Exhibit 7  Supplementary
Oil and Gas Information (unaudited) The supplemental data on the
Companys oil and gas activities on pages 60 to 63 was prepared in accordance
with the FASBs SFAS No. 69: Disclosures About Oil and Gas Producing
Activities. Activities not directly associated with conventional crude oil and
natural gas production, including synthetic oil operations, are excluded from
all aspects of this supplementary oil and gas information. RESULTS OF OPERATIONS FROM OIL AND GAS PRODUCING
ACTIVITIES   Years ended December 31
  (millions of Canadian dollars)
  
  North
  America
  
  North
  Sea
  
  Southeast
  Asia(1)
  
  Sudan
  
  Algeria
  
  Trinidad
  
  Other
  
  Total2002
  
  Net oil and gas revenue derived from proved reserves(2)
  
  1,634
  
  1,914
  
  356
  
  500
  
  
  
  
  
  
  
  4,404Less: Production costs
  
  339
  
  588
  
  86
  
  84
  
  
  
  
  
  
  
  1,097Exploration and dry hole expense
  
  194
  
  29
  
  23
  
  19
  
  5
  
  46
  
  43
  
  359Depreciation, depletion and amortization
  
  583
  
  701
  
  87
  
  92
  
  
  
  
  
  
  
  1,463Tax expense (recovery)
  
  205
  
  430
  
  75
  
  85
  
  (2
  )
  (22
  )
  (18
  )
  753Results of operations
  
  313
  
  166
  
  85
  
  220
  
  (3
  )
  (24
  )
  (25
  )
  7322001
  
  Net oil and gas revenue derived from proved reserves(2)
  
  1,744
  
  1,584
  
  350
  
  389
  
  
  
  
  
  
  
  4,067Less: Production costs
  
  323
  
  467
  
  70
  
  66
  
  
  
  
  
  
  
  926Exploration and dry hole expense
  
  123
  
  51
  
  16
  
  27
  
  7
  
  15
  
  21
  
  260Depreciation, depletion and amortization
  
  549
  
  558
  
  93
  
  77
  
  
  
  
  
  
  
  1,277Tax expense (recovery)
  
  273
  
  247
  
  95
  
  52
  
  (3
  )
  (6
  )
  (9
  )
  649Results of operations
  
  476
  
  261
  
  76
  
  167
  
  (4
  )
  (9
  )
  (12
  )
  9552000
  
  Net oil and gas revenue derived from proved reserves(2)
  
  1,527
  
  1,671
  
  403
  
  337
  
  
  
  
  
  
  
  3,938Less: Production costs
  
  256
  
  435
  
  55
  
  64
  
  
  
  
  
  
  
  810Exploration and dry hole expense
  
  83
  
  28
  
  24
  
  11
  
  17
  
  4
  
  10
  
  177Depreciation, depletion and amortization
  
  462
  
  512
  
  83
  
  80
  
  
  
  
  
  
  
  1,137Tax expense (recovery)
  
  336
  
  302
  
  126
  
  56
  
  (7
  )
  (2
  )
  (5
  )
  806Results of operations
  
  390
  
  394
  
  115
  
  126
  
  (10
  )
  (2
  )
  (5
  )
  1,008 
 (1)Includes
  operations in Indonesia and Malaysia/Vietnam.(2)Net oil and
  gas revenue derived from proved reserves is net of applicable royalties.  CAPITALIZED COSTS RELATED TO OIL AND GAS ACTIVITIES  Years ended December 31
  (millions of Canadian dollars)
  
  North
  America
  
  North
  Sea
  
  Southeast
  Asia(1)
  
  Sudan
  
  Algeria
  
  Trinidad
  
  Other
  
  Total2002
  
  Proved properties
  
  6,939
  
  5,592
  
  1,422
  
  986
  
  217
  
  45
  
  
  
  15,201Unproved properties
  
  214
  
  14
  
  156
  
  36
  
  29
  
  9
  
  
  
  458Incomplete wells and
  facilities
  
  33
  
  66
  
  22
  
  17
  
  
  
  
  
  
  
  1387,186
  
  5,672
  
  1,600
  
  1,039
  
  246
  
  54
  
  
  
  15,797Less: accumulated
  depreciation,depletion and amortization
  
  2,339
  
  2,774
  
  509
  
  271
  
  
  
  
  
  
  
  5,893Net capitalized costs
  
  4,847
  
  2,898
  
  1,091
  
  768
  
  246
  
  54
  
  
  
  9,9042001
  
  Proved properties
  
  6,183
  
  4,454
  
  1,092
  
  889
  
  26
  
  
  
  
  
  12,644Unproved properties
  
  408
  
  284
  
  195
  
  30
  
  94
  
  17
  
  
  
  1,028Incomplete wells and
  facilities
  
  24
  
  37
  
  56
  
  22
  
  23
  
  6
  
  
  
  1686,615
  
  4,775
  
  1,343
  
  941
  
  143
  
  23
  
  
  
  13,840Less: accumulated
  depreciation, depletion and amortization
  
  1,926
  
  1,965
  
  419
  
  178
  
  
  
  
  
  
  
  4,488Net capitalized costs
  
  4,689
  
  2,810
  
  924
  
  763
  
  143
  
  23
  
  
  
  9,3522000
  
  Proved properties
  
  4,783
  
  3,728
  
  759
  
  770
  
  7
  
  
  
  
  
  10,047Unproved properties
  
  363
  
  227
  
  42
  
  12
  
  76
  
  7
  
  4
  
  731Incomplete wells and
  facilities
  
  12
  
  5
  
  2
  
  27
  
  
  
  
  
  
  
  465,158
  
  3,960
  
  803
  
  809
  
  83
  
  7
  
  4
  
  10,824Less: accumulated
  depreciation,
  depletion and amortization
  
  1,515
  
  1,476
  
  321
  
  95
  
  
  
  
  
  
  
  3,407Net capitalized costs
  
  3,643
  
  2,484
  
  482
  
  714
  
  83
  
  7
  
  4
  
  7,417 
 (1)    Includes
  operations in Indonesia and Malaysia/Vietnam.   60 
   COSTS INCURRED IN OIL AND GAS ACTIVITIES  Years ended December 31
  (millions of Canadian dollars)
  
  North
  America
  
  North
  Sea
  
  Southeast
  Asia(1)
  
  Sudan
  
  Algeria
  
  Trinidad
  
  Other
  
  Total2002
  
  Property acquisition costsProved
  
  174
  
  88
  
  
  
  
  
  
  
  
  
  
  
  262Unproved
  
  50
  
  13
  
  
  
  
  
  
  
  9
  
  
  
  72Exploration costs
  
  271
  
  134
  
  36
  
  27
  
  3
  
  54
  
  43
  
  568Development costs
  
  478
  
  297
  
  233
  
  71
  
  103
  
  14
  
  
  
  1,196Total costs incurred
  
  973
  
  532
  
  269
  
  98
  
  106
  
  77
  
  43
  
  2,0982001
  
  Property acquisition costsProved
  
  828
  
  213
  
  129
  
  
  
  
  
  
  
  
  
  1,170Unproved
  
  240
  
  19
  
  245
  
  
  
  
  
  
  
  
  
  504Exploration costs
  
  251
  
  106
  
  31
  
  42
  
  22
  
  31
  
  21
  
  504Development costs
  
  553
  
  527
  
  110
  
  75
  
  41
  
  
  
  
  
  1,306Total costs incurred
  
  1,872
  
  865
  
  515
  
  117
  
  63
  
  31
  
  21
  
  3,4842000
  
  Property acquisition costsProved
  
  197
  
  70
  
  
  
  
  
  
  
  
  
  
  
  267Unproved
  
  69
  
  181
  
  
  
  
  
  
  
  
  
  
  
  250Exploration costs
  
  184
  
  46
  
  30
  
  33
  
  29
  
  7
  
  10
  
  339Development costs
  
  426
  
  257
  
  39
  
  37
  
  5
  
  
  
  
  
  764Total costs incurred
  
  876
  
  554
  
  69
  
  70
  
  34
  
  7
  
  10
  
  1,620 
 (1)Includes
  operations in Indonesia and Malaysia/Vietnam.  STANDARDIZED
MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS FROM PROVED RESERVES Future net cash flows were calculated by applying the respective
year-end prices to the Companys estimated future production of proved reserves
and deducting estimates of future development and production costs and income
taxes. Future development and production costs have been estimated based on the
assumed continuation of cost levels and economic conditions existing at each
year end. Similarly, future income taxes have been estimated based on statutory
tax rates enacted at year end. The present values of the estimated future cash
flows were determined by applying a 10% discount rate prescribed by the FASB. In order to increase the comparability between companies, the
standardized measure of discounted future net cash flows necessarily employs
uniform assumptions that do not necessarily reflect managements best estimate
of future events and anticipated outcomes. Accordingly, the Company does not
believe that the standardized measure of discounted future net cash flows will
be representative of actual future net cash flows and should not be considered
to represent the fair market value of the oil and gas properties. Actual future
net cash flows will differ significantly from those estimated due to, but not
limited to, the following: 
  production rates will
  differ from those estimated both in terms of timing and amount. For example,
  future production may include significant additional volumes from unproved
  reserves;
  future prices and economic conditions will differ from those at
  year end. For example, changes in prices increased the discounted future net
  cash flows by $9.7 billion in 2002;
  future production and development costs will be determined by
  future events and will differ from those at year end; and
  estimated income taxes will differ in terms of amounts and
  timing dependent on the above factors, changes in enacted rates and the
  impact of future expenditures on unproved properties. The standardized measure of discounted future net cash flows was
prepared using the following prices:   2002
  
  2001
  
  2000Crude oil and liquids ($/bbl)
  
  North America
  
  42.07
  
  22.48
  
  30.33North Sea
  
  46.84
  
  29.61
  
  33.14Southeast Asia(1)
  
  49.22
  
  30.10
  
  33.61Sudan
  
  44.09
  
  23.89
  
  27.59Algeria
  
  48.37
  
  29.20
  
  33.29Trinidad
  
  45.72
  
  
  
  45.13
  
  26.34
  
  31.04Natural Gas ($/mcf)
  
  North America
  
  6.06
  
  3.49
  
  13.61North Sea
  
  5.59
  
  4.97
  
  5.19Southeast Asia(1)
  
  4.94
  
  2.54
  
  3.80Trinidad
  
  1.26
  
  
  
  5.43
  
  3.25
  
  10.57 
 (1)Includes
  operations in Indonesia and Malaysia/Vietnam.  61 
   DISCOUNTED FUTURE NET CASH FLOWS FROM PROVED RESERVES  As at December 31
  (millions of Canadian dollars)
  
  North
  America
  
  North
  Sea
  
  Southeast
  Asia(1)
  
  Sudan
  
  Algeria
  
  Trinidad
  
  Total2002
  
  Future cash inflows(2)
  
  19,639
  
  13,160
  
  6,627
  
  4,090
  
  675
  
  1,143
  
  45,334Future costsProduction
  
  (4,325
  )
  (5,577
  )
  (1,040
  )
  (999
  )
  (230
  )
  (157
  )
  (12,328
  )Development and site restoration
  
  (995
  )
  (1,873
  )
  (709
  )
  (313
  )
  (64
  )
  (368
  )
  (4,322
  )Future net inflows before
  income taxes
  
  14,319
  
  5,710
  
  4,878
  
  2,778
  
  381
  
  618
  
  28,684Future income and production
  revenue taxes
  
  (5,654
  )
  (2,597
  )
  (2,011
  )
  (744
  )
  (31
  )
  (370
  )
  (11,407
  )Future net cash flows
  
  8,665
  
  3,113
  
  2,867
  
  2,034
  
  350
  
  248
  
  17,27710%discount factor
  
  (3,913
  )
  (554
  )
  (1,387
  )
  (655
  )
  (97
  )
  (161
  )
  (6,767
  )Discounted future net cash
  flows
  
  4,752
  
  2,559
  
  1,480
  
  1,379
  
  253
  
  87
  
  10,5102001
  
  Future cash inflows(2)
  
  11,376
  
  9,347
  
  4,026
  
  2,924
  
  493
  
  
  
  28,166Future costsProduction
  
  (3,449
  )
  (4,253
  )
  (875
  )
  (991
  )
  (155
  )
  
  
  (9,723
  )Development and site restoration
  
  (567
  )
  (1,616
  )
  (850
  )
  (217
  )
  (71
  )
  
  
  (3,321
  )Future net inflows before
  income taxes
  
  7,360
  
  3,478
  
  2,301
  
  1,716
  
  267
  
  
  
  15,122Future income and
  production revenue taxes
  
  (2,509
  )
  (1,284
  )
  (929
  )
  (361
  )
  (26
  )
  
  
  (5,109
  )Future net cash flows
  
  4,851
  
  2,194
  
  1,372
  
  1,355
  
  241
  
  
  
  10,01310% discount factor
  
  (1,797
  )
  (292
  )
  (804
  )
  (478
  )
  (121
  )
  
  
  (3,492
  )Discounted future net cash
  flows
  
  3,054
  
  1,902
  
  568
  
  877
  
  120
  
  
  
  6,5212000
  
  Future cash inflows(2)
  
  28,716
  
  9,448
  
  2,640
  
  2,726
  
  408
  
  
  
  43,938Future costsProduction
  
  (2,711
  )
  (3,423
  )
  (485
  )
  (724
  )
  (62
  )
  
  
  (7,405
  )Development and site restoration
  
  (292
  )
  (1,403
  )
  (160
  )
  (218
  )
  (46
  )
  
  
  (2,119
  )Future net inflows before
  income taxes
  
  25,713
  
  4,622
  
  1,995
  
  1,784
  
  300
  
  
  
  34,414Future income and
  production revenue taxes
  
  (10,663
  )
  (2,108
  )
  (852
  )
  (362
  )
  (80
  )
  
  
  (14,065
  )Future net cash flows
  
  15,050
  
  2,514
  
  1,143
  
  1,422
  
  220
  
  
  
  20,34910% discount factor
  
  (6,136
  )
  (481
  )
  (507
  )
  (515
  )
  (118
  )
  
  
  (7,757
  )Discounted future net cash
  flows
  
  8,914
  
  2,033
  
  636
  
  907
  
  102
  
  
  
  12,592 
 (1)Includes
  operations in Indonesia and Malaysia/Vietnam.(2)Future cash
  inflows are revenues net of royalties.  PRINCIPAL SOURCES OF CHANGES IN DISCOUNTED CASH FLOWS   Years
  ended December 31 (millions of Canadian dollars)
  
  2002
  
  2001
  
  2000Sales of oil and gas produced, net of production costs
  
  (3,307
  )
  (3,141
  )
  (3,128
  )Net change in prices
  
  9,709
  
  (11,795
  )
  8,957Net change in production costs
  
  (1,990
  )
  (692
  )
  (505
  )Net change in future development and site restoration costs
  
  (637
  )
  (128
  )
  (206
  )Development costs incurred during the year
  
  764
  
  375
  
  400Extensions, discoveries and improved recovery
  
  1,863
  
  1,542
  
  2,809Revisions of previous reserve estimates
  
  37
  
  216
  
  596Net purchases and sales of reserves in place
  
  17
  
  550
  
  135Accretion of discount
  
  972
  
  2,110
  
  1,057Net change in taxes
  
  (3,342
  )
  4,726
  
  (4,330
  )Other
  
  (97
  )
  166
  
  (269
  )Net change
  
  3,989
  
  (6,071
  )
  5,516Balance, beginning of year
  
  6,521
  
  12,592
  
  7,076Balance, end of year
  
  10,510
  
  6,521
  
  12,592  62 
    CONTINUITY OF PROVED NET RESERVES(1)  North
  America(2)
  
  North
  Sea
  
  Southeast
  Asia
  
  Sudan
  
  Algeria
  
  Trinidad
  
  TotalCRUDE OIL AND LIQUIDS(mmbbls)TOTAL PROVEDProved reserves at December 31, 1999
  
  157.4
  
  187.2
  
  20.0
  
  92.4
  
  6.8
  
  
  
  463.8Discoveries, additions and extensions
  
  20.2
  
  20.2
  
  4.1
  
  8.6
  
  5.0
  
  
  
  58.1Purchase of reserves
  
  1.4
  
  54.8
  
  
  
  
  
  
  
  
  
  56.2Sale of reserves
  
  (1.7
  )
  (0.1
  )
  
  
  
  
  
  
  
  
  (1.8
  )Net revisions and transfers
  
  8.0
  
  10.6
  
  (1.0
  )
  2.4
  
  0.4
  
  
  
  20.42000 Production
  
  (19.4
  )
  (38.9
  )
  (5.2
  )
  (11.0
  )
  
  
  
  
  (74.5
  )Proved reserves at December 31, 2000
  
  165.9
  
  233.8
  
  17.9
  
  92.4
  
  12.2
  
  
  
  522.2Discoveries, additions and extensions
  
  17.9
  
  53.9
  
  15.3
  
  22.5
  
  7.1
  
  
  
  116.7Purchase of reserves
  
  8.1
  
  16.2
  
  10.6
  
  
  
  
  
  
  
  34.9Sale of reserves
  
  (2.9
  )
  (4.8
  )
  
  
  
  
  
  
  
  
  (7.7
  )Net revisions and transfers
  
  4.7
  
  (0.5
  )
  1.1
  
  13.3
  
  (2.4
  )
  
  
  16.22001 Production
  
  (17.9
  )
  (38.4
  )
  (5.3
  )
  (11.9
  )
  
  
  
  
  (73.5
  )Proved reserves at December 31, 2001
  
  175.8
  
  260.2
  
  39.6
  
  116.3
  
  16.9
  
  
  
  608.8Discoveries, additions and extensions
  
  10.6
  
  13.5
  
  5.8
  
  19.0
  
  1.3
  
  18.9
  
  69.1Purchase of reserves
  
  1.1
  
  7.5
  
  
  
  
  
  
  
  
  
  8.6Sale of reserves
  
  (3.7
  )
  (2.8
  )
  
  
  
  
  
  
  
  
  (6.5
  )Net revisions and transfers
  
  (2.5
  )
  13.9
  
  (4.2
  )
  (27.7
  )
  (4.3
  )
  
  
  (24.8
  )2002 Production
  
  (17.2
  )
  (44.7
  )
  (5.1
  )
  (13.3
  )
  
  
  
  
  (80.3
  )Proved reserves at December 31, 2002
  
  164.1
  
  247.6
  
  36.1
  
  94.3
  
  13.9
  
  18.9
  
  574.9PROVED DEVELOPEDDecember 31, 1999
  
  151.9
  
  150.7
  
  17.3
  
  92.4
  
  
  
  
  
  412.3December 31, 2000
  
  160.9
  
  173.3
  
  15.2
  
  77.4
  
  
  
  
  
  426.8December 31, 2001
  
  168.6
  
  203.8
  
  13.3
  
  89.6
  
  
  
  
  
  475.3December 31, 2002
  
  157.2
  
  210.8
  
  11.9
  
  84.1
  
  2.4
  
  
  
  466.4NATURAL GAS(bcf)TOTAL PROVEDProved reserves at December 31, 1999
  
  1,724.4
  
  351.6
  
  536.6
  
  
  
  
  
  
  
  2,612.6Discoveries, additions and extensions
  
  264.4
  
  10.6
  
  89.0
  
  
  
  
  
  
  
  364.0Purchase of reserves
  
  27.2
  
  
  
  
  
  
  
  
  
  
  
  27.2Sale of reserves
  
  (53.1
  )
  (19.7
  )
  
  
  
  
  
  
  
  
  (72.8
  )Net revisions and transfers
  
  14.5
  
  (27.5
  )
  (56.9
  )
  
  
  
  
  
  
  (69.9
  )2000 Production
  
  (220.3
  )
  (42.4
  )
  (28.5
  )
  
  
  
  
  
  
  (291.2
  )Proved reserves at December 31, 2000
  
  1,757.1
  
  272.6
  
  540.2
  
  
  
  
  
  
  
  2,569.9Discoveries, additions and extensions
  
  293.8
  
  13.7
  
  455.2
  
  
  
  
  
  
  
  762.7Purchase of reserves
  
  293.6
  
  22.8
  
  125.7
  
  
  
  
  
  
  
  442.1Sale of reserves
  
  (44.7
  )
  (1.5
  )
  
  
  
  
  
  
  
  
  (46.2
  )Net revisions and transfers
  
  (24.9
  )
  (5.0
  )
  23.4
  
  
  
  
  
  
  
  (6.5
  )2001 Production
  
  (222.3
  )
  (35.3
  )
  (32.4
  )
  
  
  
  
  
  
  (290.0
  )Proved reserves at December 31, 2001
  
  2,052.6
  
  267.3
  
  1,112.1
  
  
  
  
  
  
  
  3,432.0Discoveries, additions and extensions
  
  283.1
  
  14.0
  
  11.7
  
  
  
  
  
  220.0
  
  528.8Purchase of reserves
  
  31.5
  
  0.4
  
  
  
  
  
  
  
  
  
  31.9Sale of reserves
  
  (26.7
  )
  
  
  
  
  
  
  
  
  
  
  (26.7
  )Net revisions and transfers
  
  (110.8
  )
  (4.3
  )
  (122.6
  )
  
  
  
  
  
  
  (237.7
  )2002 Production
  
  (243.6
  )
  (39.5
  )
  (32.3
  )
  
  
  
  
  
  
  (315.4
  )Proved reserves at December 31, 2002
  
  1,986.1
  
  237.9
  
  968.9
  
  
  
  
  
  220.0
  
  3,412.9PROVED DEVELOPEDDecember 31, 1999
  
  1,508.4
  
  330.7
  
  163.3
  
  
  
  
  
  
  
  2,002.4December 31, 2000
  
  1,568.4
  
  215.9
  
  120.0
  
  
  
  
  
  
  
  1,904.3December 31, 2001
  
  1,804.7
  
  213.8
  
  252.0
  
  
  
  
  
  
  
  2,270.5December 31, 2002
  
  1,746.9
  
  210.0
  
  471.6
  
  
  
  
  
  
  
  2,428.5 
 (1)
  Net reserves are after
  deducting royalties. See note 1(g) of the Consolidated Financial Statements
  for additional disclosure regarding royalties.(2)
  North American net proved
  reserves exclude synthetic crude oil reserves: 2000  36.9 mmbbls; 2001 
  36.4 mmbbls; 2002  36.7 mmbbls.   63