OCTOBER $72,519.43 $41,036.16 $30,414.12 $1,069.15 NOVEMBER 180 20 159 1 NOVEMBER 67,670.82$ 100.00% 39,587.01$ 58.50% 27,248.57$ 40.27% 835.24$ 1.23% NOVEMBER $90,849.85 $54,047.74 $35,703.59 $1,098.52 DECEMBER 176 20 155 1DECEMBER 65,402.87$ 100.00% 38,306.82$ 58.57% 26,260.81$ 40.15% 835.24$ 1.28% DECEMBER $87,791.92 $52,367.32 $34,337.05 $1,087.55 TOTAL 2149 242 1895 12TOTAL 633,711.96$ 100.00% 358,215.27$ 56.53% 265,473.81$ 41.89% 10,022.88$ 1.58% TOTAL $789,943.17 $452,744.42 $324,952.22 $12,246.53 TOTAL % OF COMM % OF RES % OF ST. LITE % OF TOTAL TPC WSTEHT CONTROL FANS/ FUELMONTH SURCHGE TOTAL SURCHGE TOTAL SURCHGE TOTAL SURCHGE TOTAL MONTH CO KWH KWH KWH MODULE WELDER SHEDJANUARY 18,585.04$ 100.00% 11,429.98$ 61.50% 6,948.53$ 37.39% 206.53$ 1.11% JANUARY 0FEBRUARY 11,618.04$ 100.00% 7,458.14$ 64.19% 4,001.21$ 34.44% 158.69$ 1.37% FEBRUARY 0MARCH 12,581.08$ 100.00% 7,854.88$ 62.43% 4,567.51$ 36.30% 158.69$ 1.26% MARCH 0APRIL 10,483.58$ 100.00% 6,645.98$ 63.39% 3,678.91$ 35.09% 158.69$ 1.51% APRIL 0MAY 6,259.53$ 100.00% 3,924.38$ 62.69% 2,227.24$ 35.58% 107.91$ 1.72% MAY 0JUNE 6,210.23$ 100.00% 3,722.04$ 59.93% 2,380.28$ 38.33% 107.91$ 1.74% JUNE 0JULY 6,124.58$ 100.00% 3,451.16$ 56.35% 2,565.51$ 41.89% 107.91$ 1.76% JULY 0AUGUST 12,726.78$ 100.00% 6,973.24$ 54.79% 5,519.63$ 43.37% 233.91$ 1.84% AUGUST 0SEPTEMBER 13,350.13$ 100.00% 7,532.00$ 56.42% 5,584.22$ 41.83% 233.91$ 1.75% SEPTEMBER 2,822 2,220 80 252 120 150OCTOBER 17,227.96$ 100.00% 10,331.95$ 59.97% 6,662.10$ 38.67% 233.91$ 1.36% OCTOBER 3,648 2,800 295 260 173 120NOVEMBER 23,402.26$ 100.00% 14,649.80$ 62.60% 8,489.18$ 36.28% 263.28$ 1.13% NOVEMBER 4,200 3,090 616 250 154 90DECEMBER 22,423.21$ 100.00% 14,060.50$ 62.71% 8,110.40$ 36.17% 252.31$ 1.13% DECEMBER 4,155 3,050 641 260 154 50TOTAL 160,992.42$ 100.00% 98,034.05$ 60.89% 60,734.72$ 37.73% 2,223.65$ 1.38% TOTAL 14,825 11,160 1,632 1,022 601 410 ATTACHMENT 4.2.3
TANANA POWER CO., INC.2007 REVENUE BREAKDOWNTOTAL % OF COMM % OF RES % OF ST. LITE % OF COMM COMM RES RES ST. LITE ST. LITE R CMONTH KWH TOTAL KWH TOTAL KWH TOTAL KWH TOTAL TOTAL ENERGY SURCHRGE ENERGY SURCHRGE ENERGY SURCHG KWHPEAK DEMANDJANUARY 138473 100% 88,437 63.87% 48,500 35.02% 1536 1.11%MONTH ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST MONTH KWHFEBRUARY 118195 100% 78,806 66.67% 37,853 32.03% 1536 1.30% JANUARY $0.00 $0.00 $0.00 JAN = 259.0MARCH 136168 100% 89,122 65.45% 45,510 33.42% 1536 1.13% FEBRUARY $0.00 $0.00 $0.00 FEB = 483.00APRIL 106831 100% 66,661 62.40% 38,634 36.16% 1536 1.44% MARCH $34.16 $34.16 $0.00 $0.00 1 MAR = 238.00MAY 89451 100% 55,451 61.99% 32,464 36.29% 1536 1.72% APRIL $0.00 $0.00 $0.00 APR = 238.00JUNE 74872 100% 43,375 57.93% 29,961 40.02% 1536 2.05% MAY $0.00 $0.00 $0.00 MAY = 234.00JULY 73499 100% 38744 52.71% 33,219 45.20% 1536 2.09% JUNE $0.00 $0.00 $0.00 JUN = 178.00AUGUST 71095 100% 39,448 55.49% 29,983 42.17% 1664 2.34% JULY $0.00 $0.00 $0.00 JUL = 164.00SEPTEMBER 87881 100% 51,823 58.97% 34,394 39.14% 1664 1.89% AUGUST $0.00 $0.00 $0.00 AUG = 174.00OCTOBER 107106 100% 65,170 60.85% 40,272 37.60% 1664 1.55% SEPTEMBER $0.00 $0.00 $0.00 SEPT = 232.00NOVEMBER 106410 100% 69,221 65.05% 35,525 33.39% 1664 1.56% OCTOBER $0.00 $0.00 $0.00 OCT = 276.00DECEMBER 127192 100% 79,777 62.72% 45,751 35.97% 1664 1.31% NOVEMBER -$34.16 -$34.16 $0.00 $0.00 0 NOV = 250.00ADJUSTMENTS 1 100% 0 0.00% 1 100.00% 0.00% DECEMBER $0.00 $0.00 $0.00 DEC = 273.00TOTAL 1237174 100% 766035 61.92% 452067 36.54% 19072 1.54% TOTAL $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 1 0 (LESS SURCHARGE BILLED &ADJUSTMENTS) TOTAL # COMM RES ST LITETOTAL % OF COMM % OF RES % OF ST. LITE % OF TOTAL COMM RES ST. LITE MONTH CUST. CUST. CUST. CUST.MONTH $$$ TOTAL $$$ TOTAL $$$ TOTAL $$$ TOTAL MONTH $$$ $$$ $$$ $$$JANUARY 167 19 147 1JANUARY 66,570.40$ 100.00% 39,463.80$ 59.28% 26,271.36$ 39.46% 835.24$ 1.25% JANUARY $89,460.21 $53,967.92 $34,393.77 $1,098.52 FEBRUARY 171 20 150 1FEBRUARY 56,931.53$ 100.00% 35,210.78$ 61.85% 20,885.51$ 36.69% 835.24$ 1.47% FEBRUARY $76,422.56 $48,113.78 $27,210.26 $1,098.52 MARCH 171 20 150 1 MARCH 65,092.38$ 100.00% 39,559.44$ 60.77% 24,697.70$ 37.94% 835.24$ 1.28% MARCH $83,447.88 $51,459.06 $30,938.53 $1,050.29 APRIL 170 18 151 1APRIL 51,137.43$ 100.00% 29,319.54$ 57.33% 20,982.65$ 41.03% 835.24$ 1.63% APRIL $65,389.98 $38,116.44 $26,223.25 $1,050.29 MAY 177 19 157 1MAY 43,370.09$ 100.00% 24,510.06$ 56.51% 18,024.79$ 41.56% 835.24$ 1.93% MAY $54,227.30 $31,156.58 $22,038.40 $1,032.32 JUNE 180 19 160 1JUNE 37,227.08$ 100.00% 19,328.06$ 51.92% 17,063.78$ 45.84% 835.24$ 2.24% JUNE $46,372.16 $24,526.50 $20,813.34 $1,032.32 JULY 179 18 160 1JULY 36,600.01$ 100.00% 17,090.79$ 46.70% 18,673.98$ 51.02% 835.24$ 2.28% JULY $45,529.26 $21,665.51 $22,831.43 $1,032.32 AUGUST 182 18 163 1AUGUST 35,743.76$ 100.00% 17,850.18$ 49.94% 17,058.34$ 47.72% 835.24$ 2.34% AUGUST $47,639.65 $24,359.95 $22,153.41 $1,126.29 SEPTEMBER 172 16 155 1SEPTEMBER 42,940.95$ 100.00% 23,019.35$ 53.61% 19,086.36$ 44.45% 835.24$ 1.95% SEPTEMBER $57,618.96 $31,583.42 $24,909.25 $1,126.29 OCTOBER 180 17 162 1OCTOBER 51,662.20$ 100.00% 28,660.09$ 55.48% 22,166.87$ 42.91% 835.24$ 1.62% OCTOBER $69,548.70 $39,387.25 $29,035.16 $1,126.29 NOVEMBER 177 17 159 1 NOVEMBER 51,214.66$ 100.00% 30,604.55$ 59.76% 19,774.87$ 38.61% 835.24$ 1.63% NOVEMBER $68,966.15 $42,071.76 $25,768.10 $1,126.29 DECEMBER 176 17 158 1DECEMBER 60,838.33$ 100.00% 35,077.78$ 57.66% 24,925.31$ 40.97% 835.24$ 1.37% DECEMBER $73,604.02 $43,000.92 $29,592.63 $1,010.47 TOTAL 2102 218 1872 12TOTAL 599,328.82$ 100.00% 339,694.42$ 56.68% 249,611.52$ 41.65% 10,022.88$ 1.67% TOTAL $778,226.83 $449,409.09 $315,907.53 $12,910.21 TOTAL % OF COMM % OF RES % OF ST. LITE % OF TOTAL TPC WSTEHT CONTROL FANS/ FUELMONTH SURCHGE TOTAL SURCHGE TOTAL SURCHGE TOTAL SURCHGE TOTAL MONTH CO KWH KWH KWH MODULE WELDER SHEDJANUARY 22,889.81$ 100.00% 14,504.12$ 63.36% 8,122.41$ 35.48% 263.28$ 1.15% JANUARY 4,934 3,820 629 263 162 60FEBRUARY 19,491.03$ 100.00% 12,903.00$ 66.20% 6,324.75$ 32.45% 263.28$ 1.35% FEBRUARY 4,484 3,530 514 237 133 70MARCH 18,321.34$ 100.00% 11,899.62$ 64.95% 6,206.67$ 33.88% 215.05$ 1.17% MARCH 5,158 4,130 523 260 175 70APRIL 14,252.55$ 100.00% 8,796.90$ 61.72% 5,240.60$ 36.77% 215.05$ 1.51% APRIL 5,032 3,830 744 250 158 50MAY 10,857.21$ 100.00% 6,646.52$ 61.22% 4,013.61$ 36.97% 197.08$ 1.82% MAY 4,833 3,650 548 260 155 220JUNE 9,145.08$ 100.00% 5,198.44$ 56.84% 3,749.56$ 41.00% 197.08$ 2.16% JUNE 3,598 2,860 10 250 128 350JULY 8,929.25$ 100.00% 4,574.72$ 51.23% 4,157.45$ 46.56% 197.08$ 2.21% JULY 3,907 3,090 11 274 142 390AUGUST 11,895.89$ 100.00% 6,509.77$ 54.72% 5,095.07$ 42.83% 291.05$ 2.45% AUGUST 3,083 2,230 14 350 139 350SEPTEMBER 14,678.01$ 100.00% 8,564.07$ 58.35% 5,822.89$ 39.67% 291.05$ 1.98% SEPTEMBER 3,963 2,860 241 359 153 350OCTOBER 17,886.50$ 100.00% 10,727.16$ 59.97% 6,868.29$ 38.40% 291.05$ 1.63% OCTOBER 4,844 3,840 349 354 201 100NOVEMBER 17,785.65$ 100.00% 11,467.21$ 64.47% 6,027.39$ 33.89% 291.05$ 1.64% NOVEMBER 4,725 3,660 475 330 150 110DECEMBER 12,765.69$ 100.00% 7,923.14$ 62.07% 4,667.32$ 36.56% 175.23$ 1.37% DECEMBER 5,971 4,540 426 363 182 460TOTAL 178,898.01$ 100.00% 109,714.67$ 61.33% 66,296.01$ 37.06% 2,887.33$ 1.61% TOTAL 54,532 42,040 4,484 3,550 1,878 2580 ATTACHMENT 4.2.3 CONT.
TANANA POWER CO., INC.2008 REVENUE BREAKDOWNTOTAL % OF COMM % OF RES % OF ST. LITE % OFCOMM COMM RES RES ST. LIGHT ST. LIGHT R CMONTH KWH TOTAL KWH TOTAL KWH TOTAL KWH TOTAL TOTAL ENERGY SURCHRGE ENERGY SURCHRGE ENERGY SURCHG KWHPEAK DEMANDJANUARY 124517 100% 78,683 63.19% 44,170 35.47% 1664 1.34%MONTH ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST ADJUST MONTH KWHFEBRUARY 111647 100% 72,187 64.66% 37,796 33.85% 1664 1.49%JANUARY $0.00$0.00 $0.00 JAN = 259.0MARCH 104294 100% 36,629 35.12% 66,001 63.28% 1664 1.60% FEBRUARY $0.00$0.00 $0.00 FEB = 275.00APRIL 89316 100% 56,118 62.83% 31,534 35.31% 1664 1.86% MARCH $34.16$34.16 $0.00 $0.00 1 MAR = 236.00MAY 78725 100% 48,606 61.74% 28,455 36.14% 1664 2.11% APRIL $0.00$0.00 $0.00 APR = 231.00JUNE 68008 100% 38,616 56.78% 27,728 40.77% 1664 2.45% MAY $0.00$0.00 $0.00 MAY = 202.00JULY 71916 100% 40,735 56.64% 29,517 41.04% 1664 2.31% JUNE $0.00$0.00 $0.00 JUN = 179.00AUGUST 73148 100% 42,605 58.24% 28,879 39.48% 1664 2.27% JULY $1,090.34$884.53 $205.81$0.00 $0.00 1,900 JUL = 208.00SEPTEMBER 76855 100% 46,036 59.90% 29,155 37.94% 1664 2.17%AUGUST $0.00$0.00 $0.00 AUG = 180.00OCTOBER 96148 100% 57,464 59.77% 37,020 38.50% 1664 1.73% SEPTEMBER $0.00$0.00 $0.00 SEPT = 221.00NOVEMBER 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! OCTOBER $0.00$0.00 $0.00 OCT = 238.00DECEMBER 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! 0 #DIV/0! NOVEMBER $0.00$0.00 $0.00 NOV = 0.00ADJUSTMENTS #DIV/0! 1,900 #DIV/0! 1 #DIV/0! #DIV/0! DECEMBER $0.00$0.00 $0.00 DEC = 0.00TOTAL 894574 100% 519579 58.08% 360256 40.27% 16640 1.86% TOTAL $1,124.50 $884.53 $205.81 $34.16 $0.00 $0.00 $0.00 1 1,900 (LESS SURCHARGE BILLED &ADJUSTMENTS)TOTAL # COMM RES ST LITETOTAL % OF COMM % OF RES % OF ST. LITE % OF TOTAL COMM RES ST. LITE MONTH CUST. CUST. CUST. CUST.MONTH $$$ TOTAL $$$ TOTAL $$$ TOTAL $$$ TOTAL MONTH $$$ $$$ $$$$$$JANUARY 176 17 158 1JANUARY 59,361.83$ 100.00% 34,698.61$ 58.45% 23,827.98$ 40.14% 835.24$ 1.41% JANUARY $71,815.58 $42,546.55 $28,258.56 $1,010.47 FEBRUARY 170 17 152 1FEBRUARY 53,260.87$ 100.00% 31,830.60$ 59.76% 20,595.03$ 38.67% 835.24$ 1.57% FEBRUARY $64,425.41 $39,039.73 $24,375.21 $1,010.47 MARCH 169 35 133 1 MARCH 50,138.39$ 100.00% 16,221.46$ 32.35% 33,081.69$ 65.98% 835.24$ 1.67% MARCH $60,626.36 $19,737.62 $39,878.27 $1,010.47 APRIL 171 17 153 1APRIL 43,295.76$ 100.00% 24,820.78$ 57.33% 17,639.74$ 40.74% 835.24$ 1.93% APRIL $52,188.17 $30,365.08 $20,812.62 $1,010.47 MAY 175 17 157 1MAY 38,205.04$ 100.00% 21,335.99$ 55.85% 16,033.81$ 41.97% 835.24$ 2.19% MAY $45,956.62 $26,077.61 $18,868.54 $1,010.47 JUNE 179 19 159 1JUNE 34,029.28$ 100.00% 17,467.67$ 51.33% 15,726.37$ 46.21% 835.24$ 2.45% JUNE $41,880.54 $22,345.54 $18,524.53 $1,010.47 JULY 172 18 153 1JULY 35,539.42$ 100.00% 18,068.98$ 50.84% 16,635.20$ 46.81% 835.24$ 2.35% JULY $42,691.78 $22,032.29 $19,649.02 $1,010.47 AUGUST 174 18 155 1AUGUST 36,365.32$ 100.00% 19,209.56$ 52.82% 16,320.52$ 44.88% 835.24$ 2.30% AUGUST $46,869.17 $25,256.24 $20,527.24 $1,085.69 SEPTEMBER 161 16 144 1SEPTEMBER 37,789.09$ 100.00% 20,598.78$ 54.51% 16,355.07$ 43.28% 835.24$ 2.21% SEPTEMBER $48,834.84 $27,145.36 $20,603.79$1,085.69 OCTOBER 171 17 153 1OCTOBER 46,729.22$ 100.00% 25,403.67$ 54.36% 20,490.31$ 43.85% 835.24$ 1.79% OCTOBER $60,574.15 $33,584.44 $25,904.02 $1,085.69 NOVEMBER 0 0 0 0 NOVEMBER -$ #DIV/0! -$ #DIV/0! -$ #DIV/0! -$ #DIV/0! NOVEMBER $0.00 $0.00 $0.00 $0.00 DECEMBER 0 0 0 0DECEMBER -$ #DIV/0! -$ #DIV/0! -$ #DIV/0! -$ #DIV/0! DECEMBER $12,453.75 $7,847.94 $4,430.58 $175.23 TOTAL 1718 191 1517 10TOTAL 434,714.22$ 100.00% 229,656.10$ 52.83% 196,705.72$ 45.25% 8,352.40$ 1.92% TOTAL $548,316.37 $295,978.40 $241,832.38 $10,505.59 TOTAL % OF COMM % OF RES % OF ST. LITE % OF TOTAL TPC WSTEHTCONTROL FANS/ FUELMONTH SURCHGE TOTAL SURCHGE TOTAL SURCHGE TOTAL SURCHGE TOTAL MONTH CO KWH KWH KWH MODULE WELDER SHEDJANUARY 12,453.75$ 100.00% 7,847.94$ 63.02% 4,430.58$ 35.58% 175.23$ 1.41% JANUARY 6,258 4,160 474 350 174 1,100FEBRUARY 11,164.54$ 100.00% 7,209.13$ 64.57% 3,780.18$ 33.86% 175.23$ 1.57% FEBRUARY 5,630 3,730 203 330 267 1,100MARCH 10,453.81$ 100.00% 3,516.16$ 33.64% 6,762.42$ 64.69% 175.23$ 1.68% MARCH 5,025 3,240 140 356 279 1,010APRIL 8,892.41$ 100.00% 5,544.30$ 62.35% 3,172.88$ 35.68% 175.23$ 1.97% APRIL 4,874 3,470 242 343 189 630MAY 7,751.58$ 100.00% 4,741.62$ 61.17% 2,834.73$ 36.57% 175.23$ 2.26% MAY 5,117 3,580 277 353 167 740JUNE 6,760.92$ 100.00% 3,787.53$ 56.02% 2,798.16$ 41.39% 175.23$ 2.59% JUNE 3,814 2,650 12 347 155 650JULY 7,152.36$ 100.00% 3,963.31$ 55.41% 3,013.82$ 42.14% 175.23$ 2.45% JULY 3,998 3,100 11 305 162 420AUGUST 10,503.85$ 100.00% 6,046.68$ 57.57% 4,206.72$ 40.05% 250.45$ 2.38% AUGUST 3,359 2,430 11 408 140 370SEPTEMBER 11,045.75$ 100.00% 6,546.58$ 59.27% 4,248.72$ 38.46% 250.45$ 2.27% SEPTEMBER 3,466 2,540 170 347 149 260OCTOBER 13,844.93$ 100.00% 8,180.77$ 59.09% 5,413.71$ 39.10% 250.45$ 1.81% OCTOBER 4,161 3,110 385 341 195 130NOVEMBER -$ #DIV/0! -$ #DIV/0! -$ #DIV/0! -$ #DIV/0! NOVEMBER 0 0 0 0 0 0DECEMBER 12,453.75$ 100.00% 7,847.94$ 63.02% 4,430.58$ 35.58% 175.23$ 1.41% DECEMBER 0 0 0 0 0 0TOTAL 112,477.65$ 100.00% 65,231.96$ 58.00% 45,092.50$ 40.09% 2,153.19$ 1.91% TOTAL 45,702 32,010 1,925 3,480 1,877 6410 ATTACHMENT 4.2.3 CONT.
ICE-THERMAL RESERVOIR REGIMEN DURING FIRST YEARS
OF OPERATION OF THE KRASNOYARSK HYDROELECTRIC PLANT
Yu. A. Grigor'ev and N. M. Sokol'nikov UDC 627.81:556.535.4/5
Filling of the reservoir at the Krasnoyarsk hydroelectric plant began in 1967. According to the original predic-
tions of the hydrometeorological service, 1967 was to be a very dry year with early passage of the floods. For this
reason it was decided to fill the reservoir by using the spring-summer floods. Filling started on April 18. The rise
of the water level in the reservoir reached 0.5-1.0 m/day. During the period between April 18 and July 1 the water
level rose 51.5 m (Fig. 1).
At the end of June. the hydrologic situation had changed in the Enisei River. In July, the flows increased
sharply as a result of heavy rains. Further rise of the water level in the reservoir was impossible because of insuf-
ficient dam height. At the end of June the eight low-level outlets, which measured 5x 5 m each, were opened and
discharged a total of 6100 mS/sec. Filling of the reservoir was slowed down. With decrease of the inflow, some of
the low-level outlets were closed at the beginning of September. On November 4, 1967, the water in the reservoir
reached its maximum level at El. 114.65 m, capacity, 30.2 km 3.
In connection with putting into operation two units and reduction of the inflow, water was withdrawn for the
first time from the reservoir, By January 1, 1968, the level had dropped to El. 112.6 m, that is, by 2 m. In 1967,
the runoff in the Enisei River was 96 km s, the volume in May-June being 36 km s and in July-September, 40 km 3.
Thus, the reservoir was filled with flood waters having a comparatively high temperature (Table 1). During the
summer period, heat reserves exceeding the usual for deep reservoirs were accumulated in the Krasnoyarsk reservoir.
These conditions affected to a significant extent the temperature regimen of the water at the upstream and down-
stream sides of the Krasnoyarsk plant during the first year of operation,
A result of the greater heat reserves in the reservoir was the slow drop in the mean water temperature during
the fall period at a site close to the dam. Thus, not until the end of December did the water temperature at the
12.0
m
110
r
8o
80
/ /
[
!
1
70
~/msAe~~ ,2
80 -
eooo~ ~' -" r "
0 --
' i;"'-"-
Fig. 1. Reservoir water levels (1) and overflows (2)
during 1967.
surface upstream from the dam drop to zero and the sur-
rounding portion freeze. According to data from the thermal
sections, during the same period the water temperature
in the bottom layers was over 3~
At the end of 1967, the reservoir was frozen over
between the vanishing point of the backwater curve and
the dam. An ice cover was observed on December 2 at the
Novoselovo and Primorsk settlements, on December 14 at
a distance of 35 km from the dam, on December IS at a
distance of 26 km from the dam, on December 21 at the
mouth of the Biryns River, and on December 26 at the dam.
The same characteristics and similar periods were observed
in the following years.
Freezing-over of the reservoir started with the devel-
opment of ice strips at the banks and freezing of thinbroken
ice into a thin ice crust. The surface of the ice cover
was continuous and smooth. An unfrozen patch of water
measuring 50 • 100 m remained in front of the intake
openings for the plant operating units. The large heat
reserves in the reservoir caused a freezing lag of over one
Translated from Gidrotekhnicheskoe Stroitel'stvo, No. I0, pp. 30-32, October, 1973.
960
CGU HS Committee on River Ice Processes and the Environment
14th Workshop on the Hydraulics of Ice Covered Rivers
Quebec City, June 19 - 22, 2007
FRAZIL ICE CONCERNS FOR CHANNELS, PUMP-LINES, PENSTOCKS,
SIPHONS, AND TUNNELS IN MOUNTAINOUS REGIONS
Robert Ettema and Gokhan Kirkil
Dept. of Civil & Environmental Engineering, and IIHR-Hydroscience & Engineering,
The University of Iowa, Iowa City, Iowa, USA 52242
robert-ettema@uiowa.edu, gokhan-kirkil@uiowa.edu
This paper discusses frazil ice concerns associated with water-conveyance
systems located in mountainous regions. Such systems commonly comprise
open-water channels (or reservoirs) linked to pressurized conduits (pump-lines,
penstocks, siphons, and tunnels) that pass water down, up, over, or through
steep terrain. The discussion addresses fundamental aspects of frazil formation
and behavior in flows undergoing substantial pressure changes. An important
consideration for such flows is that increased pressure depresses the freezing
temperature of water. As flow pressure subsequently decreases (e.g., on passing
through a turbine, or rising up a pump-line), water may become super-cooled
and prone to form frazil. The melting of ice entering a pressurized conduit (e.g.,
a penstock) can cool water flowing through the conduit. Such cooling may
occur even when there is no heat loss through the conduits wall. It is well
known that water-conveyance systems in cold regions are prone to significant
frazil-blockage problems at entrance trash-racks. Less well known, however,
are that some pressurized conduits also are at risk of accumulating frazil within
themselves, and others may disgorge bolus accumulations of frazil, possibly
mixed with other ice, that then create blockage problems at a downstream
section. Several case-studies are used to illustrate situations where frazil has
posed problems for penstocks, siphons, and tunnels in mountainous regions.
1. Introduction
A noteworthy feature of water conveyance systems located in steep mountainous regions is the
combined use of open-channel and pressurized conduits. The combinations occur in the form of
reservoirs and channels linked to one or more of the following conveyance-structure
components:
i. hydropower penstocks and turbines;
ii. pump-lines;
iii. siphons (inverted and regular); and,
iv. water-diversion tunnels.
Such conveyance components commonly comprise critical parts of water-conveyance systems
that divert water from streams, and reservoirs in mountainous terrain. Figure 1 illustrates, for
instance, a small canal conveying water to a tunnel at a water-diversion project in the Sierra
Nevada Mountains, California. Siphons and tunnels enable water to be conveyed across, or
through, steep terrain. Penstocks precipitously drop water down to hydropower turbines set a
lower elevation. Pumps enable water to be lifted to higher elevations. Though these conveyance
components are fairly common, there is little information about their performance in
mountainous terrain subject to frigid-weather conditions and, thereby, to ice.
Figure 1. A small canal conveying water to a tunnel in mountainous terrain
Of particular concern are problems attributable to frazil. It can form in several situations. The
lower air temperatures and higher wind in mountainous regions may cause water in mountain
streams and reservoirs to cool more quickly than at lower elevations, thereby creating conditions
hastening ice formation. Consequently, pump intakes, penstocks, siphons, and tunnels linked to
mountain streams and reservoirs frequently convey frigid water during winter; the severity of
conditions requires that some systems be drained during such winter. The concern for frazil
formation is aggravated by the swift and turbulent flow conditions prevailing in many mountain
streams and rivers. Further, flow pressures in water-conveyance conduits flowing full can vary
over several orders of magnitude, and thereby alter the freezing temperature of water. Together,
these aspects of water flow produce situations where frazil may form in sufficient concentrations
as to pose difficulties for water-conveyance systems in mountainous terrain. This paper outlines
and discusses the difficulties posed by frazil and other ice forms, including snow; mountainous
regions often experience relatively large amounts of snow, as well as colder air.
There is scant literature on water-conveyance systems in frigid mountainous regions. Though
Gemperline (1990) and Billfalk (1992) usefully summarizes ice considerations in the design and
operation of water intakes for hydropower facilities, and Daly (1991) does the same for water
intakes generally, none of these papers tackles the ice issues complicating the overall
performance of conveyance systems subject to substantial pressure variations. Gilpin’s
comprehensive work on freezing of water flow in pipes flows (e.g., Gilpin 1981) gives useful
insights, but only for small-bore pipes and modest pressure variation. Several anecdotal
accounts, and sundry ad-hoc reports, however, indicate that larger-scale conveyance components
in mountainous regions can encounter significant problems attributable to frazil ice and snow
(e.g., Ettema 2005).
2. Variation of Freezing Temperature with Pressure
Blockage of water intake trash-racks by frazil and other ice forms is a well-known problem (e.g.,
Gemperline 1990, Daly 1991). Frazil accumulation can block the trash rack at the entrance to a
penstock, pump-intake, siphon, and tunnel, as well as within them. Also, blockages may lead to
overflow and further jamming of approach channels or pipes. Less well known are the ice
problems attributable the changes in freezing temperature associated with the substantial
pressure changes that water flows in pressurized conduits may undergo. The principal factor to
be considered in this regard is the depression of freezing temperature as water pressure increases.
This trend is illustrated in the phase diagram of water (Figure 2).
Figure 2. A portion of the phase diagram of water (T.P. is the triple point for water)
Pressure variation may delay or hasten freezing, and it may reconstitute ice pieces passing with
water through pressurized conduits. The variation of melting/freezing temperature with gage
pressure can be expressed, from the Clapyeron equation for ice-water,
F
F
F
dH
dVTdP
dT = [1]
in which TF is freezing temperature, P is pressure, V is volume of water freezing, and HF is latent
heat of water fusion. For water, with TF in degrees Kelvin and P in MPa, the trend expressed by
Eq. (1) can be illustrated graphically using a curve such as in Figure 3. The curve itself can be
expressed as
9/1
2.395116.273
−=PTF [2]
Here, temperature, TF, is in degrees Kelvin, and gage pressure, P, is in MPa. Eq. (2) indicates
that an increase of approximately 1MPa pressure decreases the freezing temperature of water by
about 0.074oK (or 0.074oC); i.e., the freezing temperature of water becomes -0.074oC. The
average depression of freezing temperature for ice commonly found in nature (ice type 1h,
Hobbs 1974) is 0.10oC/MPa, over the pressure range associated with ice 1h, 0 < P < 209MPa.
Pressure changes of the order of 0 to 2MPa magnitude are common in closed-conduit flows
associated with hydropower penstocks, pumps, siphons, though perhaps less so in tunnels. An
elevation difference of 100m produces a pressure difference of about 1MPa.
Figure 3. A portion of the relationship between freezing-point depression, ∆TF and absolute pressure for
water; common pressure range for hydraulic structures is indicated
The following two practical questions arise regarding the depression of water’s freezing
temperature for water flowing through hydropower penstocks, pump pipelines, and siphons:
i. Why should the depression of water’s freezing temperature be of concern to the operation
of these conduits?
ii. How can water in these conduits attain the depressed freezing temperature?
The depression of freezing temperature can result in super-cooling of water and frazil formation,
with all its attendant problems of flow blockage. Accordingly, care is needed to minimize frazil
formation in such conduits. To do this requires preventing water flow from actually dropping to
its depressed freezing temperature, or below.
Water flowing down a conduit may cool owing to heat loss through the walls of the conduit, and
through the melting of ice transported with flow into the conduits. As the freezing temperature
decreases, the surface of ice melts, drawing heat from the water, thereby cooling it. The water
cools to the extent that sufficient ice melts to cool the water to its freezing temperature. The
amount of ice particles needed to cool frigid water from its initial freezing temperature to its
adjusted freezing temperature can be calculated from the heat-balance relationship
)T(C)C(Fpwatericeice∆=∆ρλρ [3]
where iceρ is ice density, λ is latent heat of melting ice, Cice is frazil ice concentration, Cp is
specific heat of water and TF is freezing temperature of water, and ∆TF = TF2 – TF1; here, TF1 is
the freezing temperature at the higher elevation, TF2 is the freezing temperature at the lower
elevation, and TF3 is the freezing temperature at the conduit’s outlet. A freezing temperature
drop ∆TF,water=0.1oK requires an ice-concentration reduction of iceC∆=1.03x10-3. Assuming an
initial freezing temperature, TF1 = 0oC, Eqs. 2 and 3 lead to a relationship between ∆Cice and net
head-drop through the conveyance structure. Figure 4 shows the relationship. For instance, the
change of ice concentration given in the above example (iceC∆=1.03x10-3) corresponds
approximately to a 100m head-drop. Estimates of frazil concentrations in streams and reservoirs
are in the order of 106 particles/m3 (Daly, 1991). If frazil particles in flowing water are taken to
be discoids, 2mm in diameter and 0.1mm thick (e.g., Chen et al., 2004), a nominal volumetric
frazil concentration is about 1.6x10-3, which means that typically there is enough frazil ice to
super-cool water in the conveyance structures diverting water from the mountain streams and
reservoirs.
Pressure-related super-cooling of water occasionally occurs in the natural environments. Alley
et al. (1998), for example, describe how water flowing through or beneath a deep glacier can
super-cool when eventually ascending a steep slope at the end of a glacier. The ascending super-
cooled water may freeze to the glacier’s floating base, as well as to other boundaries.
0
20
40
60
80
100
120
140
160
180
200
0.00E+00 5.00E-04 1.00E-03 1.50E-03 2.00E-03 2.50E-03
∆Cice, volumetric concentration of frazil needed to reach TF2
∆Η, pressure head increase along a flowconduit (m)TF1=0.00 oC
Figure 4. Variation of frazil concentration needed to reach final freezing temperature (TF2) as a
function of pressure-head increase (or elevation drop) along a conveyance structure; initial
freezing temperature is TF1
3. Frazil Formation in Hydropower Turbines and Draft-tubes
A penstock delivers water under pressure to a hydropower turbine, which then extracts much of
the power associated with the water’s flow rate and net head. For low and medium-head
turbines, the water power is converted into mechanical power by means of flow momentum
exchange; the flowing water remaining fully enclosed by the turbine and its draft tube, but at
drastically reduced pressure. However, for high-head turbines, water surrounded by air at
atmospheric pressure impacts the turbine runner, and is then discharged directly into a tailrace.
Figure 5 shows that water pressure in a penstock increases as flow moves down the penstock. A
corresponding decrease in freezing temperature accompanies the pressure increase. As the water
emerges from the penstock and passes through the turbine, its pressure decreases abruptly, with
the consequent increase in freezing temperature, and the flow of super-cooled water out of the
turbine. Super-cooled water is in an unstable state, and eventually (through nucleation by ice
fragments in the flow) will adjust itself so as to be in a stable state. When that occurs, water
releases its latent heat of fusion, and there occurs a rapid growth of frazil, which initially is in an
active state. Frazil may be swept out into the tailwater channel. If the concentration of frazil is
large, and the tailwater quite small, the frazil can congest the tailwater, eventually accumulating
back up into the turbine, possibly eventually choking flow through the turbine. Few studies have
been conducted of turbine operation when water flow is at the freezing temperature and frazil is
at the verge of forming, or actually forming.
Figure 5. Frazil formation and accumulation within a turbine and its outlet; freezing
temperatures TF1 = TF3 = 0.00oC; TF2< 0.00oC
The length, or inclination, of a penstock plays a role with respect to cooling of flow through a
penstock in frigid winter conditions. For a given drop in elevation, penstock length directly
influences flow duration through a penstock. Greater flow duration provides more time for water
to cool, by means of ice melting or heat-loss through the penstock. Accordingly, all else being
equal, a longer penstock produces more frazil.
4. Frazil Formation in Pump Lines
When passing through a pump, water pressure suddenly rises to head Hp, as indicated in Figure
6, and then reduces along the pump-line to about the equivalent of the flow depth at the flow
outlet. The freezing temperature drops correspondingly as the hydraulic grade line rises above
the pipe, causing the water potentially to be super-cool and the ice to melt. Actual super-cooling
depends on there being sufficient time for water to cool. The freezing temperature rises as the
hydraulic grade line drops and approaches the water surface at the outlet. Flow along the
declining grade line is prone to form frazil. The volume of frazil formed approximately equals
the volume of ice melted, and depends on additional heat loss through the conduit’s walls. The
frazil in super-cooled water is initially in an active state whereby it can adhere to the remaining
ice pieces conveyed with the flow, and agglomerating as a bolus, of ice pieces or slush that may
disgorge at the outlet of the pump line. The increased flow resistance produced by the
agglomerating slush may, with time, increase the flow resistance encountered by the pump.
Information on ice agglomerates or boluses, discharging from a pump line is not available
presently. There evidently are no document reports of their occurrence.
Figure 6. Frazil formation in a pump-line pipe: TF1 = TF3 = 0.00oC; TF2< 0.00oC
5. Frazil Formation in Siphons
The changes in pressure and, thereby, of freezing temperature in siphons combine the changes
occurring for flow in pump discharge lines. The formation of frazil and ice agglomerates
essentially is the same as for a long pump line. As described above for pump lines, and
penstocks, the freezing temperature declines as pressure increases (on the siphon’s downward
arm), and increases as pressure decreases (on the upward arm). Provided that the water attains
the reduced freezing temperature, the flow in the upward flow is super-cooled. Inverted siphons
are not uncommon for mountainous terrain; the siphon has an overall U-shape form, as indicated
in Figure 7. Ice entering the siphon may largely pass through the siphon, though some ice may
accumulate in the bottom, especially at locations where flow separation occurs, notably at the
first bottom bend where ice in the separation region may rest against the upper side of the siphon
pipe (Figure 8).
As water descends an inverted siphon, water pressure increases and the freezing temperature of
water is depressed. Water has to cool before attains its freezing temperature. In this regard,
frazil and ice pieces (as well as snow) entering the siphon may partially (or entirely) melt, the
heat need to melt ice being drawn from the flowing water and cooling the water. An argument
can be made that the more ice entering each siphon, the greater the internal heat sink provided
for the flow to super-cool. The dropping water then cools, even when there is no heat transfer to
the pipe and air around the pipe. The heat generated by flow friction would be negligible
compared to the heat consumed in melting ice as water drops in the siphon and flows within the
siphon.
A longer siphon (all other factors equal) provides more time for water to cool more, and thereby
for more frazil to be generated. The relatively long bottom section of the siphon enables
considerable melting of ice entering the siphon, thereby enabling the water to attain its new
freezing temperature. A longer bottom section can enable more ice to rise and accumulate along
the conduit, as sketched in Figure 8. Greater accumulation of ice would increase flow resistance,
and decrease flow rate, through the siphon, thereby compounding the frazil concern.
The location where frazil first forms in each siphon depends on the air temperature and rate of
heat loss from each siphon, as well as on water flow rate, and the amount of ice entering the
siphon. For example, under milder weather conditions and less ice entering the siphon, frazil
will form closer to the end of the siphon, and will emerge as a rather thin slush. But under more
frigid weather conditions, and more ice entering the siphon, ice forms more quickly along the
siphon, and would emerge from the siphon as a more agglomerated, clumpy bolus of ice.
Figure 7. Frazil formation in an inverted siphon; TF1 = TF3 = 0.00oC; TF2< 0.00oC
Figure 8. Flow separation at the base of an inverted siphon, and flow along the base may
increase ice accumulation
6. Frazil and Other Ice in Diversion Tunnels
Flow in most tunnels flowing full usually do not experience the great pressure fluctuations
experienced by flow in penstocks, pump-lines, and siphons. For most tunnels, the elevation drop
is relatively modest (typically much less than 100m), unless the tunnel includes a vertical drop.
Also, tunnel-wall temperature (in tunnels flowing full) is above the freezing temperature, and
warms frigid-water flows. Wall temperatures typically are between the water temperature (about
0oC for frigid water) and the temperature of the rock at some distance from the crown of the
tunnel. Rock temperatures often are estimated to be at about the yearly average air temperature
of the region in which the rock is located.
Nevertheless, tunnels still can be prone to ice problems, notably –
i. ice blockage of tunnel-entrance racks;
ii. accumulation of ice pieces drifting into a tunnel;
iii. accumulation of frazil formed by flow turbulence within the intake entrance; and,
iv. aufeis formed by freezing of water seeping into a tunnel drained during winter.
The problem of entrance-rack blockage is essentially the same as that for water intakes generally,
and is well documented (e.g., Billfalk 1992, Daly 1991, Gemperline 1990). However, a
complication for tunnel entrances in steep mountainous regions, especially in remote regions, is
that the usual methods for controlling frazil blockage of intakes along rivers and lakes are
infeasible or much more difficult to implement. The usual methods (e.g., Daly 1991) include
facilitating the formation of an intact ice cover on the approach channel immediately upstream of
the entrance, the use of warm water to heat the entrance rack, and back-flushing of flow through
the entrance rack. The more practical option presently is to mechanically break-up ice
accumulating at a rack, and sluice it sideways out of the approach channel.
There are few reports (or studies) documenting concerns caused by ice accumulation within
water-diversion tunnels, though such problems are known to occur. An operational difficulty is
that access difficulties hinder the viewing of ice accumulations in tunnels. Ettema (2005),
though, describes one instance where ice, largely frazil, accumulated in a tunnel. This instance is
briefly elaborated below as a case-study example.
Lia and Carstens (1998) describe the problems caused by aufeis formation in water diversion
tunnels for several Norwegian hydropower plants. The problem can be substantial for unlined
tunnels in rock whose water-table lies above the tunnel. Frigid air passing through such tunnels
freezes water seeping from fissures in the rock.
A related further problem is snow-drift accumulation at the entrance and outlet of tunnels. Lia
and Carstens 1998) describe large accumulations that practically dammed tunnels at Norwegian
hydropower plants. Heavy snow falls and substantial winds can result in the formation of snow
drifts. For tunnels in mountainous regions with perennial snow, the drifts can exist for several
winters and consolidate.
7. Case-Study Examples
Briefly described here are three case-study examples of frazil concerns encountered by a
penstock, a siphon, and a tunnel in mountainous regions. Each example illustrates the
difficulties that frazil may pose for these conveyance structures. Usefully documented examples
are quite rare, and the full circumstances associated with them usually unclear. Also, several
scale considerations hamper laboratory simulation of the case-study examples, or similar
situations. The difficulties include the physical chemistry of water, along with the flow lengths
and large pressures involved. These factors are almost prohibitively challenging to reproduce in
the usual hydraulics laboratory.
Frazil in a Turbine and Tailrace. A case-study example illustrating frazil formation and
accumulation at the end of a penstock is that of a micro-hydro plant at King Cove, Alaska. The
plant draws water from a glacier-fed stream, and has a gross head of 90m, and a net head of 74m
(giving ∆TF ≈ -0.06oC). Early during its operation, a large quantity of frazil formed in the
turbine and in the plant’s outflow channel. Figure 9 shows frazil being excavated from the
outflow channel.
(a) (b)
Figure 9. King Cove micro-hydro plant, Alaska (a); excavation of frazil from the plant’s small
tailrace channel (b) (Photos courtesy of King Cove Hydro)
Frazil in an Inverted Siphon. The difficulties of siphon operation in frigid winter conditions are
illustrated by a siphon conveying water across an approximately 100m-deep ravine in the Sierra
Nevada Mountains, California. Figure 10 shows the layout of the siphon. The siphon’s
operators observing flow discharging from the siphon describe how it intermittently ejects a
large bolus of ice slush that adversely affects the capacity of the outlet channel to convey water.
Though the literature lacks information about the formation of an ice “bolus,” the size, shape,
and intermittent features of a representative bolus suggests that it forms initially in flow-
separation zones within the siphon; e.g., at the downstream side of the bends at the bottom of the
siphon, as indicated in Figure 8. The ice boluses tumble, consolidate, and grow within the flow
separation region until reaching a size large enough to be caught by the flow and swept along the
siphon, eventually emerging (whale like, as the observers report) at the siphon’s outlet channel.
It is possible that several smaller boluses may merge as a single glob, and that the they collect
further slush as they rise relatively rapidly up the rising arm of the siphon. Bolus buoyancy,
added to flow drag, propel the bolus (“like a breaching whale,” as one operator characterized it)
out of the siphon’s outlet. There are no direct observations of how an ice bolus forms. There are
reports (from the siphon’s operators) of rumblings in the siphon’s bottom section at times when
the siphon is passing ice. These noises suggest, as indicated in Figure 8, that the initial ice
accumulation forms along the tunnel’s crown and in the flow-separation regions. Flow then
drags the accumulating bolus of ice along the siphon.
(a)
(b)
Figure 10. A siphon for a water-conveyance system in the Sierra Nevada Mountains, California
(a); ice boluses disgorged at the siphon’s outlet, and blocking the siphon’s outlet channel (b)
Flow through the siphon is driven by the difference in water surface elevation between the
siphon’s inlet and the outlet. As this elevation difference decreases, such as when ice severely
reduces flow through the channel, flow passes more slowly through the siphon. It is possible
therefore that ice difficulties in the channel become aggravated as they progress, because flow
slows through the siphon, ice in the siphon forms larger boluses, which in turn have greater
difficulty in passing through the channel.
Frazil Accumulation in a Diversion Tunnel. As is likely with frazil accumulation in most
tunnels, the general circumstances associated with frazil passage into the tunnel described here
are known in only approximate terms. The tunnel’s entrance is shown in Figure 1. Direct
observations of the processes resulting in the accumulation are incomplete, for various reasons
including a lack of observations about ice conditions along the canal conveying water to the
tunnel. The manner whereby ice passage and accumulation in the tunnel, nonetheless, can be
inferred from the data obtained from several sources, and from what is known in the literature
about the formation of similar accumulations in rivers and streams. The frazil accumulation was
akin to a hanging frazil “dam,” such as described in Ashton (1986) or Beltaos (1995). A couple
of differences from hanging frazil dams being that –
i. The accumulated frazil rested against the tunnel’s rock crown; and,
ii. As the frazil accumulation thickened, the constrained flow path narrowed and velocities
increased.
A construction problem had resulted in the tunnel not following a steady downward invert grade
that would have facilitated the free-surface flow of water along its entire length. The tunnel’s
initial gradient was over-steep, and an alignment correction was needed. Accordingly, the tunnel
had a mild kink at about its mid-point, where the tunnel’s grade became mildly upward so that
the tunnel would reach the required exit at an outlet channel location. Frazil entering the tunnel,
and possibly forming in an initial portion of tunnel, accumulated near the location where the
tunnel’s slope begins to arc gently upwards towards its outlet. In this region, the free-surface
flow of water along the downward reach of the tunnel gradually occupies practically the full flow
cross section of the tunnel. The approximate extent of the accumulation is indicated
approximately in Figure 11. The accumulation profile is based on observations reported by an
inspection crew who entered the tunnel drained for a scheduled inspection. The frazil
accumulation did not block flow, which continued to pass through the tunnel. Considerations
related to critical velocity for erosion of accumulated frazil slush infer that the tunnel likely
would not block owing to frazil accumulation.
(a) (b)
Figure 11. Frazil accumulation in a water-diversion tunnel: (a) approximate profile of frazil
accumulation in the tunnel; (b) a view of frazil deposited on the invert of the drained tunnel
8. Conclusions
Frazil ice often is an under-appreciated concern for many water-conveyance systems, but none
more so than systems in mountainous terrain. Mountainous terrain is more likely to have colder
weather, swift-flowing streams, and to have limited accessibility. The combined considerations
of temperature and flow speed increase the likelihood of frazil formation. Limited accessibility
aggravates the concern.
Also, because water-conveyance systems in mountainous terrain often entail the combined use of
open-channel and pressurized conduits, a further mechanism compounds frazil difficulties in
mountainous terrain. The mechanism arises when frigid water flowing in a conduit undergoes
major pressure increase, and then reduction. Increased pressure depresses water’s freezing
temperature, and thereby results in the super-cooling of water that subsequently flows with
decreasing pressure. If the water cools to the depressed freezing temperature, frazil quickly
forms when water flows at reduced pressure. Flows through a penstock and hydropower turbine,
a pump line, or a siphon, produce cycles of increased then decreased pressure, thereby exposing
these flow components to frazil. Water flowing at increased pressure may cool as ice transported
in the water melts, and also by heat loss through the conduit walls. A longer conduit (all else
equal) provides more time for water to cool to its depressed freezing temperature. Also, more ice
entering a pressurizing flow enables water to cool more quickly to the depressed freezing
temperature.
The practical consequence is that frazil can readily pose substantial difficulties for hydropower
and water-supply facilities in mountainous terrain. Frazil accumulations and blockages
potentially can occur in the approach channels, as well as block trash racks at entrances to flow
components like and penstocks, pumped water lines, siphons, and tunnels. Extensive amounts of
frazil may form at the outlet of turbines. Moreover, frazil and other ice may accumulate within
the flow components themselves. Agglomerations of ice may form in a pump line or an inverted
siphon, hampering flow passage, and be disgorged as a bolus of ice that may block flow
downstream of a pump or siphon outlet.
Acknowledgments
The writers thank Steve Daly for his suggestions made at the outset of writing this paper.
References
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Beltaos, S., 1995, River ice jams, Water Resource Publications, Littleton, CO, USA.
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Chen, Z., Ettema, R., and Lai, Y., 2004. Laboratory and numerical experiments of frazil
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91-1, US Army Corps of Engineers, Cold Regions Research & Engineering Laboratory,
Hanover, NH 03755.
Ettema, R., 2005. Ice concerns associated with the Mill-Bull Tunnel in the El Dorado Canal
system. Limited distribution report, Ettema Consulting, Iowa City, IA 52245.
Gemperline, E., 1990. Considerations in the design and operation of hydro power intakes. In
Cold Regions Hydrology and Hydraulics, Ed. by W.L. Ryan and R.D. Crissman, ASCE,
New York, 517-556.
Gilpin R.R., 1981. Modes of ice formation and flow blockage that occur while filling a cold pipe.
Cold Regions Science & Technology Vol. 5, 163–171.
Hobbs, P.V., 1974. Ice physics. Clarendon Press, Oxford, Britain.
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Polarconsult has worked on all aspects of small hydropower projects throughout Alaska.
Polarconsult's design professionals have been involved in hydropower projects for the
following Alaskan communities:
SOUTHWEST ALASKA SOUTHEAST ALASKA OTHER ALASKAN COMMUNITIES
Atka Angoon (Thayer Lake) Chitna
Akutan Hoonah Cordova
Chignik Bay Hydaburg Eagle River
Chignik Lagoon Juneau (Snettisham) Palmer (McRoberts Creek)
Larsen Bay Pelican Scammon Bay
Old Harbor Sitka Valdez (Allison Lake)
Unalaska Tenakee Springs
Our design team knows through experience how to design and build small hydro projects
in remote locations such as Tanana for constructability and ease of operation and
maintenance. For the past 17 years, the principle engineers at Polarconsult have owned
and operated the grid -tied 100-kW McRobert’s Creek Hydro Plant located in the
mountains near Palmer.
Polarconsult’s design team has also recently designed, permitted, and is currently
preparing to construct two independently owned hydroplants (2,000 kW Fishhook and
1,200 kW South Fork Projects) in southcentral Alaska. These projects are larger than
would be built in Tanana, but many of the components and design considerations are
similar to what would be needed in Tanana.
POLARCONSULT ALASKA, INC. PROPOSAL FOR HYDROPOWER RECONNAISSANCE STUDY
TANANA, ALASKA
NOVEMBER 6, 2008 PAGE 2 OF 3
Polarconsult has also recently completed the majority of the design work fo r the 650-kW
Pelican Hydro Project in southeast Alaska. Extensive dam planning and design was
required for this project. Similar work is also being performed for the Chignik Bay water
line and hydroplant. The Chignik Bay project has required dam safety inspections,
recommendations for repair, and periodic inspections over many years.
PROPOSED SCOPE OF WORK
Feasibility Study
Polarconsult will perform the necessary field investigations to complete a feasibility
study for hydroelectric project on Jackson Creek. This will include elevation
measurements along the length of the creek, installation of stream gages and taking flow
measurements, prepare preliminary designs, and provide a cost estimate for the
construction of the recommended project.
The stream gaging will require access up the river by boat, ATV, or snow machine to
identify a suitable gaging site. Our assumption for the proposal is that multiple velocity
and depth measuring recorders will be installed along with either a flume or weir. We're
also assuming a helicopter will be required to transport materials and equipment to the
gage site. This work would be done in the summer or fall of 2009. During the spring of
2010, another trip will be required to download and remove the gaging equipment. This
can be done using snow machines traveling up the river corridor.
Following the retrieval of the stream gaging data we will prepare preliminary designs for
the project, a cost estimate, and a feasibility report.
The report will also compare the proposed hydroelectric resource to a geothermal project
located at Little Melotzina Hot Springs. The analysis of the feasibility of the hot springs
will be performed using existing data. The existing data indicates that the resource has
the potential to fully meet Tanana's power needs. Therefore, for the purposes of the
analysis, it will be assumed that the resource could provide the maximum benefit which
would be meeting all of Tanana's electrical needs. The feasibility then will require a cost
estimate for the project along with an economic analysis taking into consideration the
benefit, capital cost, and operations and maintenance costs.
Both reports will be completed by the end of 2010.
Proposed Fee
The fees charged for this work will be on a time and
material basis with a total cost not to exceed
$250,000. The following table summarizes the cost
estimate for this work.
Item Cost
Gage Installation
Transporation $ 55,000
Equipment $ 40,000
Labor $ 45,000
Other Expenses $ 10,000
Gage Removal
Transporation $ 5,000
Equipment $ 2,000
Labor $ 12,000
Other Expenses $ 1,000
Preliminary Design $ 10,000
Cost Estimate $ 15,000
Report $ 15,000
Geothermal
Cost Estimate $ 20,000
Feasibility $ 20,000
Total $ 250,000
POLARCONSULT ALASKA, INC. PROPOSAL FOR HYDROPOWER RECONNAISSANCE STUDY
TANANA, ALASKA
NOVEMBER 6, 2008 PAGE 3 OF 3
General Terms and Conditions
This proposal is contingent on the following:
1. No work other than what is typical of the respective professions stated above is
included.
2. Except where otherwise noted, construction engineering and inspection services
are not included in this proposal.
3. Project timelines are from time of notice to proceed, or receipt of review
comments from previous work item.
4. Should additional work beyond the scope of this proposal be required,
Polarconsult will submit, in writing, an estimate for extra work items and will not
proceed on those items without written authorization.
5. Additional field time due to weather delays or other events beyond Polarconsult's
control will be billed at a standard 8-hour delay plus per diem.
6. Equipment, consumables, airfare, shipping, lodging and other travel-related costs
to be reimbursed on a time -and-materials basis at direct cost plus 15%.
7. This proposal is valid for 60 days.
8. Permit fees are not included with this proposal.
Thank you for the opportunity to propose on this project. If you have any questions,
please contact me at 258-2420 or by e-mail at dan@polarconsult.net.
Sincerely,
Daniel Hertrich, PE
Attachments: Fee Schedule
Polarconsult Statement of Qualifications