<<
All financial figures are unaudited and in Canadian dollars unless
otherwise noted.
TSX - COS.UN
>>
CALGARY, Oct. 29 /CNW/ - Canadian Oil Sands Trust ("Canadian Oil Sands", the "Trust" or "we") today announced that third quarter 2008 cash from operating activities nearly doubled over the same period last year, increasing to $921 million ($1.91 per Trust unit ("Unit")) compared with $484 million ($1.01 per Unit) recorded in the 2007 third quarter. Year-to-date, cash from operating activities was up 76 per cent to $1.8 billion ($3.69 per Unit) compared with the same period of 2007. The increase in cash from operating activities on both a quarter and year-to-date basis reflects a higher realized selling price for our synthetic crude oil partially offset by lower sales volumes and higher operating and Crown royalties expenses. Net income for the third quarter 2008 was $604 million ($1.25 per Unit) compared with a net income of $361 million ($0.75 per Unit) for the 2007 period. Year-to-date, net income totaled $1.4 billion ($2.91 per Unit) in 2008 compared with net income of $228 million ($0.48 per Unit) for 2007. The improvement in net income was primarily the result of higher revenues net of higher operating costs and Crown royalties in 2008. As well, in the second quarter of 2007 the Trust recorded a one time future income tax expense of $701 million for the substantive enactment of trust taxation legislation, reducing net income in 2007. Despite very strong financial results for the third quarter of 2008, Canadian Oil Sands declared a 40 per cent reduction in the quarterly distribution amount to $0.75 per Unit for Unitholders of record on November 14, 2008, payable on November 28, 2008, in response to current market conditions. Canadian Oil Sands takes a long-term view of distributions that considers, among other criteria, current and expected economic and operating conditions. While our Syncrude operation is sound and strong, as a result of the deterioration in economic conditions, in particular the significant decline in crude oil prices and the heightened risk in the credit markets, we deem it prudent to reduce the distribution in order to maintain our strong balance sheet. Expanding on the impact of the current market condition on the Trust, Marcel Coutu, President and Chief Executive Officer of Canadian Oil Sands, said: "I would like to provide our Unitholders with Canadian Oil Sands' perspective on the financial turmoil that continues to restrict access to capital markets and create significant volatility in equity valuations. The fundamentals of Canadian Oil Sands and our Syncrude project remain among the very best in our industry, from both a long-life mining resource perspective and an ever-improving operational record in producing sweet, synthetic crude oil. "As Syncrude's Stage 3 expansion neared completion, we began redirecting cash flow to our Unitholders through quarterly distributions, which have risen from $0.20 per Unit in February 2006 to $1.25 per Unit in August 2008. The increase in distributions has been a reflection of rising crude oil prices, growing production, and reduced capital spending. The distributions also reflect the execution of our financing plan following the legislation of trust taxation post 2010. In this context, we have communicated to you our plan of distributing discretionary cash flow and allowing net debt to increase to about $1.6 billion by the end of 2010." "In addition to stable operations, our ability to execute this finance strategy hinges on two key factors: oil prices and competitive access to capital markets. Clearly, both of these factors have shifted dramatically in recent weeks. The price of WTI crude oil has quickly declined from approximately US$120 per barrel when the last distribution was established to approximately US$60 to US$70 per barrel during October 2008. As well, the turmoil in the financial markets has reduced the availability of new debt and substantially increased interest costs." "Having assessed these new market conditions, Canadian Oil Sands has decided to reduce the quarterly distribution amount to $0.75 per Unit to protect and maintain a strong liquidity position and financial flexibility during this market turmoil. Our $1.6 billion net debt target by the end of 2010 remains unchanged, but we must now consider more carefully the refinancing of approximately $500 million of 2009 debt maturities in addition to the incremental leverage to meet our objective. Until debt capital markets are available to execute this strategy on an efficient basis, Canadian Oil Sands will prudently preserve its liquidity by managing the rate at which its leverage rises. Should bank facilities or debt markets not be available to fund our mid-2009 debt maturities, further distribution reductions may be required in order to fund maturities out of cash from operating activities. With the significant cash flow we continue to generate at current oil prices and the $840 million of undrawn credit facilities, we are strongly positioned until the financial turmoil subsides." "The important message is that the fundamentals of Canadian Oil Sands and Syncrude's oil production business remain very robust. Our current marginal operating cost is about $35 per barrel and our sustaining maintenance capital requirements are about $10 per barrel. In the meantime we will continue to assess market conditions to prudently execute our strategy. Despite near-term expectations of reduced global demand, our view of future crude oil prices remains constructive, based primarily on supply-side constraints. We continue to be unhedged in the sale of our crude oil production, and our objective of maintaining a strong balance sheet is serving us well in this regard." Sales volumes in 2008 were seven per cent lower quarter-over-quarter and six per cent lower year-to-date compared with 2007, averaging about 116,700 barrels per day and 105,000 barrels per day during the third quarter and year-to-date, respectively, in 2008. Sales volumes in the third quarter of 2008 were reduced by a scheduled coker turnaround. The re-start of the coker has been delayed until the first week of November to enable repairs to an associated gas compressor. The delay is not expected to affect projected production volumes for 2008 of 106 million barrels, gross to Syncrude, because bitumen froth volumes will go into tankage, which can be processed in November and December. A scheduled turnaround of another coker was also successfully completed in the second quarter, and together with a disruption in operations during the first quarter resulted in lower volumes for the first nine months of 2008 compared with the same period of 2007. In 2007, unplanned maintenance occurred on two cokers as well as planned maintenance on other units however, this work was completed by the end of the second quarter, resulting in near design capacity production for the third quarter of 2007. Operating costs in the third quarter of 2008 were $32.15 per barrel, or $11.31 per barrel higher than the comparative 2007 quarter. Year-to-date in 2008, operating costs were $36.37 per barrel, or $11.89 per barrel more than the same period of 2007. In addition to reduced production volumes in 2008 compared with 2007, inflationary cost pressures and operational inefficiencies in 2008 contributed to the rise in operating costs. More information on operating costs is provided in the Management's Discussion and Analysis ("MD&A") section of this report. In the third quarter of 2008, Syncrude's total recordable injury rate was 0.57 for every 200,000 hours worked compared to a rate of 0.40 recorded for the same period of 2007. Syncrude releases 2007 Sustainability Report In September 2008, Syncrude released its 2007 Sustainability Report, which provides a comprehensive discussion about Syncrude's social, economic and environmental performance. The report is available at www.syncrude.ca.
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CANADIAN OIL SANDS TRUST
Highlights
(millions of Canadian Three Months Ended Nine Months Ended
dollars, except Trust September 30 September 30
unit and volume amounts) 2008 2007 2008 2007
-------------------------------------------------------------------------
Net Income $ 604 $ 361 $ 1,399 $ 228
Per Trust unit- Basic $ 1.25 $ 0.75 $ 2.91 $ 0.48
Per Trust unit- Diluted $ 1.25 $ 0.75 $ 2.91 $ 0.48
Cash from Operating
Activities $ 921 $ 484 $ 1,775 $ 1,010
Per Trust unit $ 1.91 $ 1.01 $ 3.69 $ 2.11
Unitholder Distributions $ 602 $ 192 $ 1,443 $ 527
Per Trust unit $ 1.25 $0.40 $ 3.00 $ 1.10
Sales Volumes(1)
Total (MMbbls) 10.8 11.5 28.7 30.3
Daily average (bbls) 116,656 124,904 104,571 110,927
Operating Costs per barrel $ 32.15 $ 20.84 $ 36.37 $ 24.48
Net Realized SCO Selling
Price per barrel $ 127.55 $ 81.48 $ 120.19 $ 75.94
West Texas Intermediate
(average $US per barrel)(2) $ 118.22 $ 75.15 $ 113.52 $ 66.22
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(1) The Trust's sales volumes differ from its production volumes due to
changes in inventory, which are primarily in-transit pipeline
volumes, and are net of purchased crude oil volumes.
(2) Pricing obtained from Bloomberg.
>>
2008 Outlook The Trust is maintaining its estimate for 2008 Syncrude production of 106 million barrels with a range of 103 to 109 million barrels (net to the Trust, equivalent to 39 million barrels with a range of 38 to 40 million barrels). We have reduced our estimate for average WTI prices in 2008 to US$102.00 per barrel, which reflects actual prices for the first nine months of 2008 and an assumption of US$66.98 per barrel for the fourth quarter. Combined with an anticipated reduction in Crown royalties payable in 2008 and an operating cost assumption largely unchanged at $35.47 per barrel, the estimate for cash from operating activities has declined to $4.58 per Unit. With the decrease in the distribution to $0.75 per Unit announced this quarter, we are estimating net debt levels of approximately $1.1 billion at the end of 2008. More information on the Trust's Outlook is provided in the MD&A section of this report and the October 29, 2008 guidance document, which is available on the Trust's web site at www.cos-trust.com under "investor information". All statements regarding 2008 year-end numbers or future events are qualified by the forward-looking advisory contained in the MD&A. MANAGEMENT'S DISCUSSION AND ANALYSIS The following Management's Discussion and Analysis ("MD&A") was prepared as of October 29, 2008 and should be read in conjunction with the unaudited interim consolidated financial statements of Canadian Oil Sands Trust ("Canadian Oil Sands" or the "Trust") for the nine months ended September 30, 2008 and September 30, 2007, and the audited consolidated financial statements and MD&A of the Trust for the year ended December 31, 2007 and the Trust's Annual Information Form ("AIF") dated March 15, 2008. Additional information on the Trust including its AIF is available on SEDAR at www.sedar.com or on the Trust's website at www.cos-trust.com. ADVISORY - in the interest of providing the Trust's Unitholders and potential investors with information regarding the Trust, including management's assessment of the Trust's future production and cost estimates, plans and operations, certain statements throughout this MD&A and the related press release contain "forward-looking statements" under applicable securities law. Forward-looking statements in this MD&A include, but are not limited to, statements with respect to: expectations regarding the sustainability of operations at certain levels of WTI prices; future distributions and any increase or decrease from current payment amounts; the belief that inflationary pressures will continue; the belief that operational reliability will improve over time and with that improvement that operating costs will be reduced; the expected level of sustaining capital for the next few years and longer term; the expectations regarding bitumen purchases; the expected net debt level at the end of 2008; the expected impact on the Trust and distributions and the expected structure to be assumed given the Federal government's tax changes effective in 2011; plans regarding refinancing of the 2009 debt maturities and views on future credit markets and availability of financing and the impact on distributions; expectations regarding future distribution levels; the cost estimate for the SER project and the expectation that the SER project will significantly reduce total sulphur dioxide and other emissions; the completion date for the SER project; the expected impact on the Trust from announced changes by the Alberta government regarding its royalty regime; any expectations regarding the enforceability of legal rights; the expected impact of any current and future environmental legislation, including without limitation, regulations relating to tailings; the expectation that there will not be any material funding increases relative to Syncrude's future reclamation costs or pension funding for the next year; improvements in operational reliability; the belief that the Trust will not be restricted by its net debt to total capitalization financial covenant; the expectation that no crude oil hedges will be entered into in the future; the expected realized selling price, which includes the anticipated differential to WTI, to be received in 2008 for Canadian Oil Sands' product; the potential amount payable in respect of any future income tax liability; the plans regarding future expansions of the Syncrude project and in particular all plans regarding Stage 4 development; the level of energy consumption in 2008 and beyond; capital expenditures for 2008; the level of natural gas consumption in 2008 and beyond; the expected price for crude oil and natural gas in 2008; the expected production, revenues and operating costs for 2008; and the anticipated impact that certain factors such as natural gas and oil prices, foreign exchange and operating costs have on the Trust's cash from operating activities and net income. 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 Trust believes that the expectations represented by such forward-looking statements are reasonable, there can be no assurance that such expectations will prove to be correct. 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 MD&A include, but are not limited to: the impacts of regulatory changes especially as such relate to royalties, taxation, and environmental charges; the impact of technology on operations and processes and how new complex technology may not perform as expected, labour shortages and the productivity achieved from labour in the Fort McMurray area; the supply and demand metrics for oil and natural gas; the impact that pipeline capacity and refinery demand have on prices for our products; the unanimous joint venture owner approval for major expansions; the variances of stock market activities generally; normal risks associated with litigation, general economic, business and market conditions; regulatory change, and such other risks and uncertainties described from time to time in the reports and filings made with securities regulatory authorities by the Trust. You are cautioned that the foregoing list of important factors is not exhaustive. No assurance can be given that the final legislation implementing the federal tax changes regarding income trusts will not be further changed in a manner which adversely affects the Trust and its Unitholders. Furthermore, the forward-looking statements contained in this MD&A are made as of the date of this MD&A, and unless required by law, the Trust 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 MD&A are expressly qualified by this cautionary statement. REVIEW OF SYNCRUDE OPERATIONS During the third quarter of 2008, crude oil production from the Syncrude Joint Venture ("Syncrude") totalled 29.1 million barrels, or about 316,000 barrels per day, compared with 32.1 million barrels, or about 348,000 barrels per day, during the same period of 2007. Net to the Trust, production totalled 10.7 million barrels in the third quarter of 2008 compared with 11.8 million barrels in 2007, based on our 36.74 per cent working interest. Production in the third quarter of 2008 was primarily impacted by a scheduled turnaround on Coker 8-2, which began in September. The restart of the coker, originally anticipated for late October, has been delayed until the first week of November to enable repairs to an associated gas compressor. The delay is not expected to affect projected production volumes for 2008 of 106 million barrels, gross to Syncrude, because bitumen froth volumes will go into tankage, which can be processed in November and December. During the third quarter of 2007, production was relatively stable and was not significantly affected by maintenance activities. Year-to-date, Syncrude produced 77.5 million barrels in 2008, or about 283,000 barrels per day, compared with 82.6 million barrels, or about 302,000 barrels per day in 2007. In addition to the coker turnarounds during the second and third quarters, production in the first nine months of 2008 was impacted by a disruption in operations that was compounded by extremely cold weather during the first quarter. The cold weather during the first quarter of 2008 also affected bitumen production and extraction. By comparison, production in the first nine months of 2007 was impacted by unplanned maintenance on Coker 8-3 and Coker 8-2, and planned maintenance on other units. Operating costs increased to $32.15 per barrel in the third quarter of 2008, up $11.31 per barrel from the same quarter last year. Year-to-date operating costs were $36.37 per barrel in 2008 versus $24.48 per barrel in 2007 (see the "Operating costs" section of this MD&A for further discussion). Syncrude's facilities have the design capability to produce approximately 375,000 barrels per day when operating at full capacity under optimal conditions and with no downtime for maintenance or turnarounds. Under normal operating conditions, scheduled downtime is required for maintenance and turnaround activities and unscheduled downtime will occur as a result of operational and mechanical problems, unanticipated repairs and other slowdowns. When allowances for such downtime are included, the daily design productive capacity of Syncrude's facilities is approximately 350,000 barrels per day on average and is referred to as "barrels per calendar day". All references to Syncrude's productive capacity in this report refer to barrels per calendar day, unless stated otherwise. The Trust's production volumes differ from its sales volumes due to changes in inventory, which are primarily in-transit pipeline volumes that vary with current production. The impact of Syncrude's 2008 operations on Canadian Oil Sands' financial results is more fully discussed later in this MD&A.
<<
SUMMARY OF QUARTERLY RESULTS
($ millions, except per
Trust Unit and volume 2008 2007
amounts) Q3 Q2 Q1 Q4
-------------------------------------------------------------------------
Revenues(1) $ 1,381 $ 1,177 $ 907 $ 950
Net income (loss) $ 604 $ 497 $ 298 $ 515
Per Trust Unit, Basic $ 1.25 $ 1.04 $ 0.62 $ 1.07
Per Trust Unit, Diluted $ 1.25 $ 1.04 $ 0.62 $ 1.07
Cash from operating
activities $ 921 $ 413 $ 441 $ 367
Per Trust Unit(2) $ 1.91 $ 0.86 $ 0.92 $ 0.77
Unitholder distributions $ 602 $ 481 $ 360 $ 264
Per Trust Unit $ 1.25 $ 1.00 $ 0.75 $ 0.55
Daily average sales volumes
(bbls) 116,656 97,744 99,181 116,368
Net realized SCO selling
price ($/bbl)(3) $ 127.55 $ 131.32 $ 100.41 $ 88.73
Operating costs ($/bbl)(4) $ 32.15 $ 41.92 $ 35.93 $ 27.38
Purchased natural gas price
($/GJ) $ 7.86 $ 9.38 $ 7.30 $ 5.84
West Texas Intermediate
(avg. US$/bbl)(5) $ 118.22 $ 123.80 $ 97.82 $ 90.50
Foreign exchange rates
(US$/Cdn$):
Average $ 0.96 $ 0.99 $ 1.00 $ 1.02
Quarter - end $ 0.94 $ 0.98 $ 0.97 $ 1.01
($ millions, except per
Trust Unit and volume 2007 2006
amounts) Q3 Q2 Q1 Q4
-------------------------------------------------------------------------
Revenues(1) $ 936 $ 690 $ 674 $ 646
Net income (loss) $ 361 $ (395) $ 262 $ 128
Per Trust Unit, Basic $ 0.75 $ (0.82) $ 0.55 $ 0.27
Per Trust Unit, Diluted $ 0.75 $ (0.82) $ 0.54 $ 0.27
Cash from operating
activities $ 484 $ 324 $ 202 $ 412
Per Trust Unit(2) $ 1.01 $ 0.68 $ 0.42 $ 0.88
Unitholder distributions $ 192 $ 191 $ 144 $ 140
Per Trust Unit $ 0.40 $ 0.40 $ 0.30 $ 0.30
Daily average sales volumes
(bbls) 124,904 98,720 108,981 110,185
Net realized SCO selling
price ($/bbl)(3) $ 81.48 $ 76.81 $ 68.69 $ 63.71
Operating costs ($/bbl)(4) $ 20.84 $ 30.13 $ 23.56 $ 23.60
Purchased natural gas price
($/GJ) $ 4.99 $ 6.78 $ 6.99 $ 6.51
West Texas Intermediate
(avg. US$/bbl)(5) $ 75.15 $ 65.02 $ 58.23 $ 60.16
Foreign exchange rates
(US$/Cdn$):
Average $ 0.96 $ 0.91 $ 0.85 $ 0.88
Quarter - end $ 1.00 $ 0.94 $ 0.87 $ 0.86
(1) Revenues after crude oil purchases and transportation expense.
(2) Cash from operating activities per Trust Unit is a non-GAAP measure
that is derived from cash from operating activities reported on the
Trust's Consolidated Statements of Cash Flows divided by the
weighted-average number of Trust Units outstanding in the period, as
used in the Trust's net income per Unit calculations.
(3) Net realized SCO selling price after foreign currency hedging.
(4) Derived from operating costs as reported on the Trust's Consolidated
Statements of Income and Comprehensive Income, divided by the sales
volumes during the period.
(5) Pricing obtained from Bloomberg.
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During the last eight quarters, the following items have had a significant
impact on the Trust's financial results:
- U.S. dollar West Texas Intermediate ("WTI") oil prices, which impact
the Trust's revenues, increased significantly in the 2008 periods
relative to the 2007 and 2006 time periods.
- The substantive enactment of income tax legislation in June 2007 to
apply a new tax on distributions from Canadian public trusts starting
in 2011 resulted in an additional future income tax expense of
$701 million in the second quarter of 2007. Other corporate tax rate
reductions substantively enacted in the fourth and second quarters of
2007 resulted in future income tax recoveries of $153 million and
$38 million in each quarter, respectively.
- On January 2, 2007 the Trust acquired a 1.25 per cent working
interest in Syncrude from Talisman Energy Inc. Commencing in 2007,
the Trust's financial results reflect a 36.74 per cent working
interest in Syncrude while the 2006 financial results reflect the
Trust's previous ownership of 35.49 per cent.
- U.S. to Canadian dollar exchange rate fluctuations have impacted
commodity pricing and have resulted in significant unrealized foreign
exchange gains and losses on the revaluation of U.S. dollar
denominated debt.
>>
Quarterly variances in revenues, net income, and cash from operating activities are caused by fluctuations in crude oil prices, production and sales volumes, operating costs and natural gas prices. Net income also is impacted by foreign exchange gains and losses and by future income tax amounts. A large proportion of operating costs are fixed and, as such, per barrel operating costs are highly variable to production volumes. While the supply/demand balance for crude oil affects selling prices, the impact of this equation is difficult to predict and quantify and has not displayed significant seasonality. Maintenance and turnaround activities are typically scheduled to avoid the winter months; however, the exact timing of unit shutdowns cannot be precisely scheduled, and unplanned outages may occur. Accordingly, production levels may not display reliable seasonality patterns or trends. Maintenance and turnaround costs are expensed in the period incurred and can lead to significant increases in operating costs and reductions in production in those periods. Natural gas prices are typically higher in winter months as heating demand rises, but this seasonality is significantly influenced by weather conditions and North American natural gas inventory levels. REVIEW OF FINANCIAL RESULTS In the third quarter of 2008, net income amounted to $604 million, or $1.25 per Trust unit ("Unit"), compared with net income of $361 million, or $0.75 per Unit, recorded in the comparable quarter in 2007, primarily as a result of higher revenues net of higher operating costs and Crown royalties. Year-to-date net income totaled $1.4 billion, or $2.91 per Unit in 2008 compared with net income of $228 million, or $0.48 per Unit, recorded in 2007. The improvement in net income was primarily the result of higher revenues net of higher operating costs and Crown royalties in 2008 without the impact of the one-time future income tax expense of $701 million that was recorded in the second quarter of 2007. Cash from operating activities increased to $921 million for the third quarter of 2008 versus $484 million for the third quarter of 2007. Year-to-date cash from operating activities increased to $1.8 billion for 2008 versus $1.0 billion for 2007. The increase in cash from operating activities was the result of the higher revenues net of increases in operating expenses, Crown royalties and changes in non-cash working capital. Changes in non-cash working capital increased cash from operating activities by $164 million in the third quarter of 2008, primarily as a result of lower accounts receivable at September 30, 2008 versus June 30, 2008. The decline in accounts receivable was the result of lower sales volumes and oil prices in September 2008 versus June 2008. In the third quarter of 2007, changes in non-cash working capital increased cash from operating activities by $14 million, primarily as a result of higher accounts receivable net of higher accounts payable at September 30, 2007 relative to June 30, 2007. Year-to-date changes in non-cash working capital increased cash from operating activities by $28 million in 2008, primarily as a result of higher accounts payable at September 30, 2008 relative to December 31, 2007. In the same period of 2007, changes in non-cash working capital decreased cash from operating activities by $23 million, primarily as a result of higher accounts receivable offset by higher accounts payable at September 30, 2007 relative to December 31, 2007. Non-cash working capital and changes therein can vary on a period-by-period basis as a result of the timing and settlements of accounts receivable and accounts payable balances, and are impacted by a number of factors including changes in revenue, operating expenses, Crown royalties, the timing of capital expenditures, and inventory fluctuations.
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Net Income per Barrel
Three Months Ended Nine Months Ended
September 30 September 30
($ per bbl)(1) 2008 2007 Variance 2008 2007 Variance
-------------------------------------------------------------------------
Revenues after crude
oil purchases and
transportation
expense 128.66 81.48 47.18 120.93 75.94 44.99
Operating costs (32.15) (20.84) (11.31) (36.37) (24.48) (11.89)
Crown royalties (21.50) (14.32) (7.18) (18.83) (11.49) (7.34)
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75.01 46.32 28.69 65.73 39.97 25.76
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Non-production costs (1.95) (1.40) (0.55) (1.87) (1.62) (0.25)
Administration
and insurance (0.44) (0.54) 0.10 (0.70) (0.67) (0.03)
Interest, net (1.52) (1.83) 0.31 (1.73) (2.24) 0.51
Depletion,
depreciation and
accretion (11.35) (8.76) (2.59) (11.36) (8.60) (2.76)
Foreign exchange
gain (loss) (2.99) 3.59 (6.58) (1.85) 3.69 (5.54)
Future income tax
(expense) recovery
and other (0.52) (5.94) 5.42 0.64 (23.01) 23.65
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(18.77) (14.88) (3.89) (16.87) (32.45) 15.58
-------------------------------------------------------------------------
Net income per
barrel 56.24 31.44 24.80 48.86 7.52 41.34
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Sales volumes
(MMbbls) 10.8 11.5 (0.7) 28.7 30.3 (1.6)
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-------------------------------------------------------------------------
(1) Unless otherwise specified, net income and other per barrel measures
in this MD&A have been derived by dividing the relevant revenue or
cost item by the sales volumes in the period.
>>
Non-GAAP Financial Measures In this MD&A we refer to financial measures that do not have any standardized meaning as prescribed by Canadian Generally Accepted Accounting Principles ("GAAP"). These non-GAAP financial measures include cash from operating activities on a per Unit basis, net debt, total capitalization and certain per barrel measures. These non-GAAP financial measures provide additional information that we believe is meaningful regarding the Trust's operational performance, its liquidity and its capacity to fund distributions, capital expenditures and other investing activities. Users are cautioned that non-GAAP financial measures presented by the Trust may not be comparable with measures provided by other entities.
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Revenues after Crude Oil Purchases and Transportation Expense
Three Months Ended Nine Months Ended
September 30 September 30
($ millions) 2008 2007 Variance 2008 2007 Variance
-------------------------------------------------------------------------
Sales revenue(1) $ 1,462 $ 1,033 $ 429 $ 3,772 $ 2,618 $ 1,154
Crude oil purchases (73) (91) 18 (283) (299) 16
Transportation
expense (9) (8) (1) (27) (27) -
-------------------------------------------------------------------------
1,380 934 446 3,462 2,292 1,170
Currency hedging
gains(1) 1 2 (1) 3 8 (5)
-------------------------------------------------------------------------
$ 1,381 $ 936 $ 445 $ 3,465 $ 2,300 $ 1,165
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Sales volumes
(MMbbls)(2) 10.8 11.5 (0.7) 28.7 30.3 (1.6)
-------------------------------------------------------------------------
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(1) The sum of sales revenue and currency hedging gains equals Revenues
on the Trust's Consolidated Statements of Income and Comprehensive
Income. Sales revenue includes revenue from the sale of purchased
crude oil and sulphur revenue.
(2) Sales volumes, net of purchased crude oil volumes.
($ per barrel)
-------------------------------------------------------------------------
Realized SCO
selling price
before hedging(3) $127.46 $ 81.23 $ 46.23 $120.09 $ 75.66 $ 44.43
Currency hedging
gains 0.09 0.25 (0.16) 0.10 0.28 (0.18)
-------------------------------------------------------------------------
Net realized SCO
selling price $127.55 $ 81.48 $ 46.07 $120.19 $ 75.94 $ 44.25
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(3) SCO sales revenue after crude oil purchases and transportation
expense divided by sales volumes, net of purchased crude oil volumes.
>>
The increase in sales revenue for 2008 versus 2007 on a quarterly and on a year-to-date basis was due to a higher realized selling price for our synthetic crude oil ("SCO") offset by a decline in sales volumes. The increase in the SCO selling price primarily reflects the increase in WTI prices in 2008. During the third quarter of 2008, WTI prices averaged US$118.22 per barrel compared to US$75.15 per barrel for the third quarter of 2007. Year-to-date, WTI prices averaged US$113.52 per barrel in 2008 versus US$66.22 per barrel in 2007. This increase in US dollar WTI prices on a year-to-date basis was tempered, however, by a stronger Canadian dollar, which averaged $0.98 US/Cdn in 2008 compared with $0.90 US/Cdn in 2007. On a quarterly basis, the Canadian dollar averaged $0.96 US/Cdn for both 2008 and 2007. In addition to the increase in WTI prices, our SCO continued to receive a premium to Canadian dollar WTI (the "differential") in 2008. In the third quarter of 2008, the Trust's SCO realized a weighted-average premium of $3.78 per barrel compared with the average Canadian dollar WTI price versus a premium of $2.60 per barrel in the same period in 2007. Year-to-date in 2008, the Trust's SCO realized a weighted-average premium of $3.21 per barrel relative to the average Canadian dollar WTI price versus a premium of $2.40 per barrel for 2007. The Trust's sales volumes for the third quarter of 2008 averaged about 116,700 barrels per day versus an average of about 124,900 barrels per day in the third quarter of 2007. Year-to-date sales volumes averaged about 104,600 barrels per day in 2008 versus an average of about 110,900 barrels per day for 2007. Sales volumes for 2008 were impacted by the scheduled turnarounds of Cokers 8-2 and 8-1 and by operational difficulties during the first quarter. Sales volumes in 2007 were impacted by maintenance on Coker 8-3, Coker 8-2 and other units.
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Operating Costs
Three Months Ended Nine Months Ended
September 30 September 30
2008 2007 2008 2007
-------------------------------------------------------------------------
$/bbl $/bbl $/bbl $/bbl $/bbl $/bbl $/bbl $/bbl
Bitumen SCO Bitumen SCO Bitumen SCO Bitumen SCO
-------------------------------------------------------------------------
Bitumen Costs(1)
Bitumen
production(2) 15.23 9.71 15.39 10.14
Purchased
energy(2),(4) 2.41 1.23 2.97 2.13
Purchased
bitumen - - 1.22 -
-------------------------------------------------------------------------
17.64 19.60 10.94 12.31 19.58 23.08 12.27 14.49
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Upgrading Costs(3)
Bitumen
processing and
upgrading(2) 5.85 3.83 5.85 4.58
Turnaround and
catalysts 2.06 0.25 2.07 1.26
Purchased
energy(4) 3.83 2.34 4.15 2.48
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11.74 6.42 12.07 8.32
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Other and
research(2) (0.18) 0.87 1.29 1.05
Change in treated
and untreated
inventory 0.81 0.63 (0.10) 0.10
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Total Syncrude
operating
costs 31.97 20.23 36.34 23.96
Canadian Oil
Sands
adjustments(5) 0.18 0.61 0.03 0.52
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Total operating
costs 32.15 20.84 36.37 24.48
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(thousands of
barrels per
day) Bitumen SCO Bitumen SCO Bitumen SCO Bitumen SCO
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Syncrude
production
volumes(6) 351 316 392 348 333 283 357 302
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(1) Bitumen costs relate to the removal of overburden, oil sands mining,
bitumen extraction and tailings dyke construction and disposal costs.
The costs are expressed on a per barrel of bitumen production basis
and converted to a per barrel of SCO based on the effective yield of
SCO from the processing and upgrading of bitumen.
(2) Prior year information has been restated for comparative purposes to
conform to a revised presentation of costs.
(3) Upgrading costs include the production and ongoing maintenance costs
associated with processing and upgrading of bitumen to SCO. It also
includes the costs of major upgrading equipment turnarounds and
catalyst replacement, all of which are expensed as incurred.
(4) Natural gas prices averaged $7.86/GJ and $4.99/GJ in the third
quarter of 2008 and 2007, respectively. For the first nine months of
the year, natural gas costs averaged $8.13/GJ and $6.25/GJ in 2008
and 2007, respectively.
(5) Canadian Oil Sands' adjustments mainly pertain to Syncrude-related
pension costs, as well as the inventory impact of moving from
production to sales as Syncrude reports per barrel costs based on
production volumes and the Trust reports based on sales volumes.
(6) Syncrude production volumes include the impact of processed purchased
bitumen volumes.
Three Months Ended Nine Months Ended
September 30 September 30
($/bbl of SCO) 2008 2007 2008 2007
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Production costs 25.64 17.12 28.72 19.48
Purchased energy 6.51 3.72 7.65 5.00
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Total operating costs 32.15 20.84 36.37 24.48
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(GJs/bbl of SCO)
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Purchased energy consumption 0.83 0.75 0.94 0.80
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>>
In the third quarter of 2008, operating costs were $345 million, averaging $32.15 per barrel, an increase of $106 million, or $11.31 per barrel, over the third quarter of 2007 operating costs of $239 million. Year-to-date operating costs were approximately $1.0 billion in 2008, averaging $36.37 per barrel, an increase of $301 million, or $11.89 per barrel over 2007. The change in costs for the reported periods is primarily due to the following:
<<
- additional overburden material was moved during the first three
quarters of 2008 versus 2007. Syncrude also increased its use of
contracted equipment and operators to supplement its own material
movement activities in 2008 in order to increase exposed mineable ore
inventory and meet operational requirements;
- increased costs for contractors and wages for Syncrude staff on a
quarterly and on a year-to-date basis as a result of inflationary
pressures and contract settlements;
- higher energy costs reflecting higher natural gas prices and
increased purchased energy consumption on per barrel basis due to
operational inefficiencies during 2008;
- the purchase of incremental bitumen during the first half of 2008 to
support production during times of internal bitumen supply
shortfalls;
- inflationary pressure for materials and consumables;
- additional costs during the first quarter of 2008 associated with
resuming shipments at Syncrude following the disruption of operations
early in the year;
- turnaround costs were incurred in the third quarter of 2008 while
there were no associated turnaround costs during the third quarter of
2007; and
- changes in the value of Syncrude's long term incentive plan in 2008
versus 2007. A portion of Syncrude's long-term incentive plans is
based on the market return performance of several Syncrude owners'
shares and units, the market performance of which was weaker in the
third quarter of 2008 relative to the same period in 2007. There was
no significant change in year-to-date costs for Syncrude's long term
incentive plans in 2008 versus 2007.
>>
Operating costs per barrel also have increased in 2008 as a result of reduced production volumes in 2008 versus 2007 on a quarterly and year-to-date basis. A significant portion of Syncrude's operating costs are fixed and as such, any change in production impacts per unit operating costs. While inflationary pressures are expected to persist, improvements in operational reliability should help to reduce the costs related to the operational inefficiencies experienced during 2008. Non-Production Costs Non-production costs totalled $21 million and $16 million in the third quarters of 2008 and 2007, respectively. Year-to-date non-production costs totalled $54 million for 2008 and $49 million for 2007. Non-production costs consist primarily of development expenditures relating to capital programs, which are expensed, such as: commissioning costs, pre-feasibility engineering, technical and support services, research and development, and regulatory and stakeholder consultation expenditures. Non-production costs can vary on a periodic basis depending on the number of projects underway and the status of the projects. Crown Royalties In the third quarter of 2008, Crown royalties increased to $231 million, or $21.50 per barrel, from $165 million, or $14.32 per barrel, in the comparable 2007 quarter. Year-to-date Crown royalties increased to $540 million, or $18.83 per barrel, in 2008 from $348 million, or $11.49 per barrel in 2007. The increase in royalties in 2008 on both a quarterly and a year-to-date basis was primarily due to significantly increased revenues partially offset by higher operating costs and higher capital expenditures. In 2007, the Alberta government announced new Crown royalty terms, effective January 1, 2009. For oil sands projects, the new terms are based on a sliding scale royalty rate that responds to Canadian dollar equivalent WTI ("C$-WTI") price levels. The minimum royalty rate is proposed to start at one per cent of revenue and increase for every dollar oil is priced above $55 C$-WTI per barrel, to nine per cent of revenue at $120 C$-WTI per barrel or higher. The net royalty rate will start at 25 per cent of net revenue and rise for every dollar of C$-WTI increase above $55 C$-WTI per barrel up to 40 per cent of net revenue at $120 C$-WTI per barrel or higher. The Syncrude Joint Venture owners have a Crown royalty agreement with the Alberta government that codifies the current royalty terms of 25 per cent of net SCO revenues to December 31, 2015. The Crown royalty agreement also provides Syncrude with the option to convert to a bitumen-based royalty, consistent with the rest of the industry, prior to 2010. Canadian Oil Sands, as one of the Syncrude owners, is currently in discussions with the Alberta government regarding both the conversion to a bitumen-based royalty and an equitable solution to offset Syncrude's transition to the higher generic royalty rate prior to 2016. Canadian Oil Sands remains of the view that any transition to the new generic royalty terms must recognize our legal rights to the embedded value in Syncrude's contract with the Alberta government.
<<
Interest Expense, Net
Three Months Ended Nine Months Ended
September 30 September 30
2008 2007 2008 2007
-------------------------------------------------------------------------
Interest expense on
long-term debt $ 18 $ 22 $ 56 $ 71
Interest income and other (2) (1) (7) (3)
-------------------------------------------------------------------------
Interest expense, net $ 16 $ 21 $ 49 $ 68
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The Trust's net interest expense in 2008 has decreased relative to the
comparable periods in 2007 due to reduced average net debt outstanding.
Depreciation, Depletion and Accretion Expense
Three Months Ended Nine Months Ended
September 30 September 30
-------------------------------------------------------------------------
($ millions) 2008 2007 2008 2007
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Depreciation and depletion
expense $ 118 $ 98 $ 315 $ 252
Accretion expense 3 3 10 8
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$ 121 $ 101 $ 325 $ 260
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>>
The increase in depreciation and depletion ("D&D") expense in 2008 on a quarterly and on a year-to-date basis versus 2007 was due to a higher per barrel D&D rate. In 2008 the D&D rate per barrel of production increased to $11.07 from $8.31 in 2007 as a result of higher projected capital cost estimates for Syncrude in the Trust's December 31, 2007 independent reserves report.
<<
Foreign Exchange Loss (Gain)
Three Months Ended Nine Months Ended
September 30 September 30
($ millions) 2008 2007 2008 2007
-------------------------------------------------------------------------
Unrealized foreign exchange
loss (gain) $ 36 $ (59) $ 62 $ (146)
Realized foreign exchange
loss (gain) (4) 17 (9) 34
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Total foreign exchange
loss (gain) $ 32 $ (42) $ 53 $ (112)
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>>
Unrealized foreign exchange ("FX") gains and losses are the result of revaluations of our U.S. dollar denominated long-term debt caused by fluctuations in U.S. and Canadian dollar exchange rates. The unrealized FX gains and losses reported in 2008 resulted from the change in the value of the Canadian dollar relative to the U.S. dollar to $0.94 US/Cdn at September 30, 2008 from $0.98 US/Cdn at June 30, 2008 and $1.01 US/Cdn at December 31, 2007. The unrealized FX gains in 2007 were due to the change in the value of the Canadian dollar relative to the U.S. dollar to $1.00 US/Cdn at September 30, 2007 from $0.94 US/Cdn at June 30, 2007 and $0.86 US/Cdn at December 31, 2006. Future Income Tax and Other In the third quarter of 2008, a $6 million future income tax expense was recorded on the increase of temporary differences versus a future income tax expense of $69 million in the third quarter of 2007. On a year-to-date basis, a future income tax recovery of $18 million was recorded in 2008 on the reduction of temporary differences compared with a future income tax expense of $697 million in 2007. Prior to the substantive enactment of Bill C-52 in June 2007, the federal government's legislation to tax distributions from income trusts commencing in 2011, Canadian Oil Sands' future income taxes reflected only those temporary differences in the Trust's subsidiaries. On the substantive enactment of Bill C-52, Canadian Oil Sands recorded a one-time $701 million future income tax expense and a corresponding future income tax liability during the second quarter of 2007 related to the differences between the accounting and tax basis of the Trust's assets and liabilities. In June 2008, Bill C-50, which contains legislation to adjust the deemed provincial component on the tax rate on distributions from income and royalty trusts expected to apply to Canadian Oil Sands commencing in 2011, passed third reading in the House of Commons. Under this legislation, we expect the provincial component of the tax applicable to Canadian Oil Sands will be reduced from 13 per cent to 10 per cent as substantially all of Canadian Oil Sands' activities are in Alberta. For accounting purposes the adjustment to the provincial component of the tax is not considered substantively enacted as the income tax regulations for the adjustment have not been finalized. If the proposal becomes enacted, we expect to record a future income tax recovery based on the temporary differences at that time. On July 14, 2008, the Department of Finance released draft legislation for income and royalty trust conversions. The draft legislation, which was subject to public comment, is designed to permit income and royalty trusts to convert into public corporations without triggering adverse tax consequences to the income or royalty trust and its unitholders. With the taxation of income trusts commencing January 1, 2011Canadian Oil Sands has evaluated alternatives as to the best structure for its Unitholders in the future. Based on the current information and subject to the finalization of tax legislation, we will likely convert to a corporation. We plan, however, to retain the flow-through advantages of a trust structure until 2011 unless circumstances arise that favor a faster transition. Canadian Oil Sands continues to be a long-term value investment in the oil sands and does not rely on the tax efficiency of a flow-through trust model to sustain its business. Our long-life reserves and virtually non-declining production profile provide a solid foundation to generate future cash from operating activities. CHANGES IN ACCOUNTING POLICIES In its audited consolidated financial statements for the year ended December 31, 2007 ("Audited 2007 Financial Statements"), Canadian Oil Sands adopted the requirements of the Canadian Institute of Chartered Accountants ("CICA") Section 3862 Financial Instruments - Disclosures, Section 3863 Financial Instruments - Presentation and Section 1535 - Capital Disclosures. These standards were effective January 1, 2008, however, early adoption was encouraged by the CICA. Additional disclosures required as a result of adopting the standards can be found in the Trust's Audited 2007 Financial Statements. In June 2007, the CICA issued a new accounting standard Section 3031 Inventories, which replaces the existing standard for inventories, Section 3030. The main features of the new section are as follows:
<<
- measurement of inventories at the lower of cost and net realizable
value;
- consistent use of either first-in, first-out or a weighted average
cost formula to measure cost; and
- reversal of previous write-downs to net realizable value when there
is a subsequent increase to the value of inventories.
>>
The new inventory standard is effective for the Trust beginning January 1, 2008. Application of the new standard did not have an impact on the Trust's financial statements. NEW ACCOUNTING PRONOUNCEMENTS In February 2008, the CICA issued a new accounting standard, Section 3064 - Goodwill and Intangible Assets, which replaces Section 3062 - Goodwill and Other Intangible Assets, and Section 3450 - Research and Development costs. The new section establishes standards for the recognition, measurement and disclosure of goodwill and intangible assets. The section is effective for the Trust beginning January 1, 2009. Application of the new section is not expected to have a material impact on the Trust's financial statements. On February 13, 2008 the CICA Accounting Standards Board announced that Canadian public reporting issuers will be required to report under International Financial Reporting Standards ("IFRS") starting in 2011. Canadian Oil Sands has commenced assessing the impact on our business of adopting IFRS in 2011 and is preparing for the transition accordingly.
<<
UNITHOLDER DISTRIBUTIONS
Three Months Ended Nine Months Ended
September 30 September 30
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($ millions) 2008 2007 2008 2007
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Cash from operating
activities $ 921 $ 484 $ 1,775 $ 1,010
Net income $ 604 $ 361 $ 1,399 $ 228
Unitholder distributions $ 602 $ 192 $ 1,443 $ 527
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Excess (shortfall) of cash
from operating activities
over Unitholder
distributions $ 319 $ 292 $ 332 $ 483
Excess (shortfall) of net
income over Unitholder
distributions $ 2 $ 169 $ (44) $ (299)
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>>
In the third quarter of 2008, cash from operating activities exceeded Unitholder distributions by $319 million. On a year-to-date basis, cash from operating activities in 2008 exceeded Unitholder distributions by $332 million. During 2008, cash from operating activities was sufficient to fund the Trust's distributions, capital expenditures, reclamation trust fund contributions and the majority of debt repayments. Total distributions during 2008 exceeded net income on a year-to-date basis primarily as a result of DD&A, which is a non-cash item that does not affect the Trust's cash from operating activities or ability to pay distributions over the next several years. The Trust uses debt and equity financing to the extent that cash from operating activities and existing cash balances are insufficient to fund distributions, capital expenditures, reclamation trust contributions, debt repayments, acquisitions and working capital changes from financing and investing activities. On October 29, 2008 the Trust declared a quarterly distribution of $0.75 per Unit in respect of the fourth quarter of 2008 for a total distribution of $361 million. The distribution will be paid on November 28, 2008 to Unitholders of record on November 14, 2008. Quarterly distributions are approved by our Board of Directors after considering the current and expected economic conditions, ensuring financing capacity for Canadian Oil Sands' capital requirements, and with the objective of maintaining an investment grade credit rating. In establishing the distribution amount for the current quarter the Trust has recognized both the significant decrease in crude oil prices and the turmoil in worldwide credit markets. The price of WTI crude oil has quickly declined from approximately US$120 per barrel when the last distribution was established to approximately US$60 to US$70 per barrel during October 2008. While the decrease in commodity prices has been partially offset by a weakening Canadian dollar, if lower oil prices persist, cash from operating activities and our ability to fund distributions and capital expenditures will significantly decline. In addition, as a result of the ongoing credit market and banking turmoil, there is heightened financing risk around the ability of the Trust to prudently access the capital markets. The Trust has approximately $500 million of bonds maturing within the next ten months, and had planned on refinancing these debt instruments through credit facility draws and eventual refinancing in the capital markets. With the recent credit market turmoil, risk around accessing these markets in a cost-effective manner has risen. During this period of heightened financing risk, we believe that it is prudent to reduce the rate at which leverage levels rise to maintain liquidity and financial flexibility. As the financial markets calm and there is more certainty around the ability to access the markets in an efficient and cost-effective manner, we still plan on refinancing the 2009 debt maturities and increasing our net debt to about $1.6 billion by the end of 2010. At current market prices, the Trust continues to generate significant cash from operating activities and is currently undrawn on its $840 million of credit facilities. We are therefore well positioned to execute our financial and operating strategies. The current distribution continues to reflect the Trust's financial plan of managing its capital structure in anticipation of trust taxation in 2011. The Trust has been distributing a fuller amount of its cash from operating activities, and still targets long-term net debt of about $1.6 billion by the end of 2010. We believe this net debt target reflects efficient capital management and will help conserve tax pools prior to trust taxation. The target is based on Syncrude's existing productive capacity and we will reconsider this target in light of Canadian Oil Sands future capital requirement plans and any growth opportunities. In determining the Trust's distributions, Canadian Oil Sands also considers funding for its significant operating obligations, which are included in cash from operating activities. Such obligations include the Trust's share of Syncrude's pension and reclamation funding, which amounted to $32 million and $30 million on a year-to-date basis in 2008 and 2007, respectively, and approximated the related expense for both pension and reclamation of $38 million and $32 million for each of the periods, respectively. While our share of Syncrude's annual pension funding has increased modestly as a result of the most recent actuarial valuation and our share of Syncrude's future reclamation costs also has increased, we currently do not anticipate any material increases in funding related to these items for the next year. Debt covenants do not specifically limit the Trust's ability to pay distributions and are not expected to influence the Trust's liquidity in the foreseeable future. Aside from covenants relating to restrictions on Canadian Oil Sands' ability to sell all or substantially all of its assets or to change the nature of its business, the most restrictive financial covenant limits total debt-to-total capitalization at an amount less than 55 per cent. With a current net debt-to-total capitalization of approximately 20 per cent, a significant increase in debt or decrease in equity would be required to restrict the Trust's financial flexibility. Cash from operating activities and net income can fluctuate dramatically from period to period reflecting, among other things, variability in operational performance, WTI prices, SCO differentials to WTI and FX rates. The Trust strives to smooth out the effect of this variability on distributions by taking a longer-term view of our outlook for our operating and business environment, our net debt level relative to our target, and our capital expenditure and other commitments. In that regard, we may distribute more or less in a period than we generate in cash from operating activities or net income. Nonetheless, the highly variable nature of our cash from operating activities introduces risk in our ability to sustain or provide stability in distributions and any expectations regarding the stability or sustainability of distributions are unwarranted and should not be implied. As the Trust executes its financial plan and crude oil prices remain volatile, investors should anticipate increased variability in distributions and understand that current distribution levels may not be sustainable once we have reached our net debt target. As distributions comprise a larger percentage of cash from operating activities, the distributions will necessarily be more reflective of business performance and crude oil prices. Further, the taxation of income trusts commencing January 1, 2011 likely will materially alter our cash from operating activities and consequently distribution levels.
<<
LIQUIDITY AND CAPITAL RESOURCES
September 30 December 31
($ millions) 2008 2007
-------------------------------------------------------------------------
Long-term debt $ 1,116 $ 1,218
Cash and cash equivalents (278) (268)
-------------------------------------------------------------------------
Net debt(1) $ 838 $ 950
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Unitholders' equity $ 4,148 $ 4,172
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Total capitalization(2) $ 4,986 $ 5,122
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(1) Non-GAAP measure
(2) Net debt plus Unitholders' equity
Net debt to total capitalization (%) 17 19
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>>
As at September 30, 2008 the Trust had $840 million of credit facilities available and unutilized. In addition, the Trust had $67 million in letters of credit issued against a separate line of credit. During the second quarter of 2008, the Trust repaid $150 million of medium term notes that matured. Canadian Oil Sands has set a long-term net debt target of approximately $1.6 billion by the end of 2010. The Trust's actual net debt will fluctuate, however, as factors such as actual crude oil prices, Syncrude's operational performance, distributions, and FX rates vary from our assumptions. CAPITAL EXPENDITURES With the completion of Syncrude's Stage 3 project in 2006, Canadian Oil Sands' expansion capital expenditures have declined and capital costs for 2008 and 2007 are primarily related to sustaining capital. The Trust defines expansion capital expenditures as the costs incurred to grow the productive capacity of the operation, such as the Stage 3 project, while sustaining capital is effectively all other capital. Sustaining capital expenditures may fluctuate considerably year-to-year due to the timing of equipment replacement and other factors. The productive capacity of Syncrude's operations was previously described in the "Review of Syncrude Operations" section of this MD&A. In the third quarter of 2008, capital expenditures totalled $94 million, compared with expenditures of $45 million in the same quarter of 2007. The Syncrude Emissions Reduction ("SER") project accounted for $18 million and $17 million of the capital spent in the third quarters of 2008 and 2007, respectively. The remaining amounts in each quarter pertained to other sustaining capital activities including replacement trucks and infrastructure projects. Sustaining capital expenditures on a per barrel basis were approximately $8.69 and $3.95 in each of the third quarters of 2008 and 2007, respectively. Year-to-date capital expenditures totalled $195 million in 2008 versus $128 million in 2007. The SER project accounted for $56 million and $51 million of the capital spent in 2008 and 2007, respectively, with the remaining expenditures relating to other sustaining capital activities. Sustaining capital expenditures on a per barrel basis were approximately $6.78 and $4.21 on a year-to-date basis in 2008 and 2007, respectively. Syncrude is undertaking the SER project to retrofit technology into the operation of Syncrude's original two cokers to significantly reduce total sulphur dioxide and other emissions. After the completion of the SER project, stack emissions of sulphur compounds are anticipated to be about 60 per cent lower than current approved levels. In the third quarter of 2008, Syncrude completed its review of the SER project and revised its cost estimates for the project to $1.6 billion ($590 million net to the Trust) from $772 million ($284 million net to the Trust). The cost increase reflects a delay in the expected completion date and inflationary pressures. The Trust's share of the SER project expenditures incurred to date is approximately $163 million, with the remaining costs expected to be incurred over the next four years to coordinate with equipment turnaround schedules. Sustaining capital expenditures, including the SER project, are estimated to average approximately $7 per barrel for 2008. Over the longer term, we expect sustaining capital expenditures to average approximately $6 per barrel excluding inflation; however, over the next few years we may incur an additional $5 to $10 per barrel annually for large environmental and infrastructure projects. These projects include the relocation of certain mining trains and tailings systems, which is required as mining operations progress across the active leases. Tailings system projects also include initiatives to improve and supplement the effectiveness of systems used to separate water from sand and clay so that the water can be recycled back to the operation and solids can be incorporated into the final reclamation landscapes. Our per barrel estimates are based on estimated annual Syncrude production, which increases from 106 million barrels in 2008, or 39 million barrels net to the Trust, to 129 million barrels, or 47 million barrels net to the Trust, at design capacity. Syncrude's next significant growth stage is anticipated to be the Stage 3 debottleneck, which is estimated to increase Syncrude's productive capacity by about 50,000 barrels per day. Following the debottleneck, the Stage 4 expansion was expected to grow Syncrude capacity by a further 100,000 barrels per day, post-2016. Syncrude is re-evaluating its plans to increase production well beyond the 500,000 barrels per day provided by the Stage 4 expansion. The objective is to develop an expansion plan that maintains an appropriate resource life based on an independent estimate of Syncrude's reserves and resources as of December 31, 2007. The scoping engineering work on the Stage 3 debottleneck and subsequent expansion stages has been approved by the joint venture owners and is being pursued. Spending will ramp up as the engineering work progresses. The timing of the expansions will depend on the engineering and construction execution plans. It is possible that the debottleneck will be delayed beyond our current 2012 projected startup as could other expansion timing. We plan to provide more information on timing over the next year or two as the scoping work progresses. No cost estimates have been provided for these projects nor have they been approved by the Syncrude owners as they are still in the early planning stages. UNITHOLDERS' CAPITAL AND UNIT TRADING ACTIVITY The Trust's Units trade on the Toronto Stock Exchange under the symbol COS.UN. The Trust had a market capitalization of approximately $18.7 billion with 482 million Units outstanding and a closing price of $38.76 per Unit on September 30, 2008.
<<
Canadian Oil Sands Trust -
Trading Activity Third
Quarter September August July
2008 2008 2008 2008
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Unit price
High $ 55.25 $ 50.12 $ 53.26 $ 55.25
Low $ 36.20 $ 36.20 $ 45.21 $ 44.63
Close $ 38.76 $ 38.76 $ 51.46 $ 51.44
Volume traded (millions) 108.8 51.0 26.1 31.7
Weighted average Trust units
outstanding (millions) 481.5 481.5 481.5 481.5
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>>
CONTRACTUAL OBLIGATIONS AND COMMITMENTS With the exception of an additional $828 million ($304 million net to the Trust) expected to be incurred by Syncrude in respect of the SER project and the repayment of $150 million in maturing medium term notes during the second quarter of 2008, there have been no significant changes to the Trust's contractual obligations and commitments in 2008 from our 2007 year-end disclosure. FINANCIAL RISK MANAGEMENT The Trust did not have any financial derivatives outstanding at September 30, 2008. Crude Oil Price Risk Canadian Oil Sands did not have any crude oil price hedges in place for 2008 or 2007. As at September 30, 2008, the Trust remains unhedged on its crude oil price exposure and does not intend to introduce any crude oil hedge positions. Canadian Oil Sands may, however, hedge its crude oil production in the future depending on the business environment and growth opportunities. Foreign Currency Hedging As at September 30, 2008, we do not have any foreign currency hedges in place. At the present time, we do not intend to introduce any currency hedge positions. Canadian Oil Sands may, however, hedge foreign exchange rates in the future, depending on the business environment and growth opportunities. Interest Rate Risk Canadian Oil Sands' net income and cash from operating activities are impacted by interest rate changes based on the amount of floating rate debt outstanding. As at September 30, 2008, we did not have any debt outstanding bearing interest at floating market-based rates. Liquidity Risk Liquidity risk is the risk that Canadian Oil Sands will not be able to meet its financial obligations as they fall due. Canadian Oil Sands actively manages its liquidity through daily and longer-term cash, debt and equity management strategies. Such strategies encompass, among other factors: having adequate sources of financing available through its bank credit facilities, estimating future cash generated from operations based on reasonable production and pricing assumptions, analysis of economic hedging opportunities and compliance with debt covenants. Within the next year, two tranches of Canadian Oil Sands' debt will mature. As well, Canadian Oil Sands has stated its intention to increase net debt to approximately $1.6 billion by the end of 2010. Canadian Oil Sands will therefore be subject to liquidity risk in the coming years in respect of these financing requirements. In addition, we are exposed to liquidity risk to the extent we have financing requirements related to significant capital or operating commitments. Over the long-term, Canadian Oil Sands manages these risks by spreading out the maturities of its various debt tranches and maintaining a prudent capital structure. During 2007 and 2008, the economic crisis has spread resulting in a tightening of credit markets characterized by a decline in liquidity and higher borrowing costs. While Canadian Oil Sands continues to generate significant cash from operating activities and has $840 million of unutilized credit facilities to support liquidity, access to capital markets has become constrained and significantly more expensive. The Trust has approximately $500 million of debt maturities in the next ten months, and is considering the risk that the financial markets do not improve over this time frame as part of its financing plan. Should bank facilities or debt markets not be available to fund our mid-2009 debt maturities, further distribution reductions may be required in order to fund maturities out of cash from operating activities. Credit Risk Canadian Oil Sands is exposed to credit risk primarily through its trade accounts receivable balances with customers and with financial counterparties with whom the Trust has invested its cash and purchased term deposits from. At September 30, 2008, over 90 per cent of our accounts receivable balance was due from investment grade energy producers and refinery-based customers. At September 30, 2008, over 95 per cent of our cash and cash equivalents were invested in term deposits from a range of high-quality senior Canadian banks. FOREIGN OWNERSHIP Based on information from the statutory declarations by Unitholders, we estimate that, as of August 15 2008, approximately 32 percent of our Units are held by non-Canadian residents with the remaining 68 per cent of Units being held by Canadian residents. Canadian Oil Sands' Trust Indenture provides that not more than 49 per cent of its Units can be held by non-Canadian residents. The Trust regularly monitors its foreign ownership levels through declarations from Unitholders, and the next declarations will be requested as of November 14, 2008. The Trust posts its foreign ownership level on its web site at www.cos-trust.com under "Investor, Unit Information". The steps to manage foreign ownership levels are described in the Trust's AIF. SUSTAINABLE DEVELOPMENT Waterfowl Incident at Syncrude's Aurora Mine Tailings Pond In April 2008, a flock of ducks landed and died on one of Syncrude's tailings ponds. Syncrude is cooperating with Alberta Environment in their investigation into why this occurred and on improvements to help prevent future occurrences. Greenhouse Gas Emissions Reduction Requirements In 2007, through the Specified Gas Emitters Regulation, Alberta became the first province in Canada to regulate greenhouse gases by establishing intensity targets for Large Final Emitters of carbon. Effectively, the regulation requires Syncrude, beginning in the second half of 2007, to reduce its per barrel emissions of greenhouse gases by 12 per cent from the average of its annual per barrel emissions between 2003 and 2005. If Syncrude is unable to meet this target directly, it must purchase offset credits or pay into a government fund dedicated to the development of emissions reduction technology. For 2007, Syncrude met 90 per cent of its reduction target under the new regulation and offset the remainder through the payment of approximately $1 million to the Alberta government's technology fund. Syncrude's emissions calculation method and its data were externally verified. For 2008, Syncrude is accruing approximately $0.10 per barrel for compliance with the Specified Gas Emitters Regulation, which is reflected in the Trust's operating costs. The cost estimate remains preliminary pending Syncrude's actual carbon dioxide ("CO(2)") emission intensity level and clarification from the Alberta government regarding details of implementation. No cost estimates are available for future years. On March 10, 2008Canada's federal government provided further detail on its regulatory framework to reduce GHG and air pollutant emissions originally announced on April 26, 2007. The draft regulations are currently expected to be finalized in 2009 and take effect on January 1, 2010. The draft regulations for oil sands projects require existing projects to reduce emissions intensity by 18 per cent in 2010 from the 2006 level and two per cent thereafter. New oil sands facilities coming onstream over the period 2004 to 2011 also will be required to meet clean fuel standards and will be encouraged to implement mechanisms to capture CO(2) emissions. In addition to the reduction of existing GHG emissions, the capture and storage of CO(2) emissions ("CCS") will be a requirement for all oil sands projects coming onstream post 2012. The draft regulations are expected to impact both current Syncrude operations and its future expansion projects, however the full impact of the regulations cannot be quantified until they are finalized. Syncrude continues to explore and implement measures to reduce energy intensity in its operations, which reduces both CO(2) emissions and operating costs. Syncrude also is exploring the viability of developing a large scale CO(2) capture, transportation and storage network through participation in the integrated CO(2) Network ("ICON"). Reclamation In March 2008, the Alberta government certified a parcel of reclaimed land north of Fort McMurray. The 104 hectares, known as Gateway Hill, was submitted by Syncrude to the Alberta government in 2003 for certification. Alberta's Environmental Protection and Enhancement Act requires operators to conserve and reclaim specified land and obtain a reclamation certificate. These certificates are issued to operators when their site has been successfully reclaimed. Syncrude is the first in the oil sands industry to receive certification for land that has been reclaimed. Syncrude has reclaimed more than 4,500 hectares, representing the largest share in the oil sands industry. Tailings Management Syncrude's reclamation efforts also include tailings systems management. Tailings systems are designed to separate water from sand and clay to enable incorporation of solids into reclamation landscapes and recycling of water back into the operations. Syncrude and most other oil sands producers use a method called consolidated tails technology; however, additional tailings management technologies may be required in order to meet the approved closure and reclamation plan. Syncrude is exploring methods to improve and supplement the effectiveness of its tailings systems. On June 26, 2008, the Alberta Energy Resources Conservation Board ("ERCB") released a draft Directive on Tailings Criteria for public review and comment. This directive proposes to develop new industry-wide criteria to supplement existing regulations by requiring operators to:
<<
- prepare an operations and abandonment plan for every consolidated
tailings pond, which would be reviewed for the establishment of
performance measures by the ERCB;
- operate and abandon each consolidated tailings pond in accordance
with their applications or ERCB approvals;
- consume fine fluid tailings as proposed in their applications or as
approved by the ERCB; and
- specify dates for pond construction, pond use, pond closure, and
other milestones and file these dates with the ERCB through the
course of 2009.
>>
Syncrude is involved in both the review of the draft directive and submission of comments to the ERCB, as well as assessing the impact of the proposed directive on current and future operations. Until the directive is finalized, the impact, if any, of the new regulations on Syncrude cannot be fully determined. The regulation as presently drafted, however, is likely to have an adverse impact on the costs for tailings management. Syncrude is filing an amendment to its regulatory approval to modify the design of the existing Southwest Sand Storage ("SWSS") facility to permit interim storage of increased volumes of mature fine tailings. Changes to the design of the SWSS facility will be required to increase its fluid storage capacity. The change in design would not increase the footprint of the structure but rather elevate the fluid level within it. Pending regulatory approval, Syncrude intends to make use of this increase in capacity in 2009.
<<
2008 OUTLOOK
(millions of Canadian dollars, October 29, July 29,
except volume and per barrel amounts) 2008 2008
-------------------------------------------------------------------------
Syncrude production (MMbbls) 106 106
Canadian Oil Sands Sales (MMbbls) 38.9 38.9
Revenues, net of crude oil purchases and
transportation 4,336 4,734
Operating costs 1,381 1,381
Operating costs per barrel 35.47 35.46
Crown royalties 646 742
Capital expenditures 284 294
Cash from operating activities 2,204 2,356
Business environment assumptions
--------------------------------
West Texas Intermediate (US$/bbl) $ 102 $ 120
Premium (Discount) to average C$ WTI prices
(C$/bbl) $ 2.75 $ 1.50
Foreign exchange rate (US$/Cdn$) $ 0.94 $ 1.00
AECO natural gas (Cdn$/GJ) $ 8.00 $ 9.50
>>
The Trust is maintaining its estimate for 2008 Syncrude production of 106 million barrels which reflects year-to-date results, Syncrude's remaining 2008 maintenance program, and an allowance for unplanned outages. The range for Syncrude production is estimated at 103 to 109 million barrels for 2008. We have decreased the Trust's 2008 revenue outlook as a result of a lower estimated SCO sales price for the last quarter. The Trust has not assumed any further bitumen purchases in this current Outlook; however, Syncrude may purchase up to 10,000 barrels per day of additional bitumen during the remainder of 2008 to provide for flexibility in SCO production. The decrease in forecasted Crown royalties is due to the decrease in estimated revenues. Based on current assumptions, our estimate of cash from operating activities has decreased to $2,204 million, or $4.58 per Unit. With the decrease in the distribution to $0.75 per Unit in the fourth quarter of 2008, we are estimating net debt levels of approximately $1.1 billion at the end of 2008. Distributions paid in 2008 are expected to be 100 per cent taxable as other income. The actual taxability of the distributions will be determined and reported to Unitholders prior to the end of the first quarter of 2009. Changes in certain factors and market conditions could potentially impact Canadian Oil Sands' Outlook. The following table provides a sensitivity analysis of the key factors affecting the Trust's performance. In addition to the factors described in the table, the supply/demand equation and pipeline access for synthetic crude oil in the North American markets could impact the differential for SCO relative to crude benchmarks; however, these factors are difficult to predict. (NTD numbers in the following table are not final)
<<
2008 Outlook Sensitivity Analysis
Cash from Operating Activities
Annual(2) Increase
Variable(1) Sensitivity $ millions $/Trust unit
-------------------------------------------------------------------------
Syncrude operating costs
decrease C$1.00/bbl 29 0.06
Syncrude operating costs
decrease C$50 million 14 0.03
WTI crude oil price increase US$1.00/bbl 25 0.05
Syncrude production increase 2 million bbls 31 0.06
Canadian dollar weakening US$0.01/C$ 22 0.04
AECO natural gas price
decrease C$0.50/GJ 14 0.03
(1) An opposite change in each of these variables will result in the
opposite cash from operating activities impacts.
(2) Sensitivities assume a larger change in unrealized quarters to result
in the annual impact.
CANADIAN OIL SANDS TRUST
CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
(unaudited)
Three Months Ended Nine Months Ended
($ millions, except per September 30 September 30
Unit amounts) 2008 2007 2008 2007
-------------------------------------------------------------------------
Revenues $ 1,463 $ 1,035 $ 3,775 $ 2,626
Crude oil purchases and
transportation expense (82) (99) (310) (326)
-------------------------------------------------------------------------
1,381 936 3,465 2,300
-------------------------------------------------------------------------
Expenses:
Operating 345 239 1,042 741
Non-production 21 16 54 49
Crown royalties 231 165 540 348
Administration 3 4 16 14
Insurance 2 2 5 6
Interest, net (Note 8) 16 21 49 68
Depreciation, depletion
and accretion 121 101 325 260
Foreign exchange loss (gain) 32 (42) 53 (112)
-------------------------------------------------------------------------
771 506 2,084 1,374
-------------------------------------------------------------------------
Earnings before taxes 610 430 1,381 926
Future income tax expense
(recovery) and other 6 69 (18) 697
-------------------------------------------------------------------------
Net income from continuing
operations 604 361 1,399 229
Loss from discontinued
operations - - - (1)
-------------------------------------------------------------------------
Net income 604 361 1,399 228
Other comprehensive loss,
net of income taxes
Reclassification of
derivative gains to
net income (1) (2) (2) (6)
-------------------------------------------------------------------------
Comprehensive income $ 603 $ 359 $ 1,397 $ 222
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Weighted average Trust Units
(millions) 482 479 481 479
Trust Units, end of period
(millions) 482 479 482 479
Net income per Trust Unit:
Basic $ 1.25 $ 0.75 $ 2.91 $ 0.48
Diluted $ 1.25 $ 0.75 $ 2.91 $ 0.48
See Notes to Unaudited Consolidated Financial Statements
CANADIAN OIL SANDS TRUST
CONSOLIDATED STATEMENTS OF UNITHOLDERS' EQUITY
(unaudited)
Three Months Ended Nine Months Ended
September 30 September 30
($ millions) 2008 2007 2008 2007
-------------------------------------------------------------------------
Retained earnings
Balance, beginning of
period $ 1,597 $ 1,223 $ 1,643 $ 1,691
Net income 604 361 1,399 228
Unitholder distributions
(Note 9) (602) (192) (1,443) (527)
-------------------------------------------------------------------------
Balance, end of period 1,599 1,392 1,599 1,392
-------------------------------------------------------------------------
Accumulated other
comprehensive income
Balance, beginning of period 23 26 24 30
Other comprehensive loss (1) (2) (2) (6)
-------------------------------------------------------------------------
Balance, end of period 22 24 22 24
-------------------------------------------------------------------------
Unitholders' capital
Balance, beginning of period 2,524 2,499 2,500 2,260
Issuance of Trust Units
(Note 4) - - 24 239
-------------------------------------------------------------------------
Balance, end of period 2,524 2,499 2,524 2,499
-------------------------------------------------------------------------
Contributed surplus
Balance, beginning of period 3 4 5 4
Exercise of employee
stock options - - (3) -
Stock-based compensation - 1 1 1
-------------------------------------------------------------------------
Balance, end of period 3 5 3 5
-------------------------------------------------------------------------
Total Unitholders' equity $ 4,148 $ 3,920 $ 4,148 $ 3,920
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See Notes to Unaudited Consolidated Financial Statements
CANADIAN OIL SANDS TRUST
CONSOLIDATED BALANCE SHEETS
AS AT
(unaudited)
September 30 December 31
($ millions) 2008 2007
-------------------------------------------------------------------------
ASSETS
Current assets:
Cash and cash equivalents $ 278 $ 268
Accounts receivable 377 379
Inventories 104 102
Prepaid expenses 6 6
-------------------------------------------------------------------------
765 755
Property, plant and equipment, net 6,297 6,427
Goodwill 52 52
Reclamation trust 41 37
-------------------------------------------------------------------------
$ 7,155 $ 7,271
-------------------------------------------------------------------------
-------------------------------------------------------------------------
LIABILITIES AND UNITHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities $ 332 $ 289
Current portion of employee future benefits 17 16
-------------------------------------------------------------------------
349 305
Employee future benefits and
other liabilities 103 128
Long-term debt 1,116 1,218
Asset retirement obligation 235 226
Future income taxes 1,204 1,222
-------------------------------------------------------------------------
3,007 3,099
Unitholders' equity 4,148 4,172
-------------------------------------------------------------------------
$ 7,155 $ 7,271
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Commitments (Note 10)
See Notes to Unaudited Consolidated Financial Statements
CANADIAN OIL SANDS TRUST
CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited)
Three Months Ended Nine Months Ended
September 30 September 30
($ millions) 2008 2007 2008 2007
-------------------------------------------------------------------------
Cash from (used in) operating
activities
Net income $ 604 $ 361 $ 1,399 $ 228
Items not requiring outlay
of cash:
Depreciation, depletion
and accretion 121 101 325 260
Unrealized foreign exchange
on long-term debt 36 (59) 62 (146)
Future income tax expense
(recovery) 6 68 (18) 696
Other (1) 1 4 (3)
Net change in deferred items (9) (2) (25) (2)
-------------------------------------------------------------------------
757 470 1,747 1,033
Change in non-cash working
capital 164 14 28 (23)
-------------------------------------------------------------------------
Cash from operating
activities 921 484 1,775 1,010
-------------------------------------------------------------------------
Cash from (used in) financing
activities
Repayment of medium term
and Senior Notes - - (150) (272)
Net drawdown (repayment) of
bank credit facilities - (70) (16) -
Unitholder distributions
(Note 9) (602) (192) (1,443) (527)
Issuance of Trust Units
(Note 4) - (1) 21 1
-------------------------------------------------------------------------
Cash used in financing
activities (602) (263) (1,588) (798)
-------------------------------------------------------------------------
Cash from (used in)
investing activities
Capital expenditures (94) (45) (195) (128)
Acquisition of additional
Syncrude working interest - - - (231)
Disposition of properties - - - 4
Reclamation trust funding (1) (1) (4) (4)
Change in non-cash working
capital 22 (7) 22 (5)
-------------------------------------------------------------------------
Cash used in investing
activities (73) (53) (177) (364)
-------------------------------------------------------------------------
Increase (decrease) in cash
and cash equivalents 246 168 10 (152)
Cash and cash equivalents
at beginning of period 32 33 268 353
-------------------------------------------------------------------------
Cash and cash equivalents
at end of period $ 278 $ 201 $ 278 $ 201
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Cash and cash equivalents
consist of:
Cash $ 10 $ 1
Short-term investments 268 200
-------------------------------------------------------------------------
$ 278 $ 201
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Supplementary Information (Note 11)
See Notes to Unaudited Consolidated Financial Statements
NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2008
(Tabular amounts expressed in millions of Canadian dollars, except where
otherwise noted.)
1) BASIS OF PRESENTATION
The interim consolidated financial statements include the accounts of
Canadian Oil Sands Trust and its subsidiaries (collectively, the
"Trust" or "Canadian Oil Sands"), and are presented in accordance
with Canadian Generally Accepted Accounting Principles ("GAAP"). The
interim consolidated financial statements have been prepared
following the same accounting policies and methods of computation as
the consolidated financial statements for the year ended December 31,
2007, except as discussed in Note 2. Certain disclosures that are
normally required to be included in the notes to the annual audited
consolidated financial statements have been condensed or omitted. The
interim consolidated financial statements should be read in
conjunction with the consolidated financial statements and the notes
thereto in the Trust's annual report for the year ended December 31,
2007.
2) CHANGES IN ACCOUNTING POLICIES
In its consolidated financial statements for the year ended
December 31, 2007, Canadian Oil Sands adopted the requirements of the
Canadian Institute of Chartered Accountants ("CICA") Section 3862
Financial Instruments - Disclosures, Section 3863 Financial
Instruments - Presentation, and Section 1535 Capital Disclosures. The
standards were effective January 1, 2008, however early adoption was
encouraged by the CICA. Additional disclosures required as a result
of adopting the standards can be found in the Trust's consolidated
financial statements for the year ended December 31, 2007.
In June 2007, the CICA issued a new accounting standard -
Section 3031 Inventories, which replaces the existing standard for
inventories, Section 3030. The main features of the new Section are
as follows:
- Measurement of inventories at the lower of cost and net
realizable value
- Consistent use of either first-in, first-out or a weighted
average cost formula to measure cost
- Reversal of previous write-downs to net realizable value when
there is a subsequent increase to the value of inventories
The new Section was effective for the Trust beginning January 1,
2008. Application of the new Section did not have a significant
impact on the financial statements.
3) FUTURE CHANGES IN ACCOUNTING POLICIES
In February 2008, the CICA issued a new accounting standard -
Section 3064 Goodwill and Intangible Assets, which replaces Section
3062 Goodwill and Other Intangible Assets, and Section 3450 Research
and Development Costs. The new section establishes standards for the
recognition, measurement and disclosure of goodwill and intangible
assets. The section is effective for the Trust beginning January 1,
2009. Application of the new section is not expected to have a
material impact on the Trust's financial statements.
4) ISSUANCE OF TRUST UNITS
In the nine months ended September 30, 2008, approximately
2.1 million Trust Units were issued for $24 million on the exercise
of employee stock options.
5) EMPLOYEE FUTURE BENEFITS
Syncrude Canada Ltd. ("Syncrude Canada"), the operator of the
Syncrude Joint Venture, has a defined benefit and two defined
contribution plans providing pension benefits, and other retirement
post-employment benefit plans ("OPEB") covering most of its
employees. Other post-employment benefits include certain health care
and life insurance benefits for retirees, their beneficiaries and
covered dependents. The OPEB plan is not funded.
Canadian Oil Sands accrues its obligations as a joint venture owner
in respect of Syncrude Canada's employee benefit plans and the
related costs, net of plan assets. The cost of employee pension and
other retirement benefits is actuarially determined using the
projected benefit method based on length of service and reflects
Canadian Oil Sands' best estimate of the expected performance of the
plan investment, salary escalation factors, retirement ages of
employees and future health care costs. The expected return on plan
assets is based on the fair value of those assets. Past service costs
from plan amendments are amortized on a straight-line basis over the
estimated average remaining service life of active employees
("EARSL") at the date of amendment. The excess of any net actuarial
gain or loss exceeding 10 per cent of the greater of the benefit
obligation and fair value of the plan assets is amortized over the
EARSL.
Canadian Oil Sands' share of Syncrude Canada's net defined benefit
and contribution plans expense for the three and nine months ended
September 30, 2008 and 2007 is based on its 36.74 per cent working
interest. The costs have been recorded in operating expense as
follows:
Three Months Ended Nine Months Ended
September 30 September 30
2008 2007 2008 2007
---------------------------------------------------------------------
Defined benefit plans:
Pension benefits $ 8 $ 6 $ 23 $ 20
Other benefit plans 1 1 3 3
---------------------------------------------------------------------
$ 9 $ 7 $ 26 $ 23
Defined contribution plans 1 - 2 1
---------------------------------------------------------------------
Total benefit cost $ 10 $ 7 $ 28 $ 24
---------------------------------------------------------------------
6) BANK CREDIT FACILITIES
---------------------------------------------------------------------
Extendible revolving term facility (a) $ 40
Line of credit (b) 67
Operating credit facility (c) 800
---------------------------------------------------------------------
$ 907
---------------------------------------------------------------------
---------------------------------------------------------------------
Each of the Trust's credit facilities is unsecured. These credit
agreements contain typical covenants relating to the restrictions on
Canadian Oil Sands' ability to sell all or substantially all of its
assets or to change the nature of its business. In addition, Canadian
Oil Sands has agreed to maintain its total debt-to-total book
capitalization at an amount less than 60 per cent, or 65 per cent in
certain circumstances involving acquisitions.
a) The $40 million extendible revolving term facility is a 364-day
facility with a one-year term out, expiring April 23, 2009. This
facility may be extended on an annual basis with the agreement of
the bank. Amounts borrowed through this facility bear interest at
a floating rate based on bankers' acceptances plus a credit
spread, while any unused amounts are subject to standby fees. As
at September 30, 2008, no amounts were drawn on this facility.
b) The $67 million line of credit is a one-year revolving letter of
credit facility. Letters of credit drawn on the facility mature
April 30th each year and are automatically renewed, unless
notification to cancel is provided by Canadian Oil Sands or the
financial institution providing the facility at least 60 days
prior to expiry. Letters of credit on this facility bear interest
at a credit spread.
Letters of credit of approximately $67 million have been written
against the line of credit as at September 30, 2008.
c) The $800 million operating facility is a five-year facility,
expiring April 27, 2012. Amounts borrowed through this facility
bear interest at a floating rate based on either prime interest
rates or bankers' acceptances plus a credit spread, while any
unused amounts are subject to standby fees. As at September 30,
2008, no amounts were drawn on this facility.
7) LONG-TERM DEBT
On April 9, 2008, the Trust repaid $150 million of 5.75% medium term
notes.
8) INTEREST, NET
Three Months Ended Nine Months Ended
September 30 September 30
2008 2007 2008 2007
---------------------------------------------------------------------
Interest expense on
long-term debt $ 18 $ 22 $ 56 $ 71
Interest income and other (2) (1) (7) (3)
---------------------------------------------------------------------
Interest expense, net $ 16 $ 21 $ 49 $ 68
---------------------------------------------------------------------
---------------------------------------------------------------------
9) UNITHOLDER DISTRIBUTIONS
The Consolidated Statements of Unitholder Distributions is provided
to assist Unitholders in reconciling cash from operating activities
to Unitholder distributions.
Pursuant to Section 5.1 of the Trust Indenture, the Trust is required
to distribute all the Distributable Income, as defined by the Trust
Indenture, received or receivable by the Trust in a quarter. The
Trust's Distributable Income primarily consists of a royalty from its
operating subsidiary, Canadian Oil Sands Limited ("COSL"). The
royalty is designed to capture the cash generated by COSL, after the
deduction of all costs and expenses including operating and
administrative costs, income taxes, capital expenditures, debt
interest and principal repayments, working capital and reserves for
future obligations deemed appropriate. The amount of royalty income
that the Trust receives in any period has a considerable amount of
flexibility through the use of discretionary reserves and debt
borrowings or repayments (either intercompany or third party).
Quarterly distributions are determined by COSL's Board of Directors
after considering the current and expected economic and operating
conditions, ensuring financing capacity for Syncrude's expansion
projects and/or Canadian Oil Sands acquisitions, and with the
objective of maintaining an investment grade credit rating.
Three Months Ended Nine Months Ended
September 30 September 30
2008 2007 2008 2007
---------------------------------------------------------------------
Cash from operating
activities $ 921 $ 484 $ 1,775 $ 1,010
Add (Deduct):
Capital expenditures (94) (45) (195) (128)
Acquisition of additional
Syncrude working
interest - - - (231)
Disposition of properties - 4
Change in non-cash
working capital(1) 22 (7) 22 (5)
Reclamation trust funding (1) (1) (4) (4)
Change in cash and cash
equivalents and
financing, net(2) (246) (239) (155) (119)
---------------------------------------------------------------------
Unitholder distributions $ 602 $ 192 $ 1,443 $ 527
---------------------------------------------------------------------
---------------------------------------------------------------------
Unitholder distributions
per Trust Unit $ 1.25 $ 0.40 $ 3.00 $ 1.10
---------------------------------------------------------------------
---------------------------------------------------------------------
(1) From investing activities.
(2) Primarily represents the change in cash and cash equivalents and
net financing to fund the Trust's share of investing activities.
10) COMMITMENTS
During the third quarter of 2008, Canadian Oil Sands committed to
additional costs of approximately $304 million relating to its share
of Syncrude's Emissions Reduction project. The additional costs are
expected to be incurred over the next four years.
11) SUPPLEMENTARY INFORMATION
Three Months Ended Nine Months Ended
September 30 September 30
2008 2007 2008 2007
---------------------------------------------------------------------
Income tax paid $ - $ - $ - $ 1
---------------------------------------------------------------------
---------------------------------------------------------------------
Interest paid $ 18 $ 27 $ 56 $ 81
---------------------------------------------------------------------
Canadian Oil Sands Limited Canadian Oil Sands Trust
Marcel Coutu 2500 First Canadian Centre
President & Chief Executive Officer 350 - 7 Avenue S.W.
Calgary, Alberta T2P 3N9
Units Listed - Symbol: COS.UN Ph: (403) 218-6200
Toronto Stock Exchange Fax: (403) 218-6201
>>
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