Attention Business/Financial Editors:
CALGARY, Jan. 24 /CNW/ – Shell Canada Limited announces annual earnings
of $1,738 million or $2.11 per common share in 2006 compared with
$2,001 million or $2.43 per common share in 2005(1). The decrease was largely
due to the first major scheduled turnaround of the Athabasca Oil Sands
Project, together with lower natural gas prices.
Fourth-quarter earnings were $223 million compared with $611 million for
the same period in 2005(1). The decrease was mainly due to lower commodity
prices and a charge for the Long Term Incentive Plan.
Cash flow from operations was $2,614 million in 2006, down $422 million
from 2005(1), due to the same factors that impacted full year earnings.
Capital and predevelopment expenditures amounted to $2,426 million in
2006, excluding the acquisition of BlackRock Ventures Inc. (BlackRock),
compared with $1,715 million in 2005. The difference was due to increased
investment in growth activities in unconventional oil and gas.
“Strong production from our oil sands operations following the scheduled
turnarounds, and record earnings in Oil Products, underpinned our 2006
results,” said Clive Mather, President and Chief Executive Officer, Shell
Canada Limited. “Expansions of our mining, in situ and unconventional gas
businesses are now all in full swing. With the acquisition of BlackRock and
other strategic land positions, we have built a strong platform for future
growth.”
< < Earnings(footnote 1) ($ millions) Q1 05 Q2 05 Q3 05 Q4 05 Q1 06 Q2 06 Q3 06 Q4 06 416 524 450 611 451 476 588 223 Cash Flow(footnote 1) ($ millions) Q1 05 Q2 05 Q3 05 Q4 05 Q1 06 Q2 06 Q3 06 Q4 06 635 799 676 926 729 530 917 438 Capital Expenditures(footnote 2) ($ millions) Q1 05 Q2 05 Q3 05 Q4 05 Q1 06 Q2 06 Q3 06 Q4 06 269 327 410 709 404 492 592 938 (1) Prior periods restated (2) Excludes BlackRock purchase price SHELL CANADA LIMITED MANAGEMENT'S DISCUSSION AND ANALYSIS Total Company Shell Canada Limited earnings in 2006 were $1,738 million, down from $2,001 million(1) in 2005. Earnings were lower in 2006 due to the first major scheduled turnaround of the Athabasca Oil Sands Project (AOSP), which resulted in higher maintenance costs and lower production, together with lower natural gas prices. These were offset by higher oil prices and refining light oil margins, and a favourable adjustment in the second quarter of $222 million resulting from changes to federal and Alberta corporate tax rates. Total Long Term Incentive Plan (LTIP) charges were $44 million in 2006 compared to $186 million in 2005. Earnings in 2005 also included a favourable adjustment of $164 million related to the use of non-capital losses resulting from the acquisition of an affiliated company, Coral Resources Canada ULC. Earnings for the fourth quarter of 2006 were $223 million compared with $611 million for the corresponding period in 2005. The decrease was mainly due to significantly lower natural gas prices, a $135 million charge for the LTIP compared with a charge of $30 million for the same period in 2005, and the turnaround at the Sarnia Refinery. Earnings in the fourth quarter of 2005 included a favourable adjustment of $65 million related to the use of non- capital losses from the acquisition of an affiliated company. Total production for 2006 was 214,900 barrels of oil equivalent per day (BOE/d), down from 228,700 BOE/d in 2005. The decrease was mainly due to a belt tear at the mine in the first quarter and the scheduled turnaround at the mine and upgrader at mid year, as well as lower natural gas liquids (NGL) production. Total hydrocarbon production for the fourth quarter was a record 244,900 BOE/d. (1) Prior periods restated as required by Shell Canada's adoption of Emerging Issues Committee (EIC) Abstract 162 "Stock Based Compensation For Employees Eligible to Retire Before The Vesting Date" (See Note 2 to the Consolidated Financial Statements). >>
Exploration & Production
Exploration & Production (E&P) delivered earnings of $499 million in 2006
compared with $665 million in 2005. Lower natural gas prices and NGL
production due to natural field decline were offset by lower LTIP charges and
a positive tax gain of $47 million from changes to federal and Alberta
corporate tax rates. Total LTIP charges were $12 million in 2006 compared to
$54 million in 2005. Effective January 1, 2006, the Peace River business was
transferred from E&P to the Oil Sands business unit. Prior period E&P earnings
have been adjusted to exclude Peace River operations.
E&P earnings in the fourth quarter of 2006 were $53 million compared with
earnings of $263 million for the same period in 2005. The decrease in earnings
was predominately due to significantly lower prices, in addition to lower NGL
volumes, higher dry hole write-off expenses, and an LTIP charge of $35
million.
Total natural gas production in 2006 increased to 523 million cubic feet
per day (mmcf/d) from 512 mmcf/d in 2005, with increases from the Foothills
and basin-centred gas (BCG) businesses.
During the quarter, the Company received Alberta Energy and Utilities
Board approval for a downspacing application in the Chinook Ridge region in
the BCG business. Approval for downspacing will allow the Company to drill
four wells per section and utilize a pad drilling program to reduce costs and
environmental impacts. The first four wells on Shell Canada’s pad drilling
program have been successfully drilled. The BCG program produced natural gas
volumes of 23 mmcf/d for the fourth quarter of 2006, up from 8 mmcf/d for the
same period in 2005. The BCG program remains on target to deliver production
of 100 mmcf/d by the end of 2007.
The Sable Offshore Energy Project compression platform commenced
operations in the fourth quarter. Natural gas production capacity is expected
to increase over the next several weeks and the project will help to offset
natural decline rates from the producing fields over the longer term.
The Great Barasway deepwater exploration well in the Orphan Basin
offshore Newfoundland continued drilling in the fourth quarter. Drilling is
taking longer than anticipated and is now expected to conclude during the
first quarter of 2007.
The Mackenzie Gas Project is experiencing upward cost pressure,
influenced by regional and global energy industry activity. In addition, a
recent Federal Court decision regarding Aboriginal consultation by the federal
government on the proposed Mackenzie Valley pipeline has resulted in further
uncertainty regarding the regulatory process for the project. The project
proponents expect to file an updated cost estimate and schedule with
regulators later in the first quarter of 2007.
Within the Foothills business, construction is progressing on the
northeast British Columbia gas gathering system and dehydration facility,
which is designed to connect several existing gas discoveries and increase
production in 2007 from the Monkman Pass region. Two wells – a development
well and an exploration well – were drilled in 2006 in the same area as the
initial Tay River discovery. Neither well was successful in the main target
zone.
Oil Sands
Oil Sands earnings in 2006 were $718 million compared with $783 million
in 2005. Higher oil prices were offset by lower production due to the belt
tear at the mine in the first quarter of 2006 and a major scheduled turnaround
of both the mine and upgrader at mid year. The 2006 results included a
favourable tax adjustment of $144 million resulting from changes to federal
and Alberta corporate tax rates. Total LTIP charges were $8 million in 2006
compared to $30 million in 2005.
Oil Sands earnings in the fourth quarter of 2006 were $221 million, up
from $193 million for the corresponding period in 2005. Increased in situ
production, lower heavy oil differentials and an improved AOSP synthetic
product mix were offset by lower crude prices in the quarter. Earnings for the
quarter also included $21 million from AOSP Expansion 1 payments received from
the other joint venture owners and an insurance settlement of $15 million from
the June 30, 2006 fire at the BlackRock Seal battery. These earnings were
offset by an LTIP charge of $29 million.
The Company’s share of AOSP bitumen production in 2006 averaged 82,500
barrels per day (bbls/d), down from the average of 95,900 bbls/d achieved in
2005. The lower production was due to the belt tear at the mine in the first
quarter of 2006 and a major scheduled turnaround of both the mine and upgrader
at mid year. In the fourth quarter of 2006, average bitumen production was
106,600 bbls/d compared with 106,800 bbls/d for the same period in 2005.
Unit cash operating costs for the AOSP averaged $28.73 per barrel in
2006, an increase of $5.51 per barrel compared to 2005. The increase was
largely due to the first major scheduled turnaround of the AOSP, which
resulted in higher maintenance costs and lower production. Unit cash operating
costs in the fourth quarter of 2006 were $24.26 per barrel compared with
$23.88 for the same period in 2005. The Company realized an average synthetic
crude price of $55.56 for the quarter.
During the quarter, the Company received Alberta Energy and Utilities
Board approval for the Muskeg River Mine Expansion, an integral part of AOSP
Expansion 1, a 100,000 bbls/d expansion of oil sands mining and upgrading
facilities. Construction is well underway on both the upstream and downstream
components of Expansion 1, and the project now employs 2,400 people.
Total average in situ production for the full year was 12,400 bbls/d
compared to 8,900 bbls/d in 2005. In situ production for the fourth quarter
was 20,400 bbls/d, up significantly from 8,900 bbls/d in the fourth quarter of
2005 due to new thermal production at Peace River and new volumes associated
with the purchase of BlackRock Ventures Inc. (BlackRock). Year-end capacity
was 30,000 bbls/d although, as previously disclosed, production volumes at
Peace River continue to be reduced due to the apportionment on the Rainbow
Pipeline.
Construction of the 10,000 bbls/d Orion steam-assisted gravity drainage
(SAGD) project near Cold Lake is on track with a target start up in mid 2007.
During the quarter, the Company filed its regulatory application for the in
situ growth plan for a 100,000 bbls/d Peace River development.
Reserves
In 2006, gross proved natural gas reserves were 1,400 billion cubic feet
(bcf) compared with 1,592 bcf for 2005, after production of 191 bcf. Natural
gas reserve additions from extensions and discoveries of 133 bcf, including
95 bcf from continued drilling success in the BCG region, were offset by
downward technical and economic revisions.
Gross proved natural gas liquids reserves decreased to 61 million barrels
in 2006 after production of 12 million barrels and a small offset from net
positive technical and economic revisions.
The Company’s gross proved in situ bitumen reserves increased from
28 million barrels in 2005 to 96 million barrels in 2006, due mainly to the
acquisition of BlackRock. Reserves additions resulting from infill drilling in
the Peace River field were offset by production of 5 million barrels and minor
technical revisions.
In accordance with U.S. SEC regulations, the Company booked proved
reserves of 34 million barrels for Orion, reflecting only the approved first
phase of the project. Reserves for the future phases of Orion will be booked
upon final investment decision. Proved reserves for Orion of 95 million
barrels previously reported by BlackRock were prepared according to Canadian
reserve reporting regulations.
The Company’s gross proved minable bitumen reserves increased by 60 per
cent in 2006 to 1,292 million barrels from 808 million barrels in 2005.
Following the final investment decision for AOSP Expansion 1, the Company
booked 497 million barrels on a gross basis to reflect the project’s full
economic life of 38 years. Core-hole drilling activity at the Muskeg River
Mine resulted in the reclassification of 17 million barrels from the probable
to proved category. The additions were partially offset by production of
30 million barrels in 2006. Total gross proved and probable minable bitumen
reserves increased from 936 million barrels in 2005 to 1,695 million barrels
for 2006.
Shell Canada’s 2006 Annual Report will provide full gross and net
reserves information.
Oil Products
Oil Products 2006 annual earnings were a record $584 million, up
significantly from earnings of $434 million for 2005. Stronger refining
margins and a favourable second quarter adjustment of $43 million resulting
from changes to federal and Alberta corporate tax rates were partially offset
by lower refinery yield. Planned turnarounds at both the Montreal East and
Sarnia refineries in 2006, as well as feedstock limitations at both the
Scotford and Montreal East refineries, impacted refinery yield. Total LTIP
charges were $13 million in 2006 compared with $56 million in 2005.
Oil Products earnings in the fourth quarter of 2006 were $22 million
compared with $106 million for the same period in 2005. The decrease was
mainly due to higher operating expenses, which included an LTIP charge of
$36 million, lower refining and marketing margins, and lower refinery yield.
The total impact of the planned turnaround at the Sarnia Refinery was $44
million. Refinery yield was also lower in the fourth quarter of 2006 due to
feedstock limitations at Montreal East Refinery and lower benzene sales from
Scotford.
In the fourth quarter, work progressed on designs for a new heavy oil
refinery near Sarnia, Ontario. The team has begun to advance environmental
impact assessments and ongoing discussions with various regulatory and
community stakeholder groups.
Oil Products has planned a major turnaround for the Montreal East
Refinery in the second quarter of 2007. The turnaround will impact a number of
process units for approximately one month.
Corporate
Corporate incurred a loss of $63 million in 2006 compared with earnings
of $119 million in 2005. Higher interest charges were offset by lower LTIP
charges in 2006. Prior year earnings included a favourable adjustment of
$164 million related to the use of non-capital losses available to the Company
resulting from the acquisition of an affiliated company, Coral Resources
Canada ULC. Total LTIP charges in 2006 were $12 million compared to
$46 million in 2005.
Corporate incurred a loss of $73 million in the fourth quarter of 2006
compared with earnings of $49 million for the corresponding period in 2005.
The change was mainly due to higher operating expenses, which included a
$35 million LTIP charge, higher interest charges in 2006, and a favourable
adjustment of $65 million in 2005 related to the use of non-capital losses
available to the Company resulting from the acquisition of an affiliated
company, Coral Resources Canada ULC.
Cash Flow and Financing
In 2006, cash flow from operations was $2,614 million, down from
$3,036 million in 2005. The decrease is largely due to lower bitumen and NGL
volumes, lower natural gas prices and higher expenses. These were partially
offset by higher oil prices and refining light oil margins, and a favourable
adjustment resulting from changes to federal and Alberta corporate tax rates.
Cash flow from operations for the fourth quarter of 2006 was $438 million,
down from $926 million for the same period in 2005. The decrease was mainly
due to lower natural gas prices, higher LTIP charges and the turnaround at the
Sarnia Refinery.
Capital and predevelopment expenditures amounted to $2,426 million for
2006 (excluding the BlackRock purchase price of $2.4 billion net of cash
acquired) and $938 million for the fourth quarter, compared with
$1,715 million and $709 million respectively for 2005. The difference was due
to increased investment in growth activities in unconventional oil and gas.
Total debt outstanding at the end of 2006 was $1,435 million, which
includes $1,036 million of commercial paper issued under the Company’s
$1.5 billion program, borrowings of $199 million against a $1-billion
syndicated facility established in the second quarter of this year and
$200 million for a mobile equipment lease. This compares with debt on the
December 31, 2005 balance sheet of $211 million, mainly due to the mobile
equipment lease. The Company also held $1,083 million in cash on December 31,
2005.
Dividends paid in the fourth quarter of 2006 were $0.11 per common share,
totalling $91 million. This same level of dividend was paid in the third
quarter of 2006 and the fourth quarter of 2005.
Share Information
At January 15, 2007, the Company had 825,662,514 common shares
outstanding (October 15, 2006 – 825,541,514 common shares) with
21,365,238 employee stock options outstanding, of which 10,360,457 were
exercisable or could be surrendered to exercise an attached share appreciation
right (October 15, 2006 – 22,333,630 outstanding and 11,256,400 exercisable).
< < ------------------------------------------------------------------------- Stock Trading Information Fourth Quarter 2006 2005 ------------------------------------------------------------------------- Share Prices (dollars)(1) - High 43.85 42.35 - Low 28.90 32.45 - Close (end of period) 43.51 42.05 Shares traded (thousands)(1) 85,578 23,719 ------------------------------------------------------------------------- (1) Toronto Stock Exchange quotations ------------------------------------------------------------------------- >>
Additional Information
Additional information relating to Shell Canada Limited filed with
Canadian and U.S. securities regulatory authorities, including the Annual
Information Form and Form 40-F, can be found online under the Company’s
profile at www.sedar.com and www.sec.gov.
Cautionary Note
This document contains “forward-looking statements” based upon
management’s assessment of the Company’s future plans and operations. These
forward-looking statements include references to the Company’s plans for
growth, future capital and other expenditures, drilling, development,
construction and expansion plans, maintenance activities and schedules,
resources and reserves estimates, future production of resources and reserves,
the submission and receipt of regulatory applications, project costs and
schedules, the impact of compression projects, the apportionment of pipeline
capacity and oil and gas production levels.
Readers are cautioned not to place undue reliance on forward-looking
statements. Although the Company believes that the expectations represented by
such forward-looking statements are reasonable based on the information
available to it on the date of this document, there can be no assurance that
such expectations will prove to be correct. Forward-looking statements involve
numerous known and unknown risks and uncertainties that could cause actual
results to differ materially from those anticipated by the Company. These
risks and uncertainties include, but are not limited to, the risks of the oil
and gas industry (including operating conditions and costs), market
competition, demand for oil, gas and related products, disruptions in supply,
project start-up, schedules and execution, labour availability, material and
equipment shortages, constraints on infrastructure, the uncertainties
involving geology of oil and gas deposits and reserves estimates, including
the assumption that the quantities estimated can be found and profitably
produced in the future, the receipt of regulatory approvals, stakeholder
engagement, fluctuations in oil and gas prices and foreign currency exchange
rates, general economic conditions, changes in law or government policy, and
other factors, many of which are beyond the control of the Company.
The forward-looking statements contained in this document are made as of
the date of this document and the Company does not undertake any obligation to
update publicly or revise any of the forward-looking statements contained in
this document, whether as a result of new information, future events or
otherwise, except as required by law. The forward-looking statements contained
in this document are expressly qualified by this cautionary note.
Certain financial measures are not prescribed by Canadian generally
accepted accounting principles (GAAP). These non-GAAP financial measures do
not have any standardized meaning and, therefore, may not be comparable with
the calculation of similar measures of other companies. The Company includes
as non-GAAP measures return on average capital employed (ROACE), cash flow
from operations and unit cash operating cost because they are key internal and
external financial measures used to evaluate the performance of the Company.
The Company’s reserves disclosure and related information are prepared in
reliance on a decision of the applicable Canadian securities regulatory
authorities under National Instrument 51-101 – Standards of Disclosure for Oil
and Gas Activities (NI 51-101), which permits the Company to present its
reserves disclosure and related information in accordance with the applicable
requirements of the United States Financial Accounting Standards Board and the
United States Securities and Exchange Commission. This disclosure differs from
the corresponding information required by NI 51-101.
For 2006, reserves estimates associated with the BlackRock properties
were prepared by an independent qualified reserves evaluator. Otherwise, the
Company’s reserves estimates are prepared by internal qualified reserves
evaluators. With the exception of the BlackRock properties, no independent
qualified reserves evaluator or auditor was involved in the preparation of the
Company’s reserves data.
Certain volumes have been converted to barrels of oil equivalent (BOE).
BOEs may be misleading, particularly if used in isolation. A conversion of six
thousand cubic feet of natural gas to one barrel of oil, as used in this
document, is based on the energy equivalency conversion method primarily
applicable at the burner tip and does not represent a value equivalency at the
wellhead.
< < SHELL CANADA LIMITED Financial Highlights ($ millions, except as noted) (unaudited) Fourth Quarter Total year 2006 2005 2006 2005 ------------------------------------------------------------------------- (restated) (restated) Earnings 223 611 1 738 2 001 Revenues 3 581 4 043 14 806 14 394 Cash flow from operations(1) 438 926 2 614 3 036 Return on average common shareholders' equity (%) - - 19.6 27.2 Per common share (dollars) (Note 7) Earnings - basic 0.27 0.74 2.11 2.43 Earnings - diluted 0.27 0.73 2.09 2.40 Dividends paid 0.110 0.110 0.440 0.367 Results by Segment (Note 3) Earnings Exploration & Production 53 263 499 665 Oil Sands 221 193 718 783 Oil Products 22 106 584 434 Corporate (73) 49 (63) 119 ------------------------------------------------------------------------- Total 223 611 1 738 2 001 ------------------------------------------------------------------------- Revenues Exploration & Production 531 814 2 200 2 554 Oil Sands 1 024 909 3 363 3 356 Oil Products 2 641 2 985 11 367 10 779 Corporate 4 2 78 63 Inter-segment sales (619) (667) (2 202) (2 358) ------------------------------------------------------------------------- Total 3 581 4 043 14 806 14 394 ------------------------------------------------------------------------- Cash flow from operations(1) Exploration & Production 215 360 990 1 024 Oil Sands 239 363 843 1 411 Oil Products 78 216 831 527 Corporate (94) (13) (50) 74 ------------------------------------------------------------------------- Total 438 926 2 614 3 036 ------------------------------------------------------------------------- Capital and predevelopment expenditures Exploration & Production 270 319 828 796 Oil Sands 473 190 1 150 420 Oil Products 186 192 402 484 Corporate 9 8 46 15 ------------------------------------------------------------------------- Total 938 709 2 426 1 715 ------------------------------------------------------------------------- Return on average capital employed (%)(2) Exploration & Production - - 23.9 40.3 Oil Sands - - 16.6 27.8 Oil Products - - 24.0 19.8 ------------------------------------------------------------------------- Total - - 18.2 26.7 ------------------------------------------------------------------------- SHELL CANADA LIMITED Operating Highlights (unaudited) Fourth Quarter Total year 2006 2005 2006 2005 ------------------------------------------------------------------------- (restated) (restated) EXPLORATION & PRODUCTION (Note 3) Production Natural gas (mmcf/d) Western Canada natural gas 415 407 416 393 Sable natural gas 105 121 107 119 -------------------------------------- Total natural gas - gross 520 528 523 512 - net 431 428 425 413 Ethane, propane and butane (bbls/d) - gross 18 600 23 600 19 800 23 300 - net 14 800 18 600 15 900 18 600 Condensate (bbls/d) - gross 12 600 15 600 13 000 15 300 - net 9 600 12 000 10 100 11 800 Sulphur (tons/d) - gross 4 700 5 600 5 200 5 300 - net 4 700 5 000 5 000 4 800 Sales(3) - gross Natural gas (mmcf/d) 507 520 514 510 Ethane, propane and butane (bbls/d) 35 800 41 400 34 100 38 200 Condensate (bbls/d) 20 200 23 600 20 600 18 100 Sulphur (tons/d) 13 300 12 300 11 900 11 700 ------------------------------------------------------------------------- OIL SANDS (Note 3) Production Bitumen (bbls/d) - gross Minable 106 600 106 800 82 500 95 900 In situ 20 400 8 900 12 400 8 900 -------------------------------------- Total 127 000 115 700 94 900 104 800 Bitumen (bbls/d) - net Minable 105 600 105 700 81 700 95 000 In situ 20 100 8 600 12 000 8 700 -------------------------------------- Total 125 700 114 300 93 700 103 700 Sales(3) Synthetic crude sales excluding blend stocks (bbls/d) 113 100 112 300 85 900 99 400 Purchased upgrader blend stocks (bbls/d) 39 300 42 900 35 400 37 100 -------------------------------------- Total synthetic crude sales (bbls/d) 152 400 155 200 121 300 136 500 Bitumen product excluding diluent (bbls/d) 22 500 10 200 13 100 9 900 Purchased diluent (bbls/d) 6 100 2 100 3 000 1 900 -------------------------------------- Total bitumen products (bbls/d) 28 600 12 300 16 100 11 800 In situ condensate (bbls/d) 3 200 3 100 2 700 2 400 Unit Costs(4) Mining and upgrading operations Cash operating cost - excluding natural gas ($/bbl) 19.42 16.73 23.49 17.14 - natural gas ($/bbl) 4.84 7.15 5.24 6.08 -------------------------------------- Total cash operating cost ($/bbl) 24.26 23.88 28.73 23.22 Depreciation, depletion and amortization ($/bbl) 4.84 5.14 5.53 5.77 -------------------------------------- Total unit cost ($/bbl) 29.10 29.02 34.26 28.99 Unit Costs(4) In situ operations Cash operating cost - excluding natural gas ($/bbl) 11.87 12.04 14.02 13.65 - natural gas ($/bbl) 2.90 5.71 5.85 9.56 -------------------------------------- Total cash operating cost ($/bbl) 14.77 17.75 19.87 23.21 Depreciation, depletion and amortization ($/bbl) 7.61 6.45 7.85 5.11 -------------------------------------- Total unit cost ($/bbl) 22.38 24.20 27.72 28.32 ------------------------------------------------------------------------- OIL PRODUCTS Sales(3) Gasolines (m3/d) 20 800 20 900 20 800 21 000 Middle distillates (m3/d) 20 200 22 900 20 000 21 000 Other products (m3/d) 6 400 7 300 6 500 7 100 -------------------------------------- Total Oil Products sales (m3/d) 47 400 51 100 47 300 49 100 Crude oil processed by Shell refineries (m3/d)(5) 44 200 41 500 44 600 44 900 Refinery utilization (per cent)(6) 84 80 86 87 Earnings per litre (cents)(7) 0.5 2.3 3.4 2.4 ------------------------------------------------------------------------- Prices Natural gas average plant gate netback price ($/mcf) 6.51 11.53 6.79 8.23 Ethane, propane and butane average field gate price ($/bbl) 30.56 44.41 33.94 34.79 Condensate average field gate price ($/bbl) 63.93 68.30 71.63 66.76 Synthetic crude average plant gate price ($/bbl) 55.56 56.99 61.32 57.55 ------------------------------------------------------------------------- (Financial Charts) ------------------------------------------------------------------------- Natural Gas Ethane, Propane Condensate Avg. Synthetic Crude Avg. Price and Butane Price Avg. Price (Plant Gate Avg. Price (Field Gate) (Plant Gate) Netback) (Field Gate) ($/bbl) ($/bbl) ($/mcf) ($/bbl) ------------------------------------------------------------------------- Q4 05 11.53 44.41 68.30 56.99 ------------------------------------------------------------------------- Q1 06 8.29 38.04 72.30 57.04 ------------------------------------------------------------------------- Q2 06 6.53 31.84 76.78 67.72 ------------------------------------------------------------------------- Q3 06 5.81 34.79 76.69 68.37 ------------------------------------------------------------------------- Q4 06 6.51 30.56 63.93 55.56 ------------------------------------------------------------------------- SHELL CANADA LIMITED Financial and Operating Highlights (unaudited) Non-GAAP Measures Certain financial measures are not prescribed by Canadian generally accepted accounting principles (GAAP). These non-GAAP financial measures do not have any standardized meaning and, therefore, may not be comparable with the calculation of similar measures for other companies. The Corporation includes as non-GAAP measures return on average capital employed (ROACE), cash flow from operations and unit cash operating cost because they are key internal and external financial measures used to evaluate the performance of the Corporation. Definitions (1) Cash flow from operations is a non-GAAP measure and is defined as cash flow from operating activities before movement in working capital and operating activities. (2) ROACE is a non-GAAP measure and is defined as earnings plus after-tax interest expense on debt divided by the average of opening and closing common shareholders' equity plus preference shares, long-term debt and short-term borrowings. (3) Exploration & Production and Oil Products sales volumes include sales to third parties only. Oil Sands sales volumes include third-party and inter-segment sales. (4) Total unit cost for Oil Sands, including unit cash operating and unit depreciation, depletion and amortization (DD&A) costs, is a non-GAAP measure. Unit cash operating cost for Oil Sands mining and upgrading is defined as: operating, selling and general expenses plus cash cost items included in cost of goods sold (COGS), divided by synthetic crude sales excluding blend stocks. Operating, selling and general expenses associated with mining and upgrading were $725 million in the year of 2006 and $199 million in the fourth quarter of 2006. Cash cost items included in COGS were $176 million in the year of 2006 and $53 million in the fourth quarter of 2006. Unit cash operating cost for in situ operations is defined as: operating, selling and general expenses plus inter-segment purchases of natural gas, divided by bitumen product sales excluding diluent. Operating, selling and general expenses associated with in situ operations were $67 million in the year of 2006 and $24 million in the fourth quarter of 2006. Inter-segment purchases of natural gas were $28 million in the year of 2006 and $6 million in the fourth quarter of 2006. Unit DD&A cost for Oil Sands mining and upgrading is defined as: DD&A cost divided by synthetic crude sales excluding blend stocks. Unit DD&A cost includes preproduction costs, which were written off over the first three years of the project life (2003-2005). Unit DD&A cost for in situ operations is defined as: DD&A cost divided by bitumen product sales excluding diluent. Total mining unit cost includes long-term incentive plan (LTIP) costs totalling $0.42/bbl in the year of 2006 (2005 - $1.32/bbl) and $3.82/bbl for the fourth quarter of 2006 (2005 - $0.57/bbl). Total in-situ unit cost includes LTIP costs totalling $0.47/bbl in the year of 2006 (2005 - $2.25/bbl) and $2.14/bbl for the fourth quarter of 2006 (2005 - $1.21/bbl). (5) Crude oil processed by Shell refineries includes upgrader feedstock supplied to Scotford Refinery. (6) Refinery utilization equals crude oil processed by Shell refineries divided by total capacity of Shell refineries, including capacity uplifts at Scotford Refinery due to processing of various streams from the upgrader. (7) Oil Products earnings per litre equals Oil Products earnings after-tax divided by total Oil Products sales volumes. SHELL CANADA LIMITED Consolidated Statement of Earnings and Retained Earnings ($ millions, except as noted) (unaudited) Fourth Quarter Total year 2006 2005 2006 2005 ------------------------------------------------------------------------- (restated) (restated) Revenues Sales and other operating revenues 3 506 4 025 14 651 14 171 Dividends, interest and other income 75 18 155 223 ------------------------------------------------------------------------- Total revenues 3 581 4 043 14 806 14 394 ------------------------------------------------------------------------- Expenses Cost of goods sold 1 970 2 197 8 627 7 900 Operating, selling and general (Note 2) 880 648 2 494 2 419 Transportation 85 84 306 331 Exploration 45 22 131 120 Predevelopment 49 15 149 64 Depreciation, depletion, amortization and retirements 232 216 822 782 Interest on long-term debt 3 2 10 8 Other interest and financing charges 15 - 32 3 ------------------------------------------------------------------------- Total expenses 3 279 3 184 12 571 11 627 ------------------------------------------------------------------------- Earnings Earnings before income tax 302 859 2 235 2 767 ------------------------------------------------------------------------- Current income tax 88 161 518 602 Future income tax (9) 87 (21) 164 ------------------------------------------------------------------------- Total income tax 79 248 497 766 ------------------------------------------------------------------------- Earnings 223 611 1 738 2 001 ------------------------------------------------------------------------- Per common share (dollars) (Note 7) Earnings - basic 0.27 0.74 2.11 2.43 Earnings - diluted 0.27 0.73 2.09 2.40 Common shares outstanding (millions - weighted average) 826 825 825 825 ------------------------------------------------------------------------- Retained Earnings Balance at beginning of period 8 918 7 155 7 675 6 009 Earnings 223 611 1 738 2 001 ------------------------------------------------------------------------- 9 141 7 766 9 413 8 010 Common shares buy-back - - - 33 Dividends 91 91 363 302 ------------------------------------------------------------------------- Balance at end of period 9 050 7 675 9 050 7 675 ------------------------------------------------------------------------- SHELL CANADA LIMITED Consolidated Statement of Cash Flows ($ millions) (unaudited) Fourth Quarter Total year 2006 2005 2006 2005 ------------------------------------------------------------------------- (restated) (restated) Cash from Operating Activities Earnings 223 611 1 738 2 001 Exploration and predevelopment 31 19 111 99 Non-cash items Depreciation, depletion, amortization and retirements 232 216 822 782 Future income tax (9) 87 (21) 164 Other items (39) (7) (36) (10) ------------------------------------------------------------------------- Cash flow from operations 438 926 2 614 3 036 Movement in working capital and operating activities Accounts receivable securitization program - - - (150) Other working capital and operating items (Note 2) 347 419 (117) 175 ------------------------------------------------------------------------- 785 1 345 2 497 3 061 ------------------------------------------------------------------------- Cash Invested Capital and predevelopment expenditures (938) (709) (2 426) (1 715) Acquisition of BlackRock Ventures Inc. (Note 4) - - (2 428) - Movement in working capital from investing activities 148 53 309 69 ------------------------------------------------------------------------- Capital expenditures and movement in working capital (790) (656) (4 545) (1 646) Proceeds on disposal of properties, plant and equipment 105 1 106 6 Investments and other 7 - (19) - ------------------------------------------------------------------------- (678) (655) (4 458) (1 640) ------------------------------------------------------------------------- Cash from Financing Activities Common shares buy-back - - - (34) Proceeds from exercise of common share stock options 2 - 7 6 Redemption of preference shares (Note 9) - - (1) - Dividends paid (91) (91) (363) (302) Long-term debt and other - - - (135) Short-term financing (18) - 1 235 - ------------------------------------------------------------------------- (107) (91) 878 (465) ------------------------------------------------------------------------- (Decrease) Increase in cash - 599 (1 083) 956 Cash at beginning of period - 484 1 083 127 ------------------------------------------------------------------------- Cash at December 31(1) - 1 083 - 1 083 ------------------------------------------------------------------------- Supplemental disclosure of cash flow information Dividends received 4 5 13 15 Interest received 4 8 57 42 Interest paid 16 2 42 12 Income tax paid 142 123 743 683 (1) Cash comprises cash and highly liquid short-term investments. SHELL CANADA LIMITED Consolidated Balance Sheet ($ millions) (unaudited) Dec. 31, Dec. 31, 2006 2005 ------------------------------------------------------------------------- (restated) Assets Current assets Cash and short-term investments - 1 083 Accounts receivable 1 940 1 821 Inventories Crude oil, products and merchandise 523 535 Materials and supplies 100 92 Prepaid expenses 50 71 Future income tax 299 327 ------------------------------------------------------------------------- 2 912 3 929 Investments, long-term receivables and other 741 671 Properties, plant and equipment 13 669 9 066 Goodwill (Notes 4 and 5) 234 - ------------------------------------------------------------------------- Total assets 17 556 13 666 ------------------------------------------------------------------------- Liabilities Current liabilities Short-term borrowings (Note 6) 1 235 - Accounts payable, accrued liabilities and other (Note 2) 2 752 2 272 Income and other taxes payable 535 687 Current portion of asset retirement and other long-term obligations 101 26 Current portion of long-term debt 3 11 ------------------------------------------------------------------------- 4 626 2 996 Asset retirement and other long-term obligations 611 538 Long-term debt 197 200 Future income tax 2 542 1 733 ------------------------------------------------------------------------- Total liabilities 7 976 5 467 ------------------------------------------------------------------------- Shareholders' Equity Capital stock 100 4% preference shares (Note 9) - 1 825 662 514 common shares (2005 - 825 102 612) 530 523 Retained earnings 9 050 7 675 ------------------------------------------------------------------------- Total shareholders' equity 9 580 8 199 ------------------------------------------------------------------------- Total liabilities and shareholders' equity 17 556 13 666 ------------------------------------------------------------------------- SHELL CANADA LIMITED Segmented Information ($ millions) (unaudited) Fourth Quarter Exploration Total & Production Oil Sands 2006 2005 2006 2005 2006 2005 ------------------------------------------------------------------------- (restated) (restated) (restated) (Note 3) (Note 3) Revenues Sales and other operating revenues 3 506 4 025 459 740 545 435 Inter-segment sales - - 70 73 428 474 Dividends, interest and other income 75 18 2 1 51 - ------------------------------------------------------------------------- Total revenues 3 581 4 043 531 814 1 024 909 ------------------------------------------------------------------------- Expenses Cost of goods sold 1 970 2 197 - - 267 243 Inter-segment purchases - - 46 62 120 116 Operating, selling and general 880 648 171 128 223 191 Transportation 85 84 85 84 - - Exploration 45 22 45 22 - - Predevelopment 49 15 7 8 32 7 Depreciation, depletion, amortization and retirements 232 216 107 93 66 59 Interest on long-term debt 3 2 - - - - Other interest and financing charges 15 - - - - - ------------------------------------------------------------------------- Total expenses 3 279 3 184 461 397 708 616 ------------------------------------------------------------------------- Earnings (loss) Earnings (loss) before income tax 302 859 70 417 316 293 ------------------------------------------------------------------------- Current income tax 88 161 (5) 163 112 (4) Future income tax (9) 87 22 (9) (17) 104 ------------------------------------------------------------------------- Total income tax 79 248 17 154 95 100 ------------------------------------------------------------------------- Earnings (loss) 223 611 53 263 221 193 ------------------------------------------------------------------------- ------------------------------------------------------------------------- Fourth Quarter Oil Products Corporate 2006 2005 2006 2005 ------------------------------------------------------- (restated) (restated) Revenues Sales and other operating revenues 2 502 2 857 - (7) Inter-segment sales 121 120 - - Dividends, interest and other income 18 8 4 9 ------------------------------------------------------- Total revenues 2 641 2 985 4 2 ------------------------------------------------------- Expenses Cost of goods sold 1 706 1 957 (3) (3) Inter-segment purchases 453 489 - - Operating, selling and general 391 305 95 24 Transportation - - - - Exploration - - - - Predevelopment 10 - - - Depreciation, depletion, amortization and retirements 58 63 1 1 Interest on long-term debt - - 3 2 Other interest and financing charges - - 15 - ------------------------------------------------------- Total expenses 2 618 2 814 111 24 ------------------------------------------------------- Earnings (loss) Earnings (loss) before income tax 23 171 (107) (22) ------------------------------------------------------- Current income tax (6) 11 (13) (9) Future income tax 7 54 (21) (62) ------------------------------------------------------- Total income tax 1 65 (34) (71) ------------------------------------------------------- Earnings (loss) 22 106 (73) 49 ------------------------------------------------------- ------------------------------------------------------- Total Year Exploration Total & Production Oil Sands 2006 2005 2006 2005 2006 2005 ------------------------------------------------------------------------- (restated) (restated) (restated) (Note 3) (Note 3) Revenues Sales and other operating revenues 14 651 14 171 1 977 2 253 1 782 1 553 Inter-segment sales - - 216 275 1 524 1 671 Dividends, interest and other income 155 223 7 26 57 132 ------------------------------------------------------------------------- Total revenues 14 806 14 394 2 200 2 554 3 363 3 356 ------------------------------------------------------------------------- Expenses Cost of goods sold 8 627 7 900 - - 1 024 790 Inter-segment purchases - - 221 241 417 416 Operating, selling and general 2 494 2 419 446 467 792 692 Transportation 306 331 306 331 - - Exploration 131 120 131 120 - - Predevelopment 149 64 36 38 92 26 Depreciation, depletion, amortization and retirements 822 782 378 348 211 228 Interest on long-term debt 10 8 - - - - Other interest and financing charges 32 3 - - - - ------------------------------------------------------------------------- Total expenses 12 571 11 627 1 518 1 545 2 536 2 152 ------------------------------------------------------------------------- Earnings (loss) Earnings (loss) before income tax 2 235 2 767 682 1 009 827 1 204 ------------------------------------------------------------------------- Current income tax 518 602 153 411 195 41 Future income tax (21) 164 30 (67) (86) 380 ------------------------------------------------------------------------- Total income tax 497 766 183 344 109 421 ------------------------------------------------------------------------- Earnings (loss) 1 738 2 001 499 665 718 783 ------------------------------------------------------------------------- ------------------------------------------------------------------------- Total assets 17 556 13 666 3 585 3 261 8 886 4 274 Capital employed(1) 11 015 8 410 2 292 1 884 5 982 2 680 Total Year Oil Products Corporate 2006 2005 2006 2005 ------------------------------------------------------- (restated) (restated) Revenues Sales and other operating revenues 10 870 10 343 22 22 Inter-segment sales 462 412 - - Dividends, interest and other income 35 24 56 41 ------------------------------------------------------- Total revenues 11 367 10 779 78 63 ------------------------------------------------------- Expenses Cost of goods sold 7 599 7 108 4 2 Inter-segment purchases 1 564 1 701 - - Operating, selling and general 1 153 1 139 103 121 Transportation - - - - Exploration - - - - Predevelopment 21 - - - Depreciation, depletion, amortization and retirements 229 204 4 2 Interest on long-term debt - - 10 8 Other interest and financing charges - - 32 3 ------------------------------------------------------- Total expenses 10 566 10 152 153 136 ------------------------------------------------------- Earnings (loss) Earnings (loss) before income tax 801 627 (75) (73) ------------------------------------------------------- Current income tax 190 296 (20) (146) Future income tax 27 (103) 8 (46) ------------------------------------------------------- Total income tax 217 193 (12) (192) ------------------------------------------------------- Earnings (loss) 584 434 (63) 119 ------------------------------------------------------- ------------------------------------------------------- Total assets 4 846 4 688 239 1 443 Capital employed(1) 2 599 2 275 142 1 571 (1) Capital employed is the total of equity, long-term debt and short-term borrowings. SHELL CANADA LIMITED Notes to Consolidated Financial Statements (unaudited) 1. Accounting Policies These financial statements follow the same accounting policies and methods of computation as, and should be read in conjunction with, the Consolidated Financial Statements for the year ended December 31, 2005, except as described in notes 2, 3 and 4. Certain other information provided for prior periods has been reclassified to conform to the current presentation. 2. Change in Accounting Policy Shell Canada adopted Emerging Issues Committee (EIC) Abstract 162 "Stock Based Compensation For Employees Eligible to Retire Before The Vesting Date" with prior period restatement as required. The EIC mandates that employees who are eligible to retire at the grant date, or will become eligible to retire during the vesting period, should have their stock-based compensation awards recognized at the earliest eligible retirement date. The impact of this change resulted in a long-term incentive plan (LTIP) reduction in expense of $10 million for the year ended December 31, 2006 (2005 - $13 million increase in expense). These changes will also result in corresponding increases/decreases to the Cash from Operating Activities section of the Consolidated Statement of Cash Flows. Earnings per common share are increased by 0.01 for the period ended December 31, 2006 (2005 -0.01 decrease). On a diluted basis, earnings per common share are increased by 0.02 (2005 -0.01 decrease). 3. Segmented Information Effective January 1, 2006, the Peace River business was transferred from Exploration & Production to the Oil Sands business unit. Segmented information for the relevant business units has been reclassified for the prior periods. 4. Acquisition of BlackRock Ventures Inc. On June 21, 2006, the Corporation acquired more than 92 per cent of the outstanding common shares of BlackRock Ventures Inc. (BlackRock). The original offer was extended to June 27, 2006, and again to July 10, 2006, and additional common shares were acquired. The Corporation completed its acquisition of BlackRock and acquired all of the remaining common shares by way of compulsory acquisition on July 11, 2006. BlackRock was engaged in the development and production of heavy oil in Western Canada. The Corporation's total consideration for the transaction was $2,570 million ($2,428 million net of cash acquired) including acquisition costs of $12 million and working capital of $108 million. Of the consideration paid, $3,092 million was allocated to oil and natural gas properties and $234 million was allocated to goodwill. The acquisition was accounted for based on the purchase method and the allocation was supported by a third-party valuation. A summary of the purchase equation is presented as follows: Net assets acquired ($ millions) Oil and natural gas properties 3 092 Goodwill(1) 234 Working capital(2) 108 Other assets 1 Asset retirement obligations (11) Future income tax liability (854) ----------- 2 570 ----------- ----------- (1) The $234 million of goodwill has no tax basis and was allocated to the Oil Sands business unit. (2) Working capital acquired includes cash of $142 million. 5. Goodwill The goodwill is entirely due to the timing difference created between the tax basis of the assets compared to the fair value. Goodwill is not subject to amortization, but is tested for impairment on an annual basis, or more frequently if events occur that could result in impairment, by applying a fair value-based test. 6. Short-term borrowings The Corporation entered into a $1 billion revolving credit facility ("the facility") during the second quarter of 2006. The facility was arranged with a syndicate of banks and matures on June 15, 2008. This facility, along with the already established $1.5 billion commercial paper program, provided the Corporation with $2.5 billion of borrowing capacity. At December 31, 2006, the outstanding balance on the revolving credit facility was $199 million in the form of short-term borrowings that had an effective interest rate of 4.44 per cent. At December 31, 2006, the outstanding balance on the commercial paper program was $1,036 million at an effective interest rate of 4.39 per cent. 7. Earnings Per Share Fourth Quarter Total Year 2006 2005 2006 2005 ------------------------------------------------------------------------- (restated) (restated) Earnings ($ millions) 223 611 1 738 2 001 Weighted average number of common shares (millions) 826 825 825 825 Dilutive securities (millions) Options under Long Term Incentive Plan 9 10 8 9 Basic earnings per share ($ per share) 0.27 0.74 2.11 2.43 Diluted earnings per share ($ per share) 0.27 0.73 2.09 2.40 8. Employee Future Benefits The Corporation's pension plans are described in the notes to the Consolidated Financial Statements for the year ended December 31, 2005. The components of the pension expense in the Consolidated Statement of Earnings are as follows: Fourth Quarter ($ millions) Pension Benefits Other Benefits 2006 2005 2006 2005 ------------------------------------------------------------------------- Current service cost 12 10 - - Employee contributions - - - - Interest cost 32 31 3 3 Expected return on plan assets (37) (35) - - Amortization of transitional (asset) obligation (9) (9) 1 1 Amortization of net actuarial loss 22 17 - - ------------------------------------------------------------------------- Net expense 20 14 4 4 Defined contribution segment 5 5 - - ------------------------------------------------------------------------- Total 25 19 4 4 ------------------------------------------------------------------------- ------------------------------------------------------------------------- Total Year ($ millions) Pension Benefits Other Benefits 2006 2005 2006 2005 ------------------------------------------------------------------------- Current service cost 46 37 2 2 Employee contributions (3) (3) - - Interest cost 128 127 11 10 Expected return on plan assets (147) (137) - - Amortization of transitional (asset) obligation (36) (36) 2 2 Amortization of net actuarial loss 88 71 3 - ------------------------------------------------------------------------- Net expense 76 59 18 14 Defined contribution segment 25 15 - - ------------------------------------------------------------------------- Total 101 74 18 14 ------------------------------------------------------------------------- ------------------------------------------------------------------------- 9. Redemption of Preference Shares Effective September 30, 2006, the Corporation redeemed the previously outstanding 100 preference shares for cash consideration in accordance with their terms. For further information: Investor Inquiries: Ken Lawrence, Investor Relations, (403) 691-2175; Media Inquiries: Jan Rowley, Public Affairs, (403) 691-3899; Visit Shell Canada's Internet website: www.shell.ca
This website and sisters royaldutchshellgroup.com, shellnazihistory.com, royaldutchshell.website, johndonovan.website, and shellnews.net, are owned by John Donovan. There is also a Wikipedia segment.