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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934 For the quarterly period ended September 30, 2002
[_] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934 For the transition period
from.............to..........
COMMISSION FILE NUMBER 1-6702
NEXEN INC.
INCORPORATED UNDER THE LAWS OF CANADA
98-6000202
(I.R.S. EMPLOYER IDENTIFICATION NO.)
801 - 7TH AVENUE S.W.
CALGARY, ALBERTA, CANADA T2P 3P7
TELEPHONE (403) 699-4000
INDICATE BY CHECK MARK WHETHER THE REGISTRANT (1) HAS FILED ALL REPORTS REQUIRED
TO BE FILED BY SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 DURING
THE PRECEDING 12 MONTHS AND (2) HAS BEEN SUBJECT TO SUCH FILING REQUIREMENTS FOR
THE PAST 90 DAYS YES [X] NO [_]
ON SEPTEMBER 30, 2002, THERE WERE 122,803,962 COMMON SHARES ISSUED AND
OUTSTANDING.
NEXEN INC.
INDEX
PAGE NO.
--------
PART I. FINANCIAL INFORMATION
Item 1. Unaudited Consolidated Financial Statements
Unaudited Consolidated Statement of Income for
the Three and Nine Months Ended September 30,
2002 and 2001........................................... 3
Unaudited Consolidated Balance Sheet as at
September 30, 2002 and December 31, 2001 ............... 4
Unaudited Consolidated Statement of Cash Flows
for the Three and Nine Months Ended September 30,
2002 and 2001 .......................................... 5
Unaudited Consolidated Statement of Shareholders'
Equity for the Nine Months Ended September 30,
2002 and 2001 .......................................... 6
Notes to Unaudited Consolidated Financial Statements ... 7-17
Item 2. Management's Discussion and Analysis of
Financial Condition and Results of Operations ............. 18-27
Item 3. Quantitative and Qualitative Disclosures about
Market Risk ............................................... 27
Item 4. Controls and Procedures .................................. 28
PART II. OTHER INFORMATION
Item 6. Exhibits and Reports on Form 8-K ......................... 29
In this report, unless otherwise specified, all dollar amounts or references to
"$" are expressed in millions of Canadian dollars, and production and reserve
numbers represent the Company's working interest therein before royalties. On
September 30, 2002, the noon-day exchange rate for Cdn. $1.00 was US $0.6306 as
reported by the Bank of Canada. This report should be read in conjunction with
the Company's Annual Report on Form 10-K for the year ended December 31, 2001.
2
NEXEN INC.
UNAUDITED CONSOLIDATED STATEMENT OF INCOME
THREE MONTHS NINE MONTHS
ENDED ENDED
SEPTEMBER 30 SEPTEMBER 30
------------------ -------------
2002 2001 2002 2001
---- ---- ---- ----
(millions of Canadian dollars
except per share data)
REVENUES
Net Sales .............................. $ 707 $ 658 $1,876 $2,063
Gain on Disposition of Assets .......... -- 4 13 5
Marketing and Other Income ............. 12 16 46 116
------ ------ ------ ------
719 678 1,935 2,184
------ ------ ------ ------
EXPENSES
Operating and Other .................... 193 210 587 607
General and Administrative ............. 36 33 112 100
Depreciation, Depletion and Amortization 183 161 548 471
Exploration ............................ 33 90 113 194
Interest, Net (Note 5) ................. 29 25 80 88
------ ------ ------ ------
474 519 1,440 1,460
------ ------ ------ ------
INCOME BEFORE INCOME TAXES ................. 245 159 495 724
PROVISION FOR INCOME TAXES
Current Income Taxes ................... 69 64 172 183
Future Income Taxes .................... 19 10 -- 121
------ ------ ------ ------
88 74 172 304
------ ------ ------ ------
NET INCOME ................................. 157 85 323 420
DIVIDENDS ON PREFERRED SECURITIES,
NET OF INCOME TAXES ....................... 11 10 33 29
------ ------ ------ ------
NET INCOME ATTRIBUTABLE TO COMMON
SHAREHOLDERS .............................. $ 146 $ 75 $ 290 $ 391
====== ====== ====== ======
EARNINGS PER COMMON SHARE (Note 4)
Basic .................................. $ 1.20 $ 0.62 $ 2.38 $ 3.24
====== ====== ====== ======
Diluted ................................ $ 1.17 $ 0.61 $ 2.35 $ 3.21
====== ====== ====== ======
SEE ACCOMPANYING NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS.
3
NEXEN INC.
UNAUDITED CONSOLIDATED BALANCE SHEET
SEPTEMBER 30, DECEMBER 31,
2002 2001
---- ----
(millions of
Canadian dollars)
ASSETS
CURRENT ASSETS
Cash and Short-Term Investments ................... $ 123 $ 61
Accounts Receivable (Note 2) ...................... 1,004 609
Inventories and Supplies (Note 3) ................. 179 189
Other ............................................. 31 20
------ ------
Total Current Assets ........................... 1,337 879
------ ------
PROPERTY, PLANT AND EQUIPMENT ........................ 4,708 4,170
GOODWILL (Note 1) .................................... 36 36
FUTURE INCOME TAX ASSETS ............................. 206 212
DEFERRED CHARGES AND OTHER ASSETS .................... 52 28
------ ------
$6,339 $5,325
====== ======
LIABILITIES AND SHAREHOLDERS' EQUITY
CURRENT LIABILITIES
Short-Term Borrowings ............................. $ 31 $ 51
Accounts Payable and Accrued Liabilities .......... 1,051 773
Accrued Interest Payable .......................... 25 22
Dividends Payable ................................. 9 9
------ ------
Total Current Liabilities ...................... 1,116 855
------ ------
LONG-TERM DEBT (Note 5) .............................. 1,942 1,484
FUTURE INCOME TAX LIABILITIES ........................ 841 869
DISMANTLEMENT AND SITE RESTORATION ALLOWANCE ......... 202 182
OTHER DEFERRED CREDITS AND LIABILITIES ............... 33 31
SHAREHOLDERS' EQUITY (Note 6)
Preferred Securities .............................. 724 724
Common Shares, no Par Value
Authorized: Unlimited
Outstanding: 2002 - 122,803,962 shares
2001 - 121,202,444 shares ........ 435 389
Retained Earnings ................................. 960 697
Cumulative Foreign Currency Translation Adjustment 86 94
------ ------
Total Shareholders' Equity ..................... 2,205 1,904
------ ------
COMMITMENTS AND CONTINGENCIES (Note 7) ............... $6,339 $5,325
====== ======
SEE ACCOMPANYING NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS.
4
NEXEN INC.
UNAUDITED CONSOLIDATED STATEMENT OF CASH FLOWS
THREE MONTHS NINE MONTHS
ENDED ENDED
SEPTEMBER 30 SEPTEMBER 30
-------------------- -----------------
2002 2001 2002 2001
---- ---- ---- ----
(millions of Canadian dollars
except per share data)
OPERATING ACTIVITIES
Net Income ................................ $ 157 $ 85 $ 323 $ 420
Charges and Credits to Income Not Involving
Cash ................................... 204 168 538 589
Exploration Expense ....................... 33 90 113 194
Changes in Non-Cash Working Capital ....... 15 127 (92) 85
Other ..................................... (7) (2) (13) 3
------- ------- ------- -------
402 468 869 1,291
------- ------- ------- -------
FINANCING ACTIVITIES
Proceeds from Long-Term Debt (Note 5) ..... 89 -- 882 75
Repayment of Long-Term Debt (Note 5) ...... -- (137) (420) (400)
Proceeds from (Repayment of) Short-Term
Borrowings, Net ....................... (35) 27 (19) (41)
Dividends on Preferred Securities ......... (18) (17) (54) (52)
Dividends on Common Shares ................ (9) (10) (27) (28)
Issue of Common Shares .................... 7 10 46 35
Other ..................................... -- -- (23) --
------- ------- ------- -------
34 (127) 385 (411)
------- ------- ------- -------
INVESTING ACTIVITIES
Capital Expenditures
Exploration and Development ............ (405) (287) (1,057) (807)
Chemicals, Corporate and Other ......... (9) (38) (122) (71)
Proved Property Acquisitions ........... -- (2) -- (4)
Proceeds on Disposition of Assets ......... 2 3 34 4
Changes in Non-Cash Working Capital ....... (58) (29) (31) (47)
Other ..................................... -- (14) -- (16)
------- ------- ------- -------
(470) (367) (1,176) (941)
------- ------- ------- -------
EFFECTS OF EXCHANGE RATE CHANGES ON CASH
AND SHORT-TERM INVESTMENTS .................. 8 4 (16) 18
------- ------- ------- -------
INCREASE (DECREASE) IN CASH AND SHORT-TERM
INVESTMENTS ................................. (26) (22) 62 (43)
CASH AND SHORT-TERM INVESTMENTS - BEGINNING
OF PERIOD ................................... 149 89 61 110
------- ------- ------- -------
CASH AND SHORT-TERM INVESTMENTS - END OF
PERIOD ...................................... $ 123 $ 67 $ 123 $ 67
======= ======= ======= =======
Interest Paid ................................. $ 53 $ 22 $ 95 $ 81
======= ======= ======= =======
Income Taxes Paid ............................. $ 68 $ 55 $ 182 $ 170
======= ======= ======= =======
SEE ACCOMPANYING NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS.
5
NEXEN INC.
UNAUDITED CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2002 AND SEPTEMBER 30, 2001
CUMULATIVE
FOREIGN
CURRENCY
PREFERRED COMMON RETAINED TRANSLATION
SECURITIES SHARES EARNINGS ADJUSTMENT
------------ -------- ----------- -------------
(millions of Canadian dollars)
December 31, 2001 ............................... $ 724 $ 389 $ 697 $ 94
Exercise of Stock Options .................... -- 26 -- --
Issue of Common Shares ....................... -- 20 -- --
Net Income ................................... -- -- 323 --
Dividends on Preferred Securities,
Net of Income Taxes ........................ -- -- (33) --
Dividends on Common Shares ................... -- -- (27) --
Translation Adjustment ....................... -- -- -- (8)
----- ----- ----- ----
September 30, 2002 .............................. $ 724 $ 435 $ 960 $ 86
===== ===== ===== ====
CUMULATIVE
FOREIGN
CURRENCY
PREFERRED COMMON RETAINED TRANSLATION
SECURITIES SHARES EARNINGS ADJUSTMENT
------------ -------- ----------- -------------
(millions of Canadian dollars)
December 31, 2000 .......................... $ 724 $ 350 $ 323 $ 63
Exercise of Stock Options................ -- 15 -- --
Issue of Common Shares................... -- 20 -- --
Net Income............................... -- -- 420 --
Dividends on Preferred Securities,
Net of Income Taxes.................... -- -- (29) --
Dividends on Common Shares............... -- -- (28) --
Translation Adjustment................... -- -- -- 4
----- ----- ----- ----
September 30, 2001 ......................... $ 724 $ 385 $ 686 $ 67
===== ===== ===== ====
SEE ACCOMPANYING NOTES TO UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS.
6
NEXEN INC.
NOTES TO UNAUDITED CONSOLIDATED
FINANCIAL STATEMENTS (tabular amounts in millions
of Canadian dollars except as otherwise noted)
1. ACCOUNTING POLICIES
In the opinion of management, the accompanying Unaudited Consolidated Financial
Statements contain all adjustments of a normal and recurring nature necessary to
present fairly Nexen Inc.'s (Nexen or the Company) financial position at
September 30, 2002 and the results of its operations and its cash flows for the
three and nine months ended September 30, 2002 and 2001. The results of
operations and cash flows are not necessarily indicative of the results of
operations or cash flows to be expected for the year ending December 31, 2002.
The accounting policies followed by Nexen are set forth in Note 1 to the Audited
Consolidated Financial Statements included in the Company's 2001 Annual Report
on Form 10-K except for the following:
GOODWILL AND INTANGIBLE ASSETS
On January 1, 2002, Nexen adopted the new recommendations of the Canadian
Institute of Chartered Accountants with respect to goodwill and intangible
assets. Under the new standard, goodwill and intangible assets with an
indefinite useful life are no longer amortized, but are tested for impairment at
least annually. Nexen's unamortized goodwill at January 1, 2002 was $36 million.
The following table provides adjusted measures of net income and net income per
common share had the new standard been applicable for 2001.
THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
-------------------- ------------------
2002 2001 2002 2001
---- ---- ---- ----
(millions of Canadian dollars
except per share data)
NET INCOME:
Reported Net Income Attributable to
Common Shareholders...................... $ 146 $ 75 $ 290 $ 391
Add back Goodwill Amortization ............ -- 1 -- 4
------ ------- ------- -------
Adjusted Net Income Attributable to
Common Shareholders..................... $ 146 $ 76 $ 290 $ 395
====== ======= ======= =======
BASIC EARNINGS PER COMMON SHARE:
Reported Net Income Attributable to
Common Shareholders...................... $ 1.20 $ 0.62 $ 2.38 $ 3.24
====== ======= ======= =======
Adjusted Net Income Attributable to
Common Shareholders..................... $ 1.20 $ 0.63 $ 2.38 $ 3.28
====== ======= ======= =======
DILUTED EARNINGS PER COMMON SHARE:
Reported Net Income Attributable to
Common Shareholders...................... $ 1.17 $ 0.61 $ 2.35 $ 3.21
====== ======= ======= =======
Adjusted Net Income Attributable to
Common Shareholders..................... $ 1.17 $ 0.62 $ 2.35 $ 3.24
====== ======= ======= =======
These Unaudited Consolidated Financial Statements should be read in conjunction
with the Company's 2001 Audited Consolidated Financial Statements included in
the Annual Report on Form 10-K.
7
2. ACCOUNTS RECEIVABLE
SEPTEMBER 30, DECEMBER 31,
2002 2001
--------------- -------------
Trade
Oil & Gas
Marketing ........................... $ 596 $ 305
Other ................................ 331 215
Chemicals and Other .................... 54 55
---------- ------
981 575
Non-Trade .................................. 23 34
---------- ------
$ 1,004 $ 609
========== ======
3. INVENTORIES AND SUPPLIES
SEPTEMBER 30, DECEMBER 31,
2002 2001
--------------- -------------
Finished Products
Oil and Gas
Marketing.............................. $ 56 $ 56
Other.................................. 1 15
Chemicals and Other....................... 8 15
-------- ------
65 86
Work in Process............................. 6 6
Field Supplies.............................. 108 97
-------- ------
$ 179 $ 189
======== ======
4. EARNINGS PER COMMON SHARE
The calculation of basic earnings per common share is based on the weighted
average number of common shares outstanding of 122.8 million and 120.9 million
for the three months ended, and 122.2 million and 120.5 million for the nine
months ended September 30, 2002 and 2001, respectively, and net income after
deducting dividends on preferred securities, net of income taxes.
The calculation of diluted earnings per common share is based on the weighted
average number of diluted common shares outstanding of 124.5 million and 122.3
million for the three months ended, and 123.8 million and 121.8 million for the
nine months ended September 30, 2002 and 2001, respectively. For the three and
nine months ended September 30, 2002, options for 20,500 (2001 - 2,960,925) and
35,000 (2001 - 2,960,925) common shares were excluded from the diluted earnings
per common share calculation because the option exercise price was greater than
the average market price of common stock for the respective periods. During the
periods presented, outstanding stock options are the only dilutive instruments.
8
5. LONG-TERM DEBT
SEPTEMBER 30, DECEMBER 31,
2002 2001
--------------- -------------
Unsecured Syndicated Term Credit Facilities (a) ....... $ 92 $ 424
Unsecured Redeemable Notes, due 2004................... 357 358
Unsecured Redeemable Debentures, due 2006.............. 108 109
Unsecured Redeemable Medium Term Notes, due 2007....... 150 150
Unsecured Redeemable Medium Term Notes, due 2008....... 125 125
Unsecured Redeemable Notes, due 2028 .................. 317 318
Unsecured Redeemable Notes, due 2032 (a) .............. 793 --
------- --------
$ 1,942 $ 1,484
======= ========
(a) UNSECURED REDEEMABLE NOTES, DUE 2032
During March 2002, Nexen issued US $500 million principal amount of notes.
Interest is payable semi-annually at a rate of 7.875% and the principal is to be
repaid in March 2032. The notes are redeemable, in whole or in part, at any time
by the Company at a price equal to the greater of par and an amount calculated
to provide a yield equal to the yield on a United States Treasury security
having a term to maturity equal to the remaining term of the notes plus 0.375%.
Proceeds from the notes were used primarily to repay term credit facilities.
(b) INTEREST EXPENSE
Total interest costs incurred during the period were $38 million and $25 million
for the three months ended September 30, 2002 and 2001, respectively, and $100
million and $88 million for the nine months ended September 30, 2002 and 2001,
respectively. Of these amounts, the Company capitalized $9 million and $nil for
the three months ended September 30, 2002 and 2001, respectively, relating to
major development projects and $20 million and $nil for the nine months ended
September 30, 2002 and 2001, respectively. Capitalized interest relates to and
is included as part of the cost of oil and gas properties. The capitalization
rates are based on the Company's weighted average cost of borrowings.
6. SHARE CAPITAL
Nexen uses the intrinsic value based method of accounting for stock options.
Under this method, no compensation expense is recognized for stock options
granted to employees and directors. Effective January 1, 2002, Canadian
Generally Accepted Accounting Principles require companies electing not to
recognize the compensation expense determined under the fair value based method
to make pro forma disclosures of net income and earnings per common share as if
that method of accounting had been applied.
The assumptions for the three and nine months ended September 30, 2002 are the
same as for the year ended December 31, 2001, as described in Note 15(e) to the
Audited Consolidated Financial Statements included in the Company's 2001 Annual
Report on Form 10-K. Had Nexen applied the fair value based method to all
options outstanding, net income attributable to common shareholders for the
three and nine months ended September 30, 2002, would have been $140 million and
$272 million, respectively, basic earnings per common share would have been
$1.14 and $2.23, respectively, and diluted earnings per common share would have
been $1.13 and $2.20, respectively.
9
Dividends per common share for the three months ended September 30, 2002 and
2001 were $0.075 and $0.075, respectively. Dividends per common share for the
nine months ended September 30, 2002 and 2001 were $0.225 and $0.225,
respectively.
7. COMMITMENTS AND CONTINGENCIES
In November 2000, the Company committed to enter into a lease agreement upon the
completion of construction of a natural gas-fired generating facility in
Alberta. On June 28, 2002, the Company exercised its option to buy out the lease
for a cost of $67 million, which was the cost of construction plus interest on
advances during the construction phase. This amount is reflected in capital
expenditures for the nine months ended September 30, 2002.
As described in Note 10 to the Audited Consolidated Financial Statements
included in the Company's 2001 Annual Report on Form 10-K, there are a number of
lawsuits and claims pending, the ultimate results of which cannot be ascertained
at this time. Costs are recorded as they are incurred or become determinable.
Management is of the opinion that the resolution of such matters would not have
a material adverse effect upon the Company's consolidated financial position or
results of operations.
10
8. OPERATING SEGMENTS AND RELATED INFORMATION
Nexen is involved in activities relating to Oil and Gas, the Syncrude Joint
Venture and Chemicals in various geographic locations as described in Note 14 to
the Audited Consolidated Financial Statements included in the Company's 2001
Annual Report on Form 10-K.
THREE MONTHS ENDED SEPTEMBER 30, 2002
SYNCRUDE CORPORATE
JOINT AND OTHER
OIL AND GAS VENTURE CHEMICALS ITEMS(a) TOTAL
------------------------------------------------------- -------- --------- --------- -----
UNITED OTHER
YEMEN CANADA STATES AUSTRALIA COUNTRIES(b) MARKETING
----- ------ ------ --------- ------------ ---------
Net Sales ................... $ 214 $ 173 $ 72 $ 60 $ 23 $ -- $ 75 $ 88 $ 2 $ 707
Gain on Disposition of Assets -- -- -- -- -- -- -- -- -- --
Marketing and Other Income... -- 1 -- -- -- 8(c) -- -- 3(d) 12
--------------------------------------------------------------------------------------------
Total Revenues .............. 214 174 72 60 23 8 75 88 5 719
Operating and Other.......... 21 44 23 12 8 - 24 60 1 193
General and Administrative... 2 4 3 -- 7 8 -- 4 8 36
Depreciation, Depletion and
Amortization .............. 40 63 34 15 9 2 4 13 3 183
Exploration ................. 1 7 8 1 16 -- -- -- -- 33
Interest, Net ............... -- -- -- -- -- -- -- -- 29 29
--------------------------------------------------------------------------------------------
Income (Loss) Before
Income Taxes .............. $ 150 $ 56 $ 4 $ 32 $ (17) $ (2) $ 47 $ 11 $(36) $ 245
==================================================================================
Provision for Income Taxes .. 88
------
Net Income .................. $ 157
======
Identifiable Assets.......... $ 655 $2,143 $1,246 $ 107 $ 146 $ 784 $ 487 $ 540 $231(e) $6,339
============================================================================================
Capital Expenditures
Development and Other
Expenditures............. $ 48 $ 44 $ 199 $ -- $ 3 $ 1 $ 40 $ 6 $ 2 $ 343
Exploration Expenditures... 3 13 33 2 20 -- -- -- -- 71
--------------------------------------------------------------------------------------------
$ 51 $ 57 $ 232 $ 2 $ 23 $ 1 $ 40 $ 6 $ 2 $ 414
============================================================================================
Notes:
(a) Includes results of operations from a natural gas-fired generating
facility in Alberta.
(b) Includes results of operations from producing activities in Nigeria and
Colombia.
(c) Sales and cost of sales associated with the purchase and sale of crude
oil and natural gas are recorded on a net basis and included in
marketing and other income in the Unaudited Statement of Income.
Sales.............................. $ 2,865
Purchases and Transportation....... 2,857
-------
$ 8
=======
(d) Includes interest income of $2 million and foreign exchange gains of $1
million.
(e) Includes $61 million of future income tax assets.
11
NINE MONTHS ENDED SEPTEMBER 30, 2002
SYNCRUDE CORPORATE
JOINT AND OTHER
OIL AND GAS VENTURE CHEMICALS ITEMS(a) TOTAL
------------------------------------------------------- -------- --------- --------- -----
UNITED OTHER
YEMEN CANADA STATES AUSTRALIA COUNTRIES(b) MARKETING
----- ------ ------ --------- ------------ ---------
Net Sales ................... $ 576 $ 480 $ 212 $ 125 $ 60 $ -- $ 173 $ 243 $ 7 $1,876
Gain on Disposition of Assets -- -- -- -- -- -- -- 13(c) 13
Marketing and Other Income... -- 2 -- -- -- 40(d) -- 1 3(e) 46
--------------------------------------------------------------------------------------------
Total Revenues .............. 576 482 212 125 60 40 173 244 23 1,935
Operating and Other.......... 60 133 72 37 19 - 87 172 7 587
General and Administrative... 4 17 7 -- 16 23 -- 16 29 112
Depreciation, Depletion and
Amortization .............. 114 192 99 43 36 6 10 38 10 548
Exploration ................. 20 28 31 2 32 -- -- -- -- 113
Interest, Net ............... -- -- -- -- -- -- -- -- 80 80
--------------------------------------------------------------------------------------------
Income (Loss) Before Income
Taxes ..................... $ 378 $ 112 $ 3 $ 43 $ (43) $ 11 $ 76 $ 18 $(103) $ 495
=================================================================================
Provision for Income Taxes .. 172
------
Net Income .................. $ 323
======
Identifiable Assets.......... $ 655 $2,143 $1,246 $ 107 $ 146 $ 784 $ 487 $ 540 $ 231(f) $6,339
============================================================================================
Capital Expenditures
Development and Other
Expenditures............. $ 143 $ 172 $ 394 $ 46 $ 13 $ 1 $ 91 $ 36 $ 85 $ 981
Exploration Expenditures... 22 47 88 3 38 -- -- -- -- 198
--------------------------------------------------------------------------------------------
$ 165 $ 219 $ 482 $ 49 $ 51 $ 1 $ 91 $ 36 $ 85(g) $1,179
============================================================================================
Notes:
(a) Includes results of operations from a natural gas-fired generating
facility in Alberta.
(b) Includes results of operations from producing activities in Nigeria and
Colombia.
(c) The Moose Jaw Asphalt operation was disposed of on January 2, 2002 for
proceeds of $27 million, plus working capital.
(d) Sales and cost of sales associated with the purchase and sale of crude
oil and natural gas are recorded on a net basis and included in
marketing and other income in the Unaudited Statement of Income.
Sales............................... $7,301
Purchases and Transportation........ 7,261
------
$ 40
======
(e) Includes interest income of $6 million and foreign exchange losses of
$3 million.
(f) Includes $61 million of future income tax assets.
(g) Includes $67 million related to the buy out of the lease agreement for
a natural gas-fired generating facility in Alberta.
12
THREE MONTHS ENDED SEPTEMBER 30, 2001
SYNCRUDE CORPORATE
JOINT AND OTHER
OIL AND GAS VENTURE CHEMICALS ITEMS(a) TOTAL
------------------------------------------------------- -------- --------- --------- -----
UNITED OTHER
YEMEN CANADA STATES AUSTRALIA COUNTRIES(b) MARKETING
----- ------ ------ --------- ------------ ---------
Net Sales ................... $ 191 $ 161 $ 67 $ 45 $ 20 $ -- $ 53 $ 82 $ 39 $ 658
Gain on Disposition of Assets -- -- -- 3 -- -- -- -- 1 4
Marketing and Other Income... -- 1 -- -- 2 6(c) -- 2 5(d) 16
-------------------------------------------------------------------------------------------
Total Revenues .............. 191 162 67 48 22 6 53 84 45 678
Operating and Other.......... 17 40 16 15 -- 1 27 54 40 210
General and Administrative... -- 5 1 -- 6 7 -- 4 10 33
Depreciation, Depletion and
Amortization .............. 26 58 28 20 11 3 3 9 3 161
Exploration ................. 7 8 63 5 7 -- -- -- -- 90
Interest, Net ............... -- -- -- -- -- -- -- -- 25 25
-------------------------------------------------------------------------------------------
Income (Loss) Before Income
Taxes ................... $ 141 $ 51 $ (41) $ 8 $ (2) $ (5) $ 23 $ 17 $ (33) $ 159
=================================================================================
Provision for Income Taxes .. 74
------
Net Income .................. $ 85
======
Identifiable Assets.......... $ 537 $2,142 $ 719 $ 74 $ 186 $ 620 $ 365 $ 510 $ 212(e) $5,365
===========================================================================================
Additions to Property, Plant
and Equipment
Development and Other
Expenditures .......... $ 57 $ 77 $ 51 $ (3) $ 11 $ -- $ 16 $ 24 $ 14 $ 247
Exploration Expenditures. 6 16 39 3 14 -- -- -- -- 78
Proved Property
Acquisitions .......... -- 2 -- -- -- -- -- -- -- 2
-------------------------------------------------------------------------------------------
$ 63 $ 95 $ 90 $ -- $ 25 $ -- $ 16 $ 24 $ 14 $ 327
===========================================================================================
Notes:
(a) Includes results from the Moose Jaw Asphalt operation, which was
disposed of on January 2, 2002.
(b) Includes results of operations from producing activities in Nigeria.
(c) Sales and cost of sales associated with the purchase and sale of crude
oil and natural gas are recorded on a net basis and included in
marketing and other income in the Unaudited Statement of Income.
Sales......................................... $ 2,838
Purchases Purchases and Transportation........ 2,832
-------
$ 6
=======
(d) Includes interest income of $3 million and foreign exchange gains of $2
million.
(e) Includes $147 million of future income tax assets.
13
NINE MONTHS ENDED SEPTEMBER 30, 2001
SYNCRUDE CORPORATE
JOINT AND OTHER
OIL AND GAS VENTURE CHEMICALS ITEMS(a) TOTAL
------------------------------------------------------- -------- --------- --------- -----
UNITED OTHER
YEMEN CANADA STATES AUSTRALIA COUNTRIES(b) MARKETING
----- ------ ------ --------- ------------ ---------
Net Sales ................... $ 556 $ 534 $ 301 $ 137 $ 46 $ -- $ 170 $ 258 $ 61 $2,063
Gain on Disposition of Assets -- -- 1 3 -- -- -- -- 1 5
Marketing and Other Income .. -- 3 1 -- 5 92(c) -- 2 13(d) 116
--------------------------------------------------------------------------------------------
Total Revenues .............. 556 537 303 140 51 92 170 260 75 2,184
Operating and Other.......... 49 117 47 42 9 1 89 185 68 607
General and Administrative... 2 19 6 1 16 18 -- 13 25 100
Depreciation, Depletion and
Amortization .............. 82 168 87 55 22 10 9 26 12 471
Exploration ................. 19 33 88 9 45 -- -- -- -- 194
Interest, Net ............... -- -- -- -- -- -- -- -- 88 88
--------------------------------------------------------------------------------------------
Income (Loss) Before Income
Taxes ..................... $ 404 $ 200 $ 75 $ 33 $ (41) $ 63 $ 72 $ 36 $ (118) $ 724
==================================================================================
Provision for Income Taxes .. 304
------
Net Income .................. $ 420
======
Identifiable Assets.......... $ 537 $2,142 $ 719 $ 74 $ 186 $ 620 $ 365 $ 510 $ 212(e) $5,365
============================================================================================
Additions to Property, Plant
and Equipment
Development and Other
Expenditures .......... $ 129 $ 246 $ 110 $ (3) $ 15 $ -- $ 33 $ 44 $ 27 $ 601
Exploration Expenditures. 36 61 131 9 40 -- -- -- -- 277
Proved Property
Acquisitions........... -- 4 -- -- -- -- -- -- -- 4
--------------------------------------------------------------------------------------------
$ 165 $ 311 $ 241 $ 6 $ 55 $ -- $ 33 $ 44 $ 27 $ 882
============================================================================================
Notes:
(a) Includes results from the Moose Jaw Asphalt operation, which was
disposed of on January 2, 2002.
(b) Includes results of operations from producing activities in Nigeria.
(c) Sales and cost of sales associated with the purchase and sale of crude
oil and natural gas are recorded on a net basis and included in
marketing and other income in the Unaudited Statement of Income.
Sales................................ $ 10,313
Purchases and Transportation......... 10,221
--------
$ 92
========
(d) Includes interest income of $15 million and foreign exchange losses of
$2 million.
(e) Includes $147 million of future income tax assets.
14
9. DIFFERENCES BETWEEN CANADIAN AND UNITED STATES GENERALLY ACCEPTED
ACCOUNTING PRINCIPLES
The Unaudited Consolidated Financial Statements have been prepared in accordance
with generally accepted accounting principles in Canada. Canadian principles
differ from US principles as follows:
(a) UNAUDITED CONSOLIDATED STATEMENT OF INCOME
THREE MONTHS NINE MONTHS
ENDED ENDED
SEPTEMBER 30 SEPTEMBER 30
---------------- -------------------
2002 2001 2002 2001
---- ---- ---- ----
Net Income as Reported in Accordance
with Canadian Principles ............. $ 157 $ 85 $ 323 $ 420
Impact of US Principles:
Dividends on Preferred Securities (i) (18) (17) (54) (52)
Less: Associated Future Income ... 7 7 21 23
Taxes
Depreciation Expense (ii) ........... (12) (11) (35) (35)
----- ----- ----- -----
Net Income in Accordance with US
Principles (iii) ..................... $ 134 $ 64 $ 255 $ 356
===== ===== ===== =====
Earnings per Common Share in
Accordance with US Principles
Basic ........................... $1.09 $0.53 $2.09 $2.96
===== ===== ===== =====
Diluted ......................... $1.08 $0.52 $2.06 $2.92
===== ===== ===== =====
(b) UNAUDITED CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
THREE MONTHS NINE MONTHS
ENDED ENDED
SEPTEMBER 30 SEPTEMBER 30
---------------- -------------------
2002 2001 2002 2001
---- ---- ---- ----
Net Income in Accordance with US
Principles $ 134 $ 64 $ 255 $ 356
Other Comprehensive Income, net of tax:
Translation Adjustment on Net
Investment (iv) .................. 59 32 (8) 40
Hedge of Net Investment (iv) ........ (76) (60) 5 (72)
Other ............................... -- 3 -- (4)
----- ----- ----- -----
Comprehensive Income .................. $ 117 $ 39 $ 252 $ 320
===== ===== ===== =====
15
(c) UNAUDITED CONSOLIDATED BALANCE SHEET
SEPTEMBER 30, 2002 DECEMBER 31, 2001
----------------------------- ---------------------------
CANADIAN US CANADIAN US
PRINCIPLES PRINCIPLES PRINCIPLES PRINCIPLES
---------- ---------- ---------- ----------
ASSETS
Accounts Receivable............................... $ 1,004 $ 1,004 $ 609 $ 616
Property, Plant and Equipment, Net................ $ 4,708 $ 4,927 $ 4,170 $ 4,424
Deferred Charges and Other Assets................. $ 52 $ 74 $ 28 $ 51
LIABILITIES AND SHAREHOLDERS' EQUITY
Accounts Payable and Accrued Liabilities ......... $ 1,051 $ 1,051 $ 773 $ 780
Long-Term Debt.................................... $ 1,942 $ 2,698 $ 1,484 $ 2,242
Future Income Tax Liabilities..................... $ 841 $ 846 $ 869 $ 878
Preferred Securities.............................. $ 724 $ - $ 724 $ -
Retained Earnings................................. $ 960 $ 1,193 $ 697 $ 965
Cumulative Foreign Currency Translation
Adjustment..................................... $ 86 $ - $ 94 $ -
Accumulated Other Comprehensive Income............ $ - $ 57 $ - $ 60
(d) UNAUDITED CONSOLIDATED STATEMENT OF CASH FLOWS
In accordance with US principles, dividends on preferred securities of $18
million and $54 million for the three and nine months ended September 30, 2002,
respectively (September 30, 2001 - $17 million and $52 million), that are
included in financing activities would be reported in operating activities.
In accordance with US principles, geological and geophysical costs of $13
million and $48 million for the three and nine months ended September 30, 2002,
respectively (September 30, 2001 - $18 million and $59 million) that are
included in investing activities would be reported in operating activities.
(e) RECENT DEVELOPMENTS IN US ACCOUNTING STANDARDS
In June 2001, the Financial Accounting Standards Board (FASB) issued Statement
No. 143, "Accounting for Asset Retirement Obligations" (FAS 143). FAS 143
requires liability recognition for retirement obligations associated with
tangible long-lived assets. The obligations included within the scope of FAS 143
are those for which a company faces a legal obligation for settlement. The
initial measurement of the asset retirement obligation is to be at fair value.
The asset retirement cost equal to the fair value of the retirement obligation
is to be capitalized as part of the cost of the related long-lived asset and
amortized to expense over the useful life of the asset. FAS 143 is effective for
all fiscal years beginning after June 15, 2002. The total impact on the
Company's financial statements has not yet been determined.
NOTES:
i. In accordance with US principles, the preferred securities are
classified as long-term debt rather than shareholders' equity.
Accordingly, the pre-tax dividends are included in interest expense and
the related income tax is included in the provision for income taxes in
the Unaudited Consolidated Statement of Income. The related pre-tax
issue costs are included in deferred charges and other assets and the
foreign currency translation gains or losses are included in other
comprehensive income in the Unaudited Consolidated Balance Sheet. The
pre-tax dividends are included in operating activities in the Unaudited
Consolidated Statement of Cash Flows.
16
ii. In accordance with US principles, the liability method of accounting
for income taxes was adopted in 1993. In Canada, the liability method
was adopted in 2000. Under US principles, the adjustment on initial
adoption was included in property, plant and equipment rather than
retained earnings. This results in increased depreciation expense under
US principles.
iii. In accordance with US principles, transportation costs are classified
as an operating expense on the income statement rather than as a
deduction from revenue. For the three months ended September 30, 2002
and 2001, transportation costs related to Nexen's oil and gas
operations are $9 million and $9 million, respectively. For the nine
months ended September 30, 2002 and 2001, transportation costs related
to Nexen's oil and gas operations are $26 million and $26 million,
respectively.
iv. In accordance with US principles, exchange gains and losses arising
from the translation of the Company's net investment in self-sustaining
foreign operations and long-term monetary liabilities are included in
comprehensive income which is added, net of tax, to net income in
determining total comprehensive income. Additionally, translation on
our US dollar long-term debt is included in comprehensive income, net
of tax, as it has been designated as a hedge of our foreign net
investment. Cumulative amounts are included in accumulated other
comprehensive income in the Unaudited Consolidated Balance Sheet. In
accordance with Canadian principles, such amounts are included in the
cumulative foreign currency translation adjustment in shareholders'
equity in the Unaudited Consolidated Balance Sheet.
v. On January 1, 2001, Nexen adopted FASB Statement No. 133 "Accounting
for Derivative Instruments and Hedging Activities", as modified by
Statement No. 138 "Accounting for Certain Derivative Instruments and
Certain Hedging Activities" (FAS 133). FAS 133 requires the Company to
recognize all derivative instruments on the balance sheet as either an
asset or a liability measured at fair value. Changes in the fair value
of derivatives are recognized in earnings unless specific hedge
criteria are met. For cash flow hedges, changes in the fair value of
derivatives that are designated as hedges are recognized in earnings in
the same period as the hedged item. Any fair value change in a
derivative before that period is recognized on the balance sheet and in
other comprehensive income. For fair value hedges, both the derivative
instrument and the underlying commitment are recognized on the balance
sheet at their fair value. Any changes in the fair values are reflected
in earnings. Included in both accounts receivable and accounts payable
at September 30, 2002 and December 31, 2001, are $nil and $7 million
related to fair value hedges, respectively. The hedges convert fixed
prices for physical delivery of natural gas into floating prices
through fixed to floating swaps. There is no impact on earnings.
17
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
THE FOLLOWING DISCUSSION AND ANALYSIS SHOULD BE READ IN CONJUNCTION WITH THE
UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS INCLUDED IN THIS REPORT. THE
UNAUDITED CONSOLIDATED FINANCIAL STATEMENTS HAVE BEEN PREPARED IN ACCORDANCE
WITH GENERALLY ACCEPTED ACCOUNTING PRINCIPLES (GAAP) IN CANADA. THE IMPACT OF
THE SIGNIFICANT DIFFERENCES BETWEEN CANADIAN AND UNITED STATES PRINCIPLES ON
NEXEN'S FINANCIAL RESULTS ARE DISCLOSED IN NOTE 9 TO THE UNAUDITED CONSOLIDATED
FINANCIAL STATEMENTS.
IN THE MANAGEMENT'S DISCUSSION AND ANALYSIS CERTAIN TERMS SPECIFIC TO THE OIL
AND GAS INDUSTRY ARE USED INCLUDING "CASH FLOW FROM OPERATIONS". "CASH FLOW FROM
OPERATIONS" IS A NON-GAAP TERM AND IS DEFINED AS CASH GENERATED FROM OPERATING
ACTIVITIES IN THE STATEMENT OF CASH FLOWS BEFORE CHANGES IN NON-CASH WORKING
CAPITAL AND OTHER.
THIRD QUARTER HIGHLIGHTS
Cash flow from operations for the third quarter of 2002 was $394 million while
net income was $157 million. Strong commodity prices, narrow oil quality
differentials and growing production levels continued to generate solid
financial results. Production averaged 275,000 barrels of oil equivalent per
day, a 4% increase over the third quarter of 2001. Quarterly capital
expenditures were $414 million as activity on our key development projects in
the Gulf of Mexico, Colombia and Synthetic Crude, including Syncrude, continued.
Year to date, cash flow from operations was $974 million while net income was
$323 million.
During the first nine months of 2002, our financial capacity remained strong.
Cash generated from operating activities was used to fund almost 75% of our
capital investment program. In addition, we issued US $500 million of 30-year
bonds in early March. The funds have been used to repay existing bank debt and
fund the remainder of our capital investment program and dividend requirements.
At September 30, 2002, we had undrawn, committed long-term credit facilities of
just under $1.5 billion and a senior debt rating of BBB from Standard and Poor's
Corporation, Baa2 from Moody's Investors Services, Inc. and BBB from Dominion
Bond Rating Services Inc.
18
OVERVIEW OF VARIANCE FOR NET INCOME
The following table provides a summary of net income variances for the three and
nine months ended September 30, 2002 as compared to the comparable period in
2001.
2002 VS. 2001
-------------
(millions of Canadian dollars)
THREE NINE
MONTHS MONTHS
ENDED ENDED
SEPTEMBER 30 SEPTEMBER 30
------------ ------------
NET INCOME - SEPTEMBER 30, 2001 .................... $ 85 $ 420
Favourable (unfavourable)
CASH COMPONENTS
Commodity Prices, net of royalties
Crude oil prices .......................... 66 16
Natural gas prices ........................ 2 (157)
Production Volumes, net of royalties ............ 12 23
Oil and Gas Operating Expenses
Conventional .............................. (20) (57)
Synthetic ................................. 3 2
Marketing ...................................... 2 (52)
Chemicals ...................................... (2) (2)
General and Administrative ..................... (3) (12)
Interest, Net .................................. (4) 8
Current Income Taxes ........................... (5) 11
Other .......................................... -- (9)
----- -----
TOTAL CASH VARIANCE .............................. 51 (229)
----- -----
NON-CASH COMPONENTS
Depreciation, Depletion and Amortization Expense (22) (77)
Exploration Expense ............................ 57 81
Future Income Taxes ............................ (9) 121
Other .......................................... (5) 7
----- -----
TOTAL NON-CASH VARIANCE .......................... 21 132
----- -----
NET INCOME - SEPTEMBER 30, 2002 .................. $ 157 $ 323
===== =====
Net income for the third quarter was $72 million higher than the $85 million
realized in the third quarter of 2001. Higher crude oil prices, increased
production rates and lower exploration expense contributed to the increase. This
was partially offset by higher oil and gas operating costs and depreciation,
depletion and amortization.
Net income for the first nine months of 2002 was $323 million, $97 million lower
than the comparable period in 2001. Lower natural gas prices, higher oil and gas
operating costs and depreciation, depletion and amortization and lower trading
profits from our Marketing operation contributed to the shortfall.
These items are discussed more fully in the remainder of the Management's
Discussion and Analysis.
19
The following discussions should be read in conjunction with Note 8 to the
Unaudited Consolidated Financial Statements.
PRODUCTION
The following table presents Nexen's working interest production volumes before
royalties for the three and nine months ended September 30, 2002 and 2001:
THREE MONTHS NINE MONTHS
ENDED ENDED
SEPTEMBER 30 SEPTEMBER 30
---------------- ----------------
2002 2001 2002 2001
---- ---- ---- ----
Crude Oil and Natural Gas Liquids
(thousand barrels per day)
Yemen .............................. 118.5 118.1 118.3 118.4
Canada ............................. 55.3 58.4 57.3 57.2
United States ...................... 8.9 9.8 9.8 10.1
Syncrude Joint Venture ............. 18.9 15.3 16.1 15.9
Australia .......................... 18.9 9.7 13.3 10.9
Other Countries .................... 7.9 7.5 9.3 5.0
----- ----- ----- -----
228.4 218.8 224.1 217.5
===== ===== ===== =====
Natural Gas
(million cubic feet per day)
Canada ............................ 167 169 167 173
United States ..................... 115 108 116 120
--- --- --- ---
282 277 283 293
=== === === ===
Total Production - Equivalent Barrels
(thousand barrels per day) .......... 275 265 271 266
=== === === ===
Nexen's quarterly production averaged 275,000 equivalent barrels per day, up 4%
from the third quarter of last year and up 1% from the second quarter of this
year. Crude oil volumes grew 4% to 228,400 barrels per day, led by strong
production in Australia and at Syncrude. Natural gas volumes were relatively
unchanged from 2001 levels, averaging 282 million cubic feet per day. Production
volumes in the first nine months of the year averaged 271,000 equivalent barrels
per day, up 2% from the comparable period in 2001.
Our Masila Block in Yemen continued to provide solid production and cash flow.
Our share of production averaged 118,500 barrels per day in the third quarter.
Offshore Australia, our Buffalo field produced 18,900 barrels per day,
reflecting our successful infill drilling program. In Canada, production volumes
averaged 83,100 equivalent barrels per day, down slightly from the third quarter
last year. Syncrude achieved record quarterly production, averaging 18,900
barrels per day net to Nexen, as operations returned to normal levels following
a major turnaround completed in the second quarter. Offshore Nigeria, production
from our Ejulebe property averaged 7,000 barrels per day in the third quarter.
During September, extreme weather conditions disrupted virtually all of our US
development and production operations. For the quarter, our production in the
Gulf of Mexico averaged 28,000 equivalent barrels per day, as production gains
from the Vermilion 76 exploitation program were offset by four days of lost
production due to Tropical Storm Isidore.
20
Operations were further disrupted in early October by Hurricane Lili which
caused all of our production in the Gulf of Mexico to be shut-in for three days
and reduced production from our Eugene Island fields for an additional four
days. The damage to our Eugene Island fields is being repaired and production in
the Gulf has been restored to approximately 26,500 equivalent barrels per day.
COMMODITY PRICES
THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
---------------------- ----------------------
2002 2001 2002 2001
---- ---- ---- ----
WTI Average (US$ per barrel) ................. $ 28.30 $ 26.76 $ 25.40 $ 27.82
Crude Oil and Natural Gas Liquids (per barrel)
Yemen ...................................... $ 42.29 $ 37.57 $ 37.79 $ 37.40
Canada ..................................... $ 35.18 $ 29.82 $ 30.66 $ 27.48
United States .............................. $ 41.73 $ 38.95 $ 37.78 $ 41.01
Syncrude Joint Venture ..................... $ 44.26 $ 41.59 $ 39.85 $ 42.76
Australia .................................. $ 43.57 $ 37.37 $ 39.40 $ 40.04
Nigeria .................................... $ 41.63 $ 39.44 $ 38.64 $ 40.96
Corporate Average .......................... $ 40.77 $ 35.90 $ 36.26 $ 35.58
NYMEX Gas Average (US$ per mmbtu) ............ $ 3.21 $ 2.77 $ 3.05 $ 4.43
Natural Gas (per thousand cubic feet)
Canada .................................... $ 3.05 $ 3.16 $ 3.21 $ 5.82
United States ............................. $ 4.93 $ 4.63 $ 4.85 $ 7.63
Corporate Average ......................... $ 3.82 $ 3.74 $ 3.89 $ 6.56
Crude oil and natural gas prices were strong during the quarter. The West Texas
Intermediate crude oil price (WTI) averaged US $28.30 per barrel compared to US
$26.76 in the third quarter of 2001. The New York Mercantile Exchange natural
gas price (NYMEX) averaged US $3.21 per million British thermal units (mmbtu)
for the third quarter of 2002, 16% above the average for 2001.
Nexen's average realized crude oil price was $40.77 per barrel due to the strong
WTI reference price and narrow oil quality differentials. The Masila crude oil
quality differential averaged US $1.02 per barrel during the third quarter
compared to US $3.00 in 2001. The narrow differential was caused by a strong
Brent crude oil price combined with a premium to Brent for Masila blend crude
oil in the quarter. During the quarter, the differential for Canadian heavy oil
crude averaged US $5.98 per barrel compared to US $8.27 in 2001. As a result,
crude oil prices for Canada exceeded 2001 levels. Approximately 15% of the
Company's crude oil production is Canadian heavy oil. Year to date, Nexen's
average realized crude oil price was $36.26 per barrel compared to $35.58 during
the comparable period in 2001.
Our realized natural gas price was $3.82 per thousand cubic feet compared to
$3.74 in the third quarter of 2001. The average realized natural gas price year
to date was $3.89 per thousand cubic feet compared to $6.56 in the first nine
months of 2001, which is a result of record natural gas prices experienced
during the first part of 2001. All gas produced from the Gulf of Mexico is sold
based on spot prices, as is approximately 80% of gas produced in Canada.
21
OPERATING AND OTHER
Operating costs for conventional oil and gas production increased $57 million
compared to the first nine months of 2001. On a barrel of oil equivalent basis,
conventional production costs were $4.52 compared to $3.87 in 2001.
Approximately 50% of the per barrel increase relates to operations in the Gulf
of Mexico. Operational difficulties and increased workovers have increased costs
and temporarily reduced production, resulting in increases in per unit costs. In
addition, weather-related shut-ins in the quarter also contributed to the
increase. Costs have also increased in Yemen and Canada, where industry cost
pressures and maturing assets have led to higher costs.
Operating costs for Syncrude were $24 million during the quarter, a $3 million
decrease compared to the third quarter of 2001. Year to date, operating costs
were $87 million, relatively unchanged from the comparable period of 2001. On a
barrel of oil equivalent basis, production costs were $18.95 compared to $20.11
in 2001. Operating costs for the total year are expected to average $18 to $19
per barrel.
DEPRECIATION, DEPLETION AND AMORTIZATION
Depreciation, depletion and amortization for conventional oil and gas properties
increased by $70 million compared with the first nine months of 2001. On a
barrel of oil equivalent basis, the depletion rate for conventional oil and gas
properties was $6.91 in the first nine months of the year compared to $6.03
during the same period last year. The increase is related in part to increased
finding and development costs in Canada, Yemen and the Gulf of Mexico during
2001.
EXPLORATION EXPENSE
THREE MONTHS ENDED NINE MONTHS ENDED
SEPTEMBER 30 SEPTEMBER 30
------------------------- -------------------------
2002 2001 2002 2001
(millions of Canadian dollars)
Seismic....................................... $ 12 $ 18 $ 48 $ 59
Unsuccessful Exploration Drilling............. 6 66 27 98
Other......................................... 15 6 38 37
---------- ----------- ------------ ---------
$ 33 $ 90 $ 113 $ 194
========== =========== ============ =========
Exploration expense was $113 million during the first nine months of 2002, $81
million lower than the comparable period in 2001. The lower expense reflects
lower levels of exploration drilling and successful exploratory drilling in
Nigeria. In 2001, increased exploration expense reflected an expanded
exploratory drilling program including the third quarter dry hole costs for the
Scout deep water well in the Gulf of Mexico. In addition, expanded seismic
programs in Yemen, Colombia, the Gulf of Mexico and Canada during 2001
contributed to higher exploration expense.
MARKETING
Nexen's Marketing operation is involved in activities intended to enhance price
realizations from the sale of oil and gas production and for energy trading
purposes. Energy trading activities involve taking net open positions that
enable the Marketing operation to generate income based on competitive
information. These activities also expose the Company to the risk of loss from
fluctuating market prices. The extent of exposure under these activities is
restricted to prescribed limits and is monitored daily using value-at-risk,
stress testing and scenario analysis. The value-at-risk calculation estimates
the maximum probable loss, given a 95% confidence level, that the Company would
incur if the outstanding positions were unwound
22
over a two day time period. The value-at-risk was $19 million at September 30,
2002 compared to $13 million at September 30, 2001.
Consistent with Nexen's intention and management practices with respect to the
revenues to be derived from its energy trading activities, all energy contracts
are marked to market with the associated gains and losses recorded on a net
basis and included in Marketing and Other Income in the Unaudited Consolidated
Statement of Income. Related accounts receivable and accounts payable are
recorded in the Unaudited Consolidated Balance Sheet on a gross basis reflecting
the full extent of Nexen's exposure to credit risk and its obligations. During
the first nine months of 2002, net revenue from these activities, including the
related derivative instruments, was $40 million, compared to $92 million for the
first nine months of 2001. Reduced net revenue is primarily a result of lower
trading profits from natural gas basis exposure.
CHEMICALS
During the first nine months of 2002, operating income from our chemicals
operations was $18 million compared to $36 million for the first nine months of
2001. Reduced sales volumes and lower prices related to general economic
conditions and higher depreciation contributed to the decrease.
CORPORATE EXPENSES
GENERAL AND ADMINISTRATIVE
General and administrative expenses for the first nine months of 2002 increased
by $12 million compared to the first nine months of last year. This relates
primarily to higher staffing levels and a larger capital investment program.
INTEREST EXPENSE
Total interest costs incurred increased by $12 million year to date compared to
2001. The higher borrowing rate on our new 30-year notes was the primary driver.
Net interest expense, however, decreased by $8 million as we capitalized $20
million of interest expense on expenditures related to major on-going
development projects in 2002. No interest was capitalized in the comparable
period of 2001 as no major development projects were underway.
GAIN ON DISPOSITION OF ASSETS
During the first quarter of 2002, proceeds of $27 million on the sale of our
asphalt operation in Moose Jaw, Saskatchewan resulted in a $13 million gain.
PROVISION FOR INCOME TAXES
The effective tax rate for the first nine months of 2002 was 35% compared to 42%
in the comparable period of 2001. The reduced rate reflects lower federal and
provincial statutory tax rates for Canadian non-oil and gas operations, as well
as a higher portion of income from international operations where the tax rates
are lower than Canadian tax rates.
The majority of our 2002 current income taxes are paid in Yemen and Australia.
Current taxes include cash taxes in Yemen of $57 million during the quarter,
compared to $53 million in the third quarter of 2001. Year to date, cash taxes
in Yemen were $149 million compared to $152 million in the comparable
23
period of 2001. In addition, alternative minimum tax is payable in the United
States and federal and provincial capital taxes are payable in Canada.
CAPITAL EXPENDITURES
Capital investment of $414 million during the third quarter increased our
expenditures to $1,179 million for the first nine months of 2002, a $297 million
increase over the same period in 2001. Approximately 90% of the capital program
related to oil and gas expenditures, of which approximately 80% related to
development activities with the remainder for exploration projects. Development
activities are focused on our five major development projects - Aspen and
Gunnison in the Gulf of Mexico, Guando in Colombia, our Long Lake Synthetic
Crude Project and Syncrude in Northern Alberta. Development activities continue
to focus on increasing production, reserves and profitability in our core areas.
Our exploration activities included exploration wells in the Gulf of Mexico,
Canada and Brazil.
UNITED STATES
Construction delays caused by poor weather conditions in the Gulf of Mexico have
deferred initial production from our deep-water Aspen development project by two
months to early December. Aspen consists of two subsea development wells
tied-back to the Shell-operated Bullwinkle production platform. The platform has
been modified to accommodate Aspen's production and the two 16-mile pipelines
are 50% complete. Both development wells have been drilled, with the first well
complete and ready for tie-in. The second well is expected to be completed by
the end of November.
Peak production from Aspen is projected to reach between 15,000 and 18,000
equivalent barrels per day, net to Nexen, in January 2003. Our share of
development costs is estimated at US $194 million and operating costs, including
processing fees, are expected to average under US $2 per equivalent barrel. We
have a 60% interest in this project.
Development of the Gunnison field, also located in the deep-water Gulf of
Mexico, is on budget and on schedule for production start-up in early 2004.
Fabrication of the SPAR production facility is 40% complete. The last of nine
development wells has been drilled and completion operations will begin in 2003.
The facilities are being designed for daily production of 40,000 barrels of oil
and 200 million cubic feet of natural gas. We have a 30% interest in this
project. Our share of development costs is estimated at US $128 million and
operating costs are expected to average just over US $1 per equivalent barrel.
We have completed drilling the Fergana prospect, located on South Timbalier
Blocks 239 and 248, approximately 115 miles south of New Orleans in 210 feet of
water. The well reached its objective depth and is currently being evaluated,
although mechanical problems late in the drilling process have limited the well
information we obtained. The parties expect to reach a decision on further
activity at Fergana by year-end.
Fergana is the first prospect in a three-year joint venture with Shell
Exploration & Production Company to explore a 1,044 square mile area of the Gulf
of Mexico continental shelf for natural gas in deep Miocene reservoirs. Nexen
has a 40% interest in the joint venture.
24
SYNTHETIC CRUDE OIL PROJECTS
Our Premium Synthetic Crude Oil Project in the Athabasca region of Alberta
received regulatory approval for a steam assisted gravity drainage (SAGD) pilot
project. The pilot consists of three horizontal well pairs. Drilling has
commenced and we expect to begin steam injection during the first quarter of
2003. This pilot project will test well productivity and allow us to collect
Long Lake bitumen to process through our demonstration plant.
The Long Lake project consists of SAGD development of Nexen's bitumen resource
to feed an upgrader capable of producing 60,000 barrels per day of premium
synthetic crude oil. Front-end engineering design and preparation of detailed
cost estimates for the project are in progress and we are finalizing selection
of licensors for major components. Final regulatory approval and project
sanctioning are scheduled for late 2003. Facilities construction is expected to
commence in 2004, with bitumen SAGD production operations scheduled for 2006 and
upgrader start-up in 2007.
At our Syncrude Joint Venture, progress on the Stage 3 expansion is also
continuing. Detailed design engineering is close to 80% complete for both the
upgrader expansion and the Aurora Train 2. We expect this expansion to add 8,000
barrels per day (110,000 gross) of production starting in early 2005. The
Syncrude owners are currently reviewing the gross capital costs for the Phase 3
expansion. Recent analysis indicates that these costs may increase from the
original estimate of $4.1 billion to around $5.7 billion. Based on detailed
design work, the current estimate reflects higher material, labour and
engineering costs, as well as a schedule extension. Syncrude continues to look
for ways to reduce costs while maintaining the quality of the facility. Nexen
has a 7.23% interest in the Syncrude Joint Venture.
COLOMBIA
Development of the Guando field in Colombia continues, with eight development
wells drilled so far this year. Guando's current production of 5,700 barrels per
day (gross) is surpassing expectations given several high-rate wells recently
drilled. Four additional development wells are expected to be drilled in the
fourth quarter, while Phase 1 waterflood pilot facilities are expected to be
operational by year-end. Guando is located on the Boqueron block in the Upper
Magdelena Valley in Colombia. We have a 20% interest in Guando.
OTHER INTERNATIONAL
Offshore Brazil, we participated in the drilling of an exploration well on Block
BC-20, located in the Campos Basin in 5,900 feet of water. The well encountered
non-commercial quantities of hydrocarbons and was written off in the third
quarter. A second exploration well is expected to be drilled on the Block in
late 2002 or early 2003. Nexen has a 20% interest in BC-20.
OTHER
In November 2000, Nexen committed to enter into a lease agreement upon the
completion of construction of a natural gas-fired generating facility in
Alberta. On June 28, 2002, Nexen exercised its option to buy out the lease for a
cost of $67 million, which was the cost of construction plus interest on
advances during the construction phase. This amount is reflected in capital
expenditures for the year.
Nexen expects cash requirements for its 2002 capital program to reach
approximately $1.6 billion. The Company expects that cash flow from operations
and existing committed borrowing capacity will be sufficient to fund its 2002
capital program and meet financial obligations as they come due.
25
LIQUIDITY
During the first nine months of 2002, cash flow generated from operating
activities decreased from the corresponding period of 2001. Lower natural gas
prices, higher costs and reduced cash flow from our Marketing operation
contributed to the decrease. In addition, an increase in working capital during
the first nine months reduced cash flow from operating activities by $92
million. This is primarily related to an increase in accounts receivable. At
December 31, 2001, we sold accounts receivable of $90 million to minimize our
all-in cost of financing but did not sell any at September 30, 2002. Accounts
receivable also increased as a result of higher crude oil and natural gas prices
relative to year-end.
In March, Nexen issued US $500 million of 7.875% debt securities (the Notes).
The Notes mature on March 15, 2032 and were priced to yield 8.05%. The Notes are
unsecured and rank equally with the Company's other senior unsecured
indebtedness. Proceeds were used to repay existing bank debt and to fund a
portion of Nexen's capital investment program and dividend requirements.
At September 30, 2002, Nexen had unused committed long-term lines of credit of
$1,484 million and undrawn short-term operating loan facilities of $140 million.
In addition, Nexen has two existing shelf prospectuses for debt securities; one
in Canada for $500 million and one in the United States for US $500 million.
OTHER
YEMEN
Our Masila block operations in Yemen were unaffected by an explosion and fire
aboard the supertanker Limburg, inbound for Nexen's Ash Shihr export terminal.
Tanker loadings were delayed while Nexen's tugboat secured the Limburg to
prevent it from running aground. Loading has resumed and oil exports are
occurring as scheduled.
OUTLOOK
We have revised our 2002 production outlook from 280,000 equivalent barrels per
day to between 270,000 and 272,000 equivalent barrels. The growth of our oil
production has been on target all year. However, the delayed start-up of Aspen,
weather-related production shut-ins in the US Gulf, mechanical problems in
Australia and lower than expected growth in our North American gas production is
causing us to reduce our outlook for the fourth quarter and full year.
NEW ACCOUNTING PRONOUNCEMENTS
In June 2001, the FASB issued Statement No. 143, "Accounting for Asset
Retirement Obligations" (FAS 143). FAS 143 requires liability recognition for
retirement obligations associated with tangible long-lived assets. The
obligations included within the scope of FAS 143 are those for which a company
faces a legal obligation for settlement. The initial measurement of the asset
retirement obligation is to be at fair value. The asset retirement cost equal to
the fair value of the retirement obligation is to be capitalized as part of the
cost of the related long-lived asset and amortized to expense over the useful
life of the asset. FAS 143 is effective for all fiscal years beginning after
June 15, 2002. The total impact on the Company's financial statements has not
yet been determined.
26
SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS
Certain statements in this report constitute "forward-looking statements" within
the meaning of the United States PRIVATE SECURITIES LITIGATION REFORM ACT OF
1995, Section 21E of the United States SECURITIES EXCHANGE ACT OF 1934, as
amended, and Section 27A of the United States SECURITIES ACT OF 1933, as
amended. Such statements are generally identifiable by the terminology used such
as "plan", "expect", "estimate", "budget" or other similar words.
The forward-looking statements are subject to known and unknown risks and
uncertainties and other factors , some of which are identified herein and in our
2001 Annual Report on Form 10-K, which may cause actual results, levels of
activity and achievements to differ materially from those expressed or implied
by such statements. Such factors include, among others: market prices for oil
and gas and chemicals products; the ability to produce and transport crude oil
and natural gas to markets; the results of exploration and development drilling
and related activities; foreign currency exchange rates; economic conditions in
the countries and regions in which the Company carries on business; actions by
governmental authorities including increases in taxes, changes in environmental
and other regulations, and renegotiations of contracts; and, political
uncertainty, including actions by terrorists, insurgent groups or other conflict
including conflict between states. The impact of any one factor on a particular
forward-looking statement is not determinable with certainty as such factors are
interdependent upon other factors, and management's course of action would
depend upon its assessment of the future considering all information then
available. In that regard, any statements as to future crude oil, natural gas or
chemicals prices and production levels, cost recovery oil revenues and the
Company's share of production from operations in Yemen, capital expenditures,
the allocation of capital expenditures to exploration and development
activities, sources of funding for its capital program, debt levels, cash flows,
uses of cash flows, drilling of new wells, future production rates, expected
operating costs, dates by which certain areas will be developed or will come
on-stream and changes in any of the foregoing are forward-looking statements.
Although the Company believes that the expectations conveyed by the
forward-looking statements are reasonable based on information available to it
on the date such forward-looking statements were made, no assurances can be
given as to future results, levels of activity and achievements. All subsequent
forward-looking statements, whether written or oral, attributable to the Company
or persons acting on its behalf are expressly qualified in their entirety by
these cautionary statements.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
We are exposed to all of the normal market risks inherent within the oil and gas
business, including our marketing operations, and the chemicals business. Risks
include commodity price risk, foreign currency rate risk, interest rate risk and
credit risk. We manage our operations in a manner intended to minimize our
exposure as described in our 2001 Annual Report on Form 10-K. There have been no
significant changes in Nexen's exposure to these market risks since December 31,
2001.
27
ITEM 4. CONTROLS AND PROCEDURES
(a) EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES
Our Chief Executive Officer and Chief Financial Officer have evaluated
the effectiveness of our disclosure controls and procedures (as defined
in Exchange Act Rules 13a-14(c) and 15-d-14(c)) within 90 days of the
filing of this Form 10-Q (Evaluation Date). They concluded that, as of
the Evaluation Date, our disclosure controls and procedures were
adequate and effective in ensuring that material information relating
to the Company and its consolidated subsidiaries would be made known to
them by others within those entities, particularly during the period in
which this quarterly report was being prepared.
(b) CHANGES IN INTERNAL CONTROLS
We currently have in place systems relating to internal controls and
procedures with respect to our financial information. Management
periodically reviews and evaluates these internal control systems.
Based on these evaluations, there were no significant deficiencies or
material weaknesses in these internal controls requiring corrective
actions. As a result, no corrective actions were taken. There have been
no significant changes in our internal controls or in other factors
that could significantly affect these internal controls subsequent to
the date of their most recent evaluation.
28
PART II. OTHER INFORMATION:
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
99.1 - Certification of periodic report by Chief Executive Officer
pursuant to 18 U.S.C., Section 1350, as adopted pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002.
99.2 - Certification of periodic report by Chief Financial Officer
pursuant to 18 U.S.C., Section 1350, as adopted pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002.
(b) Reports on Form 8-K
On July 17, 2002 a current report on Form 8-K was filed to report
a change in Nexen Inc.'s independent auditors from Arthur Andersen
LLP to Deloitte & Touche LLP.
29
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the
Registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
NEXEN INC.
/s/ Marvin F. Romanow
-----------------------------
Marvin F. Romanow
Executive Vice-President, and
Chief Financial Officer
(Principal Financial Officer)
/s/ Una M. Power
-----------------------------
Una M. Power
Controller
(Principal Accounting Officer)
DATE: November 7, 2002
30
CERTIFICATIONS
I, Charles W. Fischer, President and Chief Executive Officer, certify that:
1. I have reviewed this quarterly report on Form 10-Q of Nexen Inc.
2. Based on my knowledge, this quarterly report does not contain any
untrue statement of a material fact or omit to state a material fact
necessary to make the statements made, in light of the circumstances
under which such statements were made, not misleading with respect to
the period covered by this quarterly report;
3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and
cash flows of the registrant as of, and for, the periods presented in
this quarterly report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as
defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and
we have:
(a) designed such disclosure controls and procedures to ensure
that material information relating to the registrant,
including its consolidated subsidiaries, is made known to us
by others within those entities, particularly during the
period in which this quarterly report is being prepared;
(b) evaluated the effectiveness of the registrant's disclosure
controls and procedures as of a date within 90 days prior to
the filing date of this quarterly report (the "Evaluation
Date"); and
(c) presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures based
on our evaluation as of the Evaluation Date;
5. The registrant's other certifying officers and I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the
audit committee of registrant's board of directors (or persons
performing the equivalent function):
(a) all significant deficiencies in the design or operation of
internal controls which could adversely affect the
registrant's ability to record, process, summarize and report
financial data and have identified for the registrant's
auditors any material weaknesses in internal controls; and
(b) any fraud, whether or not material, that involves management
or other employees who have a significant role in the
registrant's internal controls; and
6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in
internal controls or in other factors that could significantly affect
internal controls subsequent to the date of our most recent evaluation,
including any corrective actions with regard to significant
deficiencies and material weaknesses.
Date: November 7, 2002
/s/ Charles W. Fischer
--------------------------------------
Charles W. Fischer
President, and Chief Executive Officer
31
I, Marvin F. Romanow, Executive Vice-President, and Chief Financial Officer,
certify that:
1. I have reviewed this quarterly report on Form 10-Q of Nexen Inc.
2. Based on my knowledge, this quarterly report does not contain any
untrue statement of a material fact or omit to state a material fact
necessary to make the statements made, in light of the circumstances
under which such statements were made, not misleading with respect to
the period covered by this quarterly report;
3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and
cash flows of the registrant as of, and for, the periods presented in
this quarterly report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as
defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and
we have:
(a) designed such disclosure controls and procedures to ensure
that material information relating to the registrant,
including its consolidated subsidiaries, is made known to us
by others within those entities, particularly during the
period in which this quarterly report is being prepared;
(b) evaluated the effectiveness of the registrant's disclosure
controls and procedures as of a date within 90 days prior to
the filing date of this quarterly report (the "Evaluation
Date"); and
(c) presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures based
on our evaluation as of the Evaluation Date;
5. The registrant's other certifying officers and I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the
audit committee of registrant's board of directors (or persons
performing the equivalent function):
(a) all significant deficiencies in the design or operation of
internal controls which could adversely affect the
registrant's ability to record, process, summarize and report
financial data and have identified for the registrant's
auditors any material weaknesses in internal controls; and
(b) any fraud, whether or not material, that involves management
or other employees who have a significant role in the
registrant's internal controls; and
6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in
internal controls or in other factors that could significantly affect
internal controls subsequent to the date of our most recent evaluation,
including any corrective actions with regard to significant
deficiencies and material weaknesses.
Date: November 7, 2002
/s/ Marvin F. Romanow
-------------------------------
Marvin F. Romanow
Executive Vice-President,
and Chief Financial Officer