HomeMy WebLinkAboutTDX Power NSG AEA Grant Application 9-22-14Renewable Energy Fund Round VIII
Grant Application - Standard Form
AEA 15003 Page 1 of 35 7/2/14
Application Forms and Instructions
This instruction page and the following grant application constitutes the Grant Application Form for
Round VIII of the Renewable Energy Fund. A separate application form is available for projects
with a primary purpose of producing heat (see RFA section 1.5). This is the standard form for all
other projects, including projects that will produce heat and electricity. An electronic version of the
Request for Applications (RFA) and both application forms is available online at:
http://www.akenergyauthority.org/REFund8.html.
• If you need technical assistance filling out this application, please contact Shawn Calfa, the
Alaska Energy Authority Grants Administrator at (907) 771-3031 or at scalfa@aidea.org.
• If you are applying for grants for more than one project, provide separate application forms
for each project.
• Multiple phases for the same project may be submitted as one application.
• If you are applying for grant funding for more than one phase of a project, provide
milestones and grant budget for each phase of the project.
• In order to ensure that grants provide sufficient benefit to the public, AEA may limit
recommendations for grants to preliminary development phases in accordance with 3 ACC
107.605(1).
• If some work has already been completed on your project and you are requesting funding
for an advanced phase, submit information sufficient to demonstrate that the preceding
phases are completed and funding for an advanced phase is warranted.
• If you have additional information or reports you would like the Authority to consider in
reviewing your application, either provide an electronic version of the document with your
submission or reference a web link where it can be downloaded or reviewed.
• In the sections below, please enter responses in the spaces provided, often under the
section heading. You may add additional rows or space to the form to provide sufficient
space for the information, or attach additional sheets if needed.
REMINDER:
• Alaska Energy Authority is subject to the Public Records Act AS 40.25, and materials
submitted to the Authority may be subject to disclosure requirements under the act if no
statutory exemptions apply.
• All applications received will be posted on the Authority web site after final
recommendations are made to the legislature.
• In accordance with 333 (b) Applicants may request trade secrets or proprietary company
data be kept confidential subject to review and approval by the Authority. If you want
information is to be kept confidential the applicant must:
o Request the information be kept confidential.
o Clearly identify the information that is the trade secret or proprietary in their
application.
o Receive concurrence from the Authority that the information will be kept confidential.
If the Authority determines it is not confidential it will be treated as a public record in
accordance with AS 40.25 or returned to the applicant upon request.
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Grant Application - Standard Form
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SECTION 1 – APPLICANT INFORMATION
Name (Name of utility, IPP, or government entity submitting proposal)
TDX Power, North Slope Generating
Type of Entity: Fiscal Year End:
Electric Utility September 30th
Tax ID #27-0004843
Tax Status: x For-profit ☐ Non-profit ☐ Government (check one)
Date of last financial statement audit:
Mailing Address: Physical Address:
615 E. 82nd Ave., Suite 200 Same
Anchorage, AK 99518
Telephone: Fax: Email:
907-762-8478 907-278-2332 jlyons@tdxpower.com
1.1 APPLICANT POINT OF CONTACT / GRANTS MANAGER
Name:
John Lyons Title: General Manager
Mailing Address:
615 E. 82nd Ave., Suite 200
Anchorage, AK 99518
Telephone: Fax: Email:
907-762-8478 907-278-2332 jlyons@tdxpower.com
1.1.1 APPLICANT ALTERNATE POINTS OF CONTACT
Name Telephone: Fax: Email:
Kord Christianson 907-360-2939 907-278-2332 kord@tdxpower.com
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1.2 APPLICANT MINIMUM REQUIREMENTS
Please check as appropriate. If you do not to meet the minimum applicant requirements, your
application will be rejected.
1.2.1 As an Applicant, we are: (put an X in the appropriate box)
x An electric utility holding a certificate of public convenience and necessity under AS 42.05, or
☐ An independent power producer in accordance with 3 AAC 107.695 (a) (1), or
☐ A local government, or
☐ A governmental entity (which includes tribal councils and housing authorities)
1.2 APPLICANT MINIMUM REQUIREMENTS (continued)
Please check as appropriate.
x 1.2.2 Attached to this application is formal approval and endorsement for the project by the
applicant’s board of directors, executive management, or other governing authority. If the
applicant is a collaborative grouping, a formal approval from each participant’s governing
authority is necessary. (Indicate by checking the box)
x 1.2.3 As an applicant, we have administrative and financial management systems and follow
procurement standards that comply with the standards set forth in the grant agreement
(Section 3 of the RFA). (Indicate by checking the box)
x 1.2.4 If awarded the grant, we can comply with all terms and conditions of the award as
identified in the Standard Grant Agreement template at
http://www.akenergyauthority.org/REFund8.html. (Any exceptions should be clearly noted
and submitted with the application.) (Indicate by checking the box)
x 1.2.5 We intend to own and operate any project that may be constructed with grant funds for
the benefit of the general public. If no please describe the nature of the project and who will
be the primary beneficiaries. (Indicate yes by checking the box)
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SECTION 2 – PROJECT SUMMARY
This section is intended to be no more than a 2-3 page overview of your project.
2.1 Project Title – (Provide a 4 to 7 word title for your project). Type in space below.
Deadhorse Waste Heat to Energy Plant
2.2 Project Location –
Include the physical location of your project and name(s) of the community or communities that will
benefit from your project in the subsections below.
2.2.1 Location of Project – Latitude and longitude, street address, or community name.
Latitude and longitude coordinates may be obtained from Google Maps by finding you project’s
location on the map and then right clicking with the mouse and selecting “What is here? The
coordinates will be displayed in the Google search window above the map in a format as follows:
61.195676.-149.898663. If you would like assistance obtaining this information please contact
AEA at 907-771-3031.
70°11'59.60"N Latitude 148°28'0.23"W Longitude
100 Powerplant Way, Deadhorse, AK 99734
Prudhoe Bay, Alaska
2.2.2 Community benefiting – Name(s) of the community or communities that will be the
beneficiaries of the project.
Prudhoe Bay (Sagavanirktok) in the North Slope Borough
2.3 PROJECT TYPE
Put X in boxes as appropriate
2.3.1 Renewable Resource Type
☐ Wind ☐ Biomass or Biofuels (excluding heat-only)
☐ Hydro, Including Run of River ☐ Hydrokinetic
☐ Geothermal, Excluding Heat Pumps ☐ Transmission of Renewable Energy
☐ Solar Photovoltaic ☐ Storage of Renewable
X Other (Waste Heat to Energy) ☐ Small Natural Gas
2.3.2 Proposed Grant Funded Phase(s) for this Request (Check all that apply)
Pre-Construction Construction
X Reconnaissance X Final Design and Permitting
X Feasibility and Conceptual Design X Construction
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2.4 PROJECT DESCRIPTION
Provide a brief one paragraph description of the proposed project.
TDX proposes to install (3) 800 kWe Organic Rankine Cycle (ORC) power generation units to
generate electric power from waste heat in the flue gas of two Solar Turbine Taurus 70 gas
turbines. Furthermore TDX intends to utilize low grade waste heat downstream of the ORC to
pre-heat turbine inlet air to significantly improve the emissions profile at low temperatures.
This new facility will require an extended 40x64’ structure to the West of the new gas turbine plant
building. Approximately 10.5 MWth waste heat would be drawn from the gas turbine stacks and
used to produce 2.1 MWe (net) electricity year round through the ORC system. Downstream the
flue gas is exhausted through a separate stack.
Systems are built on a pile foundation with an air gap. The extended facility will remain on the
footprint of the existing gravel pad. Glycol fluid coolers are placed on the roof of the extension
from lower level switchgear and shop rooms. Heat is intercepted downstream of the ORC and
upstream of the fluid coolers and used in a coil to preheat inlet combustion air from each side of
the main turbine room.
(3) 800 kWe ORC (2) Existing Gas Turbine Inlet Air Dampers
(2) Existing Gas Turbine Exhaust Stacks
(1) Glycol Fluid Cooler
(1) ORC Exhaust Stack
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2.5 PROJECT BENEFIT
Briefly discuss the financial and public benefits that will result from this project, (such as reduced
fuel costs, lower energy costs, local jobs created, etc.)
With this project TDX will reduce the variable fuel and maintenance costs associated with electric
power production. Waste heat to power increases the available electric production capacity using
a heat source that has no commodity cost to TDX and is not subject to any volatility.
The project will demonstrate very high efficiency ORC power generation with superheat and
recuperation and the productive use of waste heat to improve emissions. The approach can be
replicated in many Alaskan locations that employ simple cycle gas turbines and/or reciprocating
engines.
With the additional electrical capacity provided, the project will reduce run-hours on peaking gas
turbines to prolong life and reduce maintenance costs. It will reduce local NOx and SOx emissions
from power production by warming turbine inlet air at low outside air conditions to keep emission
control (OxyCat) systems optimized. In addition overall plant emissions will be reduced by 27% or
12,087 metric tons per year reduction of GHG’s. The value of this annual GHG reduction is
$488,917 based up AEA’s Evaluation Tool Model mid-range benchmark price (2013) of $40.45/MT
GHG.
Variable cost savings are passed through to commercial and industrial customers who provide
jobs, housing, and other facilities to support oil-field workers who travel in and out of the area from
locations all over the State of Alaska. The block of electricity produced from ORC will cost less
than the remaining block of electricity from gas turbines. The net effect is an overall reduction in
cost of electricity of an estimated 5.4%
If demand for LNG from the North Slope increases in the future this project would generate
electricity from waste heat to flatten volatility and hedge the risks for electricity ratepayers.
Competitive and reliable electricity has an economic benefit for ratepayers in Prudhoe Bay that
provide jobs to Alaskan’s from other communities and natural resources revenue to the State.
2.6 PROJECT BUDGET OVERVIEW
Briefly discuss the amount of funds needed, the anticipated sources of funds, and the nature and
source of other contributions to the project.
The budget outlined in this grant application is the complete budget associated with the
development and turnkey installation of the proposed ORC system in an extension to the existing
gas turbine plant at the site that begins operation in 2017.
A heat and power purchase agreement (HPPA) will define the purchase price for heat and power
and is subject to approval by the Regulatory Commission of Alaska (RCA). This HPPA will provide
for outside capital investment in exchange for a contract for the sale of electricity.
Total capital cost for the building extension, ORC system, balance of plant, and controls is
presently estimated at $14,497,695. Funding for the project will come from Alaska Critical Energy
(ACE), TDX Power (TDX), and AEA grant in the amount of $4,000,000. ACE capital contribution to
the project will be made in the framework of a HPPA and the remainder will be provided by TDX.
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We understand that grant funding in each additional phase is contingent upon successfully
completing an earlier phase. A summary of the anticipated project costs and source of funds in
outlined below. Grantee funds apply to TDX. Other funds apply to the counterparty to a HPPA
with TDX.
Grant Funds Grantee Funds/Other Total Funds
Phase 1: Reconnaissance $125,000 $75,000 $200,000
Phase 2: Feasibility and Concept Design $187,500 $112,500 $300,000
Phase 3: Detail Design and Permitting $544,635 $319,865 $864,500
Phase 4: Construction $3,142,865 $9,989,392 $13,131,989
Total $4,000,000 $10,497,696 $14,497,695
2.7 COST AND BENEFIT SUMMARY
Include a summary of grant request and your project’s total costs and benefits below.
Costs for the Current Phase Covered by this Grant
(Summary of funds requested)
2.7.1 Grant Funds Requested in this application $ 4,000,000
2.7.2 Cash match to be provided $ 10,497,695
2.7.3 In-kind match to be provided $ 0
2.7.4 Other grant funds to be provided $ 0
2.7.5 Total Costs for Requested Phase of Project (sum of 2.7.1 through 2.7.4) $ 14,497,695
Other items for consideration
2.7.6 Other grant applications not yet approved $ 0
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Project Costs & Benefits
(Summary of total project costs including work to date and future cost estimates to get to a fully
operational project)
2.7.7 Total Project Cost
Summary from Cost Worksheet, Section 4.4.4, including
estimates through construction.
$13,717,479 present value at
3% cost of capital over the
duration of the construction
of the project
$ 14,497,695 total cost
2.7.8 Additional Performance Monitoring Equipment not
covered by the project but required for the Grant
Only applicable to construction phase projects
$ 0
No additional performance
monitoring equipment was
included. Regular operations
require utility grade
performance monitoring
equipment and
instrumentation
2.7.9 Estimated Direct Financial Benefit (Savings)
The economic model used by AEA is available at
www.akenergyauthority.org/REFund8.html. This
economic model may be used by applicants but is not
required. Other economic models developed by the
applicant may be used, however the final benefit/cost
ratio used will be derived from the AEA model to ensure
a level playing field for all applicants.
$17,556,738 present value at
3% cost of capital
$904,172 in first year of
operation based on 227,751
MMBtu of natural gas fuel
savings for gas turbine
electricity production at a
cost of $3.97/MMBtu. These
savings are assumed to
escalate at 3% per year for 20
years.
2.7.10 Other Public Benefit
If you can calculate the benefit in terms of dollars please
provide that number here and explain how you
calculated that number in Section 5 below.
$ 9,493,534 present value at
3% cost of capital
$488,917 in first year of
operation based on 12,087
metric tons of carbon dioxide
reduction per year.
SECTION 3 – PROJECT MANAGEMENT PLAN
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Describe who will be responsible for managing the project and provide a plan for successfully
completing the project within the scope, schedule and budget proposed in the application.
3.1 Project Manager
Tell us who will be managing the project for the Grantee and include contact information, a resume
and references for the manager(s). In the electronic submittal, please submit resumes as separate
PDFs if the applicant would like those excluded from the web posting of this application. If the
applicant does not have a project manager indicate how you intend to solicit project management
support. If the applicant expects project management assistance from AEA or another government
entity, state that in this section.
John Lyons, TDX General Manager, will act as Project Manager. His resume is attached.
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3.2 Project Schedule and Milestones
Please fill out the schedule below. Be sure to identify key tasks and decision points in in your
project along with estimated start and end dates for each of the milestones and tasks. Please
clearly identify the beginning and ending of all phases of your proposed project.
Please fill out form provided below. You may add additional rows as needed.
Milestones Start Date Calendar Days End Date
Reconnaissance 01-Jul-15 Phase 1 Total 31-Oct-15
Project scoping and contractor solicitation 01-Jul-15 30 31-Jul-15
Resource identification and analysis 15-Jul-15 15 30-Jul-15
Land use, permitting, and environmental analysis 01-Aug-15 45 15-Sep-15
Preliminary design and cost analysis 15-Aug-15 20 04-Sep-15
Cost of energy and market analysis 01-Sep-15 30 01-Oct-15
Simple economic analysis 01-Oct-15 15 16-Oct-15
Final report and recommendations 16-Oct-15 15 31-Oct-15
Feasibility Analysis and Concept Design 31-Oct-15 Phase 2 Total 26-Apr-16
Project scoping and contractor solicitation 31-Oct-15 30 30-Nov-15
Detailed resource assessment 31-Oct-15 30 30-Nov-15
Identification of land regulatory issues 15-Dec-15 30 14-Jan-16
Permitting and environmental analysis 15-Dec-15 90 14-Mar-16
Detailed analysis of current cost of energy and future market 15-Jan-16 20 04-Feb-16
Assessment of alternatives 15-Jan-16 20 04-Feb-16
Conceptual design and costs estimates 15-Feb-16 30 16-Mar-16
Detailed economic and financial analyses 15-Mar-16 20 04-Apr-16
Conceptual business & operations plan 15-Mar-16 30 14-Apr-16
Final report and recommendations 14-Apr-16 10 24-Apr-16
Final Design & Permitting 24-Apr-16 Phase 3 Total 20-Nov-16
Project scoping and contractor solicitation 24-Apr-16 45 08-Jun-16
Permit applications 23-Jul-16 120 20-Nov-16
Final environmental assessment and mitigation plans 23-Jul-16 120 20-Nov-16
Resolution of land use, right of way issues 24-Apr-16 90 23-Jul-16
Permitting, right-of-ways, site control 24-Apr-16 90 23-Jul-16
Final system design 24-Apr-16 90 23-Jul-16
Final cost estimate 23-Jul-16 30 22-Aug-16
Updated economic and financial analyses 22-Aug-16 30 21-Sep-16
Power or heat sale agreements in place 20-Nov-16 30 20-Dec-16
Final business and operational plan 23-Jul-16 120 20-Nov-16
Project Requirements – Construction 20-Nov-16 Phase 4 Total 05-Nov-17
Design & feasibility requirements 20-Nov-16 20 10-Dec-16
Bid documents 20-Nov-16 30 20-Dec-16
Vendor selection and award 20-Dec-16 15 04-Jan-17
Construction – unique to each project 04-Jan-17 245 06-Sep-17
Integration and testing 06-Sep-17 45 21-Oct-17
Final acceptance, commissioning and start-up 21-Oct-17 15 05-Nov-17
Operations 05-Nov-17
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3.3 Project Resources
Describe the personnel, contractors, personnel or firms, equipment, and services you will use to
accomplish the project. Include any partnerships or commitments with other entities you have or
anticipate will be needed to complete your project. Describe any existing contracts and the
selection process you may use for major equipment purchases or contracts. Include brief resumes
and references for known, key personnel, contractors, and suppliers as an attachment to your
application.
Alaska Critical Energy, LLC (ACE) – will be the counterparty with TDX in a planned heat and power
purchase agreement (HPPA) and will be a provider of support, major equipment, and off-site
system construction where applicable though all phases of the project. ACE is a joint venture of
University Mechanical, a large Seattle area mechanical contractor, and Supercritical Technologies
who together are developing waste heat to energy projects in Alaska.
TDX and ACE anticipate using much of the same team that successfully supported development
and construction of the gas turbine plant for the experience they have with this specific site and its
power generation systems. With our counterparty to the HPPA We have begun to communicate
with each of these potential contractors and suppliers about the project but firm commitments
would be premature until there is more detail about the project developed during Phase 1 and
Phase 2.
Peak Oilfield Service Co. – Technical support and construction associated with civil, pile, and
structural necessary to prepare the building extension for use as an ORC power generation plant.
Conam Construction Company – Technical support and construction associated with the balance
of plant systems necessary to put the equipment into operation.
SLR International Corporation – Environmental and air permitting for TDX North Slope Generating
Station.
Marsh Creek LLC – Owners engineering consulting support during project development,
construction, and commissioning
University Mechanical Contractors – Fabrication of the ORC system integrating the Barber Nichols
core turbo-machinery. Design and construction support.
Supercritical Technologies – ORC system design, integration, and commissioning support
3.4 Project Communications
Discuss how you plan to monitor the project and keep the Authority informed of the status. Please
provide an alternative contact person and their contact information.
John Lyons is listed as project manager in Section 1.1 of this grant. John will be the primary
contract with the Alaska Energy Authority (AEA) and he will coordinate with the ORC electricity
provider and contractors as necessary. Regular status updates on the project will be made in
writing on a quarterly basis and at the completion of each phase. Kord Christianson is listed as
alternate contact in Section 1.1.1 of this grant.
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With TDX support, Alaska Critical Energy LLC (ACE) will help plan and deliver presentations as
necessary on each phase of the grant as the project develops led by Eric Moe (206-890-3266,
emoe@umci.com) and Chal Davidson (518-225-3275, cdavidson@supercriticaltech.com) who
represent each joint venture partner in ACE.
3.5 Project Risk
Discuss potential problems and how you would address them.
Technology Risk: Organic rankine cycle (ORC) power generation is not broadly used in Alaska.
However ORC is a mature technology. Our HPPA counterparty and their technical advisors,
including Barber Nichols, have experience with the technology and its application.
(http://www.barber-nichols.com/industries/energy).
Construction Risk: Extreme weather and temperatures on the North Slope of Alaska pose a
challenge to successful project implementation and operation. The risk is mitigated by TDX’s
extensive experience in the establishment and management of remote power projects in Alaska.
Performance Risk: The key performance risk is that the ORC system underperforms and produces
less power than anticipated. The HPPA will guide the performance requirements and set the
financial incentives necessary to ensure successful energy production, minimum output, and
uptime. Systems will be in place to maintain minimum temperatures and additional procedures in
place to manage cold temperature shut down and startup. Systems will be maintained by 24/7/365
operating staff and remotely monitored by the manufacturer.
Regulatory Risk: The ORC system in this application will extract waste heat from the gas turbine
stacks for heat recovery and exhaust the flue gas from a separate stack. Air permit will be required
that addresses lower temperature output but expect the regulatory authorities to look favorably
upon the project as a means to produce additional power from waste heat. Regulatory approval is
required for the HPPA.
Revenue Risk: Loss of customers could lead to a loss of electrical demand necessary to produce
the waste heat necessary for the full production capacity of the ORC system. The ORC will be built
with three 800 kWe units should the load decline which will enable greater rangeability.
3.6 Project Accountant(s)
Tell us who will be performing the accounting of this Project for the Grantee and include contact
information, a resume and references for the project accountant(s). In the electronic submittal,
please submit resumes as separate PDFs if the applicant would like those excluded from the web
posting of this application. If the applicant does not have a project accountant indicate how you
intend to solicit project management support.
Laura Bain, Controller - See attached resume
Kristin, Canaday, Accountant – See attached resume
3.7 Financial Accounting System
Discuss the accounting system that will be used to account for project costs and whom will be the
primary user of the accounting system.
The Accounting System: Viewpoint software which specializes in project cost accounting.
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Primary Users: Laura Bain & Kristin Canaday
3.8 Financial Management Controls
Discuss the controls that will be utilized to ensure that only costs that are reasonable, ordinary and
necessary will be allocated to this project. Also discuss the controls in place that will ensure that
no expenses for overhead, or any other unallowable costs will be requested for reimbursement
from the Renewable Energy Fund Grant Program.
TDX Power Finance performs GAAP accounting. All staff is very experienced in financial controls.
TDX Power has had a number of other successful grants. Because of experience with government
contracts TDX Power accounting staff has knowledge of FARS. This includes having an
understanding of what are allowable and unallowable costs. Staff will become very familiar with
and committed to the grant terms in order to adhere to the proper controls.
SECTION 4 – PROJECT DESCRIPTION AND TASKS
The level of information will vary according to phase(s) of the project you propose to undertake
with grant funds.
If some work has already been completed on your project and you are requesting funding for an
advanced phase, submit information sufficient to demonstrate that the preceding phases are
satisfied and funding for an advanced phase is warranted.
4.1 Proposed Energy Resource
Describe the potential extent/amount of the energy resource that is available.
Discuss the pros and cons of your proposed energy resource vs. other alternatives that may be
available for the market to be served by your project. For pre-construction applications, describe
the resource to the extent known. For design and permitting or construction projects, please
provide feasibility documents, design documents, and permitting documents (if applicable) as
attachments to this application.
Each existing Taurus 70 combustion gas turbine at ISO conditions produces 7,965 kWe at a heat
rate of 10,505 btu/kWh. Exhaust temperature is 945°F at an exhaust flow of 213,350 lb/hr. The
OxyCat system works in a temperature range of 600-1200°F.
Inefficiency produces heat that is rejected to atmosphere at a rate of 23,426 kWth assuming the
power production at conditions noted above. Of that heat we assume that approximately 60%
(14,056 kWth) can be readily harvested and used to produce power in a bottoming cycle with ORC
technology. The three ORC units proposed require 10,500 kWth to produce 2,100 kWe net
electricity so there is about 33% excess heat in one of the two gas turbines operating at 100% to
produce the heat required for ORC power generation. Or in other words, as long as one turbine is
operating at 75% capacity (5,974 kWe) we will be able to produce full capacity from the ORC
system.
In the TDX network, baseload electrical demand is as low as 5.0 MWe but is expected to grow 2.0
MWe with the aggregation of new customers. Once in operation we would expect to satisfy
summer baseload conditions with one turbine operating at 4.9 MWe with the ORC generating 2.1
MWe for a total of 7.0 MWe. Off peak each turbine has even higher heat rate but the waste heat
production still allows for power generation. This allows us to reduce run-time on the peaking gas
turbine and to satisfy minimum load conditions and perform maintenance.
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Steam turbine generators (STG) are an alternative to ORC for power production in the bottoming
cycle of a gas turbine plant. ORC systems operate more efficiently that STG at lower pressure
using a refrigerant as the working fluid. This avoids high operating and maintenance costs
associated with higher pressures and water chemistry.
Supercritical CO2 (SCO2) power generation systems are in development in the industry for power
generation and may replace larger ORC systems and prime movers in the future that are greater
than 3 MWe but more likely 5 MWe. Significant technical challenges remain in the industry that will
make it difficult to control SCO2 systems well in smaller applications such as this so confidence lies
in ORC at the scale proposed.
4.2 Existing Energy System
4.2.1 Basic configuration of Existing Energy System
Briefly discuss the basic configuration of the existing energy system. Include information about the
number, size, age, efficiency, and type of generation.
The existing gas turbine plant (which will be put into operation in 2014) features two Solar Taurus
70 gas turbines with the characteristics noted below. Natural gas is the fuel source. To meet NOx
requirements set by the EPA and the air permit the inlet air temperature cannot drop below -20°F.
Recovered waste heat will be utilized to temper cold incoming combustion air below -20°F to above
-10°F so that the OxyCat emission control system operates efficiently and the turbine operates with
the lowest possible heat rate.
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.
The existing facility is fueled by natural gas obtained from Norgasco at a current price of about
$3.97 per MMBtu. Since the project uses waste heat as the energy source it will reduce the
natural gas demand. The addition of 2.1 MWe from the ORC project will enable additional
customer growth without an investment in another prime mover. Furthermore it will enable a single
turbine to run longer before a peaking turbine is required to satisfy electrical load conditions.
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0
1000
2000
3000
4000
5000
6000
7000
8000
9000
Total Power Generation (kWe)Hours at or Above a Given Load -Summer, 2014
TDX Power Generation -North Slope
Power generation required at ISO conditions
to produce enough waste heat to fully load
ORC power generation to 2.1 MWe during
summer baseload conditions.
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4.2.3 Existing Energy Market
Discuss existing energy use and its market. Discuss impacts your project may have on energy
customers.
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TDX North Slope Generation generated 66,769,397 kWh in electricity for 79 customers during the
fiscal year ended 9/30/2013, an increase of 8.9% over the prior period. The three years ended
9/30/2013 averaged 10.2% increase in electricity demand. To meet growing demand TDX is in the
process of installing two additional Solar Taurus 70 gas turbines, rated at 7,965 kWe each.
The installation of an ORC based waste heat recovery system will increase the station’s output
capacity and reduce emissions.. In addition the ORC project will flatten the impact of any fuel price
volatility for customers in the rate base and help minimize regulatory risk that could impede normal
operations. Lastly the ORC project will help prolong longer operation into the season with operation
of a single turbine which helps reduce maintenance cost and operating flexibility.
4.3 Proposed System
Describe the system you are intending to develop and address potential system design, land
ownership, permits, and environmental issues.
4.3.1 System Design
Provide the following information for the proposed renewable energy system:
• A description of renewable energy technology specific to project location
• Optimum installed capacity
• Anticipated capacity factor
• Anticipated annual generation
• Anticipated barriers
• Basic integration concept
• Delivery methods
The renewable energy technology proposed is Organic Rankine Cycle (ORC) power generation
using waste heat as the primary source. The optimum installed capacity in this application is 2,400
kWe gross, 2,100 kWe net. This is a system with three units designed to produce heat year round
from baseload gas turbine power production for the local community. The system is sized to create
full power with as little as one gas turbine operating at 75%. The system is expected to produce a
minimum of 18,042 MWh electricity per year with a capacity factor of 98%. A picture of one ORC
unit is provided below.
The ORC cycle was first documented by Scottish engineer William Rankine in the 1850’s and has
been deployed worldwide. The ORC's principle is based on a turbo-generator working to transform
thermal energy into electric energy. An ORC power system uses the same concepts as a steam
engine to make electrical power, but the working fluid is typically a hydrocarbon (“organic fluid”)
rather than steam. In the simplified diagram below, flue gas from the adjacent TDX gas turbine
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plant is the heat source. Low grade heat is rejected to atmosphere at higher ambient air
temperatures and to the gas turbine inlet air at lower temperatures to improve the emissions
profile. In the process of our intended HPPA partner, superheat and recuperation are added to
increase output and electrical efficiency.
Anticipated barriers are not likely to be technical but extra care is required in evaluating the
construction and operation in the extreme environment on the North Slope. TDX is confident that
the footprint is available on the site to support a building extension for the ORC plant. In addition,
the magnitude of waste heat available year-round is sufficient to support system operation as
intended. Initial economic estimates suggest an attractive project meeting requirements of both
parties to an HPPA while providing economic benefit to ratepayers. Regulatory approval will be
required for the operation as well as for the HPPA.
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The diagram below reflects the site of the ORC power generation system adjacent to the existing
(new) gas turbine power plant. The building extension remains on the existing gravel pad. Power
will flow to TDX’s electrical grid and low grade heat to turbine inlet air when appropriate to improve
combustion and the emissions profile.
The ORC system will be fully integrated with existing power production and monitored both on site
and remotely. Delivery of major equipment to the site will be by barge from Seattle to Prudhoe or
Anchorage then by truck to Deadhorse. Funds for the project will come from TDX, its HPPA
counterparty (ACE) and the AEA through a Round 8 grant.
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 land ownership issues. TDX has a 25+ year utility property lease and is sure that the
system can be fully installed with an extension to the existing building that remains on the gravel
pad. Access to the site is well understood from the recent efforts to complete the gas turbine plant.
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4.3.3 Permits
Provide the following information as it may relate to permitting and how you intend to address
outstanding permit issues.
• List of applicable permits
• Anticipated permitting timeline
• Identify and discuss potential barriers
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
The proposed project is an extension to an existing facility, and therefore should pose minimal risk
in altering any of the above environmental constraints. Flue gas temperatures from the ORC
system will remain in the range of 200-300°F to avoid the risk of condensation in the Arctic
environment that would otherwise create significant issues..
4.4 Proposed New System Costs and Projected Revenues
(Total Estimated Costs and Projected Revenues)
The level of cost information provided will vary according to the phase of funding requested and
any previous work the applicant may have done on the project. Applicants must reference the
source of their cost data. For example: Applicants records or analysis, industry standards,
consultant or manufacturer’s estimates.
4.4.1 Project Development Cost
Provide detailed project cost information based on your current knowledge and understanding of
the project. Cost information should include the following:
• Total anticipated project cost, and cost for this phase
• Requested grant funding
• Applicant matching funds – loans, capital contributions, in-kind
• Identification of other funding sources
• Projected capital cost of proposed renewable energy system
• Projected development cost of proposed renewable energy system
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The proposed project will cost an estimated $14,497,695 with the cost of the first three phases
through design and permitting $1,464,500. The total figure will be solidified through the first three
phases of the project and negotiations with contractors. TDX will enter into a heat and power
purchase agreement (HPPA) with Alaska Critical Energy LLC (ACE) who will make capital
investments in the ORC system of approximately $9,649,350 and operate it through an O&M
contract with TDX for the duration of the project. TDX will invest in site preparation needed to
house, connect, integrate, and monitor the equipment. For the total project TDX requests
$4,000,000 in grant funding and will provide the necessary additional cash to complete the project
over and above that delivered through the HPPA.
4.4.2 Project Operating and Maintenance Costs
Include anticipated O&M costs for new facilities constructed and how these would be funded by the
applicant.
(Note: Operational costs are not eligible for grant funds however grantees are required to meet
ongoing reporting requirements for the purpose of reporting impacts of projects on the communities
they serve.)
Annual operating and maintenance costs will be addressed in an O&M contract between ACE and
TDX. We expect the thermal energy used to improve emissions and the cost of electrical capacity
in the HPPA to be offset the maintenance revenue that we earn under the HPPA under contract.
Heat will be recovered in the ORC plant and provided to the gas turbine building to displace gas
consumption.
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
TDX provides power to 79 customers (as of 9/30/13) on the North Slope. Electricity generated by
the project would be purchased by TDX from ACE at a price agreed in a HPPA during the final
design and permitting phase of the project as indicated in the schedule herein. Initial analysis
suggests a likely power purchase rate of between $0.1050 and $0.1250/kWh when operation starts
in 2017.
With the addition of TDX fixed costs and capital recovery this block of power will be sold at a rate
less than the current price that the ratepayers pay providing an overall discount in the cost of
power of approximately 4.8-5.4%.
As a regulated electric utility the proposed rate of return would not exceed that allowed by the
Regulatory Commission of Alaska, approximately 10.9% return on equity.
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4.4.4 Project Cost Worksheet
Complete the cost worksheet form which provides summary information that will be considered in
evaluating the project.
Please fill out the form provided below.
Renewable Energy Source
The Applicant should demonstrate that the renewable energy resource is available on a
sustainable basis.
Baseload operation of a single gas turbine at 75% or higher has enough waste heat to generate
2.1 MWe power from flue gas using ORC. Operational data and load growth, and parasitic load
within the gas turbine plant produces enough power and waste heat to fully load the ORC system.
The resource is available year round as the powerplant operates in continuous service to
customers unless there is an unscheduled interruption.
Existing Energy Generation and Usage
a) Basic configuration (if system is part of the Railbelt 1 grid, leave this section blank)
i. Number of generators/boilers/other Two
ii. Rated capacity of generators/boilers/other 7,965 kWe at ISO conditions
iii. Generator/boilers/other type Taurus 70 combustion gas turbine
iv. Age of generators/boilers/other 2014
v. Efficiency of generators/boilers/other 9,955 btu/kWh electric at ISO conditions
b) Annual O&M cost (if system is part of the Railbelt grid, leave this section blank)
i. Annual O&M cost for labor $1,900,403 (FY 2013)
ii. Annual O&M cost for non-labor $ 6,555,416 (FY 2013)
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] 66,769,397 (FY 2013)
ii. Fuel usage
Diesel [gal]
Other 3,539,898 therms natural gas
iii. Peak Load 12.6 MWe (get more info from TDX)
iv. Average Load 7.9 MWe (YTD 2014)
v. Minimum Load 5.0 MWe (based on July, 2014)
vi. Efficiency 34.3% (consistent with heat rate above)
vii. Future trends Increase in demand due to aggregation of self-generation loads, additional
man-camp construction underway, and increased oil field support and O&M
services as the oil fields age.
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.
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d) Annual heating fuel usage (fill in as applicable)
i. Diesel [gal or MMBtu] 0
ii. Electricity [kWh] 0
iii. Propane [gal or MMBtu] 0
iv. Coal [tons or MMBtu] 0
v. Wood [cords, green tons, dry tons] 0
vi. Other 1,722 MMBtu natural gas for turbine inlet air and 17,632
MMBtu for natural gas for heating the gas turbine building
Proposed System Design Capacity and Fuel Usage
(Include any projections for continued use of non-renewable fuels)
a) Proposed renewable capacity
(Wind, Hydro, Biomass, other)
[kW or MMBtu/hr]
2,100 kW electricity, 4.1 MMBtu/h (1,202 kW thermal)
Gas Turbine Flue Gas Waste Heat to Energy
b) Proposed annual electricity or heat production (fill in as applicable)
i. Electricity [kWh] 18,012,750 kWh
ii. Heat [MMBtu] 1,732 MMBtu for turbine inlet air heated to -10°F and
17,632 MMBtu for gas turbine building heating vs. gas
c) Proposed annual fuel usage (fill in as applicable)
i. Propane [gal or MMBtu] 0
ii. Coal [tons or MMBtu] 0
iii. Wood or pellets [cords, green tons,
dry tons]
0
iv. Other 292,676 MMBtu waste heat, 21.0% electrical efficiency
Project Cost
a) Total capital cost of new system $14,497,695 (assumed to include development cost)
b) Development cost $1,364,500 (assumed to be phases 1-3)
c) Annual O&M cost of new system $197,338
d) Annual fuel cost $0 (waste heat)
Project Benefits
a) Amount of fuel displaced for
i. Electricity 2,083,350 therms natural gas per year
ii. Heat 1,934,000 therms natural gas per year
iii. Transportation 0
b) Current price of displaced fuel $0.397/therm natural gas assumed in 2017
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c) Other economic benefits $448,917/year GHG reduction at $.4045/kWh
d) Alaska public benefits Emission reductions, industry competitiveness,
model for other turbine or internal combustion
applications throughout Alaska
Power Purchase/Sales Price
a) Price for power purchase/sale Power prices in a HPPA between TDX and ACE will be
determined in the Final Design and Permitting Phase
of the project. At this stage, purchase price is
estimated to be between $0.1050 and $0.1250/kWh,
and the sale price approximately 4.8 to 5.4% less than
what the utility rate base is paying for power now.
Project Analysis
a) Basic Economic Analysis
Project benefit/cost ratio 1.97 based on PV savings / PV capital cost
Payback (years) 10.41 years without grant funding, 7.54 years with grant funding
4.4.5 Impact on Rates
Briefly explain what if any effect your project will have on electrical rates in the proposed benefit
area. If the is for a PCE eligible utility please discuss what the expected impact would be for both
pre and post PCE.
The project would serve to reduce project fuel consumption, and therefore the cost of generation.
Wherein the cost of power to Deadhorse (including COPA) has averaged $0.2082/kWh during
fiscal-year-to-date 2014, the implementation of a waste heat recovery project at the site would
reduce relative fuel consumption and thus reduce the need for customers to pay COPA charges,
which sometimes account for 40% or more of the cost of electricity.
Furthermore, the project would create certainty in the future cost of the block of power produced
with this asset and flatten the risk of volatility in fuel prices to the ratepayer who bears that risk.
Net impact on electricity rates is expected to be in the 4.8-5.4% range and will be determined
during the negotiations of the HPPA in the final design and permitting phase of the project.
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SECTION 5– PROJECT BENEFIT
Explain the economic and public benefits of your project. Include direct cost savings, and
how the people of Alaska will benefit from the project.
The benefits information should include the following:
• Potential annual fuel displacement (gallons and dollars) over the lifetime of the evaluated
renewable energy project
• Anticipated annual revenue (based on i.e. a Proposed Power Purchase Agreement price, RCA
tariff, or cost based rate)
• Potential additional annual incentives (i.e. tax credits)
• Potential additional annual revenue streams (i.e. green tag sales or other renewable energy
subsidies or programs that might be available)
• Discuss the non-economic public benefits to Alaskans over the lifetime of the project
Potential annual fuel displacement is 227,751 MMBtu which equates to 1,632,624 gallons diesel
equivalent. Based on a natural gas price of $3.97 per MMBtu escalated by 3% over the life of the
project we estimate $17,556,738 in natural gas fuel savings over the minimum 20 year life of the
project which represents a decrease in rates of approximately 5.4%.
Subject to further analysis and regulatory approval, annual revenue for the block of power sold into
the electrical network would be $2,462,764 per year with a $0.1365/kWh assumption escalating at
3% per year.
Tax credits are not assessed for the production of renewable power from waste heat. TDX will
receive and additional revenue stream from the operation and maintenance of the ORC system but
it is expected to be fully offset by an electrical capacity and heat charge.
Alaskans will benefit from the project from reduced local emissions as well as 12,087 metric tons
carbon emission reductions per year at a value of $488,917. Lower rates and emission create
competitiveness in the oil and gas industry on the North Slope.
Demonstration of a remarkable project may be replicated in other parts of the state and highlight
the resource opportunity and economic value of waste heat for energy generation.
5.1 Public Benefit for Projects with Private Sector Sales
Projects that include sales of power to private sector businesses (sawmills, cruise ships, mines,
etc.), please provide a brief description of the direct and indirect public benefits derived from the
project as well as the private sector benefits and complete the table below. See section 1.6 in the
Request for Applications for more information.
Renewable energy resource availability (kWh per month) 1,533,000 kWh/month at a capacity
factor over 95%, available anytime
the primary turbines are running,
unlike many other intermittent
renewables like wind and solar
Estimated sales (kWh) 360,255,000 kWh (over 20 years)
Revenue for displacing diesel generation for use at
private sector businesses ($)
$66,175,404 (natural gas over 20
years with 3% annual escalation)
Estimated sales (kWh)
Revenue for displacing diesel generation for use by the
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Alaskan public ($)
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SECTION 6– SUSTAINABILITY
Discuss your plan for operating the completed project so that it will be sustainable.
Include at a minimum:
• Proposed business structure(s) and concepts that may be considered.
• How you propose to finance the maintenance and operations for the life of the project
• Identification of operational issues that could arise.
• A description of operational costs including on-going support for any back-up or existing
systems that may be require to continue operation
• Commitment to reporting the savings and benefits
The proposed business structure is a 20-year heat and power purchase agreement (HPPA)
between TDX Power (TDX) and Alaska Critical Energy LLC (ACE). The HPPA will have financial
metric incentives (capacity, reliability, and net output performance) to insure ORC system
performance.
ACE will finance its portion of the project with equity and a loan against future cash flows defined
by the HPPA. Operations and maintenance will be managed under contract between ACE and
TDX, designed to offset electric capacity and other energy charges. Major overhaul and repair of
ORC systems will be the responsibility of ACE.
For TDX, the proposed project will be an addition to the existing operation that has a demonstrated
reliability of 98%. TDX purchase this utility in 2003, doubled generation capacity in 2007, and will
double generation capacity again by December 2014 to continue reliable utility operations. The
ORC project will improve cash flows and the company’s ability to continue the meet the growing
demand for energy on the North Slope.
Operational issues that could arise include system failures and weather presenting challenges in
servicing equipment with off-site personnel should there be an unscheduled interruption. In
addition over the life of the project there could be a reduction in electrical demand on the grid due
to reductions of oil field support services centered in Deadhorse that reduces the amount of
available waste heat for power generation.
TDX and ACE are committed to reporting the savings and benefits to AEA annually.
SECTION 7 – READINESS & COMPLIANCE WITH OTHER GRANTS
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Discuss what you have done to prepare for this award and how quickly you intend to proceed with
work once your grant is approved.
Tell us what you may have already accomplished on the project to date and identify other grants
that may have been previously awarded for this project and the degree you have been able to
meet the requirements of previous grants.
TDX North Slope has successfully operated the North Slope generating facility since 2003. The
facility is growing and currently in the process of completing a project to install 15 MWe new
production capacity.
We are prepared to proceed quickly if the grant is approved. There has been an initial technical
and economic analysis performed and a preliminary assessment of the physical layout of major
equipment at the site. There has been extensive communication between TDX, ACE (the HPPA
counterparty), and various contractors that would be required to support development of the
project.
SECTION 8 – LOCAL SUPPORT AND OPPOSITION
Discuss local support and opposition, known or anticipated, for the project. Include letters of
support or other documentation of local support from the community that would benefit from this
project. The Documentation of support must be dated within one year of the RFA date of July 2,
2014
We do not know of any local support or opposition to the intended project. We anticipate that the
effort will be viewed favorably by both regulatory authorities and ratepayers.
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SECTION 9 – GRANT BUDGET
Tell us how much you are seeking in grant funds. Include any investments to date and funding
sources, how much is being requested in grant funds, and additional investments you will make as
an applicant.
9.1 Funding sources and Financial Commitment
Provide a narrative summary regarding funding source and your financial commitment to the
project
TDX is seeking $4,000,000 total in grant funds. We understand that grant funding in each
additional phase is contingent upon successfully completing an earlier phase. A summary of the
anticipated project costs and source of funds in outlined below. Grantee funds apply to TDX.
HPPA funds apply to the counterparty to TDX in a heat and power purchase agreement which is
intended to be Alaska Critical Energy LLC (ACE).
Grant Funds Grantee Funds/HPPA Total Funds
Phase 1: Reconnaissance $125,000 $75,000 $200,000
Phase 2: Feasibility and Concept Design $187,500 $112,500 $300,000
Phase 3: Detail Design and Permitting $544,635 $319,865 $864,500
Phase 4: Construction $3,142,865 $9,989,392 $13,131,989
Total $4,000,000 $10,497,696 $14,497,695
TDX North Slope Generating has demonstrated its ability to expand and finance required power
generation and distribution upgrades and expansion since acquiring the utility in 2003 To the
extent that additional cash is needed to build out, or to operate the proposed project on a short-
term basis, TDX has proven itself a creditworthy borrower with access to debt capital.
9.2 Cost Estimate for Metering Equipment
Please provide a short narrative, and cost estimate, identifying the metering equipment, and its
related use to comply with the operations reporting requirement identified in Section 3.15 of the
Request for Applications.
Instrumentation and metering equipment for an electric utility plant is part of the normal course of
business in running a regulated electric utility and will be included in the project and integrated with
the existing control and metering systems. TDX will comply with the operations reporting
requirement.
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Applications MUST include a separate worksheet for each project phase that was identified in
section 2.3.2 of this application, (I. Reconnaissance, II. Feasibility and Conceptual Design, III. Final
Design and Permitting, and IV. Construction and Commissioning). Please use the tables provided
below to detail your proposed project’s budget. Be sure to use one table for each phase of your
project.
If you have any question regarding how to prepare these tables or if you need assistance preparing
the application please feel free to contact AEA at 907-771-3031 or by emailing the Grants
Administrator, Shawn Calfa, at scalfa@aidea.org.
Milestone or Task
Anticipated
Completion
Date
RE- Fund
Grant
Funds
Grantee
Matching
Funds
Source of
Matching
Funds:
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
TOTALS
Part 1 - Reconnaissance
Project scoping and contractor
solicitation 31-Jul-15 $31,250 $18,750 Cash $50,000
Resource identification 30-Jul-15 $31,250 $18,750 Cash $50,000
Land use, permitting, and
environmental 15-Sep-15 $12,500 $7,500 Cash $20,000
Preliminary design and cost
analysis 04-Sep-15 $18,750 $11,250 Cash $30,000
Cost of energy and market
analysis 01-Oct-15 $12,500 $7,500 Cash $20,000
Simple economic analysis 16-Oct-15 $12,500 $7,500 Cash $20,000
Final report and
recommendations 31-Oct-15 $6,250 $3,750 Cash $10,000
TOTALS $125,000 $75,000 Cash $200,000
Budget Categories:
Direct Labor & Benefits $75,000 $75,000 Cash $150,000
Travel & Per Diem $20,000 $0 Cash $20,000
Equipment $0 $0 Cash $0
Materials & Supplies $10,000 $0 Cash $10,000
Contractual Services $10,000 $0 Cash $10,000
Construction Services $0 $0 Cash $0
Other $10,000 $0 Cash $10,000
TOTALS $125,000 $75,000 Cash $200,000
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Milestone or Task
Anticipated
Completion
Date
RE- Fund
Grant
Funds
Grantee
Matching
Funds
Source of
Matching
Funds:
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
TOTALS
Part II - Feasibility Analysis
Project scoping and contractor
solicitation 30-Nov-15 $18,750 $11,250 Cash $30,000
Detailed resource assessment 30-Nov-15 $9,375 $5,625 Cash $15,000
Identification of land regulatory
issues 14-Jan-16 $18,750 $11,250 Cash $30,000
Permitting and environmental
analysis 14-Mar-16 $46,875 $28,125 Cash $75,000
Detailed analysis of current cost of
energy and future market 04-Feb-16 $18,750 $11,250 Cash $30,000
Assessment of alternatives 04-Feb-16 $9,375 $5,625 Cash $15,000
Conceptual design and costs
estimates 16-Mar-16 $18,750 $11,250 Cash $30,000
Detailed economic and financial
analyses 04-Apr-16 $18,750 $11,250 Cash $30,000
Conceptual business & operations
plan 14-Apr-16 $18,750 $11,250 Cash $30,000
Final report and recommendations 24-Apr-16 $9,375 $5,625 Cash $15,000
TOTALS $187,500 $112,500 Cash $300,000
Budget Categories:
Direct Labor & Benefits $112,500 $112,500 Cash $225,000
Travel & Per Diem $15,000 $0 Cash $15,000
Equipment $0 $0 Cash $0
Materials & Supplies $15,000 $0 Cash $15,000
Contractual Services $30,000 $0 Cash $30,000
Construction Services $0 $0 Cash $0
Other $15,000 $0 Cash $15,000
TOTALS $187,500 $112,500 Cash $300,000
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Milestone or Task
Anticipated
Completion
Date
RE- Fund
Grant
Funds
Grantee
Matching
Funds
Source of
Matching
Funds:
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
TOTALS
Phase III - Final Design & Permitting
Project scoping and contractor
solicitation 08-Jun-16 $27,232 $15,993 Cash $43,225
Permit applications 20-Nov-16 $81,695 $47,980 Cash $129,675
Final environmental assessment and
mitigation plans 20-Nov-16 $81,695 $47,980 Cash $129,675
Resolution of land use, right of way
issues 23-Jul-16 $13,616 $7,997 Cash $21,613
Permitting, right-of-ways, site
control 23-Jul-16 $13,616 $7,997 Cash $21,613
Final system design 23-Jul-16 $245,086 $143,939 Cash $389,025
Final cost estimate 22-Aug-16 $27,232 $15,993 Cash $43,225
Updated economic and financial
analyses 21-Sep-16 $13,616 $7,997 Cash $21,613
Power or heat sale agreements in
place 20-Dec-16 $13,616 $7,997 Cash $21,613
Final business and operational plan 20-Nov-16 $27,232 $15,993 Cash $43,225
TOTALS $544,635 $319,865 Cash $864,500
Budget Categories:
Direct Labor & Benefits $172,900 $172,900 Cash $345,800
Travel & Per Diem $21,613 $0 Cash $21,613
Equipment $0 $0 Cash $0
Materials & Supplies $21,613 $0 Cash $21,613
Contractual Services $285,285 $146,965 Cash $432,250
Construction Services $0 $0 Cash $0
Other $43,225 $0 Cash $43,225
TOTALS $544,635 $319,865 Cash $864,500
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Milestone or Task
Anticipate
d
Completio
n Date
RE- Fund
Grant
Funds
Grantee
Matching
Funds
Source of
Matching
Funds:
Cash/In-
kind/Federal
Grants/Other
State
Grants/Other
TOTALS
Phase IV – Construction
Design & feasibility
requirements 10-Dec-16 $62,857 $219,807 Cash/HPPA $282,664
Bid documents 20-Dec-16 $62,857 $219,807 Cash/HPPA $282,664
Vendor selection and award 04-Jan-17 $62,857 $219,807 Cash/HPPA $282,664
Construction – unique to each
project 06-Sep-17 $2,844,293 $8,946,249 Cash/HPPA $11,790,541
Integration and testing 21-Oct-17 $31,429 $109,903 Cash/HPPA $141,332
Final acceptance,
commissioning and start-up 05-Nov-17 $31,429 $109,903 Cash/HPPA $141,332
Operations 00-Jan-00 $47,143 $164,855 Cash/HPPA $211,998
TOTALS $3,142,865 $9,990,330 Cash/HPPA $13,133,195
Budget Categories:
Direct Labor & Benefits $628,573 $1,698,066 Cash/HPPA $2,326,639
Travel & Per Diem $31,697 $110,842 Cash/HPPA $142,538
Equipment $1,602,593 $5,104,131 Cash/HPPA $6,706,724
Materials & Supplies $314,286 $1,099,033 Cash/HPPA $1,413,319
Contractual Services $157,143 $549,516 Cash/HPPA $706,660
Construction Services $408,572 $1,428,743 Cash/HPPA $1,837,315
Other $0 $0 Cash/HPPA $0
TOTALS $3,142,865 $9,990,331 Cash/HPPA $13,133,195
Note: Cash/HPPA means that the capital expenses are incurred by both TDX and the counterparty
to the Heat and Power Purchase Agreement (HPPA) which is Alaska Critical Energy LLC (ACE).
Renewable Energy Fund Round VIII
Grant Application - Standard Form
AEA 15003 Page 34 of 35 7/2/14
SECTION 10 – AUTHORIZED SIGNERS FORM
Community/Grantee Name:
TDX Power, North Slope Generating
Regular Election is held:
Date:
Authorized Grant Signer(s):
Printed Name Title Term Signature
See TDX Power Board of
Directors Resolution
Dated Nov 2013 attached
I authorize the above person(s) to sign Grant Documents:
(Highest ranking organization/community/municipal official)
Printed Name Title Term Signature
Grantee Contact Information:
Mailing Address:
615 E 82nd Ave, Suite 200
Anchorage AK 99518
Phone Number:
907-762-8478
Fax Number:
E-mail Address:
kord@tdxpower.com
Federal Tax ID #:27-0004843
Please submit an updated form whenever there is a change to the above information.