EX-99.1 2 exhibit99_1.htm EXHIBIT 99.1: NEWS RELEASE DATED JANUARY 24, 2007
 
 
 
FOR IMMEDIATE RELEASE
WEDNESDAY, JANUARY 24, 2007
 
Shell Canada Announces Earnings of $1.7 Billion

 
 
 
 
Calgary, Alberta - 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 20051. 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 20051. 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 20051, 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."
 
Investor Inquiries:             Media Inquiries:
Ken Lawrence                                    Jan Rowley
Investor Relations                                Public Affairs
(403) 691-2175                                 (403) 691-3899
 
Visit Shell Canada’s Internet website: www.shell.ca
 
 

SHELL CANADA LIMITED
 
MANAGEMENT’S DISCUSSION AND ANALYSIS
 
 
 
Total Company
Shell Canada Limited earnings in 2006 were $1,738 million, down from $2,001 million1  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.
 
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.
 

 
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).
 
SHELL CANADA LIMITED
Management's Discussion and Analysis (continued)
 

 
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.
 
 
SHELL CANADA LIMITED
Management's Discussion and Analysis (continued)
 
 
 
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.
 
 
SHELL CANADA LIMITED
Management's Discussion and Analysis (continued)
 
 
 
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.
 
 
 
SHELL CANADA LIMITED
Management's Discussion and Analysis (continued)
 
 
 
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).
 
SHELL CANADA LIMITED
Management's Discussion and Analysis (continued)
 

 
 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.
 
SHELL CANADA LIMITED
Management's Discussion and Analysis (continued)
 
 
 
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 operations1 
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 operations1 
        
    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
Total natural gas - net
431
428
425
413
         
Ethane, propane and butane (bbls/d) - gross
18 600
23 600
19 800
23 300
Ethane, propane and butane (bbls/d) - net
14 800
18 600
15 900
18 600
         
Condensate (bbls/d) - gross
12 600
15 600
13 000
15 300
Condensate (bbls/d) - net
9 600
12 000
10 100
11 800
         
Sulphur (tons/d) - gross
4 700
5 600
5 200
5 300
Sulphur (tons/d) - net
4 700
5 000
5 000
4 800
         
Sales3 - 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
       
 
Sales3   
      
 
    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 Costs4
        
         
Mining and upgrading operations
        
         
    Cash operating cost - excluding natural gas ($/bbl)
19.42
16.73
23.49
17.14
    Cash operating cost - natural gas ($/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
 

SHELL CANADA LIMITED
        
Operating Highlights (continued)
        
(unaudited)
        
 
    Fourth Quarter                Total Year
 
2006
2005
2006
2005
 
  
(restated)
  
(restated)
OIL SANDS (continued)
        
         
Unit Costs4
        
         
In situ operations
        
         
    Cash operating cost - excluding natural gas ($/bbl)
11.87
12.04
14.02
13.65
    Cash operating cost - natural gas ($/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
        
         
Sales3   
        
    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
         
 
 
 

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 311   
-
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, 2006
Dec. 31, 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
       
___________________________
      
Clive Mather, Director
      
       
     
___________________________
      
Kerry L. Hawkins, Director
      
 

SHELL CANADA LIMITED
                      
Segmented Information
                      
($ millions)
                      
(unaudited)
                      
                       
   
Fourth Quarter
                       
       
Exploration
            
 
  
Total
& Production
Oil Sands
Oil Products
Corporate
   
2006
2005
2006
2005
2006
2005
2006
2005
2006
2005
 
    
(restated)
  
(restated)
  
(restated)
  
(restated)
  
(restated)
       
(Note 3)
(Note 3)
      
 
Revenues
                    
 
Sales and other operating revenues
  
3 506
4 025
459
740
545
435
2 502
2 857
-
( 7)
Inter-segment sales
  
-
-
70
73
428
474
121
120
-
-
Dividends, interest and other income
  
75
18
2
1
51
-
18
8
4
9
Total revenues
  
3 581
4 043
531
814
1 024
909
2 641
2 985
4
2
Expenses
                    
 
Cost of goods sold
  
1 970
2 197
-
-
267
243
1 706
1 957
( 3)
( 3)
Inter-segment purchases
  
-
-
46
62
120
116
453
489
-
-
Operating, selling and general
  
880
648
171
128
223
191
391
305
95
24
Transportation
  
85
84
85
84
-
-
-
-
-
-
Exploration
 
45
22
45
22
-
-
-
-
-
-
Predevelopment
  
49
15
7
8
32
7
10
-
-
-
Depreciation, depletion,
                   
 
    amortization and retirements
  
232
216
107
93
66
59
58
63
1
1
Interest on long-term debt
  
3
2
-
-
-
-
-
-
3
2
Other interest and financing charges
  
15
-
-
-
-
-
-
-
15
-
Total expenses
  
3 279
3 184
461
397
708
616
2 618
2 814
111
24
Earnings (loss)
                    
 
Earnings (loss) before income tax
  
302
859
70
417
316
293
23
171
( 107)
( 22)
Current income tax
  
88
161
( 5)
163
112
( 4)
( 6)
11
( 13)
( 9)
Future income tax
 
( 9)
87
22
( 9)
( 17)
104
7
54
( 21)
( 62)
Total income tax
  
79
248
17
154
95
100
1
65
( 34)
( 71)
Earnings (loss)
  
223
611
53
263
221
193
22
106
( 73)
49
 

SHELL CANADA LIMITED
                      
Segmented Information (continued)
                      
($ millions)
                      
(unaudited)
                      
                       
   
Total Year
                       
       
Exploration
            
 
  
Total
& Production
Oil Sands
Oil Products
Corporate
   
2006
2005
2006
2005
2006
2005
2006
2005
2006
2005
 
    
(restated)
  
(restated)
  
(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
10 870
10 343
22
22
Inter-segment sales
  
-
-
216
275
1 524
1 671
462
412
-
-
Dividends, interest and other income
  
155
223
7
26
57
132
35
24
56
41
Total revenues
  
14 806
14 394
2 200
2 554
3 363
3 356
11 367
10 779
78
63
Expenses
                    
 
Cost of goods sold
  
8 627
7 900
-
-
1 024
790
7 599
7 108
4
2
Inter-segment purchases
  
-
-
221
241
417
416
1 564
1 701
-
-
Operating, selling and general
  
2 494
2 419
446
467
792
692
1 153
1 139
103
121
Transportation
  
306
331
306
331
-
-
-
-
-
-
Exploration
 
131
120
131
120
-
-
-
-
-
-
Predevelopment
  
149
64
36
38
92
26
21
-
-
-
Depreciation, depletion,
                   
 
    amortization and retirements
  
822
782
378
348
211
228
229
204
4
2
Interest on long-term debt
  
10
8
-
-
-
-
-
-
10
8
Other interest and financing charges
  
32
3
-
-
-
-
-
-
32
3
Total expenses
  
12 571
11 627
1 518
1 545
2 536
2 152
10 566
10 152
153
136
Earnings (loss)
                    
 
Earnings (loss) before income tax
  
2 235
2 767
682
1 009
827
1 204
801
627
( 75)
( 73)
Current income tax
  
518
602
153
411
195
41
190
296
( 20)
( 146)
Future income tax
 
( 21)
164
30
( 67)
( 86)
380
27
( 103)
8
(46)
Total income tax
  
497
766
183
344
109
421
217
193
( 12)
( 192)
Earnings (loss)
  
1 738
2 001
499
665
718
783
584
434
( 63)
119
                       
                       
Total assets
  
17 556
13 666
3 585
3 261
8 886
4 274
4 846
4 688
239
1 443
                       
Capital employed 1
  
11 015
8 410
2 292
1 884
5 982
2 680
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
    Goodwill1                      234
    Working capital2                          108
    Other assets                                                              1
    Asset retirement obligations                      ( 11)
    Future income tax liability                 ( 854)
                                  2 570
       
1The $234 million of goodwill has no tax basis and was allocated to the Oil Sands business unit.
     
       
2Working capital acquired includes cash of $142 million.
      
 


SHELL CANADA LIMITED
Notes to Consolidated Financial Statements (Continued)
(unaudited)

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
           
 

SHELL CANADA LIMITED
Notes to Consolidated Financial Statements (Continued)
(unaudited)
    
     
     
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.