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Canadian Oil Sands Limited 2000 First Canadian Centre 350–7th Avenue SW Calgary, Alberta T2P 3N9

Tel: 403 218 6200
Fax: 403 218 6201

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Press Release Details

Canadian Oil Sands' 2013 Budget Focused on Advancing Major Capital Projects

11/29/2012

CALGARY, ALBERTA--(Marketwire - Nov. 29, 2012) -

Unless otherwise noted: All figures are based on Canadian Oil Sands' 36.74 per cent working interest in the Syncrude joint venture; all financial figures are in Canadian dollars and have been prepared in accordance with Canadian Generally Accepted Accounting Principles ("GAAP").

Canadian Oil Sands Limited's (TSX:COS) (OTCQX:COSWF) (COS) budget for 2013 supports continued progress on Syncrude's multi-year major capital projects program, which is scheduled to be largely complete by the end of 2014. This program is directed at improving environmental performance and maintaining a strong base of long-life crude oil production.

COS plans to invest about $1.3 billion at Syncrude in 2013. Approximately 63 per cent, or $836 million, will be invested in major projects to replace or relocate mining infrastructure and to develop facilities to reclaim tailings, a by-product of the mining process. About $393 million is directed to regular maintenance, which represents smaller projects and annually occurring expenditures to maintain production. The remaining $97 million reflects capitalized interest.

"Syncrude's major projects are advancing on-schedule and on-budget, and our finance plan for these projects is in excellent shape. Our balance sheet is stronger than we had anticipated exiting 2012," said Marcel Coutu, President and Chief Executive Officer. "We intend to maintain our current quarterly dividend of $0.35 per share through 2013 based on our healthy financial position and the assumptions provided today in our 2013 budget."

Major Projects Capital Allocation

($ billions, COS' 36.74% share) Expected

Spend to

Dec. 31, 2012
Expected

Spend in

2013
Expected

Spend in

2014-2015
Total
Mine Train Replacements/Relocations $ 0.8 $ 0.6 $ 0.6 $ 2.0
Aurora North Tailings Management 1 0.2 0.1 0.0 0.3
Centrifuge Tailings Management 0.1 0.2 0.4 0.7
Total Major Projects Spending $ 1.1 $ 0.9 $ 1.0 $ 3.0
1 Aurora North Tailings Management expected spend in 2014 is approximately $20 million (net 36.74% to COS).
Total project costs include both capital costs and certain non-production costs. Costs exclude capitalized interest.

Added Coutu: "We are looking forward to making significant progress on Syncrude's major capital projects in 2013, which will greatly reduce any perceived capital risk. Once this investment has been made in our base operations, we are in the advantageous position of having the infrastructure in place to produce strong, stable volumes of fully upgraded, light crude oil for decades."

2013 Objectives

COS has established the following objectives for 2013:

  • Aim to maintain a quarterly dividend of $0.35 per share in 2013, based on the assumptions outlined in the 2013 budget.
  • Maintain a strong balance sheet while remaining unhedged on oil prices, thereby providing investors with the full potential of this commodity.
  • Increase production by about three per cent, equivalent to three million barrels gross to Syncrude, over estimated 2012 production.
  • Improve per barrel operating expenses in 2013 over 2012.
  • Complete the Aurora North Tailings Management project.
  • Achieve 90 per cent completion on the Aurora Mine Train Relocation.
  • Achieve 75 per cent completion on the Mildred Lake Mine Train Replacement.
  • Invest $25 million ($70 million gross to Syncrude) in research and development, directed at reducing operating expenses, improving reliability, enhancing environmental performance and realizing potential cost savings in environmental initiatives.

2013 Budget Highlights

  • COS' production outlook for Syncrude is 105 million to 115 million barrels (39 to 42 million barrels net to COS). The single point production estimate is 110 million barrels (40.4 million barrels net to COS). The production outlook incorporates a planned turnaround of Coker 8-1 in the second half of 2013.
  • Sales, net of crude oil purchases and transportation expense, are anticipated to total $3,233 million, based on a WTI crude oil price assumption of US$85 per barrel, a foreign exchange rate of $1.00 U.S./Cdn, and a discount for Syncrude Crude Oil (SCO) to Cdn WTI of $5 per barrel.
  • Operating expenses are anticipated to total $1,482 million to produce Syncrude's blend of fully upgraded SCO. On a per barrel basis, operating expenses are estimated to be $36.67, which includes purchased energy costs of $4.40.
  • Cash flow from operations is estimated at $1,045 million ($2.16 per share).
  • Cash balances will be used to fund 2013 capital spending and to support dividends, resulting in an expected net debt level of about $1.3 billion at year-end 2013.
  • Allowable deductible costs for royalty purposes in 2013 are anticipated to exceed deemed bitumen revenues. As a result, COS expects to pay minimum royalties at one per cent of gross deemed bitumen revenues in 2013. In addition, we will continue to accrue the transition royalty and upgrader growth capital recapture payments.
  • COS estimates current taxes of approximately $350 million in 2013. COS expects deductions for capital expenditures made in 2012 and 2013 will be available in 2014 and beyond, resulting in lower taxes in subsequent years, based on the assumptions outlined in the 2013 budget.

2013 Budget Summary

(millions of Canadian dollars, except volume and per barrel amounts)
Syncrude production (mmbbls) 110
Canadian Oil Sands sales (mmbbls) 40.4
Sales, net of crude oil purchases and transportation 3,233
Operating expenses 1,482
Operating expenses per barrel 36.67
Crown royalties 113
Cash flow from operations 1,045
Total capital expenditures 1,326
Business environment assumptions
West Texas Intermediate (U.S.$/bbl) 85.00
Premium (Discount) to average Cdn$ WTI prices (Cdn$/bbl) -5.00
Foreign exchange rate (U.S.$/Cdn$) 1.00
AECO natural gas (Cdn$/GJ) 3.50

The 2013 budget may be impacted by a variety of factors. Some of the more significant variables include, without limitation:

  • Crude oil prices: Canadian Oil Sands' 2013 production is currently unhedged. Accordingly, COS' cash flow from operations is highly sensitive to changes in crude oil prices and foreign exchange rates. Every US$1.00 per barrel change in the annual WTI crude oil price impacts cash flow from operations by about $30 million, or $0.06 per share.
  • Syncrude operational reliability and production: Timing of unit turnarounds and maintenance are not always precisely scheduled and unplanned outages may occur. In addition to the impact on production, unplanned maintenance costs can affect operating expenses. Every two million barrel change in Syncrude annual production impacts cash flow from operations by about $44 million, or $0.09 per share.
  • Given the sensitivity of earnings and cash flow to conditions such as oil prices and differentials, exchange rates, production levels and operating and capital costs, the corporation may need to adjust dividends in 2013 if the operating environment as projected in the budget does not prevail.

2013 Cash Flow From Operations Sensitivities

(after tax; COS anticipates recording approximately $350 million in current taxes in 2013)

An opposite change in each of these variables will result in the opposite cash flow from operations impact

$ Millions $/Share
Syncrude operating expense decrease (Cdn $1.00/bbl) 30 0.06
Syncrude operating expense decrease (Cdn $50 million) 14 0.03
WTI crude oil price increase (U.S. $1.00/bbl) 30 0.06
Syncrude production increase (2 million bbls) 44 0.09
Canadian dollar weakening (U.S. $0.01/Cdn$) 25 0.05
AECO natural gas price decrease (Cdn $0.50/GJ) 16 0.03

More information on Canadian Oil Sands' 2013 Budget is provided in our 2013 Guidance Document, which is available on COS' web site at www.cdnoilsands.com under "Investor Centre". Canadian Oil Sands intends to continue providing quarterly updates to its guidance.

2013 Budget Conference Call

A conference call and webcast will be held tomorrow, November 30, 2012 at 8:00 a.m. MT (10:00 a.m. ET).

To participate, please dial (888) 231-8191 (toll-free in North America) or (647) 427-7450 approximately 10 minutes prior to the conference call. An archived recording of the call will be available from approximately 11:00 a.m. MT on November 30 until midnight of December 7, 2012 by dialing (855) 859-2056 or (403) 451-9481 and entering conference password 70803185.

A live and archived audio webcast of the conference call will also be available on Canadian Oil Sands' website at www.cdnoilsands.com, under the Presentations and Events section in the Investor Centre, or via the following link:

http://event.on24.com/r.htm?e=542350&s=1&k=B2B8C275990C46324C22634ED6B9F160

Canadian Oil Sands Limited

Canadian Oil Sands is a pure investment opportunity in light, sweet crude oil. Through our 36.74% interest in the Syncrude project, we offer a solid, robust production stream of fully upgraded crude oil, exposure to future crude oil prices, potential growth through high-quality oil sands leases and an attractive dividend.

For more information please visit our web site at: www.cdnoilsands.com

Ticker Symbols

Toronto Stock Exchange: COS

OCTQX: COSWF

Forward-looking Information Advisory: In the interest of providing Canadian Oil Sands Limited ("Canadian Oil Sands" or the "Corporation") shareholders and potential investors with information regarding the Corporation, including management's assessment of the Corporation's future production and cost estimates, plans and operations, certain statements throughout this release contain "forward-looking information" under applicable securities law.

Forward-looking statements are typically identified by words such as "anticipate", "expect", "believe", "plan", "intend" or similar words suggesting future outcomes. Forward-looking statements in this press release include, but are not limited to, statements with respect to: the expected amount of total major projects spending in 2013; the expected amount of regular maintenance costs and capitalized interest in 2013; the expectation that spending on the Syncrude major projects will taper off after 2014; the intention to maintain the current quarterly dividend of $0.35 per share through 2013 based on the assumptions in the 2013 budget; future dividends and any increase or decrease from current payment amounts; the expected amount of total capital expenditures in 2013; the expected amount of 2012-2015 major project spending for the mine train relocations/replacements, the Aurora North composite tails plant and the Mildred Lake centrifuge plant; the expected amount of total major project spending; the belief that Syncrude's major projects will provide the necessary infrastructure to produce crude oil for decades; the expectation that 2013 Syncrude production will increase by about three per cent over estimated 2012 production; plans regarding crude oil hedges in the future; the expectation that the Aurora North composite tails plant will be complete in 2013; the expectation that the Aurora North mine train relocations will be 90 per cent complete after 2013; the expectation that the Mildred Lake mine train replacements will be 75 per cent complete after 2013; the expectation that the Corporation will invest $25 million ($70 million gross to Syncrude) in research and development in 2013; the expected 2013 single-point Syncrude production estimate of 110 million barrels (40.4 million barrels net to the Corporation) and the expected 2013 Syncrude production range of 105 to 115 million barrels (39 to 42 million barrels net to the Corporation); the timing of the turnaround of Coker 8-1; the expected sales in 2013; the expected West Texas Intermediate ("WTI") price in 2013; the expected average discount for synthetic crude oil ("SCO") to WTI in 2013; the expected foreign exchange rate in 2013; the expected operating expenses and purchased energy costs in 2013; the expected cash flow from operations and cash flow from operations per share in 2013; all expectations regarding net debt; the expected amount of Crown royalties in 2013; the expected amount of current taxes in 2013; the expectations regarding the amount of taxes after 2013; the expected natural gas prices in 2013; and the anticipated impact of increases or decreases in oil prices, production, operating expenses, foreign exchange rates and natural gas prices on the Corporation's cash flow from operations.

You are cautioned not to place undue reliance on forward-looking statements, as there can be no assurance that the plans, intentions or expectations upon which they are based will occur. By their nature, forward-looking statements involve numerous assumptions, known and unknown risks and uncertainties, both general and specific, that contribute to the possibility that the predictions, forecasts, projections and other forward-looking statements will not occur. Although the Corporation believes that the expectations represented by such forward-looking statements are reasonable and reflect the current views of the Corporation, there can be no assurance that such expectations will prove to be correct.

The factors or assumptions on which the forward-looking information is based include, but are not limited to: the assumptions outlined in the Corporation's 2012 and 2013 guidance document as posted on the Corporation's website at www.cdnoilsands.com as of the date hereof and as subsequently amended or replaced from time to time, including without limitation, the assumptions as to production, operating expenses and oil prices; the successful and timely implementation of capital projects; Syncrude's major project spending plans; the ability to obtain regulatory and Syncrude joint venture owner approval; the Corporation's ability to either generate sufficient cash flow from operations to meet its current and future obligations or obtain external sources of debt and equity capital; the continuation of assumed tax, royalty and regulatory regimes and the accuracy of the estimates of the Corporation's reserves and resources volumes.

Some of the risks and other factors which could cause results to differ materially from those expressed in the forward-looking statements contained in this press release include, but are not limited to: general operational issues relating to a complex, integrated mining and upgrading facility; operating constraints due to weather, especially as it relates to bitumen production; general economic, business and market conditions; changes in commodity prices; the unanimous joint venture owner approval for major expansions; the impact that pipeline capacity and refinery demand have on prices for the Corporation's product; the occurrence of unexpected events such as fires, equipment failures and other similar events; the impacts of legislative or regulatory changes, especially as such relate to royalties, taxation, the environment and tailings; unsuccessful and untimely implementation of planned turnarounds and capital projects; the volatility of crude oil prices; the volatility of the SCO to WTI differential and such other risks and uncertainties described in the Corporation's Annual Information Form dated February 23, 2012 and in the reports and filings made with the securities regulatory authorities from time to time by the Corporation, which are available on the Corporation's profile on SEDAR at www.sedar.com and on the Corporation's website at www.cdnoilsands.com.

You are cautioned that the foregoing list of important factors is not exhaustive. The 2013 Budget reflects various assumptions, which are outlined in the guidance document dated November 29, 2012. Furthermore, the forward-looking statements contained in this press release are made as of the date of this press release, and unless required by law, the Corporation does not undertake any obligation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or otherwise. The forward-looking statements contained in this press release are expressly qualified by this cautionary statement. The information was approved by management on November 29, 2012 and circumstances after this date may change the outcomes or results achieved.

Non-GAAP Financial Measures: In this press release we refer to financial measures that do not have any standardized meaning as prescribed by Canadian GAAP, such as cash flow from operations, cash flow from operations on a per share basis, free cash flow, net debt and certain per barrel measures. Please refer to Canadian Oil Sands' Third Quarter 2012 Report, which is available on the Corporation's profile on SEDAR at www.sedar.com and on the Corporation's website at www.cdnoilsands.com for more information regarding non-GAAP financial measures. Free cash flow is not discussed in our Third Quarter 2012 Report, but is discussed in this release. Free cash flow (cash flow from operations less capital expenditures) is a non-GAAP financial measure which we believe provides additional meaningful information about the Corporation's liquidity and its capacity to fund dividends.

Contact Information:

Canadian Oil Sands Limited

Siren Fisekci

VP, Investor & Corporate Relations

(403) 218-6228





Canadian Oil Sands Limited

Alison Trollope

Manager Investor Relations

(403) 218-6231

www.cdnoilsands.com

Contact: 

A   B   C   D   E   F   G   H   I   J   K   L   M   N   O   P   Q   R   S   T   U   V   W   X   Y   Z  
A
Alberta Oil Sand(s) Deposits

The four deposits, Athabasca, Peace River, Cold Lake and Wabasca, have total resource in place estimated at 1.7 trillion to 2.5 trillion barrels. The Athabasca Oil Sands deposit, Alberta's largest and most accessible source of bitumen, contains more than one trillion barrels of bitumen over an area encompassing more than 30,000 square kilometers.

 
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B
Bitumen
The molasses-like substance that comprises up to 18 per cent of oil sands. Bitumen, in its raw state, is black, asphalt-like oil. It requires upgrading or blending to make it transportable by pipeline and usable by conventional refineries.
 
Bitumen cracking
A process that breaks large, complex hydrocarbon molecules into smaller, simpler compounds by means of heat.
 
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C
Carbon dioxide (CO2)
A non-toxic gas produced from decaying materials, respiration of animal life, and combustion of organic matter, including fossil fuels; carbon dioxide is the most common greenhouse gas produced by human activities.
 
Cokers
Vessels in which bitumen is cracked into its fractions and from which coke is withdrawn to start the process of converting bitumen to upgraded crude oil.
 
Conventional oil
Petroleum found in liquid form, flowing naturally, or capable of being pumped without further processing or dilution.
 
Cyclofeeder
Specialized equipment that receives oil sand feed and turns it into a slurry form for transport to the pump box.
 
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D
Debottleneck
An undertaking to systematically remove plant capacity limitations through modifications of existing facilities and/or addition of capital facilities.
 
Diesel cetane count
A quality specification important in the production of diesel fuels.
 
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E
Extraction
The process of separating bitumen from oil sand.
 
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F
Feedstocks
Raw material supplied to refinery, oil sands upgrader, or petrochemical plant.
 
Flue gas scrubber/desulphurizer
Equipment that removes sulphur dioxide and other emissions.
 
Fluid coking
A major part of the upgrading process whereby high temperatures in a coker break down the complex bitumen molecules, reject carbon and cause bitumen molecules to reformulate into lighter fractions that become the main ingredients in upgraded crude oil.
 
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G
Greenhouse gases
Any of the various gases that contribute to the greenhouse effect.
 
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L
LC-Finer hydroprocessor
A major upgrading unit that breaks down bitumen by adding hydrogen with the aid of a catalyst to produce gas oil.
 
Line-out
The process of optimizing an operational unit or facility to reach its design capacity.
 
Low-energy extraction
A process for extracting bitumen that uses about one-third of the energy of the traditional process, bringing significant cost and environmental benefits.
 
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M
Middle distillates
A classification of refined petroleum products that includes kerosene, diesel, and jet fuel.
 
Mine train
Modular units for crushing and mixing the oil sands with warm water to facilitate the extraction of bitumen from the oil sands.
 
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N
Naphtha
A refined petroleum product in the lighter classification that is often used to make gasoline.
 
Netback
Average realized selling price, after hedging, less operating costs and Crown royalties.
 
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O
Oil sand(s)
A composition of sand, bitumen, mineral-rich clays and water.
 
Oil sand(s) lease
A long-term agreement with the provincial government that permits the leaseholder to extract bitumen, other metals and minerals contained in the oil sands in the specified lease area.
 
Ore grade
The percentage of bitumen by weight in the oil sands.
 
Overburden
Layer of rocky, clay-like material that lies under muskeg and above oil sands deposits.
 
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S
Strip ratio
The ratio of waste (overburden material that covers mineable ore) to ore; used to define the quality of an oil sands ore body.
 
Sulphur dioxide (SO2)
A compound of sulphur and oxygen produced by burning sulphur.
 
Synbit
Typically, a synbit blend is a ~50/50 mix of bitumen and synthetic crude oil.
 
Syncrude Project
Canadian Oil Sands is a pure investment opportunity in light, sweet crude oil. Through our 36.74% interest in the Syncrude project, we offer a solid, robust production stream of fully upgraded crude oil, exposure to future crude oil prices, potential growth through high-quality oil sands leases and an attractive dividend.
 
Synthetic crude oil (SCO)
A high-quality product resulting from the mining, extraction and upgrading of bitumen.
 
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T
Tailings
A combination of water, sand, silt, fine clay particles and residual hydrocarbon that is a by-product of removing bitumen from oil sand.
 
Tailings systems
Separation of water from sand and clay to enable incorporation of solids into reclamation landscapes and recycling of water back into the operations.
 
Tar sands
Oil sands are also referred to as tar sands. Oil sands are a naturally occurring combination of clay, sands, water and bitumen (a heavy, black viscous oil), whereas tar is a man-made substance.
 
Total volume to bitumen in place (TV/BIP)
The ratio of total ore plus overburden volume to total bitumen in place.
 
Turnaround
A unit shutdown essential for good maintenance of the mining, producing and upgrading facilities. A turnaround reduces production but does not usually halt it entirely as the various operating units are often duplicated.
 
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U
Upgrader
A facility that upgrades bitumen (extra heavy oil) into synthetic crude oil.
 
Upgrading
The conversion of heavy bitumen into a lighter crude oil by increasing the ratio of hydrogen to carbon, either by removing carbon (coking) or adding hydrogen (hydroprocessing).
 
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V
Vacuum Distillation Unit (VDU)
Capable of processing 285,000 barrels of bitumen a day, the VDU pulls streams of light and heavy-gas oil from hot bitumen feed delivered by the diluents recovery unit.
 
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