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Increasing Natural Gas Requirements Oil sands production, and its cogeneration based natural gas demand, is expected to increase fourfold over the next decade, straining our natural gas supplies Energy Alberta Corp. will replace a portion of the expected oil sands natural gas demand, with nuclear energy By 2025, 70% of the oil sands production will be using in situ technology, requiring 4.2 bcf/d a natural gas A single CANDU 6 can support, on the order of, 100,000 to 150,000 barrels a day of SAGD production, replacing approximately 0.17 to 0.26 bcf/d of natural gas demand
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Oil Sands & Nuclear Energy: Our Integrated Energy Vision
Presentation for: Energy Roundtable, Calgary
Presentation by Wayne Henuset, DirectorSeptember 26, 2006
Our Mission
Energy Alberta Corp. will be a profitable energy provider, at the lowest cost, utilizing proven nuclear technology to supply low cost steam, electricity and hydrogen to oil sands operators
Increasing Natural Gas Requirements
• Oil sands production, and its cogeneration based natural gas demand, is expected to increase fourfold over the next decade, straining our natural gas supplies
• Energy Alberta Corp. will replace a portion of the expected oil sands natural gas demand, with nuclear energy
• By 2025, 70% of the oil sands production will be using in situ technology, requiring 4.2 bcf/d a natural gas
• A single CANDU 6 can support, on the order of, 100,000 to 150,000 barrels a day of SAGD production, replacing approximately 0.17 to 0.26 bcf/d of natural gas demand
Our Strengths
Zero Emissions• Cleanest energy alternative
Cost of Nuclear Fuel per year (150,000 b/d)• $18 Million• Long-term (20 to 30 year) fuel contracts• Off-take agreements fixed cost for 30
years, retrofit for another 30 years
Cost of Natural Gas Fuel per year (150,000 b/d)• $550 Million
Proven Technology• CANDU online refuelling
Spent Fuel• Safe storage at plant site (short-term)• Transported outside of Alberta (long-term)
Nuclear as a Hedging Tool
Nuclear energy is competitive in today’s natural gas price environment, and is clearly less expensive when emission costs are considered
Our fuel costs are fixed on a long-term basis– CANDU fuel costs are $18 Million Canadian
per year (using U3O8 at US$32 / pound)• Natural gas is based on the spot market,
and costs over $550 Million a year (2005 AECO-C average)
– A doubling of the contracted price of uranium would only increase our energy costs by 3%
Our “emissions” costs are fixed– Energy Alberta Corp. pays an annual amount
for the disposal and management of spent fuel; few other sources of energy generation currently pay for their “waste” products
Nuclear Renaissance
• 442 reactors operating today• 28 more reactors under construction• Over 50 reactors being proposed
Ontario, USA, Europe, China, and Southeast Asia
• Public opinionEAC commissioned Longwoods International to
conduct a public opinion survey (Alberta, November 2005) on the idea of using nuclear to power oil sands development
• 40% of respondents in favour• 36% of respondents were
neutral
Energy Alberta Corp.’s Business Model
• Partnered with world leader in new build nuclear reactors – Atomic Energy of Canada Ltd. (AECL)
• Long-term energy off-taker agreements with major energy companies
– 20 to 30 year commitments– Open season process starting in November 2007
• CANDU 6– Online refuelling– Highest plant uptime vs. competition
• Latest CANDU 6 performance uptime exceeds 90%, based upon improved operator performance
Atomic Energy of Canada Limited
10% of the nuclear reactors, worldwide– Canadian Crown Corporation
Ontario basedAECL and Team CANDU will provide
– Design– Turnkey construction for a guaranteed
fixed priceOn-time & On-budget Track record
Romania (1996, and 2007)China (2002 and 2003)South Korea (1997, 1998, and 1999)
– Operations support– Spent fuel management support
Corporate Milestones
July 2005– Concept formulated
July 2005 to July 2006– Discussions with industry
August 2006– EAC-AECL Exclusivity Agreement
November 2007– Open Season process begins
January 2008– Capacity is contracted
March 2008– Regulatory Process commences
March 2011– Construction commences
December 2016– Nuclear power plant is fully
operational