UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934

For the Quarter Ended September 30, 2000
Commission File No. 1-8968

ANADARKO PETROLEUM CORPORATION
17001 Northchase Drive, Houston, Texas 77060-2141
(281) 875-1101

Incorporated in the Employer Identification
State of Delaware No. 76-0146568

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 (or for such
shorter period that the registrant was required to file such reports)
and (2) has been subject to such filing requirements for the past 90 days.
Yes X No _____

The number of shares outstanding of the Company's common stock as
of October 31, 2000 is shown below:

Number of Shares
Title of Class Outstanding

Common Stock, par value $0.10 per share 248,785,417

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

ANADARKO PETROLEUM CORPORATION
CONSOLIDATED STATEMENT OF INCOME AND COMPREHENSIVE INCOME
(Unaudited)

Three Months Ended Nine Months Ended
millions, except September 30 September 30
per share amounts 2000 1999 2000 1999

Revenues
Gas sales $503.7 $ 98.2 $ 758.4 $259.8
Oil and condensate sales 339.7 55.1 555.6 156.7
Natural gas liquids sales 84.5 26.4 164.6 58.6
Minerals and other 28.2 0.6 30.5 2.3
Total 956.1 180.3 1,509.1 477.4

Costs and Expenses
Operating expenses 119.8 35.2 208.6 103.7
Administrative and general 43.7 24.6 103.9 72.2
Depreciation, depletion and
amortization 215.6 51.7 334.8 162.2
Other taxes 52.2 9.7 76.8 27.4
Provision for doubtful 23.3 --- 23.3 ---
accounts
Impairments related to
international properties --- --- --- 20.0
Amortization of goodwill 11.3 --- 11.3 ---
Total 465.9 121.2 758.7 385.5

Operating Income 490.2 59.1 750.4 91.9

Other (Income) Expense
Merger expenses 63.7 --- 63.7 ---
Interest expense 27.9 17.9 69.5 55.0
Other (income) expense (29.0) 0.4 (29.3) (0.3)
Total 62.6 18.3 103.9 54.7

Income Before Income Taxes 427.6 40.8 646.5 37.2

Income Taxes 179.2 19.3 278.6 25.4

Net Income $248.4 $ 21.5 $ 367.9 $ 11.8

Preferred Stock Dividends 2.7 2.7 8.2 8.1

Net Income Available
to Common Stockholders $245.7 $ 18.8 $ 359.7 $ 3.7

Comprehensive Income - Net of Tax
Foreign currency translation
adjustments 1.8 --- 1.8 ---

Comprehensive Income $247.5 $ 18.8 $ 361.5 $ 3.7

Per Common Share
Net income - basic $ 1.07 $ 0.15 $ 2.22 $ 0.03
Net income - diluted $ 1.03 $ 0.15 $ 2.14 $ 0.03
Dividends $ 0.05 $ 0.05 $ 0.15 $ 0.15

Average Number of Common
Shares Outstanding 230.4 127.4 162.2 124.4

See accompanying notes to consolidated financial statements.
-2-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
CONSOLIDATED BALANCE SHEET
(Unaudited)

millions, except September 30, December 31,
share amounts 2000 1999

ASSETS
Current Assets
Cash and cash equivalents $ 129.2 $ 44.8
Accounts receivable, net of allowance 835.0 259.6
Inventories 98.3 46.1
Other current assets 41.2 5.4
Total 1,103.7 355.9

Properties and Equipment
Original cost 15,253.8 5,917.2
Less accumulated depreciation,
depletion and amortization 2,578.6 2,236.0
Net properties and equipment - based on
the full cost method of accounting
for oil and gas properties 12,675.2 3,681.2

Other Assets 285.4 61.3

Goodwill, net of amortization 1,027.3 ---

$15,091.6 $4,098.4

See accompanying notes to consolidated financial statements.
-3-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
CONSOLIDATED BALANCE SHEET (continued)
(Unaudited)

millions, except September 30, December 31,
share amounts 2000 1999

LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities
Accounts payable
Trade and other $ 832.3 $ 298.6
Banks 87.1 26.4
Accrued expenses
Interest 87.3 20.0
Taxes and other 164.1 42.2
Total 1,170.8 387.2

Long-term Debt 4,024.2 1,443.3

Other Long-term Liabilities
Deferred income taxes 3,261.3 576.8
Other 391.7 156.5
Total 3,653.0 733.3

Stockholders' Equity
Preferred stock, par value $1.00
(2,000,000 shares authorized, 200,000
shares issued as of September 30, 2000
and December 31, 1999) 200.0 200.0
Common stock, par value $0.10
(450,000,000 shares authorized,
251,060,146 and 129,620,333 shares
issued as of September 30, 2000 and
December 31, 1999, respectively) 25.1 13.0
Paid-in capital 5,170.3 633.9
Retained earnings (as of September 30,
2000, retained earnings were not
restricted as to the payment of
dividends) 1,097.9 763.5
Deferred compensation (46.7) (7.9)
Unearned employee stock ownership plan
(1,153,673 shares as of September 30, (72.8) ---
2000)
Executives and Directors Benefits Trust,
at market value (2,000,000 shares as of
September 30, 2000 and December 31, (132.0) (67.9)
1999)
Treasury stock (39 shares as of
September 30, 2000) --- ---
Accumulated other comprehensive income -
foreign currency translation 1.8 ---
adjustments
Total 6,243.6 1,534.6

$15,091.6 $4,098.4

See accompanying notes to consolidated financial statements.
-4-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
CONSOLIDATED STATEMENT OF CASH FLOWS
(Unaudited)
Nine Months Ended
September 30
millions 2000 1999

Cash Flow from Operating Activities
Net income $367.9 $ 11.8
Adjustments to reconcile net income to
net cash provided by operating activities:
Depreciation, depletion and amortization 335.7 163.4
Amortization of goodwill 11.3 ---
Non-cash merger expense 30.8 ---
Interest expense - zero coupon debentures 6.9 ---
Deferred income taxes 191.9 8.8
Provision for doubtful accounts 23.3 ---
Impairments of international properties --- 20.0
Other non-cash items (24.5) ---
943.3 204.0
Increase in accounts receivable (155.7) (30.3)
Increase in inventories (6.1) (2.0)
Decrease in accounts payable -
trade and other and accrued expenses (23.3) (39.5)
Other items - net 85.7 (6.2)
Net cash provided by operating activities 843.9 126.0

Cash Flow from Investing Activities
Additions to properties and equipment (976.5) (431.6)
Sales and retirements of properties
and equipment 42.6 102.5
Acquisition costs, net of cash acquired (55.4) ---
Proceeds from the sale of assets to be
leased, net --- 3.8
Net cash used in investing activities (989.3) (325.3)

Cash Flow from Financing Activities
Additions to debt 344.7 300.0
Retirements of debt (277.5) (320.1)
Issuance of common stock 176.7 260.7
Increase (decrease) in accounts payable, banks 19.3 (16.6)
Dividends paid (33.4) (26.9)
Net cash provided by financing activities 229.8 197.1

Net Increase (Decrease) in Cash and Cash
Equivalents 84.4 (2.2)

Cash and Cash Equivalents at Beginning of 44.8 17.0
Period

Cash and Cash Equivalents at End of Period $129.2 $ 14.8

See accompanying notes to consolidated financial statements.
-5-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)

1. Summary of Accounting Policies

General Anadarko Petroleum Corporation is engaged primarily in the
exploration, development, production and marketing of natural gas,
crude oil, condensate and natural gas liquids (NGLs). On July 14, 2000,
Union Pacific Resources Group Inc. (UPR) merged with Anadarko Petroleum
Corporation. See Note 2. The terms "Anadarko" and "Company" refer to
Anadarko Petroleum Corporation and its subsidiaries. The principal
subsidiaries of Anadarko are: UPR; Anadarko Algeria Corporation;
Anadarko Canada Corporation; Anadarko Energy Services Company; and,
Anadarko Gathering Company. Certain amounts have been reclassified to
conform to the current presentation.

The portion of gathering revenues, processing revenues and the margin
related to oil and gas marketing activities has been reported as a net
addition to oil and gas revenues in the accompanying statement of
income.

Goodwill Goodwill represents the excess of the purchase price over
the estimated fair value of the assets acquired and liabilities assumed
in the merger with UPR and is being amortized on a straight-line basis
over 20 years. The Company reviews goodwill to determine if there has
been any impairment. Any impairment would be charged to expense in the
period identified.

2. Merger Transaction On April 2, 2000, Anadarko and UPR entered
into a Merger Agreement. On July 13, 2000, the stockholders of both
companies approved the merger transaction. Each share of common stock
of UPR issued and outstanding was converted into 0.455 shares of
Anadarko common stock. The merger was treated as a tax-free
reorganization and accounted for as a purchase business combination
under generally accepted accounting principles. Under this method of
accounting, the Company's historical operating results for periods
prior to the merger are the same as Anadarko's historical operating
results. At the date of the merger, the assets and liabilities of
Anadarko remain based upon their historical costs, and the assets and
liabilities of UPR are recorded at their estimated fair market values.

-6-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

2. Merger Transaction (continued)

The following is a calculation of the purchase price:

millions, except per share amounts

Shares of common stock issued 114.1
Average of Anadarko stock price per share
around the merger announcement $ 35.58
Fair value of stock issued $4,060.1
Add: Fair value of vested UPR employee
stock options assumed by Anadarko,
less common stock issuance costs 99.6
4,159.7
Add: Capitalized merger costs 146.3
Purchase price $4,306.0

Capitalized merger costs relate primarily to severance and relocation
costs of UPR employees ($82 million), professional fees directly
related to the merger ($43 million) and other direct transaction costs
($21 million). In addition, merger costs of $64 million were expensed
in the third quarter of 2000 related to the UPR merger. These relate
primarily to the issuance of stock for retention of employees ($45
million), deferred compensation ($8 million), transition, hiring and
relocation costs ($6 million) and vesting of restricted stock and stock
options ($5 million).

The following is the allocation of the purchase price to specific
assets and liabilities based on estimates of fair values and costs,
which will be adjusted to actual amounts as determined. Such
adjustments are not expected to be material.

millions

Current assets $ 657.0
Properties and equipment 8,395.0
Other assets 240.6
Goodwill 1,038.6
Current liabilities 928.0
Long-term debt 2,506.8
Deferred income taxes 2,468.4
Other long-term liabilities 268.3
Stockholders' equity $4,159.7

-7-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

2. Merger Transaction (continued)

In the third quarter of 2000, costs of $34.3 million, related to the
closing of UPR's offices in Fort Worth, Texas, were included in
capitalized merger costs. During the quarter, 181 employees actually
separated and were paid pursuant to the severance plans and 151
employees were relocated from Fort Worth to Houston.

The remaining accrued liability balance included in capitalized merger
costs is expected to be spent in 2000 and 2001. The following table
summarizes the activity in the accrued liability account for the three
and nine months ended September 30, 2000:

millions

Capitalized merger costs $146.3
Cash payments (102.7)
Non-cash payments (9.6)
Ending balance $ 34.0

The pro forma results for 2000 and 1999 are a result of combining the
three and nine months income statements of Anadarko with the three and
nine months income statements of UPR adjusted for 1) certain costs that
UPR had expensed under the successful efforts method of accounting that
are capitalized under the full cost method of accounting; 2)
depreciation, depletion and amortization expense of UPR calculated in
accordance with the full cost method of accounting applied to the
adjusted basis of the properties acquired using the purchase method of
accounting; 3) decreases to interest expense for the capitalization of
interest on significant investments in unevaluated properties and major
development projects and partly offset by the revaluation of UPR debt
under the purchase method of accounting, including the elimination of
amortization of historical debt issuance costs; 4) issuance of Anadarko
common stock and common stock equivalents pursuant to the merger
agreement, and 5) the related income tax effects of these adjustments
based on the applicable statutory tax rates. It should be noted that
the pro forma results do not include any merger expenses.

-8-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

2. Merger Transaction (continued)

The following table presents the unaudited pro forma results of the
Company as though the merger had occurred on January 1, 1999.

Three Months Ended Nine Months Ended
millions, except September 30 September 30
per share amounts 2000 1999 2000 1999

Revenues $1,007.7 $616.5 $2,617.9 $1,650.5
Net income available to
common stockholders $ 270.4 $111.2 $ 642.8 $ 198.4
Earnings per share - basic $ 1.10 $ 0.46 $ 2.64 $ 0.83
Earnings per share - diluted $ 1.06 $ 0.46 $ 2.58 $ 0.82

3. Inventories Materials and supplies and natural gas inventories
are stated at the lower of average cost or market. Natural gas, when
sold from inventory, is charged to expense using the average cost
method. Oil, due from third-parties, is stated at market value. The
major classes of inventories are as follows:

September 30, December 31,
millions 2000 1999

Materials and supplies $49.7 $14.2
Oil, due from third-parties 37.7 24.6
Natural gas, stored in inventory 10.9 7.3
$98.3 $46.1

4. Properties and Equipment Oil and gas properties include costs
of $2,823.9 million and $323.0 million at September 30, 2000 and
December 31, 1999, respectively, which were excluded from capitalized
costs being amortized. These amounts represent costs associated with
unevaluated properties and major development projects.

-9-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

5. Long-term Debt As a result of the merger, the liabilities of UPR
became liabilities of the Company. Accordingly, the financial statements
of the Company include an aggregate of approximately $2.5 billion of
outstanding UPR debt at the date of the merger. A summary of
long-term debt follows:

September 30, December 31,
millions 2000 1999

Commercial Paper $ 140.8 $ 198.3
Notes Payable, Banks 103.0 145.0
Long-term Portion of Capital Lease 12.2 ---
8 1/4% Notes due 2001 100.0 100.0
6.8% Debentures due 2002 246.9 ---
6 3/4% Notes due 2003 100.0 100.0
5 7/8% Notes due 2003 100.0 100.0
6.5% Notes due 2005 191.3 ---
7.375% Debentures due 2006 247.1 ---
7% Notes due 2006 194.1 ---
6.75% Notes due 2008 150.4 ---
7.8% Debentures due 2008 149.7 ---
7.3% Notes due 2009 155.6 ---
7.05% Debentures due 2018 183.0 ---
Zero Coupon Convertible
Debentures due 2020 351.6 ---
7 1/4% Debentures due 2025 0.3 100.0
7.5% Debentures due 2026 188.2 ---
7% Debentures due 2027 100.0 100.0
6.625% Debentures due 2028 100.0 100.0
7.15% Debentures due 2028 333.5 ---
7.20% Debentures due 2029 300.0 300.0
7.95% Debentures due 2029 238.5 ---
7.73% Debentures due 2096 100.0 100.0
7 1/4% Debentures due 2096 100.0 100.0
7.5% Debentures due 2096 138.0 ---
$4,024.2 $1,443.3

The commercial paper and notes payable to banks have been classified as
long-term debt in accordance with Statement of Financial Accounting
Standards (SFAS) No. 6, "Classification of Short-term Obligations
Expected to be Refinanced", under the terms of Anadarko's Bank Credit
Agreements.

-10-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

5. Long-term Debt (continued)

In March 2000, Anadarko issued $345 million of Zero Coupon Convertible
Debentures due March 2020, with a face value at maturity of $690
million. The Debentures were issued at a discount and accrue interest
at 3.50% annually until reaching face value at maturity; however,
interest will not be paid prior to maturity. The Debentures are
convertible into common stock at the option of the holder at any time
at a fixed conversion rate. Holders have the right to require Anadarko
to repurchase their Debentures at a specified price in March 2003, 2008
and 2013. The Debentures are redeemable at the option of Anadarko after
three years. The net proceeds from the offering were used to repay
floating interest rate debt.

In April 2000, the Company entered into a 364-Day Credit Agreement. The
aggregate amount of commitments is $300 million and expires in April
2001. In October 2000, the Company amended the UPR Competitive
Advance/Revolving Credit Agreement. The amendment reduced bank
commitments to $450 million, provided a Company guarantee and shortened
the maturity to October 2001. As of September 30, 2000, the Company had
$103 million outstanding under various credit agreements.

6. Supplemental Information for Guarantee of Securities

In connection with the merger transaction, Anadarko has guaranteed all
of the outstanding publicly held indebtedness of UPR and its subsidiary
Anadarko Canada Corporation (ACC). In order to provide meaningful
financial data relating to the guarantee, the following condensed
consolidating financial information as of September 30, 2000 and for
the three and nine months ended September 30, 2000, has been provided
following the policies set forth below:

1) The Company accounts for investments in subsidiaries on the cost
basis. Earnings of subsidiaries are therefore not reflected in the
related investment accounts. Investments in subsidiaries are
included in Other Assets.

2) Certain reclassifications were made to conform the financial
information to the financial presentation on a consolidated basis.
The principal adjusting entries eliminate investments in
subsidiaries and intercompany transactions and balances.

-11-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

6. Supplemental Information for Guarantee of Securities (continued)

<CAPTIONS>
SUPPLEMENTAL CONDENSED CONSOLIDATING INCOME STATEMENTS
Three Months Ended September 30, 2000

Other Consolidating Anadarko
millions Anadarko UPR ACC Subsidiaries Adjustments Consolidated

Revenues
Gas sales $203.7 $255.2 $ 58.5 $20.1 $(33.8) $503.7
Oil and condensate sales 56.5 162.7 51.0 69.5 --- 339.7
Natural gas liquids sales --- 39.0 3.3 42.2 --- 84.5
Minerals and other 0.5 27.3 --- 0.6 (0.2) 28.2
Total 260.7 484.2 112.8 132.4 (34.0) 956.1

Cost and Expenses
Operating expenses 19.8 41.0 26.8 66.2 (34.0) 119.8
Administrative and general 24.2 14.6 1.0 3.9 --- 43.7
Depreciation, depletion and
amortization 55.8 120.7 30.4 8.7 --- 215.6
Other taxes 14.5 36.2 0.5 1.0 --- 52.2
Provision for doubtful
accounts --- --- --- 23.3 --- 23.3
Amortization of goodwill 11.3 --- --- --- --- 11.3
Total 125.6 212.5 58.7 103.1 (34.0) 465.9

Operating Income 135.1 271.7 54.1 29.3 --- 490.2

Other (Income) Expense
Merger expenses 63.0 0.7 --- --- --- 63.7
Interest expense 20.6 1.1 5.1 1.1 --- 27.9
Other (income) expense (3.8) (43.5) 14.7 (0.2) 3.8 (29.0)
Total 79.8 (41.7) 19.8 0.9 3.8 62.6

Income Before Income Taxes 55.3 313.4 34.3 28.4 (3.8) 427.6

Income Taxes 26.1 130.2 (2.7) 24.6 1.0 179.2

Net Income $ 29.2 $183.2 $ 37.0 $ 3.8 $ (4.8) $248.4

-12-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

6. Supplemental Information for Guarantee of Securities (continued)

SUPPLEMENTAL CONDENSED CONSOLIDATING INCOME STATEMENT
Nine Months Ended September 30, 2000

Other Consolidating Anadarko
millions Anadarko UPR ACC Subsidiaries Adjustments Consolidated

Revenues
Gas sales $468.4 $255.2 $ 58.5 $ 70.9 $(94.6) $ 758.4
Oil and condensate sales 152.0 162.7 51.0 189.9 --- 555.6
Natural gas liquids sales 0.1 39.0 3.3 122.2 --- 164.6
Minerals and other 1.9 27.3 --- 1.9 (0.6) 30.5
Total 622.4 484.2 112.8 384.9 (95.2) 1,509.1

Cost and Expenses
Operating expenses 58.6 41.0 26.8 177.4 (95.2) 208.6
Administrative and general 74.5 14.6 1.0 13.8 --- 103.9
Depreciation, depletion and
amortization 159.7 120.7 30.4 24.0 --- 334.8
Other taxes 37.3 36.2 0.5 2.8 --- 76.8
Provision for doubtful
accounts --- --- --- 23.3 --- 23.3
Amortization of goodwill 11.3 --- --- --- --- 11.3
Total 341.4 212.5 58.7 241.3 (95.2) 758.7

Operating Income 281.0 271.7 54.1 143.6 --- 750.4

Other (Income) Expense
Merger expenses 63.0 0.7 --- --- --- 63.7
Interest expense 60.0 1.1 5.1 3.3 --- 69.5
Other (income) expense (53.1) (43.5) 14.7 (0.3) 52.9 (29.3)
Total 69.9 (41.7) 19.8 3.0 52.9 103.9

Income Before Income Taxes 211.1 313.4 34.3 140.6 (52.9) 646.5

Income Taxes 62.5 130.2 (2.7) 87.7 0.9 278.6

Net Income $148.6 $183.2 $ 37.0 $ 52.9 $(53.8) $ 367.9

SUPPLEMENTAL CONDENSED CONSOLIDATING BALANCE SHEET
As of September 30, 2000

Other Consolidating Anadarko
millions Anadarko UPR ACC Subsidiaries Adjustments Consolidated

Assets
Current Assets $ 26.3 $ 843.5 $ 21.0 $ 292.0 $ (79.1) $ 1,103.7
Net Properties and Equipment 3,454.1 6,896.7 1,510.0 814.4 --- 12,675.2
Other Assets 4,828.7 128.9 28.5 96.1 (4,796.8) 285.4
Goodwill 1,027.3 --- --- --- --- 1,027.3
$9,336.4 $7,869.1 $1,559.5 $1,202.5 $(4,875.9) $15,091.6

Liabilities and Stockholders'
Equity
Current Liabilities $ 199.3 $ 472.8 $ 195.6 $ 381.7 $ (78.6) $ 1,170.8
Long-term Debt 1,532.7 1,784.7 706.8 --- --- 4,024.2
Other Long-term Liabilities 643.7 2,250.3 552.6 205.6 0.8 3,653.0
Stockholders' Equity 6,960.7 3,361.3 104.5 615.2 (4,798.1) 6,243.6
$9,336.4 $7,869.1 $1,559.5 $1,202.5 $(4,875.9) $15,091.6

-13-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

6. Supplemental Information for Guarantee of Securities (continued)

SUPPLEMENTAL CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2000

Other Anadarko
millions Anadarko UPR ACC Subsidiaries Consolidated

Cash Flow from Operating
Activities
Net income $ 94.8 $183.2 $37.0 $ 52.9 $367.9
Adjustments to reconcile net
income to net cash provided
by operating activities 271.2 190.4 24.7 89.1 575.4
366.0 373.6 61.7 142.0 943.3
Changes in assets and
Liabilities 13.5 (58.3) (13.1) (41.5) (99.4)
Net Cash Provided by Operating
Activities 379.5 315.3 48.6 100.5 843.9

Cash Flow Used in Investing
Activities (635.5) (184.5) (48.6) (120.7) (989.3)

Cash Flow from Financing
Activities 244.4 (14.6) --- --- 229.8

Net Increase (Decrease) in Cash
and Cash Equivalents (11.6) 116.2 --- (20.2) 84.4

Cash and Cash Equivalents at
Beginning of Period 18.0 --- --- 26.8 44.8

Cash and Cash Equivalents at
End of Period $ 6.4 $116.2 $ --- $ 6.6 $129.2

7. Preferred Stock In each of the first, second and third quarters
of 2000 and 1999, dividends of $13.65 per share (equivalent to $1.365
per Depositary Share) were paid to holders of preferred stock.

8. Common Stock Under the most restrictive provisions of the
Company's credit agreements, which limit the payment of dividends,
retained earnings were not restricted as to the payment of dividends at
September 30, 2000 and December 31, 1999, respectively.

The Company's basic earnings per share (EPS) amounts have been computed
based on the average number of common shares outstanding. Diluted EPS
amounts include the effect of the Company's outstanding stock options
under the treasury stock method and the net effect of the assumed
conversion of the convertible debentures.

-14-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

8. Common Stock (continued)

The reconciliation between basic and diluted EPS is as follows:

Three Months Ended Three Months Ended
September 30, 2000 September 30, 1999
millions except Per Share Per Share
per share amounts Income Shares Amount Income Shares Amount

Basic EPS
Income available to
common stockholders $245.7 230.4 $1.07 $18.8 127.4 $0.15
Effect of convertible
debentures 1.9 8.0 -- --
Effect of dilutive
stock options -- 2.9 -- 0.9
Diluted EPS
Income available to
common stockholders plus
assumed conversion $247.6 241.3 $1.03 $18.8 128.3 $0.15

<CAPTION
Nine Months Ended Nine Months Ended
September 30, 2000 September 30, 1999
millions except Per Share Per Share
per share amounts Income Shares Amount Income Shares Amount

Basic EPS
Income available to
common stockholders $359.7 162.2 $2.22 $ 3.7 124.4 $0.03
Effect of convertible
debentures 4.4 6.2 -- --
Effect of dilutive
stock options -- 1.9 -- 0.7
Diluted EPS
Income available to
common stockholders plus
assumed conversion $364.1 170.3 $2.14 $ 3.7 125.1 $0.03

For the three and nine months ended September 30, 2000 and 1999,
options for 0.7 million and 3.2 million, respectively, shares of common
stock were excluded from the diluted EPS calculation because the
options' exercise price was greater than the average market price of
common stock for the periods.

On July 13, 2000, the stockholders of Anadarko approved an increase in
the authorized number of Anadarko common shares from 300 million to 450
million. On July 14, 2000, each share of common stock of UPR issued and
outstanding was converted into 0.455 shares of Anadarko common stock with
approximately 114.1 million shares issued to the stockholders of UPR.

-15-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

9. Statement of Cash Flows Supplemental Information The amounts of
cash paid (received) for interest (net of amounts capitalized) and
income taxes are as follows:

Nine Months Ended
September 30
millions 2000 1999

Interest $43.9 $55.1
Income taxes $36.6 $(0.2)

The merger was completed through the issuance of common stock, which
was a non-cash transaction that was not reflected in the statement of
cash flows. See Note 2. The $55.4 million of acquisition costs
reflected in "Cash Flow from Investing Activities" in the consolidated
statement of cash flows represents capitalized merger costs accrued in
connection with the merger of $146.3 million, less the cash acquired on
the date of the merger of $90.9 million.

10. Commitments and Contingencies UPR was a party to several long-
term firm gas transportation agreements that supported the gas
marketing program within the gathering, processing and marketing (GPM)
business segment, which was sold to Duke Energy Field Services, Inc.
(Duke). Most of the GPM business segment's firm long-term
transportation contracts were transferred to Duke in the GPM
disposition. As part of the GPM disposition, UPR and Duke agreed that
UPR will keep Duke whole on certain transportation contracts (keep-
whole agreement). UPR will pay Duke if transportation market values
fall below the contract transportation rates, while Duke will pay UPR
if the market value exceeds the contract transportation rates.
Transportation contracts transferred to Duke in the GPM disposition and
included in the keep-whole agreement with Duke relate to various
pipelines. It is UPR's contention (disputed by Duke) that the keep-
whole agreement has terminated. As of September 30, 2000, Other Long-
term Liabilities included $90.8 million related to this agreement.

-16-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

11. Legal Proceedings

General The Company is a defendant in a number of lawsuits and is
involved in governmental proceedings arising in the ordinary course of
business, including, but not limited to, royalty claims, contract
claims and environmental claims. The Company has also been named as a
defendant in various personal injury claims, including numerous claims
by employees of third-party contractors alleging exposure to asbestos
and benzene while working at the Corpus Christi refinery, which the
Company sold in segments in 1987 and 1989. While the ultimate outcome
and impact on the Company cannot be predicted with certainty,
management believes that the resolution of these proceedings will not
have a material adverse effect on the consolidated financial position
of the Company, although results of operations and cash flow could be
significantly impacted in the reporting periods in which such matters
are resolved. Discussed below are several specific proceedings.

Mineral Reservation Litigation In August 1994, the surface owners
(McCormick, et al.) of portions of five sections of Colorado land that
are subject to mineral reservations made by the Company's predecessor
in title brought suit against the Company in State District Court, Weld
County, Colorado, to quiet title to minerals, including oil (in some of
the lands) and natural gas. On June 23, 1997, the State District Court
granted the Company's Motion for Summary Judgment, holding as a matter
of law that the mineral reservations at issue were unambiguous and
included all valuable non-surface substances, including oil and gas.
The Colorado Court of Appeals affirmed the decision of the State
District Court in granting the Company's Motion for Summary Judgment on
December 10, 1998 and then denied the surface owners' Motion for
Rehearing. The surface owners then filed a Petition for Writ with the
Colorado Supreme Court, which was granted in September 1999. Oral
arguments were heard on June 13, 2000. A decision is expected by the
end of the first quarter of 2001.

Royalty Litigation During September of 2000, the Company was named
as a defendant in a case styled U.S. of America ex rel. Harold E.
Wright v. AGIP Company, et al. (the "Gas Qui Tam case") filed in the
U.S. District Court for the Eastern District of Texas, Lufkin Division.
This lawsuit generally alleges that the Company and 118 other
defendants improperly measured and otherwise undervalued natural gas in
connection with a payment of royalties on production from federal and
Indian lands. Recently the case has been transferred to the U.S.
District Court, Multi-District Litigation Docket pending in Wyoming.
Motions to dismiss will be filed by the Company and numerous other
defendants before the end of the year.

-17-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

11. Legal Proceedings (continued)

Based on the Company's present understanding of the various
governmental and False Claims Act proceedings described above, the
Company believes that it has substantial defenses to these claims and
intends to vigorously assert such defenses. However, if the Company is
found to have violated the Civil False Claims Act, the Company could be
subject to a variety of sanctions, including treble damages and
substantial monetary fines.

A group of royalty owners purporting to represent UPR's gas royalty
owners in Texas (Neinast, et al.) was granted class action
certification in December 1999, by the 21st Judicial District Court of
Washington County, Texas, in connection with a gas royalty underpayment
case against the Company. This certification did not constitute a
review by the Court of the merits of the claims being asserted. The
royalty owners' pleadings did not specify the damages being claimed,
although most recently a demand for damages in the amount of $100
million has been asserted. The Company is of the opinion that the
amount of damages at risk are substantially less than the amount
demanded by the class action counsel and the Company intends to
vigorously assert its defenses. The Company is currently appealing the
class certification order and hopes to have same overturned. A hearing
on the merits of the appeal has now been scheduled for December 1,
2000.

A group of royalty owners in the State of Oklahoma surrounding the
Beaver County Gathering System allege five separate claims against the
defendants that included UPR. This matter styled Galen Bridenstine v.
Kaiser Francis Oil Company, et al. (including UPR) has been certified
as a class action and is currently scheduled for trial in February
2001. The plaintiffs contend that gathering, compression and
dehydration fees deducted by the defendants from royalty payments were
in violation of the Oklahoma Check Stub Statute and were improper. The
damages asserted for this claim are approximately $40 million. In
addition, four additional claims have been asserted by the class
plaintiffs, including claims for gas mismeasurement, failure to pay
royalties on a higher price contract and failure to pay royalties on
condensate. The total actual damages sought are approximately $55
million. In addition, the plaintiffs seek punitive damages. The
Company is working vigorously to assert its defenses in this matter and
believes that the Company would be entitled to indemnity, if an adverse
judgment was entered against the Company. The Company has asserted an
indemnity claim against the company from which it purchased the assets
that are at issue in this litigation.

-18-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

11. Legal Proceedings (continued)

A class action lawsuit entitled Gilbert H. Coulter, et al. v. Anadarko
Petroleum Corporation has been certified in the 26th Judicial District
Court, Stevens County, Kansas. In this action, the royalty owners
contend that royalty was underpaid as a result of the deduction for
certain post-production costs in the calculation of royalty. The
Company believes that its method of calculating royalty was proper and
that its gas was marketable in the condition produced, and thus
plaintiffs' claims are without merit. This case was certified as a
class action in August 2000.

Kansas Ad Valorem Tax
General - The Natural Gas Policy Act of 1978 allowed a "severance,
production or similar" tax to be included as an add-on, over and above
the maximum lawful price for natural gas. Based on the Federal Energy
Regulatory Commission (FERC) ruling that the Kansas ad valorem tax was
such a tax, the Company collected the Kansas ad valorem tax.

Background of Pan Energy Litigation - FERC's ruling regarding the
ability of producers to collect the Kansas ad valorem tax was appealed
to the United States Court of Appeals for the District of Columbia
Circuit (D.C. Circuit). The Court held in June 1988 that FERC failed
to provide a reasoned basis for its findings and remanded the case to
FERC.

Ultimately, the D.C. Circuit issued a decision on August 2, 1996 ruling
that producers must refund all Kansas ad valorem taxes collected
relating to production since October 1983. The Company filed a
petition for writ of certiorari with the Supreme Court. That petition
was denied on May 12, 1997.

PanEnergy Litigation - On May 13, 1997, the Company filed a lawsuit in
the Federal District Court for the Southern District of Texas against
PanEnergy seeking declaration that pursuant to prior agreements
Anadarko is not required to issue refunds to PanEnergy for the
principal amount of $14 million (pretax) and, if the petition for
adjustment is denied in its entirety by FERC with respect to PanEnergy
refunds, interest in an amount of $33.4 million (pretax) as of
September 30, 2000. The Company also seeks from PanEnergy the return
of the $0.8 million (pretax) charged against income in 1993 and 1994.
In October 2000, the U.S. Magistrate issued recommendations concerning
motions for summary judgment previously filed by both parties. In

-19-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

11. Legal Proceedings (continued)

essence, the Magistrate's recommendation finds that the Company should
be responsible for refunds attributable to the time period following
August 1, 1985 while Duke Energy (as the successor company to Anadarko
Production Company) should be responsible for refunds attributable to
the time period before August 1, 1985. Remaining in dispute is
approximately $7-$8 million in refunds attributable to Pan Eastern
Exploration Company for the pre-August 1, 1985 time frame. The dispute
over Pan Eastern's refunds is currently set for trial on the
January/February 2001 trial docket of the U.S. District Court in
Houston, Texas.

Anadarko's net income for 1997 included a $1.8 million charge (pretax)
related to the Kansas ad valorem tax refunds. This charge reflects
all principal and interest which may be due at the conclusion of all
regulatory proceedings and litigation to parties other than PanEnergy.
The Company is currently unable to predict the final outcome of this
matter and no provision for liability (excluding amounts recorded in
1993, 1994 and 1997) has been made in the accompanying financial
statements.

12. New Accounting Principles

Accounting for Derivatives SFAS No. 133, "Accounting for Derivative
Instruments and for Hedging Activities", as amended, provides guidance
for accounting for derivative instruments and hedging activities. SFAS
No. 133, as amended, is effective for fiscal years beginning after June
15, 2000. The Company is evaluating the impact of the provisions of
SFAS No. 133 and believes it will not have a material effect on the
Company's financial condition or results of operations.

Revenue Recognition The Securities and Exchange Commission (SEC)
issued Staff Accounting Bulletin (SAB) No. 101, "Revenue Recognition in
Financial Statements" in December 1999. SAB No. 101 summarizes the SEC
staff's views in applying generally accepted accounting principles to
selected revenue recognition issues. The SEC staff has issued a
document to address significant implementation issues related to SAB
No. 101. To the extent that SAB No. 101 ultimately changes Anadarko's
revenue recognition practices, Anadarko will be required to adopt SAB
No. 101 no later than the quarter beginning October 1, 2000, with any
cumulative effect adjustment computed as of January 1, 2000.

-20-

Item 1. Financial Statements (continued)

ANADARKO PETROLEUM CORPORATION
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(Unaudited)

12. New Accounting Principles (continued)

Currently, Anadarko includes the margin related to oil and gas
marketing activities as oil and gas revenues. SAB No. 101 requires
that the purchases of oil and gas related to marketing, currently
included in the margin, be reclassified to costs and expenses. The
Company estimates that the effect, if SAB No. 101 had been adopted for
the three and nine months ended September 30, 2000, would be an
increase to revenues of $0.9 billion and $1.7 billion, respectively,
offset by an increase to costs and expenses of $0.9 billion and $1.7
billion, respectively.

13. The information, as furnished herein, reflects all normal
recurring adjustments that are, in the opinion of management,
necessary to a fair statement of financial position as of September
30, 2000 and December 31, 1999, the results of operations for the
three and nine months ended September 30, 2000 and 1999, and cash
flows for the nine months ended September 30, 2000 and 1999.

-21-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations

The Company has made in this report, and may from time to time
otherwise make in other public filings, press releases and discussions
with Company management, forward looking statements within the meaning
of Section 27A of the Securities Act of 1933 and Section 21E of the
Securities Exchange Act of 1934 concerning the Company's operations,
economic performance and financial condition. These forward looking
statements include information concerning future production and
reserves, schedules, plans, timing of development, contributions from
oil and gas properties, and those statements preceded by, followed by
or that otherwise include the words "believes", "expects",
"anticipates", "intends", "estimates", "projects", "target", "goal",
"plans", "objective", "should" or similar expressions or variations on
such expressions. For such statements, the Company claims the
protection of the safe harbor for forward looking statements contained
in the Private Securities Litigation Reform Act of 1995. Such
statements are subject to various risks and uncertainties, and actual
results could differ materially from those expressed or implied by such
statements due to a number of factors in addition to those discussed
elsewhere in this Form 10-Q and in the Company's other public filings,
press releases and discussions with Company management. Anadarko
undertakes no obligation to publicly update or revise any forward-
looking statements. See Additional Factors Affecting Business in the
Management's Discussion and Analysis of Financial Condition and Results
of Operations included in the Company's 1999 Annual Report on Form 10-K.

Overview of Operating Results

Anadarko's net income available to common stockholders in the third
quarter of 2000 totaled $245.7 million ($1.07 per share - basic).
Anadarko attributes its performance to continued growth in production
volumes and to strong commodity prices. Anadarko's results include the
effect of its acquisition of Union Pacific Resources Group Inc. (UPR),
which closed July 14, 2000. Net income includes a charge of $63.7
million ($40.8 million after taxes) for a portion of the costs
associated with the UPR acquisition. Excluding this item, Anadarko's
net income for the third quarter of 2000 was $286.5 million, or $1.24
per share (basic), on revenues of $956.1 million. For the same period
in 1999, Anadarko's net income was $18.8 million, or $0.15 per share
(basic), on revenues of $180.3 million.

For the nine-month period ending September 30, 2000, Anadarko's net
income available to common stockholders was $359.7 million, or $2.22
per share (basic), on $1.5 billion of revenues. Excluding the item
discussed above, Anadarko's net income available to common
stockholders for the first nine months of 2000 was $400.5 million, or
$2.47 per share (basic). By comparison, for the first nine months
of 1999, Anadarko had net income available to common stockholders of
$3.7 million, or $0.03 per share (basic) on revenues of $477.4
million. The 1999 results included a non-cash charge of $20 million

-22-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

before taxes ($12.8 million after taxes) related to the Company's
exploration activity in Eritrea. Excluding the impairment, net income
available to common stockholders for the first nine months of 1999 was
$16.5 million, or $0.13 per share (basic).

Costs and expenses during the third quarter of 2000 were $465.9
million, an increase of 284% compared to $121.2 million for the third
quarter of 1999. For the first nine months of 2000, costs and expenses
totaled $758.7 million, an increase of 108% compared to $365.5 million,
excluding the impairment, for the first nine months of 1999. The
increase for both periods in 2000 is primarily due to higher
depreciation, depletion and amortization expense, operating expenses
and other taxes all related to the increase in production volumes
associated with the acquisition, higher administrative and general
expenses associated with the Company's expanded workforce, a provision
for doubtful accounts of $23.3 million and amortization of goodwill
related to the merger of $11.3 million.

Merger expenses of $64 million were expensed in the third quarter of
2000 related to the UPR merger. These relate primarily to the
issuance of stock for retention of employees ($45 million), deferred
compensation ($8 million), transition, hiring and relocation costs ($6
million) and vesting of restricted stock and stock options ($5 million).

Interest expense for the third quarter of 2000 increased 56% to $27.9
million compared to $17.9 million for the third quarter of 1999. For
the first nine months of 2000, interest expense was $69.5 million, an
increase of 26% compared to $55.0 million for the same period of 1999.
The increases in interest expense in 2000 are primarily due to higher
levels of long-term debt in 2000 compared to 1999 as a result of the
UPR acquisition, partially offset by higher capitalized interest.

Volumes and Prices
During the third quarter of 2000, Anadarko produced approximately 39.8
million energy equivalent barrels, up 243% from the 11.6 million
barrels produced in the same period of 1999. During the first nine
months of 2000, Anadarko produced approximately 67.2 million energy
equivalent barrels, up 82% from the 36.8 million barrels produced in
the same period of 1999. The increased production comes as a result of
the acquisition of UPR, oil production growth in Algeria and gas
production growth in East Texas.

Natural Gas Natural gas production in the third quarter of 2000
averaged 1,498 million cubic feet (MMcf) per day, an increase of 229%
over the 456 MMcf per day produced in the same period last year.
Natural gas prices at the wellhead averaged $3.80 per thousand cubic
feet (Mcf) during the third quarter of 2000, compared with an average
of $2.40 per Mcf in the comparable quarter of 1999.

-23-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

The following table shows the Company's volumes and average prices for
the three and nine months ended September 30, 2000 and 1999:
Three Months Ended Nine Months Ended
September 30 September 30
2000 1999 2000 1999

Natural gas
United States
Bcf 115.9 41.9 209.0 127.9
MMcf/d 1,260 456 763 468
Price per Mcf $4.01 $2.40 $3.49 $1.97
Canada
Bcf 21.4 --- 21.4 ---
MMcf/d 232 --- 78 ---
Price per Mcf $2.74 --- $2.74 ---
Other International
Bcf 0.5 --- 0.5 ---
MMcf/d 6 --- 2 ---
Price per Mcf $1.10 --- $1.10 ---
Total
Bcf 137.8 41.9 230.9 127.9
MMcf/d 1,498 456 843 468
Price per Mcf $3.80 $2.40 $3.42 $1.97
Crude oil and condensate
United States
MBbls 4,966 1,967 8,715 6,458
MBbls/d 54 21 32 24
Price per barrel $30.65 $18.62 $28.42 $14.16
Algeria
MBbls 2,321 818 6,544 4,108
MBbls/d 25 9 24 15
Price per barrel $31.09 $20.99 $29.18 $14.97
Canada
MBbls 2,015 --- 2,015 ---
MBbls/d 22 --- 7 ---
Price per barrel $25.34 --- $25.34 ---
Other International
MBbls 3,509 --- 3,509 ---
MBbls/d 38 --- 13 ---
Price per barrel $19.10 --- $19.10 ---
Total
MBbls 12,811 2,785 20,783 10,566
MBbls/d 139 30 76 39
Price per barrel $26.73 $19.32 $26.79 $14.47
Natural gas liquids
United States
MBbls 3,845 1,787 7,765 4,949
MBbls/d 42 19 28 18
Price per barrel $21.13 $14.76 $20.77 $11.84
Canada
MBbls 145 --- 145 ---
MBbls/d 2 --- 1 ---
Price per barrel $22.55 --- $22.55 ---
Total
MBbls 3,990 1,787 7,910 4,949
MBbls/d 43 19 29 18
Price per barrel $21.18 $14.76 $20.81 $11.84
Total Energy Equivalent
Barrels (MMEEBs) 39.8 11.6 67.2 36.8

Bcf - billion cubic feet
MBbls - thousand barrels
MBbls/d - thousand barrels per day
Mcf - thousand cubic feet
MMcf/d - million cubic feet per day
MMEEBs - million energy equivalent barrels

-24-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

In the first nine months of 2000, Anadarko's natural gas production
averaged 843 MMcf per day, up 80% from the average of 468 MMcf per day
produced a year earlier. The wellhead price for natural gas in the
first nine months of 2000 averaged $3.42 per Mcf, compared with $1.97
per Mcf in the same period last year.

Crude Oil, Condensate and Natural Gas Liquids Total production of
crude oil and condensate in the third quarter averaged 139,000 barrels
per day, up 363% from 30,000 barrels per day in the third quarter of
1999. Oil prices in the third quarter of 2000 averaged $26.73 per
barrel, compared with $19.32 per barrel in the same quarter last year.

Anadarko's production of crude oil and condensate for the first nine
months of 2000 averaged 76,000 barrels per day, up 95% from the
average of 39,000 barrels per day in the comparable 1999 period.
Anadarko's average oil price for the 2000 period was $26.79 per
barrel, compared with $14.47 per barrel in the same period last year.

Volumes of NGLs during the quarter averaged 43,000 barrels per day, up
126% from 19,000 barrels per day in the third quarter of 1999. Prices
during the quarter for Anadarko's natural gas liquids (NGLs) averaged
$21.18 per barrel, compared with the $14.76 per barrel average in the
same quarter last year.

Anadarko's NGLs volumes during the first nine months of 2000 averaged
29,000 barrels per day, an increase of 61% over the 18,000 barrels per
day produced in the same period in 1999. The average price per barrel
for NGLs during the 2000 period was $20.81, compared with $11.84 a
year earlier.

Capital Expenditures, Liquidity and Dividends

During the first nine months of 2000, Anadarko's capital spending
(including capitalized interest and overhead) was $976.5 million
compared to $431.6 million in the same period of 1999.

As a result of the merger, the liabilities of UPR became liabilities of
the Company. Accordingly, the financial statements of the Company
include an aggregate of approximately $2.5 billion of outstanding UPR
debt assumed at the date of the merger.

-25-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

at a fixed conversion rate. Holders have the right to require Anadarko
to repurchase their Debentures at a specified price in March 2003, 2008
and 2013. The Debentures are redeemable at the option of Anadarko after
three years. The net proceeds from the offering were used to repay
floating interest rate debt.

In April 2000, the Company entered into a 364-Day Credit Agreement. The
aggregate amount of commitments is $300 million and expires in April
2001. In October 2000, the Company amended the UPR Competitive
Advance/Revolving Credit Agreement. This amendment reduced bank
commitments to $450 million, provided a Company guarantee and shortened
the maturity to October 2001.

Anadarko currently anticipates that the 2000 capital expenditures will
be about $1.6 billion. This amounts to a $484 million or 43% increase
over the combined total of Anadarko's previously announced 2000 capital
budget of $766 million and the $350 million remaining from the 2000
capital budget of UPR. Anadarko's capital spending will focus on
natural gas projects in East Texas and Louisiana, gas assets in western
Canada, and gas and oil projects on the shelf, sub-salt and deep water
properties in the Gulf of Mexico. Anadarko also will pursue selected
high potential exploration projects in North America and
internationally.

The Company believes that cash flows and existing or available credit
facilities will provide the majority of funds to meet its capital and
operating requirements for the remainder of 2000.

Exploration and Development Activities

During the third quarter of 2000, Anadarko participated in a total of
276 wells, including 91 oil wells, 163 gas wells and 22 dry holes.
This compares to a total of 52 wells, including 11 oil wells, 34 gas
wells and 7 dry holes during the third quarter of 1999.

For the first nine months of 2000, Anadarko participated in a total of
492 wells, including 170 oil wells, 292 gas wells and 30 dry holes.
This compares to a total of 136 wells, including 35 oil wells, 77 gas
wells and 24 dry holes during the first nine months of 1999. The
increase in activity during 2000 was directly related to the increase
in capital expenditures due to higher commodity prices. This increase
in activity has led to higher production volumes. Following is a
description of activity during the first nine months of 2000.

-26-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

Onshore - Lower 48 States

Bossier Sand Play
Development - The rig count in Anadarko's most active drilling area
increased by two during the third quarter, bringing the total number of
rigs operating in the Bossier Sand to 28 (24 in East Texas and four in
northwest Louisiana). During the first nine months of 2000, Anadarko
completed 105 wells in the Bossier. The Company now has 265 wells that
produced an average of 234 MMcf/d of gas (gross) and 178 MMcf/d of gas
(net) in the third quarter.

One completion during the third quarter was the Edwards A-4 well in the
Dew/Mimms Creek Field, which tested 30.2 MMcf/d of gas from the Bonner
Sand. Another well completed in the third quarter was the Thigpen A-2
well in the Dew/Mimms Creek Field of Freestone County, Texas. The well,
which tested more than 17 MMcf/d of gas from the Moore and Bonner
sands, steps out more than 1.5 miles from Anadarko's best producer in
the play so far. The results from the third quarter also included the
Adams A-2 well in the Dew Field, which tested 23.4 MMcf/d of gas.

During the third quarter, Anadarko increased its leasehold position,
which now covers approximately 200,000 acres, 75% of which is
undeveloped. At current activity levels, the Company has a two-year
infill and development inventory.

The Company's gas gathering capabilities were enhanced during the third
quarter with the August 1 start-up of operations at the Buffalo Central
Gathering Facility (CGF). The Buffalo facility and the Goode Ranch CGF,
which Anadarko began building in the third quarter, are designed for
separation and dehydration of gas. Altogether, Anadarko's gas gathering
network has more than 10,000 horsepower of compression - capable of
processing 350 MMcf/d of gas - and more than 100 miles of pipeline.

Exploration - In the process of extending its Bossier discoveries,
Anadarko continues to uncover new exploration opportunities. So far in
2000, the Company has drilled seven exploration wells, five of which
are discoveries. The other two wells are currently being drilled. In
fact, the Bossier Play actually consists of six separate fields and the
Company is developing other pay zones in addition to the Bossier Sand
formation.

South Louisiana During the third quarter, the fourth well was spud
in the Kent Bayou Field of Terrebonne Parish, Louisiana, to further
delineate the discovery. In addition, the Continental Land and Fur Co.
No. 3 well was completed with estimated initial production of 6,000
barrels of oil per day (BOPD) and 22 MMcf/d of gas, following the

-27-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

installation of processing equipment. Volumes from the two wells
currently producing are 2,400 BOPD and 10 MMcf/d of gas. Anadarko is
currently upgrading facilities by adding compression, separators and a
new oil sales pipeline that should increase production significantly by
the end of November 2000. Anadarko owns a 66.7% working interest in the
Kent Bayou Field, which was discovered in 1999.

The Company's ongoing horizontal drilling program in the Austin Chalk
resulted in two significant completions in south Louisiana during the
third quarter. The Exxon Minerals A-1 RE well tested 480 BOPD and 2.5
MMcf/d of gas after re-entering the Chalk and being drilled laterally
for a distance of 3,500 feet. Anadarko owns a 78% working interest in
the well which is located in the Masters Creek Field in Rapides
Parish, Louisiana. In Vernon Parish, Louisiana, the Company completed
the Strickland 17 No. 1 RE, which was drilled using stacked horizontal
laterals. The re-entry, which covered 3,500 feet in the Chalk A and
3,200 feet in the Chalk B, tested 644 BOPD and 2.1 MMcf/d of gas.
Anadarko has a 100% working interest in the well, which is located in
the Masters Creek Field.

Hugoton Embayment During the third quarter, Anadarko stepped up
drilling programs in southwest Kansas. The goal is to offset declines
in production from the older Hugoton Field with new production from
deeper zones from the area. The Bush B-3 well in the Evalyn Field of
Seward County, Kansas, was re-completed to the Marmaton "C" interval.
The well is flowing 353 BOPD and 276 thousand cubic feet per day of
gas through a 25/64-inch choke. In Stevens County, Kansas, Anadarko
completed a well as a lower Morrow producer. The HJV Christopher A-1
well flowed 10.5 MMcf/d of gas and 45 barrels of condensate per day.
The Company owns a 100% working interest in the well. Anadarko also re-
completed the Adams L-3 well in the Eubank Field of Haskell County,
Kansas, which tested 149 BOPD from the Morrow Lime formation. The
Company has a 100% working interest in the well. Also in the Eubank
Field, Anadarko completed a four-well deep drilling program resulting
in combined gross production of 258 BOPD and 1.3 MMcf/d of gas from
seven different intervals. In the Lorena East Field of Texas County,
Oklahoma, Anadarko completed the Murphy Trust A-1 well. The well
produced 300 BOPD from the Basal Chester formation. Anadarko owns a
64% working interest in the well.

Texas Panhandle Another five wells were completed in the West
Panhandle Field of Moore County, Texas, as the Company continued with
its infill drilling program targeting the shallow Red Cave formation.
Seven wells were placed on production during the third quarter at a
combined initial rate of 5.5 MMcf/d of gas (gross). So far in 2000,
Anadarko has drilled 29 successful Red Cave wells, which have added
8.0 MMcf/d of gas (gross) to the Company's production volumes.
Anadarko owns a 100% working interest in these 2,300-foot low-cost gas
wells.

-28-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

Permian Basin The Company's waterflood program in the Snyder Field
of Howard County, Texas, continued at a brisk pace during the third
quarter. Individual well results were highlighted by the B.S. TXL "D"
No. 3335, No. 3336 and No. 3320, which tested at a combined rate of
181 BOPD (gross) from the San Angelo/Clearfork formation. The Susie B.
Snyder No. 2012 well tested 59 BOPD (gross), while the Susie B. Snyder
"C" No. 2819 well produced 101 BOPD (gross). Both wells were completed
in the San Angelo formation. The Susie B. Snyder No. 2010 was
completed in the San Angelo/Clearfork formation and tested 144 BOPD
(gross). Anadarko has a 100% working interest in each of these wells.

Activity was strong in the Revilo Field of Scurry County, Texas,
during the third quarter, with four completions. The P.P. Boyles No.
16 well and the M.M. Boyd No. 8 tested at a combined rate of 149 BOPD
(gross). The Company has a 100% working interest in these
Wichita/Albany producers. The M.M. Boyd No. 7 produced 49 BOPD (gross)
after being completed in the San Angelo formation. The Iona Williamson
No. 10 well was completed in the Glorieta and Clearfork formations and
tested 57 BOPD (gross). The Company has a 100% working interest in
both of these wells.

A nine-well development drilling program in the North Shugart Field of
Eddy County, New Mexico was concluded in the third quarter. As a
result of the initiative, gross production from the Bone Spring
formation increased to 959 BOPD and 1.5 MMcf/d of gas, up from 40 BOPD
and 90 Mcf/d of gas prior to the program.

Two completions from the third quarter included the Paton "B" No. 3
Federal well which tested 62 BOPD (gross) from the Grayburg formation
and the Baish Federal No. 11, that produced 90 BOPD (gross) from the
Bone Spring formation. Anadarko owns a 100% working interest in each
well.

In the Ozona Field, of Crockett County, Texas, activity continued at a
steady pace highlighted by development drilling in the Canyon Sand and
Strawn intervals. During the third quarter Anadarko completed 11
development wells which produced 2.5 MMcf/d of gas (gross). Year-to-
date, 40 wells have been completed in the Ozona Field, adding 7 MMcf/d
of gas (gross).

Rocky Mountains The 2000 coal-bed methane drilling program in Utah
began in the third quarter. Using two rigs, the Company has drilled 31
successful wells, with another 22 wells planned for the fourth
quarter. The majority of production from these wells initially will be
water, with gas volumes ramping up through 2001.

-29-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

In the Helper Field of Carbon County, Utah - the focal point of
Anadarko's coal-bed methane program - construction to expand the
existing central production facility (CPF) was initiated and is
expected to be completed in the fourth quarter of 2000. Currently
processing 23 MMcf/d of gas (gross), the CPF is at full capacity. The
expansion project will increase its capabilities to 33 MMcf/d of gas.
Construction also began on a new CPF, an electrical distribution
system and a pipeline network for the Clawson Spring Field in Carbon
and Emery Counties, Utah. This project is also expected to be
completed in the fourth quarter.

The pace of drilling in the greater Wamsutter area in Wyoming
increased in the third quarter as a result of government approval of
the Continental Divide/Wamsutter II Environmental Impact Study. A
total of 49 wells have been drilled as part of a four-rig drilling
program in the area, which will continue through 2000. Anadarko has an
average 25% working interest in these wells. In addition, Anadarko
expects to have two Company-operated rigs running during the fourth
quarter that will be focused on development drilling. One will be
dedicated to an infill project in the Wamsutter Field and the other to
a drilling project in the Brady Field.

In the overthrust belt of western Wyoming, activity was highlighted by
the completion of the Kewanee Federal 1A well. This horizontal re-
entry in the Madison formation tested at rates as high as 52 MMcf/d of
gas which will flow to the Whitney Canyon plant. Anadarko owns a 12.6%
working interest in the well and a 19% working interest in the Whitney
Canyon plant.

Golden Trend Anadarko launched a 19-well drilling program in the
third quarter to develop oil reserves in the Northeast Purdy Springer
Unit (NEPSU). The initiative will focus on CO2 flood infill drilling
in the NEPSU. There were two active rigs in operation at the end of
the third quarter, and the Company expects to have three rigs active
in the fourth quarter.

Carthage During the third quarter, Anadarko completed 12 wells in
the Carthage area of East Texas, which added 11 MMcf/d of gas (gross)
to the Company's production volumes. Four rigs are currently operating
in the play, developing tight gas sands in the Cotton Valley interval.
The Sandbar prospect, an exploratory well targeting the deeper Bossier
formation, was also spud in the third quarter.

Net volumes from the more than 900 wells currently producing in the
four areas comprising the Carthage Field are about 100 MMcf/d of gas
and about 5,000 barrels of oil and NGLs per day.

-30-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

Central Texas Continued development of the Buda and Austin Chalk
formations is the primary focus of Anadarko's efforts in central
Texas. Using six rigs, the Company completed 16 wells in the third
quarter, which added incremental production of 38.1 MMcf/d of gas and
6,100 BOPD. Particularly noteworthy was the Becker No. 1 RE well in
the Navasota River Field of Washington County, Texas which is
producing 22.3 MMcf/d of gas. Anadarko has a 100% working interest in
the well. Current net volumes from Anadarko's nearly 1,200 producing
wells in central Texas are 190 MMcf/d of gas and 13,935 BOPD.

Re-entering producing intervals through the use of horizontal drilling
is a major component of Anadarko's Austin Chalk program. A total of 11
workover rigs were also in operation during the third quarter,
conducting fracture stimulation operations that increased the Company's
production volumes.

Offshore - Gulf of Mexico

Anadarko was the apparent high bidder on 17 of 18 blocks on which the
Company bid in the Federal OCS Lease Sale No. 177 conducted by the
Minerals Management Service on August 23, 2000. Six of the blocks are
in the Mustang Island area offshore Texas, where water depths run as
shallow as 250 feet. The rest are deepwater blocks located in the East
Breaks and Garden Banks areas in water depths up to 4,000 feet. Three
of the blocks surround Anadarko's LaSalle deepwater prospect, which is
expected to be drilled in December 2000 or January 2001. The Company
invested $4.7 million to acquire the lease acreage and holds a 100%
working interest in 15 of the blocks and a 50% working interest in the
other two blocks. To date, Anadarko has officially been awarded 15 of
the 17 blocks for which it was the apparent high bidder.

Sub-salt Installation of the production facilities to develop the
Tanzanite (Eugene Island 346) and Hickory (Grand Isle 110/111/116)
Fields 80 miles off the coast of Louisiana was completed during the
third quarter. Both procedures were completed during a three-week
period in late August and early September. The Tanzanite platform,
located in 314 feet of water, is designed with six drilling slots and
will have the capacity to produce 200 MMcf/d of gas and 15,000 BOPD.
The Hickory platform, located in 320 feet of water, will be capable of
producing 300 MMcf/d of gas and 15,000 BOPD through eight drilling
slots. Anadarko has a 100% working interest in Tanzanite and has a 50%
working interest in Hickory. Initial production from both fields is
expected during the fourth quarter of 2000.

In the Hickory Field during the third quarter, Anadarko also spudded
the Grand Isle 111 well No. 1, which is testing a separate fault block
adjacent to the original discovery well (Grand Isle 116 No. 1). Also
known as the North Hickory prospect, the well is currently being
sidetracked to the top of the Hickory structural closure.

-31-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

At the Mahogany production platform (Ship Shoal 349/359), Anadarko
spudded the A-9 exploratory well during the third quarter. The well is
targeting natural gas in the deeper "T" sand interval below the main
"P" sand pay zone which produces oil. At the end of October the A-9
well was drilling at 11,364 feet.

Deepwater A third sidetrack well to the Green Canyon 608 No. 1 well
was drilled during the third quarter, as delineation of the Marco Polo
discovery continued. Drilling is also underway on the Green Canyon 608
No. 2 well, which is designed to test for additional pay intervals in a
separate fault block. The Company owns a 100% working interest in the
Marco Polo prospect. Elsewhere in the deepwater, the Company spudded
the Mississippi Canyon 711 No. 5 well as part of an effort to determine
the extent of the Gomez discovery.

Conventional At the Matagorda Island 622/623 complex, the largest
gas field offshore Texas, the operator completed the D-3 well during
the third quarter as part of an ongoing program to increase natural gas
volumes. The well was brought on-line at a rate of 35 MMcf/d of gas. In
addition, production from the C-8 well, which began drilling in the
second quarter, commenced in the third quarter. A procedure to install
larger 5-1/2 inch tubing during the third quarter also helped
accelerate production. Gross volumes from the field at the end of the
third quarter were more than 200 MMcf/d of gas. The Company has a
37.5% working interest in the complex.

The South Marsh Island Block 269 No. 7 STDK #1 well was drilled during
the third quarter and encountered 60 feet of pay. Completion efforts
are currently underway with initial production expected to be 25 MMcf/d
of gas (gross). Anadarko owns a 55% working interest in the well and
serves as operator.

During the third quarter, the second well was spud at Ship Shoal Block
296. The well encountered two pay sands totaling 60 feet after being
drilled to a depth of 10,345 feet. The No. 2 well is awaiting the
fabrication and installation of production facilities. Flow rates are
estimated at 25-40 MMcf/d of gas. The No. 1 well, which was spud during
the second quarter, logged 75 feet of pay. Anadarko owns a 35% working
interest in the field.

In the third quarter, Anadarko had a discovery at Ship Shoal Block 207.
The A-35 well encountered more than 100 feet of net gas pay in four
zones. Production is expected to commence in November 2000 at an
initial rate of 15 MMcf/d of gas. Anadarko serves as operator of the
well and has a 53% working interest.

-32-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

Alaska

Development facilities at the Alpine Field on the North Slope are
nearly complete, with first production on schedule to begin later in
the fourth quarter of 2000. Anadarko expects volumes to average 80,000
BOPD (gross) in 2001.

During the third quarter, Anadarko sold a 33.33% working interest in
its North Slope acreage held under exclusive lease option to AEC Oil &
Gas (USA) Inc., a wholly owned subsidiary of Alberta Energy Company
Limited. The lease covers 3.1 million acres under option from the
Arctic Slope Regional Corporation in the Foothills region south of
Prudhoe Bay. Anadarko is operator, with a 66.67% working interest. The
transaction complements Anadarko's purchase of MacKenzie Delta Basin
acreage in Canada's Northwest Territories (see below for details).

International

Canada In August 2000, Anadarko purchased a 37.5% working interest
in two exploration licenses covering 530,000 acres in the MacKenzie
Delta region from Alberta Energy Company Ltd. (AEC) of Calgary.
Increasing Canadian holdings in the MacKenzie Delta fits Anadarko's
long-term strategy of providing natural gas to North American markets.
The transaction involves two onshore blocks adjacent to the gas-rich
Parsons Lake Field. The purchase complements Anadarko's MacKenzie
Delta/Beaufort Sea holdings, which consist of non-operated working
interests that range from 3% to 24% in 11 significant discovery
licenses and one production license. Combined, the properties cover
more than 142,000 gross acres and include the Amauligak Field, the
largest offshore field in the Canadian portion of the Beaufort Sea.

In another development, Anadarko submitted a successful bid for an
exploration license on one of the MacKenzie Delta/Beaufort Sea tracts
offered in the August 14, 2000 lease sale by the Minister of Indian
Affairs and Northern Development. The Company acquired a 100% working
interest in Exploration License No. 407, which is centrally located in
a region where 53 fields with reserves of 9 trillion cubic feet of gas
and 1 billion barrels of oil have already been discovered (source:
National Energy Board). Exploration License 407 covers about 176,000
acres and is immediately northwest of the giant Taglu Field.

During the first nine months of 2000, 254 wells were completed in the
shallow gas Hatton play of southwest Saskatchewan, adding production of
16 MMcf/d of gas (net). The Hatton Field is currently producing 72.8
MMcf/d of gas (net) with the Company's working interest in these wells
averaging about 85%. Anadarko has a two-year inventory of 610 shallow
gas wells.

-33-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

Combined production from the various heavy oil programs underway in
Eastern Alberta is currently about 16,000 BOPD. In the Kehewin/Moose
Hills areas, the primary area of focus, 112 wells have been drilled
year to date with cumulative incremental production of more than
700,000 barrels or nearly 2,700 BOPD. Using 2-D seismic data, Anadarko
has located new productive channels on 50,000 acres acquired last year,
with additional drilling planned for this year. A 130 square-mile 3-D
seismic acquisition program is planned for later in the 2000-2001
winter season. Overall, Anadarko projects more than 1,000 drilling
locations in its inventory for this very economic play.

Production at the Klua Field in British Columbia has been expanded by
10 MMcf/d of gas, with volumes currently running at 28 MMcf/d of gas
(gross). Another 50 drilling locations have been identified in various
plays throughout British Columbia where Anadarko will have nine rigs
active during the 2000-2001 winter season.

Algeria During the third quarter, Anadarko and partners awarded the
Engineering Procurement and Construction (EPC) contract to build a
central production facility to develop the Ourhoud Field. The new
facilities, which are being built by a joint venture group composed of
JGC Corporation of Japan and Initec of Spain, will have a capacity of
230,000 BOPD (gross) when completed. First production is expected in
late 2002. The EPC contract calls for the construction of three oil
processing units, along with water injection and gas processing and
injection facilities, a field gathering system and crude oil storage
and shipping installations.

In addition, the Company and its partners signed an addendum to the EPC
contract with Brown and Root Condor for development of the satellite
fields (HBNSE, RBK, QBN and BKNE) adjacent to the Hassi Berkine South
(HBNS) Field. The contract includes construction of a third production
train under Anadarko's Stage II development program that will increase
gross plant capacity by an additional 75,000 BOPD in the second half of
2002.

Highlights from Anadarko's drilling program in the third quarter
included a number of significant wells. The HBN-5 well, located in the
southern portion of the Hassi Berkine (HBN) Field, encountered 38 feet
of net pay in the TAGI reservoir and was completed as an oil producer.
The well tested 4,623 BOPD and 4.1 MMcf/d of gas. The HBN-6 well,
located in the northern area of the HBN Field, was completed as an oil
producer in September. The well encountered nearly 72 feet of net pay
in the main TAGI reservoir. The QB-12 well in the north central portion
of the Ourhoud Field encountered 112 feet of net pay and was suspended
as a planned oil producer.

-34-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

Latin America In Venezuela, during the third quarter, three
successful wells were drilled in the Oritupano Leona Field. The Orm-
144, Orm-145 and Orm-146 wells are being completed in the Oficina
formation. Anadarko has a 45% working interest in this field. Third
quarter drilling activity brings the number of wells drilled to date in
2000 to 22 wells of a planned 28 wells for the year. Daily production
has increased to 45,000 BOPD (gross) (20,000 BOPD net to Anadarko), up
from 40,000 BOPD (gross) (18,000 BOPD net) at the beginning of the
year.

In Guatemala, an 11,500 foot exploration well is presently drilling on
La Sabana No. 1. Anadarko operates all of its activities in Guatemala
with a 100% interest.

West Africa In the third quarter, Anadarko entered into a farmout
agreement for three exploration blocks off the coast of West Africa.
Anadarko will serve as operator and holds a 50% interest in the Agali
Block offshore Gabon and will also operate the Marine IX Block
offshore the Republic of Congo with a 37.5% interest. On the Keta
Block in Ghana, a shelf-edge exploration well is expected to be
drilled later this year in which Anadarko has a 50% interest. A
deepwater 3-D seismic survey is planned for the Agali Block early in
2001 to evaluate prospective areas identified on a recent 2-D survey.
A deepwater exploration well is planned for the Marine IX Block in
2001.

North Atlantic Margin Anadarko acquired two blocks in the most
recent licensing round in the Faroe Islands and is currently
evaluating its options which could include exploratory drilling to
chase the play northward.

New Accounting Principles

Accounting for Derivatives Statement of Financial Accounting
Standards (SFAS) No. 133, "Accounting for Derivative Instruments and
for Hedging Activities", as amended, provides guidance for accounting
for derivative instruments and hedging activities. SFAS No. 133, as
amended, is effective for fiscal years beginning after June 15, 2000.
The Company is evaluating the impact of the provisions of SFAS No. 133
and believes it will not have a material effect on the Company's
financial condition or results of operations.

-35-

Item 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations (continued)

document to address significant implementation issues related to SAB
No. 101. To the extent that SAB No. 101 ultimately changes Anadarko's
revenue recognition practices, Anadarko will be required to adopt SAB
No. 101 no later than the quarter beginning October 1, 2000, with any
cumulative effect adjustment computed as of January 1, 2000.

-36-

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Use of Derivatives Anadarko produces, purchases and sells natural
gas, crude oil and NGLs. As a result, Anadarko's financial results can
be significantly affected by changes in these commodity prices.
Anadarko uses derivative commodity instruments to hedge the Company's
exposure to changes in the market price of natural gas and crude oil,
and to provide methods to fix the price for natural gas independently
of the physical purchase or sale. Derivative commodity instruments
also provide methods to meet customer pricing requirements while
achieving a price structure consistent with the Company's overall
pricing strategy. While derivative commodity instruments are intended
to reduce the Company's exposure to declines in the market price of
natural gas and crude oil, the derivative commodity instruments may
also limit Anadarko's gain from increases in the market price of
natural gas and crude oil. As a result, gains and losses on derivative
commodity instruments are generally offset by similar changes in the
realized price of natural gas and crude oil. Gains and losses are
recognized in revenues for the periods to which the derivative
commodity instruments relate. In the event of a loss of correlation
between oil and gas reference prices for a derivative commodity
instrument and actual oil and gas prices, gains or losses for the
amount the instrument has not offset the change in actual prices are
recognized in the period.

Occasionally, the Company may enter into derivative commodity
instruments for trading purposes with the objective of generating
profits on or from exposure to shifts or changes in the market price
of natural gas and crude oil. These trading activities do not qualify
as hedges of production and are marked to market in the period.
Trading gains or losses are recorded with revenues from the
corresponding product. Anadarko's derivative commodity instruments
currently are comprised of futures, swaps and options contracts.

The volume of derivative commodity instruments utilized by the Company
to hedge its market price risk can vary during the year within the
boundaries of its established policy guidelines. Through the use of
sensitivity analysis the Company evaluates separately, for its non-
trading and trading activities, the potential effect that reasonably
possible near term changes in the market prices of natural gas and
crude oil prices may have on the cash flows from the Company's
derivative commodity instruments. Based on an analysis utilizing the
actual derivative contractual volumes and assuming a 10% adverse
movement in commodity prices, the potential decrease in the fair value
of the derivative commodity instruments at September 30, 2000 and
December 31, 1999 does not have a material adverse effect on the
financial position or results of operations of the Company.

-37-

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Anadarko is also exposed to risk resulting from changes in interest
rates as a result of the Company's variable and fixed interest rate
debt as well as fixed to floating interest rate swaps. The Company has
evaluated the potential effect that reasonably possible near term
changes in interest rates may have on the fair value of the Company's
various debt instruments and its interest rate swap agreements. Based
upon an analysis, utilizing the actual interest rates in effect as of
September 30, 2000 and December 31, 1999 and assuming a 10% increase in
interest rates, the potential decrease in the fair value of the
derivative interest swap instruments at September 30, 2000 and December
31, 1999 does not have a material effect on the financial position or
results of operations of the Company.

Foreign Currency Risk At September 30, 2000, the Company's Canadian
subsidiary had $650 million outstanding of fixed-rate notes and
debentures denominated in U.S. dollars. For the third quarter and nine
month period of 2000, the Company recognized an $11 million pretax non-
cash loss associated with the remeasurement of this debt. The
potential foreign currency remeasurement impact on earnings from a 5%
change in the September 30, 2000 Canadian exchange rate would be about
$37 million.

The Company periodically enters into foreign currency contracts to
hedge specific currency exposures from commercial transactions. The
following table summarizes the Company's open foreign currency
positions at September 30, 2000:

Maturity Year
millions, except rates 2000 2004 Total

Notional amount $ 18.0 $ 70.0 $88.0

Forward rate 1.4719 1.3629
Market rate 1.5051 1.4714
Decrease in rate (0.0332) (0.1085)

Fair value - gain (loss) $ (0.6) $ (7.6) $(8.2)

-38-

Part II. OTHER INFORMATION

Item 1. Legal Proceedings

See Note 11 of the Notes to Consolidated Financial Statements under
Part I. Financial Information of this Form 10-Q.

Item 4. Submissions of Matters to a Vote of Security Holders

On July 13, 2000, in a special meeting held in Houston, Texas, the
stockholders of Anadarko approved the merger transaction with Union
Pacific Resources Group, Inc. and other related matters. Following are
the voting results:

(a) Approval of the issuance of Anadarko common shares pursuant to the
proposed merger.

106,804,068 votes for, 197,990 votes against, 133,433 shares
abstained and 7,872,462 shares not voted.

(b) Approval of the Amendment to the Restated Certificate of
Incorporation to increase the maximum size of the Board of
Directors from nine to 15 directors.

114,305,164 votes for, 562,268 votes against and 140,521 shares
abstained.

(c) Approval of the Amendment to the Restated Certificate of
Incorporation to increase the authorized number of Anadarko common
shares from 300,000,000 to 450,000,000.

113,838,085 votes for, 1,021,147 votes against and 148,721 shares
abstained.

(d) Approval of the Amendment to the 1999 Stock Incentive Plan.

92,492,810 votes for, 14,369,547 votes against, 279,814 shares
abstained and 7,865,782 shares not voted.

-39-

Item 6. Exhibits and Reports on Form 8-K

(a) Exhibits

Exhibits not incorporated by reference to a prior filing are
designated by an asterisk (*) and are filed herewith; all exhibits
not so designated are incorporated herein by reference to a prior
filing as indicated.

Exhibit Original Filed File
Number Description Exhibit Number

2(a) Agreement and Plan of Merger 2.1 to Form 8-K dated 1-8968
dated as of April 2, 2000, April 2, 2000
among Anadarko, Subcorp and
UPR

(b) Amendment No. 1 to Rights 2.4 to Form 8-K dated 1-8968
Agreement, dated as of April 2, 2000
April 2, 2000 between
Anadarko and Rights Agent

3(a) Restated Certificate of 19(a)(i) to Form 10-Q 1-8968
Incorporation of Anadarko for quarter ended
Petroleum Corporation, September 30, 1986
dated August 28, 1986

(b) Amendment to the Restated 3(b) to Form 10-Q 1-8968
Certificate of Incorporation for quarter ended
of Anadarko Petroleum March 31, 1999
Corporation, dated
April 29, 1999

(c) Certificate of Correction 3(c) to Form 10-Q 1-8968
filed to correct the for quarter ended
Amendment to the Restated June 30, 1999
Certificate of Incorporation
of Anadarko Petroleum
Corporation, dated
June 15, 1999

(d) Certificate of Amendment of 4.1 to Form 8-K dated 1-8968
Anadarko's Restated July 28, 2000
Certificate of Incorporation

* (e) By-laws of Anadarko
Petroleum Corporation,
as amended

4(a) 364-Day Credit Agreement, 4(a) to Form 10-Q 1-8968
Dated as of April 14, 2000 for quarter ended
March 31, 2000

-40-

Item 6. Exhibits and Reports on Form 8-K (continued)

Exhibit Original Filed File
Number Description Exhibit Number

*4(b) Amended and Restated
Competitive Advance/
Revolving Credit Agreement,
Dated as of October 25, 2000

*10(a) Employment Agreement

* (b) First Amendment to Andadarko
Petroleum Corporation Key
Employee Change of Control
Contract

*12 Computation of Ratios of
Earnings to Fixed Charges
and Earnings to Combined
Fixed Charges and Preferred
Stock Dividends

*27 Financial Data Schedule

(b) Reports on Form 8-K

A report on Form 8-K dated July 28, 2000 was filed in which the
earliest event reported was July 14, 2000. This event was
reported under Item 2, "Acquisition or Disposition of Assets",
Item 5, "Other Events", and Item 7 "Financial Statements, Pro
Forma Financial Information and Exhibits".

-41-

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 duly authorized officer and principal
financial officer.

ANADARKO PETROLEUM CORPORATION
(Registrant)

November 10, 2000 By: [MICHAEL E. ROSE]
Michael E. Rose - Executive Vice President,
Finance and Chief Financial Officer