Roadshow Presentation April 2010 Tonbridge Power Inc. The - - PowerPoint PPT Presentation

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Roadshow Presentation April 2010 Tonbridge Power Inc. The - - PowerPoint PPT Presentation

Roadshow Presentation April 2010 Tonbridge Power Inc. The Waterpark Place 20 Bay Street, 11 th Floor Toronto, ON t: 416.850.2150 f: 416.850.1985 www.tonbridgepower.com 1 Disclaimer This presentation and the preliminary prospectus, including


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1 Tonbridge Power Inc. The Waterpark Place 20 Bay Street, 11th Floor Toronto, ON t: 416.850.2150 f: 416.850.1985 www.tonbridgepower.com

Roadshow Presentation

April 2010

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Disclaimer

This presentation and the preliminary prospectus, including the documents incorporated therein by reference (the “Prospectus”) filed by Tonbridge Power Inc. (the “Corporation”) dated December 11, 2009, contain forward-looking information under Canadian securities legislation. Forward-looking information includes, but is not limited to, information with respect to the completion of the development and construction by the Corporation of the Tonbridge Power Line and the timetable, costs and financing of the Tonbridge Power Line, demand for transmission capacity, supply of transmission capacity, the benefits of the Tonbridge Power Line and any future projects, including Project 2 (as defined in this presentation), currency fluctuations, requirements for additional capital, and government regulation of transmission operations, including the auctioning of capacity and the permitting required for the Tonbridge Power Line and future projects, including Project 2. Generally, forward-looking information can be identified by the use of forward-looking terminology such as “plans”, “expects” or “does not expect”, “is expected”, “budget”, “scheduled”, “estimates”, “forecasts”, “intends”, “anticipates” or “does not anticipate”, or “believes”, or variations of such words and phrases or statements that certain actions, events or results “may”, “could”, “would”, “might” or “will be taken”, “occur” or “be achieved”. Forward-looking information is based on the

  • pinions and estimates of management as of the date such statements are made and is based on a number of assumptions and subject to a variety of risks and

uncertainties and other factors that could case actual events to differ materially from those projected in the forward-looking information. Many of these assumptions are based on factors and events that are not within the control of the Corporation and there is no assurance that they will prove to be correct. Estimates with respect to the timetable for and completion of the Tonbridge Power Line and any future projects, including Project 2, required government and regulatory approvals for the Tonbridge Power Line and any future projects, including Project 2, the ability to generate revenue, the thermal capacity of the Tonbridge Power Line, the ability to exploit certain operating margins, the reorganization of the electricity industry, future interest rates, capital resources available, the availability of credit-worthy electrical shippers, the use of certain technologies and materials and annual impairment tests, are based on such things as research by the Corporation of capital and

  • perating costs, contracts signed by the Corporation to date, recent estimates of construction and costs, construction estimates and schedules which have been

developed by the Corporation’s personnel and independent consultants and reports from counterparties and electrical shippers. Important factors that could cause actual results to differ materially from the Company's expectations are disclosed under the headings “Risk Factors”in the Company’s Prospectus, the Annual Information Form dated April 27, 2009 and the MD&A, all of which are available under the profile of the Company on SEDAR, and elsewhere in documents filed fromtime to time with the Canadian provincial securities regulators. Forward-looking information is subject to known and unknown risks, uncertainties and other factors that may cause the actual results, level of activity, performance or achievements of the Corporation to be materially different from those expressed or implied by such forward-looking information, including but not limited to risks related to judicial proceedings, land assembly, technology and materials, wind firming, capital resources, revenue, operating margins, litigation risk, restructuring of electrical industry, competition, annual impairment tests, labour relations, insurance, damage from weather and other disasters, operating and maintenance risks, environmental risks, hazards of high-voltage electricity transmission, counterparty and credit risk, financing arrangements, and other risks relating to the Offering. Although management of the Corporation has attempted to identify important factors that could cause actual results to differ materially from those contained in forward-looking information, there may be other factors that cause results not to be as anticipated, estimated or intended. There can be no assurance that such information will prove to be accurate, as actual results and future events could differ materially from those anticipated in such statements. Accordingly, readers should not place undue reliance on forward-looking information. The Corporation does not undertake to update any forward-looking information, except in accordance with applicable securities laws.

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  • Energy. Energy. Energy.

Wind Geothermal Solar Biogas Hydro

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Generation

Ideal scenario

Transmission Consumption

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Unbalanced delivery

No New Transmission Capability More Consumption New / Remote Generation

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Major hurdle

NIMBYISM

30-40 year infrastructure deficit

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Nimbyism has a price

Higher electricity cost Less stable grid Less renewable generation

Constant Congestion

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Independent Transmission Developers

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Powerful opportunity

Connecting the Alberta/US grid

Generation

World-Class Wind Resource in Montana

Gap

No Interconnect between Alberta and U.S.

Demand

Alberta: deregulation U.S. Northwest: insufficient RPS capacity

Alberta Montana

CANADA U.S.

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MATL:

The route 300 MW

Northbound

300 MW

Southbound

345 km 230 kV

CANADA UNITED STATES

Lethbridge Cut Bank Great Falls

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MATL:

The progress

Fully permitted Fully sold Fully funded

CANADA UNITED STATES

Lethbridge Cut Bank Great Falls

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Pre-permit stage

MATL:

Fully permitted

and Permits required Fully Permitted Other independent transmission developers Utilities

Alberta Energy & Utilities Board (AEUB) National Energy Board (NEB) Montana Dept. of Environmental Quality (MDEQ) US Dept. of Energy (DOE) Federal Energy Regulatory Commission (FERC) Western Electricity Coordinating Council (WECC) 12

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MATL:

Fully sold

NaturEner

300MW

Blowup of Map w/ MATL line

Northbound Southbound

Invenergy 180MW Wind Hunter 70MW WAPA 50MW 300MW

CANADA UNITED STATES

25-Year Take/Pay (5-Year Option) Average $5.00/MWh 2.5% annual escalator

Lethbridge Cut Bank Great Falls 13

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MATL:

Fully funded

$161 Million

2%

@

Construction funding:

(WAPA)

WAPA Regions

Sierra Nevada Region CRSP Management Center Upper Great Plains Desert Southwest Region Rocky Mountain Region

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MATL:

Great project economics $25M revenues $22M EBITDA

10-year fixed price operating and maintenance contract

25-Year Take/Pay (5-Year Option) Average $5.00/MWh 2.5% annual escalator

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MATL:

Project timeline

Milestone 0% 25% 50% 75% 100% Target Completion Major Permits

2008

Compeletion of Final Design Transmission

Q2’10

Substations

Q2’10

Ordering of major equipment

Q2’10

Pole insertion & construction Transmission

Q2’11

Substations

Q2’11

System commissioning & line in service

Q2’11

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Tonbridge Growth Strategy

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Project pipeline

Project Size (MW) Prospect and Feasibility Development and Permitting Finance Construct Operate

MATL Upgrade 250 each north & south Green Line 500-1000 each north & south

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MATL upgrade:

Being built now

650 MW cable cross-section

CANADA UNITED STATES

MATL 300 MW

250 MW Proposed Upgrade 100 MW Efficiency Buffer

Lethbridge Cut Bank Great Falls

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MATL upgrade:

Attractive economics MATL 300 MW MATL UPGRADE 550 MW

$15 - $20 Million capital Regulatory approval Phase shifting transformer

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Green line:

The route

Montana Alberta Washington Idaho

Mid-Columbia Hub

British Columbia

Connecting Montana’s wind resource to the Mid-C Hub

MATL Colstrip transmission line 500kV Proposed route to Townsend Garrison interconnect Townsend interconnect Proposed route to Garrison

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Green line:

Anchor tenant strategy

1,000 MW cable capacity Anchor Tenant: Gaelectric North America Inc. & Invenergy LLC

13% Return on Asset

  • 500 MW Take/Pay contract
  • Shares in development cost
  • Receives future transmission credit

Unallocated capacity 50 MW

OASIS auction

500MW

100 MW efficiency buffer

350MW

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Green line:

Anchor Tenants

Gaelectric North America Inc.

  • Focused on assembling large wind power projects in high wind resource areas and

supporting grid expansion to deliver power to growing loads and “green power” markets

  • Part of the Gaelectric group of companies, each active in different fields of renewable

power generation and energy storage

Invenergy Wind Development LLC

  • Focused on development, ownership, operation and management of large-scale wind

energy generation assets in North America and Europe

  • Invenergy companies have approx. 2,000 MW of wind projects in operation or construction
  • Affiliate of Chicago-based Invenergy Wind LLC

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Green line:

Timeline

Feasibility study 2010 Regulatory approval 15 to 24 months Notice to proceed 2012 Construction 9 to 15 months Commercial

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2013

CANADA UNITED STATES

Lethbridge Cut Bank Great Falls

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Tonbridge Power:

Strong outlook

PROJECT Economics TARGET DATE PROGRESS

MATL $22 million EBITDA 2011 under construction MATL Upgrade TBD 2013 being built now

  • nly ~$15 million investment

Green Line 13% ROA 2013 development risk shared by shippers

Long-term + Fixed Rate Contracts = Growing + Predictable Cash Flows

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Appendix:

Corporate overview

TSX-V symbol: TBZ Price: (04/08/10) $2.40 Market cap: $85.7 M Shares outstanding: Issued: 35.7 M Fully diluted: 41.1 M Working Capital: ($2.1 M) Cash & cash equivalents: $1.2 M LT debt: $38.1 M

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Appendix:

Management

Johan van’t Hof, CA – Chief Executive Officer & Director

  • 18 years project finance experience in the power industry as the project finance partner at

PriceWaterhouseCoopers (PWC) – head of electricity division;

  • Responsible for development/financing of over 25 infrastructure projects worldwide

Robert van Beers – COO & Director

  • Over 25 years of experience in global power sector strategy and organizational restructuring as the

Head of North American Strategy at PWC and the Head of the Energy Department at Charles River;

  • Involved in all stages of developing power projects including engineering, regulatory permitting,

feasibility studies

Caren Narvet, CGA – Chief Financial Officer, Regulatory & Reporting

  • 15 years of experience in finance, senior commercial banking with Bank of Montreal

Robert McFarlane – Chief Business Officer, Head of Capital Markets & Corporate Communications

  • 10 years of experience in energy finance while at CIBC Debt Capital Markets;
  • Involved with a cross section of projects in recent years including Equador Wind Power Project in Loja

with Villonaco Wind Power SA; 54MW Wind Project with Manitoulin Power LLP; Portland Connecticut Gas Pipeline Disposition

David Axford – Senior Vice President, Project Development

  • Over 25 years of experience in the chemicals and power industries in Alberta, Ontario and Dubai
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Appendix:

Independent Directors of the Board

John Etchart – Chairman

  • Former Chair of Northwest Power Planning Council;
  • Former advisor to Montana Governor Racicot

Jeff Myers – Director

  • President of Pristine Power;
  • Former President Westcoast Power

David Matheson, QC – Director

  • Special counsel at McMillan Binch

John Wiebe, PhD – Director

  • President of Globe Foundation of Canada;
  • Regional Head of Environment Canada

Walter Pollock – Director

  • Former Chief Transmission Officer, Bonneville Power Administration