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TransAlta Corporation Investor Presentation April 2017 1 Forward - - PowerPoint PPT Presentation
TransAlta Corporation Investor Presentation April 2017 1 Forward - - PowerPoint PPT Presentation
TransAlta Corporation Investor Presentation April 2017 1 Forward Looking Statements This presentation may include forward-looking statements or information (collectively referred to herein as forward -looking statements) within the meaning
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This presentation may include forward-looking statements or information (collectively referred to herein as “forward-looking statements”) within the meaning of applicable securities
- legislation. All forward-looking statements are based on our beliefs as well as assumptions based on information available at the time the assumptions were made and on
management’s experience and perception of historical trends, current conditions, and expected future developments, as well as other factors deemed appropriate in the
- circumstances. Forward-looking statements are not facts, but only predictions and generally can be identified by the use of statements that include phrases such as “may”, “will”,
“believe”, “expect”, “anticipate”, “intend”, “plan”, “project”, “forecast”, “foresee”, “potential”, “enable”, “continue”, or other comparable terminology. These statements are not guarantees of our future performance and are subject to risks, uncertainties, and other important factors that could cause our actual performance to be materially different from that
- projected. In particular, this presentation contains forward-looking statements pertaining to our business strategy and goals, including our strategy and position to grow gas-fired and
renewable generation; the anticipated benefits of shifting to a capacity market structure; the repositioning of our capital structure by pursuing project-level debt; anticipated future financial performance, including as it pertains to comparable earnings before interest, taxes, depreciation, and amortization (“EBITDA”), comparable funds from operations (“FFO”), and comparable free cash flow; the timing and the completion and commissioning of projects under development, including the South Hedland power project and its associated costs and benefits; the coal-to-gas conversions, including costs of any such conversions and the anticipated reduction in emissions; development of a pump-storage project at Brazeau, including the anticipated benefits, total investment costs, location of developments, the increase to capacity and the timing of construction; access to low cost growth capital; ability to realize growth opportunities, including brownfield solar and battery sites in Alberta in regard to future growth opportunities and targeted gas and renewable acquisitions in Australia, the United States and Canada; ability to further hedge at prices higher than the current market in Alberta; estimated regulatory environment, including anticipated cost/tonne for carbon emissions; ability to monetize the off-coal transition payment; the generation supply mix in Alberta by 2030; attributes of coal-to-gas conversions, including the anticipated capital costs, investment life, reduction in emissions and operating costs; expectations related to future earnings and cash flow from operating and contracting activities; expectations in respect of financial ratios and targets, including dividend payout ratio; the Corporation’s plans and strategies relating to repositioning its capital structure and strengthening its balance sheet, including the allocation of debt between the Corporation and TransAlta Renewables Inc. as well as the debt reductions that are expected to occur; the potential drop-down candidates from TransAlta Corporation to TransAlta Renewables Inc.; and the Corporation’s ownership level of TransAlta Renewables Inc. Factors that may adversely impact our forward-looking statements include risks relating to: fluctuations in market prices and the availability of fuel supplies required to generate electricity; our ability to contract our generation for prices that will provide expected returns; the regulatory and political environments in the jurisdictions in which we operate; adverse regulatory developments, including unanticipated impacts on existing generation and coal-to-gas conversions; environmental requirements and changes in, or liabilities under, these requirements; changes in general economic conditions including interest rates; operational risks involving our facilities, including unplanned outages at such facilities; disruptions in the transmission and distribution of electricity; the effects of weather; disruptions in the source of fuels, water, or wind required to operate our facilities; natural or man-made disasters; the threat of domestic terrorism and cyberattacks; equipment failure and our ability to carry out, or have completed, repairs in a cost-effective manner or timely manner; commodity risk management; industry risk and competition; fluctuations in the value of foreign currencies and foreign political risks; the need for additional financing; structural subordination of securities; counterparty credit risk; insurance coverage; our provision for income taxes; legal, regulatory, and contractual proceedings involving the Corporation;
- utcomes of investigations and disputes; reliance on key personnel; labour relations matters; risks associated with development projects and acquisitions, including delays in the
construction of or increased costs associated with the South Hedland power project; and any market disruption, including any actions taken by the Balancing Pool as the buyer under the power purchase arrangements. The foregoing risk factors, among others, are described in further detail in the Risk Management section of our Management Discussion and Analysis and under the heading “Risk Factors” in our Annual Information Form. Readers are urged to consider these factors carefully in evaluating the forward-looking statements and are cautioned not to place undue reliance on these forward-looking statements. The forward-looking statements included in this document are made only as of the date hereof and we do not undertake to publicly update these forward-looking statements to reflect new information, future events or otherwise, except as required by applicable laws. In light of these risks, uncertainties, and assumptions, the forward-looking events might occur to a different extent or at a different time than we have described, or might not occur. We cannot assure that projected results or events will be achieved. Certain financial information contained in this presentation, including comparable FFO and comparable FCF, may not be standard measures defined under International Financial Reporting Standards (“IFRS”) and may not be comparable to similar measures presented by other entities. These measures should not be considered in isolation or as a substitute for measures prepared in accordance with IFRS. For further information on non-IFRS financial measures we use, see the section entitled “Non-IFRS Measures” contained in our Management Discussion and Analysis, filed with Canadian securities regulators on www.sedar.com. Unless otherwise specified, all dollar amounts are expressed in Canadian dollars.
Forward Looking Statements
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TransAlta’s Investment Merits
- Geographic: Over 8,600 MW’s of net generation capacity in
Canada (75%) , U.S. (18%) and Australia (7%)
- Fuel: Over 70 facilities including wind, hydro, gas, co-generation,
coal
- Supporting Stable EBITDA: 70% - 85% contracted generation
- ver next four years
- Reliable: Average contract duration of approximately six years
- Liquidity: $1.7 billion at December 31, 2016
- Annual Cash Payments: From Alberta government for coal
compensation total more than $500 million
- Renewables’ skill sets: Alberta’s largest generator with technical,
financial, project management, and operating expertise.
- Access to low cost growth capital: Via TransAlta Renewables
and internally generated cash.
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Seizing Investment Opportunities in Targeted Markets
Region Opportunity (MW’s) Strategic Considerations
Alberta
5,000
- ~3,000MW’s of coal-to-gas conversions; extending life
- f existing depreciated assets
- 600 – 900MW’s pump storage at Brazeau; grow site
capacity to between 955 – 1,255MW’s
- Brownfield wind farms shovel ready for upcoming
renewables bid
- Brownfield solar and battery sites ready for future
- pportunities
Australia
5,000
- Wind/solar focus with sites in active development
- Offtake agreements
- Targeted gas and renewables acquisitions
Saskatchewan
1,500
- Wind and Solar sites being developed
Eastern Canada
1,000
- Ontario RFPs greenfield solar/ small hydro uprates
- Targeted gas and renewables acquisitions
U.S.
500
- Renewables expansion at existing facilities
- Targeted gas and renewables acquisition
TransAlta’s Global Generation Portfolio
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TransAlta’s Generation Asset Overview
Coal: 4,931MW (~73% in Canada) Wind/Solar: 1,384MW (~84% in Canada) Gas: 1,323MW (~68% in Canada) Hydro: 926MW (~100% in Canada)
TransAlta is Canada’s largest generator of wind power and the largest generator of renewable energy in Alberta
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Gas & Renewables Cash Flow Leading the Way
- Gas-fired and renewable assets were approximately 70% of total
Cash Flow From Generation
(1) in 2016 and approximately 11% higher
than in 2015.
- $3.3 billion of assets positioned in markets where public policy is
promoting clean power; Canada, Australia and the US
(1) Cash Flow From Generation = Comparable EBITDA (adjusted for the Keephills 1 force majeure provisions) less sustaining capital.
$0 $100 $200 $300 $400 $500 $600 $700 $800 $900 2014 2015 2016
$ millions
Cash Flow From Generation
Renewables & Gas Coal Total Generation
(1) (1)
11% increase 10% increase
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Contracted Generation Portfolio Supports Stable EBITDA
Stable cashflows underpinned by contract and hedging strategy
Alberta
- Highly hedged through 2017
- Market volatility allow opportunity to
further hedge at prices higher than the current market
Pacific Northwest
- Puget Sound Energy and other long-term
contracts provide base of between ~280MW and 380MW
- Additional shorter-term hedges managed
dynamically to capture market volatility
Merchant exposure in Alberta and the Pacific NW
2017 Hedge prices AB ~$45 - $50/MWh PacNW ~$45 - $50/MWh 2018 Hedge prices AB ~$45 - $50/MWh PacNW ~$45 - $50/MWh
Total portfolio contractedness(1)
MW 85% 73% 70% 69%
(1) As of Dec. 31, 2016
1,000 2,000 3,000 4,000 5,000 6,000 2017 2018 2019 2020
PPAs Long-term contract Short-term contract / Hedges Open Merchant
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Key Growth Drivers in Australian Power Markets
Plant Net MW’s Counterpart
Fortescue River Gas Pipeline
- n/a
South Hedland(1) 150 Horizon Power, Fortescue Metals Group Solomon 125 Fortescue Metals Group Parkeston 55 Newmont Power Pty Southern Cross 245 BHP Billiton Nickel West
- 2015 Federal Renewable Energy Target (RET) legislation creates a
driver for new transmission connected to solar and wind projects.
- Recent transmission stability issues in Southern Australia triggering a
review of the need for distributed peak power.
Aging coal fleet in Eastern Australia provides opportunity for alternate fuel sources to replace these assets
(1) South Hedland is expected to be commissioned mid-2017
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South Hedland Power Station
150 MW Combined Cycle Gas Power Station in Western Australia
- $585 million project
(1) has been funded without increasing TA debt
- Expected to generate ~$80 million of EBITDA on an annualized basis
- Commissioning expected on budget in mid-2017
(1) Total estimated project spend is AUD$570 million. Total estimated project spend is stated in CAD$ and includes estimated capital interest costs and may change due to fluctuation in foreign exchange rates.
Seizing Opportunities in Alberta and Canada’s Transition to an Off-Coal and Carbon Tax Regime
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Rules at the federal and provincial levels are under discussion and costs/tonne are currently estimated to be:
- Federal: $50/Tonne by 2022
- Alberta: $30/Tonne starting in 2018
Transitioning Off Carbon.. Removing an Uneconomic Input
“Threading the needle on carbon exposure means transitioning out of carbon sooner rather than later to avoid being subjected to an increasing cost environment.” Dawn Farrell, CEO TransAlta Corporation
Pricing carbon is the new reality, it will become the largest sole input cost to power generation driven by policies of the Federal and Provincial governments.
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Required to eliminate coal emissions by 2030. Will receive annual off-coal transition payments from Alberta government starting in 2017.
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TransAlta’s Off-Coal Transition Agenda in Alberta
TransAlta’s Response to the Changing Environment
- Working with stakeholders to create new capacity
market
- Converting coal-fired plants to gas-fired
- Development of Brazeau pump storage solution
- Bidding in the AESO REP auctions
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Implementing the Climate Leadership Plan
- 14 annual cash payments of $37.4 million totaling $542 million
- Payments expected to occur in third quarter each year until 2030.
- Opportunity to monetize contracted cash flow stream
(~$400 – $420 million)
- Compensation will be recognized as ‘net other operating income/
(loss)’
- Depreciation expense increases by approximately $60 million due
to reductions in useful lives for the Alberta coal assets
Off-Coal Transition Payments Agreement
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Implementing the Climate Leadership Plan
Creating a new Capacity Market Executing coal-to-gas conversions to extend useful lives of coal facilities Supporting Renewable Electricity
- Fair treatment of existing renewable generation including the
value of renewable energy credits on existing generation
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Memorandum of Understanding Tangible Cooperation and Collaboration with the Alberta Government in terms of:
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Alberta’s Climate Leadership Plan
CLP Requires
- Retirement of 6,200MW of baseload coal-fired generation by 2030
= ~40% of current installed capacity
- Installation of 5,000MW of intermittent renewable electricity by 2030
= ~2,000MW of reliable generation
Changing the Supply Mix
Issues: Energy-Only Markets
- System reliability risk; renewables
require backup support (lower reserve margins)
- Depressed price distorts signal for
new firm generation investment
Solution: Capacity Market
- System reliability is maintained
- Provides appropriate price
signals to support new firm generation investment
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Energy Only vs. Capacity Markets
Energy/AS
Energy-Only Market
Capacity Energy/AS
Capacity Market
- Energy market revenues recover
marginal costs
- Capacity market revenues recover
fixed operating & capital costs and provide for return
- All costs and return of capital
must be recovered from energy prices in the power market
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Capacity Market – A Stable Investment Environment
TransAlta is well positioned to compete in a capacity market with highly depreciated coal units that will be converted to gas- fired generation Allows existing and new dispatchable generation to compete for capacity Provides price and cash flow certainty, resulting in access to lower cost of capital Government has committed that non-dispatchable existing renewables will not be economically harmed
1 2 3 4
TransAlta advocates for, and supports, a Capacity Market
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- Biggest market change in two decades.
- Timelines are aggressive; need to align with the first coal retirements.
- Schedule risk has been identified by the AESO
Capacity Market Transition Timeline
2017 2018 2019 2020 2021
Implementation First Procurement First Delivery Schedule risk Design
Legend:
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- What is the best capacity contract term (e.g. 1 year, up
to 7 years)?
- Resource eligibility – should demand participation and
renewables be allowed?
- Will subsidization of renewables distort price formation?
- Requirement to participate – will it be “must offer”?
- How will capacity costs be charged to consumers?
- How will consumers hedge?
Alberta’s Capacity Market Transition - Unknowns
Key Market Design Considerations
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TransAlta’s Coal Fleet – Leveraging Critical Mass
- ~3,000MW of coal-fired installed capacity eligible for coal-to-gas conversion;
representing ~50% of total coal capacity in Alberta
- Majority of TransAlta’s coal units are highly depreciated – providing for low-cost
capacity in Capacity Market
- Federal regulations provide opportunity for conversions; proposed standard of
550 t/GWh is under review
Plant MW (Net) Annual GWh1 Commissioned Retirement Under Exiting Rules2 Retirement Under Federal Gas Regulation
Sundance 3 368 2,740 1976 2026 2036 Sundance 4 406 3,023 1977 2027 2037 Sundance 5 406 3,023 1978 2028 2028 Sundance 6 401 2,986 1980 2029 2038 Keephills 1 & 2 790 6,046 1984 2029 2040 Sheerness 1(3) 98 708 1986 2030 2045 Sheerness 2(3) 98 707 1990 2030 2045 Genesee 3 233 1,675 2005 2030 2045 Keephills 3 232 1,675 2011 2030 2045
1Based on 85% availability 2Sundance & Keephills 1 and 2 retirement dates are based on existing Federal coal legislation; remaining coal units are based on CLP date of 2030 3Sheerness 1 and 2 capacity based on 25% ownership interest
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Coal-to-Gas Conversion Attributes vs. Coal Generation
Lower Operating Cost
- 40-50% lower operating & sustaining capital
- 65% lower carbon costs
Conversion & Life Extension Competitive Capital Costs
- ~60 days required to convert coal burners to gas
- Potential to add 15 years to Alberta coal fleet
- Utilizes existing capital, sites and transmission
- $125 - $150/KW cost for burner conversion
Flexibility
- Similar ramping and lower minimum stable
requirements Reduced Emissions
- 40% reduction in CO2 & up to 70% reduction in NOx
- 100% reduction in Mercury and SOx
Critical path items include: Securing fuel supply and regulatory approval for gas pipeline Technology & Innovation
- Supports market implementation and development of
renewable generation
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Coal-to-Gas Conversion – A Comparative Analysis
Coal-to-Gas Conversion Reciprocating Engine New CCGT Facility Cost (per KW) $125 to $150 $1,300 to $1,400 $1,500 - $1,700 Carbon Tax Higher Lower Lower Capacity Baseload/Mid-merit Peaking Baseload Ramping Slower Faster Faster Time to Build 60 days 2.5 to 3.5 years 4 to 5 years Unit Size ~400 MW 10 to 20 MW 400 to 800 MW Investment Commitment 15 years 30 years 30 years
Coal-to-Gas conversions provide: higher returns, at lower cost, over a shorter project life with less regulatory risk.
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Plant Owner Conversion Details Harding Street Station Indianapolis Power & Light 2015/16 650MW (Units 5/6/7) Commissioned: 1958 – 1973 Clinch River American Electric Power 2016 476MW (Units 1/2) Commissioned: 1958 Big Sandy American Electric Power 2016 268MW (1 Unit) Commissioned: 1963 Shawville NRG 2015/16 626MW (4 Units) Commissioned: 1954 – 1960 Big Cajun NRG 2015 580MW (1 Unit) Commissioned: 1982
Examples of Executed Coal-to-Gas Conversions
The conversion of coal units to gas-fired generation has been taking place in the United States for a number of years.
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Brazeau Investment Supports System Reliability
600 to 900 MW pumped storage expansion Increases Brazeau’s capacity to 955 - 1,255 MW. Low cost alternative to greenfield build out Investment of ~$1.8 billion to ~$2.5 billion Targeting 2021 commencement of construction, subject to long-term contract 1 2 3
Brazeau
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Large battery storage to support adoption of renewables
Current Capacity of Brazeau is 355MW
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Brazeau Hydro – Looking Forward
1
New Dam New Turbines
1 2 2
Brownfield Expansion Utilizes existing site and infrastructure Reliability Provides system support as wind build-out occurs Flexibility Fast ramping Sustainability Perpetual assets – existing hydro fleet is 100 yrs. old
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Brazeau Hydro – Our Action Plan
2017 2018 2019 2020 2021 2022 2023 2024 2025
Environmental Studies Regulatory Applications Engineering Procurement Construction COD Stakeholder Engagement Secure Contract
Securing long-term contract with AESO is a key stage gate
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Leveraging TransAlta’s Operating Advantage in Alberta
History of developing and operating renewables facilities has lead to:
- Strong understanding of wind resources and hydrology
- Long-standing land owner and stakeholder relationships aid future
development plans
- Trusted developer and supporter of community enhancement projects
(TransAlta Tri Leisure Centre) 300MW’s of development ready wind sites in Alberta
- Advanced stages of development available for near-term AESO REP
- Near existing transmission and infrastructure
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Financial Strategy
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50 100 150 200 250 300 350 400 450 500 2013 2014 2015 2016 2017 2018-2020
Comparable FCF Growth
Sufficient FCF to Fund Growth and Strengthen B/S
$280 to $315 million of Comparable FCF
(1) between 2013 and 2016
$M Outlook Range Target
(1) Comparable Free Cash Flow includes dividend payments on preferred shares but not dividend payments on common shares. (2) Allocation between debt and growth shown for illustrative purposes only.
Expect capacity market to deliver similar FCF as current PPA
Growth(2) Debt(2)
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Upcoming Debt Maturities
(1) Debt related to RNW. (2) Includes USD$20 million of debt related to RNW.
$400 $520 $700 $167 $400 $400 $296
$0 $200 $400 $600 $800 $1,000 $1,200 2017 2018 2019 2020 2021-2040 USD CAD
Upcoming Debt Maturities ($ millions)
1 2
$360M of non-recourse debt raised in 2016 will be used to settle 2017 maturities
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Finance & Treasury Overview
Area of Focus Execution
Liquidity
- Average liquidity of $1.3B since 2014; liquidity of ~$1.7B at
December 31, 2016 including cash of $305 million
Area of Focus Execution
Financial Ratios
- Ratios expected to improve once South Hedland is operational
Ratio 2013 2014 2015 2016 Target
Comparable FFO before Interest to Adjusted Interest 3.7 3.8 3.8 3.8 4 – 5x Adjusted FFO to Adjusted Net Debt 15.2 16.9 15.2 17.0 20 – 25% Adjusted Net Debt to Comparable EBITDA 4.6 4.2 5.0 3.8 3 – 3.5
(1) Reduction in Available Liquidity due to reduction in US bilateral credit facility from $300 million to $200 million.
Outlook and Priorities
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Executing on our 2016 Priorities
Secured a mutually beneficial coal transition arrangement with the Alberta Government Continued to reposition our capital structure Continued to grow TransAlta Renewables Inc. Continued to focus on delivering strong operational, safety and financial performance
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Executing on 2016 Financial Goals
$990 $1,065 $1,100 $- $200 $400 $600 $800 $1,000 $1,200 Low 2016 High
Comparable EBITDA
$755 $763 $835 $- $200 $400 $600 $800 $1,000 Low 2016 High
Comparable FFO
$250 $299 $300 $- $100 $200 $300 $400 Low 2016 High 87% 89% 89% 80% 85% 90% Low 2016 High
Comparable FCF CAD Coal Availability
(1) Includes $80 million provision adjustment related to the Keephills 1 force majeure.
(1)
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2017 Priorities – Positioning for Competition
Work collaboratively with the Government of Alberta
- Advance our investment in Brazeau by securing long-term contract
- Contribute to the design of a new capacity market
- Establish terms and conditions to convert coal plants to gas
Commission South Hedland Grow renewables through RFP’s in Saskatchewan, Alberta and Australia Execute our financing strategy to further strengthen the balance sheet Continue to lead in safety and environment performance while delivering against our 2017 financial targets
1 2 3 4 5
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2017 Outlook Ranges ($M)
Comparable EBITDA $1,025 $1,135 Comparable Funds from Operations $765 $855 Sustaining Capital (260) (280) Pfd Share/Other Distributions (205) (210) Comparable Free Cash Flow $300 $365 Comparable Free Cash Flow Per Share $1.04 $1.27 Annual Dividend $0.16 $0.16 Dividend Payout Ratio 15% 13%
2017 Outlook
Range of Key Assumptions
Power Prices Alberta Spot ($/MWH) $ 24
- $ 30
Alberta Contracted ($/Mwh) $ 45
- $ 50
Mid-C Spot (US$/MwH) $ 23
- $ 28
Mid-C Contracted (US$/MWh) $ 45
- $ 50
Other Canadian Coal Availability 86%
- 88%
Hydro / Wind Resource Long term average
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Executing Our Strategic Objectives
2016 2017
Operational Excellence
- Reduced OM&A costs by $20 million
year over year through improved mine planning and mine methodologies, reduced equipment requirements and optimized contractor usage.
- Continued focus on delivering
strong operational, safety and financial performance.
Increase Financial Flexibility
- Entered into an off-coal agreement
with the Government of Alberta for ~$524 million over the next 14 years.
- Raised ~$360 million of project debt
and increased liquidity to ~$1.7 billion at year end.
- Met 2016 guidance for comparable
EBITDA
(1), FFO and FCF; at the high
end of FCF outlook range.
- Reposition our capital
structure by pursuing $700 to $900 million of project-level debt over the next 18 months.
- Repayment of maturing debt
in 2017 with existing liquidity.
- Target FCF of $400 million by
2018 to 2020.
Strategic Growth
- Plan to participate in the 2017 Alberta
RFP for renewables.
- Conversion of coal plants to gas.
- Announced Brazeau pump storage
hydro project development.
- Longer-term, prepare to
capitalize on opportunities in renewable generation.
- Continue to seek a long-term
contract for our Brazeau project with the Government
- f Alberta.
(1) Excluding adjustment to provisions relating mostly to prior years.
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Leveraging TransAlta Renewables Inc.
TransAlta Corporation and TransAlta Renewables are strategically aligned
TransAlta Renewables TransAlta Public
~60-80% ~20-40%
- TransAlta is the largest
shareholder of TransAlta Renewables Inc. and will maintain ~60-80% ownership
- Unlocks the value of long-life
contracted assets on attractive terms
- Provides access to lower cost
funding
- Strong currency to support
accretive acquisition of third party assets
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TransAlta Renewables (TSX:RNW)
- Provides stable, consistent returns through the ownership of highly
contracted power generation and other infrastructure assets
Enterprise Value¹ $4.8 Billion Market Cap.2 $3.7 Billion 2017 Comparable EBITDA (guidance) $425 - $450 million 2017 Comparable CAFD (guidance) $235 - $260 million Dividend Yield 6.0% Net Generating Capacity (incl. South Hedland) 2,441 MW TransAlta Corporation’s Ownership 64%
¹ Does not include capital required to complete South Hedland Project
2 Based on closing price as of March 1, 2017 and including Class B shares
Wind Hydro Gas Fired Gas Pipeline
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Significant Drop-Down Inventory
Potential Drop-Down Candidates from TransAlta Corporation Gas Fired Generation
- ~400 MW in Alberta & Ontario including:
- 244 MW Poplar Creek facility in AB
- ~150 MW from 4 facilities through TA Cogen
- ~$140M EBITDA
Alberta Hydro
- ~800 MW from 13 units in Alberta, representing
90% of Alberta’s hydro
- ~$60 - $120M EBITDA
Other Renewables
- 20 MW wind facility in ON
- 50 MW wind facility in Minnesota
- 21 MW solar facilities in
Massachusetts
Appendix
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Financial Performance by Business Segment
Business Segment 2011 2012 2013 2014 2015
(1)
2016
(1)
Comparable EBITDA ($M) Canadian Coal $273 $373 $311 $389 $393 $393 U.S. Coal $211 $148 $67 $65 $67 $41 Gas $275 $312 $332 $312 $330 $372 Wind and Solar $163 $151 $181 $179 $176 $195 Hydro $105 $127 $148 $87 $73 $82 Energy Marketing $101 ($13) $58 $75 $37 $52 Corporate ($84) ($83) ($74) ($71) ($72) ($70)
- Comp. EBITDA ($M)
$1,044 $1,016 $1,023 $1,036 $1,004 $1,065
- Comp. FFO ($M)
$812 $788 $729 $762 $740 $763
(1) Canadian Coal is normalized for provision adjustments including $80 million and $59 million in 2016 and 2015, respectively.
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Australia – 20 Years of Investment Experience
100 200 300 400 500 600 $0 $20 $40 $60 $80 $100 $120 $140 $160 $180 $200 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 Net Capacity (MW) Australian Revenue (CAD$ millions)
December 2002 Added remaining 15% ownership in Southern Cross January 2006 Gas turbine commissioned at Southern Cross September 2015 Solomon facility, acquired from Fortescue in 2012, commissioned. Mid-2017 150 MW South Hedland facility expected to
- n-line
Original Investment Parkeston (55 MW net to TransAlta). January 1999 TransAlta acquired a 85% interest in Southern Cross; cash consideration of $187 million.