e10vq
Table of Contents

 
 
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
     
þ   QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly Period Ended March 31, 2006
OR
     
o   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 1-4300
APACHE CORPORATION
(Exact Name of Registrant as Specified in Its Charter)
     
Delaware   41-0747868
     
(State or Other Jurisdiction of   (I.R.S. Employer
Incorporation or Organization)   Identification Number)
     
Suite 100, One Post Oak Central    
2000 Post Oak Boulevard, Houston, TX   77056-4400
     
(Address of Principal Executive Offices)   (Zip Code)
Registrant’s Telephone Number, Including Area Code: (713) 296-6000
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 þ NO o
Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act).
YES þ NO o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):
Large accelerated filer þ      Accelerated filer o      Non-accelerated filer o
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ
Number of shares of Registrant’s common stock, outstanding as of March 31, 2006                                           330,338,839
 
 

 


TABLE OF CONTENTS

PART I FINANCIAL INFORMATION
ITEM 1 FINANCIAL STATEMENTS
ITEM 2 MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
ITEM 3 QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 4 CONTROLS AND PROCEDURES
PART II OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
ITEM 2. CHANGES IN SECURITIES, USE OF PROCEEDS AND ISSUER PURCHASES OF EQUITY SECURITIES
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
ITEM 5. OTHER INFORMATION
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
SIGNATURES
EXHIBIT INDEX
401(k) Savings Plan
Money Purchase Retirement Plan
Statement of computation of ratio of earnings to fixed charges
Certification of CEO
Certification of CFO
Certification of CEO and CFO


Table of Contents

PART I – FINANCIAL INFORMATION
ITEM 1 – FINANCIAL STATEMENTS
APACHE CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED OPERATIONS
(Unaudited)
                 
    For the Quarter Ended March 31,  
    2006     2005  
    (In thousands, except per common share data)  
REVENUES AND OTHER:
               
Oil and gas production revenues
  $ 1,950,298     $ 1,626,649  
Other
    48,804       35,639  
 
           
 
    1,999,102       1,662,288  
 
           
OPERATING EXPENSES:
               
Depreciation, depletion and amortization
    372,577       339,413  
Asset retirement obligation accretion
    20,645       13,159  
Lease operating costs
    291,614       233,171  
Gathering and transportation costs
    26,104       23,780  
Severance and other taxes
    146,414       72,186  
General and administrative
    45,672       50,411  
Financing costs:
               
Interest expense
    42,863       45,266  
Amortization of deferred loan costs
    508       658  
Capitalized interest
    (14,193 )     (13,409 )
Interest income
    (6,364 )     (927 )
 
           
 
    925,840       763,708  
 
           
INCOME BEFORE INCOME TAXES
    1,073,262       898,580  
Provision for income taxes
    412,341       338,097  
 
           
NET INCOME
    660,921       560,483  
Preferred stock dividends
    1,420       1,420  
 
           
INCOME ATTRIBUTABLE TO COMMON STOCK
  $ 659,501     $ 559,063  
 
           
NET INCOME PER COMMON SHARE:
               
Basic
  $ 2.00     $ 1.70  
 
           
Diluted
  $ 1.97     $ 1.67  
 
           
The accompanying notes to consolidated financial statements
are an integral part of this statement.

1


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED CASH FLOWS
(Unaudited)
                 
    For the Quarter Ended  
    March 31,  
    2006     2005  
    (In thousands)  
CASH FLOWS FROM OPERATING ACTIVITIES:
               
Net income
  $ 660,921     $ 560,483  
Adjustments to reconcile net income to net cash provided by operating activities:
               
Depreciation, depletion and amortization
    372,577       339,413  
Asset retirement obligation accretion
    20,645       13,159  
Provision for deferred income taxes
    160,672       98,187  
Other
    9,385       11,826  
Changes in operating assets and liabilities:
               
(Increase) decrease in receivables
    22,257       (177,175 )
(Increase) decrease in drilling advances and other
    108,789       (17,410 )
(Increase) decrease in inventories
    (4,132 )     4,697  
(Increase) decrease in deferred charges and other
    (16,664 )     (7,665 )
Increase (decrease) in accounts payable
    (40,217 )     6,952  
Increase (decrease) in accrued expenses
    (226,350 )     19,908  
Increase (decrease) in advances from gas purchasers
    (6,368 )     (5,692 )
Increase (decrease) in deferred credits and noncurrent liabilities
    (18,231 )     (10,511 )
 
           
Net cash provided by operating activities
    1,043,284       836,172  
 
           
CASH FLOWS FROM INVESTING ACTIVITIES:
               
Additions to property and equipment
    (1,012,039 )     (790,350 )
Acquisition of Amerada Hess properties
    (230,080 )      
Proceeds from sale of Egyptian properties
    409,197        
Other, net
    (53,582 )     32,448  
 
           
Net cash used in investing activities
    (886,504 )     (757,902 )
 
           
CASH FLOWS FROM FINANCING ACTIVITIES:
               
Debt borrowings
    158,273       6,862  
Payments on debt
    (3,800 )     (63,530 )
Dividends paid
    (34,433 )     (27,631 )
Common stock activity
    3,238       7,771  
Treasury stock activity, net
    936       (2,085 )
Cost of debt and equity transactions
    (182 )     (78 )
Other
    (5,657 )     10,679  
 
           
Net cash provided by/(used in) financing activities
    118,375       (68,012 )
 
           
NET INCREASE/(DECREASE) IN CASH AND CASH EQUIVALENTS
    275,155       10,258  
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
    228,860       111,093  
 
           
CASH AND CASH EQUIVALENTS AT END OF PERIOD
  $ 504,015     $ 121,351  
 
           
The accompanying notes to consolidated financial statements
are an integral part of this statement.

2


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)
                 
    March 31,     December 31,  
    2006     2005  
    (In thousands)  
ASSETS
               
 
               
CURRENT ASSETS:
               
Cash and cash equivalents
  $ 504,015     $ 228,860  
Receivables, net of allowance
    1,446,970       1,444,545  
Inventories
    226,761       209,670  
Drilling advances
    111,936       146,047  
Prepaid assets and other
    67,592       132,955  
 
           
 
    2,357,274       2,162,077  
 
           
 
               
PROPERTY AND EQUIPMENT:
               
Oil and gas, on the basis of full cost accounting:
               
Proved properties
    24,552,532       23,836,789  
Unproved properties and properties under development, not being amortized
    870,520       795,706  
Gas gathering, transmission and processing facilities
    1,451,849       1,359,477  
Other
    327,030       312,970  
 
           
 
    27,201,931       26,304,942  
Less: Accumulated depreciation, depletion and amortization
    (9,885,404 )     (9,513,602 )
 
           
 
    17,316,527       16,791,340  
 
           
OTHER ASSETS:
               
Goodwill, net
    189,252       189,252  
Deferred charges and other
    136,050       129,127  
 
           
 
  $ 19,999,103     $ 19,271,796  
 
           
The accompanying notes to consolidated financial statements
are an integral part of this statement.

3


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)
                 
    March 31,     December 31,  
    2006     2005  
    (In thousands)  
LIABILITIES AND SHAREHOLDERS’ EQUITY
               
 
               
CURRENT LIABILITIES:
               
Accounts payable
  $ 669,371     $ 714,598  
Accrued operating expense
    59,216       66,609  
Accrued exploration and development
    499,081       460,203  
Accrued compensation and benefits
    94,765       125,022  
Accrued interest
    45,706       32,564  
Accrued income taxes
    53,824       120,153  
Current debt
    157,574       274  
Asset retirement obligation
    160,163       93,557  
Derivative instruments
    204,597       256,115  
Other
    191,327       317,469  
 
           
 
    2,135,624       2,186,564  
 
           
LONG-TERM DEBT
    2,189,126       2,191,954  
 
           
 
               
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
               
Income taxes
    2,778,909       2,580,629  
Advances from gas purchasers
    62,400       68,768  
Asset retirement obligation
    1,315,658       1,362,358  
Derivative instruments
    92,206       152,430  
Other
    168,684       187,878  
 
           
 
    4,417,857       4,352,063  
 
           
 
               
SHAREHOLDERS’ EQUITY:
               
Preferred stock, no par value, 5,000,000 shares authorized – Series B, 5.68% Cumulative Preferred Stock, 100,000 shares issued and outstanding
    98,387       98,387  
Common stock, $0.625 par, 430,000,000 shares authorized, 337,197,428 and 336,997,053 shares issued, respectively
    210,748       210,623  
Paid-in capital
    4,187,570       4,170,714  
Retained earnings
    7,143,328       6,516,863  
Treasury stock, at cost, 6,858,589 and 6,875,823 shares, respectively
    (89,539 )     (89,764 )
Accumulated other comprehensive loss
    (293,998 )     (365,608 )
 
           
 
    11,256,496       10,541,215  
 
           
 
  $ 19,999,103     $ 19,271,796  
 
           
The accompanying notes to consolidated financial statements
are an integral part of this statement.

4


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED SHAREHOLDERS’ EQUITY
(Unaudited)
                                                                   
                                                      Accumulated        
              Series B                                     Other     Total  
    Comprehensive       Preferred     Common     Paid-In     Retained     Treasury     Comprehensive     Shareholders’  
    Income       Stock     Stock     Capital     Earnings     Stock     Income (Loss)     Equity  
                              (In thousands)                          
BALANCE AT DECEMBER 31, 2004
            $ 98,387     $ 209,320     $ 4,106,182     $ 4,017,339     $ (97,325 )   $ (129,482 )   $ 8,204,421  
Comprehensive income (loss):
                                                                 
Net income
  $ 560,483                           560,483                   560,483  
Commodity hedges, net of income tax benefit of $82,210
    (136,997 )                                     (136,997 )     (136,997 )
 
                                                               
Comprehensive income
  $ 423,486                                                            
 
                                                               
Dividends:
                                                                 
Preferred
                                (1,420 )                 (1,420 )
Common ($.08 per share)
                                (26,238 )                 (26,238 )
Common shares issued
                    291       19,781                         20,072  
Treasury shares issued, net
                          98             3,464             3,562  
Other
                          66                         66  
 
                                                   
BALANCE AT MARCH 31, 2005
            $ 98,387     $ 209,611     $ 4,126,127     $ 4,550,164     $ (93,861 )   $ (266,479 )   $ 8,623,949  
 
                                                   
 
                                                                 
BALANCE AT DECEMBER 31, 2005
            $ 98,387     $ 210,623     $ 4,170,714     $ 6,516,863     $ (89,764 )   $ (365,608 )   $ 10,541,215  
Comprehensive income (loss):
                                                                 
Net income
  $ 660,921                           660,921                   660,921  
Commodity hedges, net of income tax benefit of $39,414
    71,610                                       71,610       71,610  
 
                                                               
Comprehensive income
  $ 732,531                                                            
 
                                                               
Dividends:
                                                                 
Preferred
                                (1,420 )                 (1,420 )
Common ($.10 per share)
                                (33,036 )                 (33,036 )
Common shares issued
                    125       14,532                         14,657  
Treasury shares issued, net
                          2,292             225             2,517  
Other
                          32                         32  
 
                                                   
BALANCE AT MARCH 31, 2006
            $ 98,387     $ 210,748     $ 4,187,570     $ 7,143,328     $ (89,539 )   $ (293,998 )   $ 11,256,496  
 
                                                   
The accompanying notes to consolidated financial statements
are an integral part of this statement.

5


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
     These financial statements have been prepared by Apache Corporation (Apache or the Company) without audit, pursuant to the rules and regulations of the Securities and Exchange Commission (SEC), and reflect all adjustments which are, in the opinion of management, necessary for a fair statement of the results for the interim periods, on a basis consistent with the annual audited financial statements. All such adjustments are of a normal recurring nature. Certain information, accounting policies, and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. These financial statements should be read in conjunction with the financial statements and the summary of significant accounting policies and notes included in the Company’s most recent annual report on Form 10-K.
Reclassifications
     Certain prior period amounts have also been reclassified to conform with current year presentations.
1. ACQUISITIONS AND DIVESTITURES
2006 Acquisitions and Divestitures
     Amerada Hess
     On January 5, 2006, the Company purchased Amerada Hess’s interest in eight fields located in the Permian Basin of West Texas and New Mexico for $269 million. Apache estimates that these fields had proved reserves of 27 million barrels of liquid hydrocarbons and 27 billion cubic feet of natural gas as of year-end 2005. The Company had previously announced on October 13, 2005 that it had agreed to purchase Amerada Hess’s interest for $404 million. The price and number of properties involved in this transaction were reduced as a result of third parties exercising their preferential rights.
     On January 6, 2006, the Company completed the sale of its 55 percent interest in the deepwater section of Egypt’s West Mediterranean Concession to Amerada Hess for $413 million. Apache did not have any oil and gas reserves recorded for these properties. Apache first announced this transaction on October 13, 2005.
2006 Second-Quarter Events
     BP plc (BP)
     On April 19, 2006, the Company announced that it has finalized an agreement to acquire BP’s remaining producing properties on the Outer Continental Shelf of the Gulf of Mexico for $1.3 billion in cash. The properties include 18 producing fields (11 of which are operated) covering 92 blocks with estimated proved reserves of 27 million barrels of liquid hydrocarbons and 185 billion cubic feet (Bcf) of natural gas. Many of the fields are subject to exercise of preferential rights to purchase by other interest owners. The transaction, which is subject to government approvals, is expected to close by the end of the second quarter.
     Pioneer Natural Resources (Pioneer)
     On April 25, 2006, the Company completed the purchase of Pioneer’s operations in Argentina for $675 million. This transaction was first announced on January 17, 2006. Apache estimates the transaction includes proved reserves of 22 million barrels (MMbbls) of liquid hydrocarbons and 297 billion cubic feet (Bcf) of natural gas. The oil and gas assets are located in the Neuquen, San Jorge and Austral basins of Argentina. Net current production is approximately 9,000 b/d of liquid hydrocarbons and 125 MMcf/d of natural gas. The assets include five operated and three non-operated gas processing plants and 112 miles of operated pipelines in the Neuquen Basin. Also included are 2,200 square miles of 3-D seismic data.

6


Table of Contents

2005 Acquisitions
     There were no material acquisitions in the three months ended March 31, 2005.
2. HEDGING AND DERIVATIVE INSTRUMENTS
     Apache uses a variety of strategies to manage its exposure to fluctuations in crude oil and natural gas commodity prices. As established by the Company’s hedging policy, Apache primarily enters into cash flow hedges in connection with selected acquisitions to protect against commodity price volatility. The success of these acquisitions is significantly influenced by Apache’s ability to achieve targeted production at forecasted prices over the long-term. These hedges effectively reduce price risk on a portion of the production from the acquisitions.
     Apache entered into, and designated as cash flow hedges, various fixed-price swaps, option collars and puts in connection with anticipation of the BP Gulf of Mexico property acquisition and the previous ExxonMobil and Anadarko acquisitions. These positions were entered into in accordance with the Company’s hedging policy and involved two counterparties, both of which are rated A+ or better. As of March 31, 2006, the outstanding positions of our natural gas and crude oil cash flow hedges were as follows:
                         
Production       Total Volumes   Weighted Average   Fair Value Asset/
Period   Instrument Type   (MMBtu/Bbl)   Floor/Ceiling   (Liability)
                    (In thousands)
2006
  Gas Collars     24,750,000     5.50 / 6.66     (38,351 )
 
  Gas Fixed-Price Swap     3,116,000     5.79     (6,718 )
 
  Gas Put Option     9,200,000     7.00     3,942  
 
  Oil Collars     3,245,000     32.07 / 40.66     (90,071 )
 
  Oil Fixed-Price Swap     1,011,500     62.30     (6,831 )
 
  Oil Put Option     1,155,000     28.00      
 
                       
2007
  Gas Collars     42,820,000     6.70 / 8.25     (83,148 )
 
  Gas Fixed-Price Swap     1,761,000     5.57     (6,778 )
 
  Oil Collars     1,911,000     33.00 / 39.25     (55,052 )
 
  Oil Fixed-Price Swap     1,903,000     66.29     (5,875 )
 
                       
2008
  Gas Collars     18,300,000     8.15 / 10.47     (1,370 )
 
  Oil Fixed-Price Swap     1,830,000     66.85     (2,609 )
     The natural gas and crude oil prices shown in the above table are based on the NYMEX index and have been valued using actively quoted prices and quotes obtained from reputable third-party financial institutions. The above prices represent a weighted average of several contracts entered into and are on a per million British thermal units (MMBtu) or per barrel (Bbl) basis for gas and oil derivatives, respectively.
     In March, the Company purchased a 100,000 MMBtu per day NYMEX call option for $6 million with a strike price of $10.50 per MMBtu. The option is for the months of August 2006 through November 2006 and was purchased to mitigate price exposure on prior hedged volumes in the event of significant potential price spikes from extreme weather or hurricane induced production curtailments. The call option is marked to market each period and any gains or losses are reflected in “Revenue and Other, Other.”
     A reconciliation of the components of accumulated other comprehensive income (loss) in the statement of consolidated shareholders’ equity related to Apache’s commodity derivative activity is presented in the table below:
                 
    Gross     After tax  
    (In thousands)  
Unrealized loss on derivatives at December 31, 2005
  $ (398,229 )   $ (256,858 )
Net losses realized into earnings
    48,973       31,588  
Net change in derivative fair value
    62,051       40,022  
 
           
Unrealized loss on derivatives at March 31, 2006
  $ (287,205 )   $ (185,248 )
 
           

7


Table of Contents

     Based on current market prices as of March 31, 2006, the Company recorded an unrealized loss in other comprehensive income (loss) of $287 million ($185 million after tax), primarily representing commodity derivative hedges. Gains and losses on the commodity hedges will be realized in future earnings contemporaneously with the related sales of natural gas and crude oil production applicable to specific hedges. Of the $287 million estimated unrealized loss on derivatives at March 31, 2006, approximately $196 million ($126 million after tax) applies to the next 12 months; however, estimated and actual amounts are likely to vary materially as a result of changes in market conditions. These contracts, designated as hedges, qualified and continue to qualify for hedge accounting in accordance with Statement of Financial Accounting Standards (SFAS) No. 133, as amended.
3. DEBT
     The Company is currently amending its existing five-year revolving U.S. credit facility which is scheduled to mature on May 28, 2009. The amendment is expected to: 1) extend the maturity to May 28, 2011, 2) increase the size of the facility from $750 million to $1.5 billion and 3) reduce the facility fees and reduce the margin over LIBOR on loans. The company is also asking the lenders to extend the maturity dates of the $450 million U.S. credit facility, the $150 million Canadian facility and the $150 million Australian facility, for an additional year from May 12, 2010 to May 12, 2011. Once the amendment to the credit facility is final, the Company plans to increase its commercial paper program to $1.95 billion from $1.20 billion.
4. CAPITAL STOCK
     During the first quarter of 2006 and 2005, Apache paid $33 million and $26 million, respectively, in dividends on its Common Stock. The increase in the first-quarter 2006 common stock dividends from the amount paid for the same period last year, primarily reflects a 25 percent higher common stock dividend rate and a slight increase in common shares outstanding. On September 15, 2005, the Company announced that its Board of Directors voted to increase the quarterly cash dividend on its common stock to 10 cents per share from eight cents per share, effective with the November 2005 payment. In addition, in each period, Apache paid a total of $1.4 million in dividends on its Series B Preferred Stock issued in August 1998.
5. NET INCOME PER COMMON SHARE
     A reconciliation of the components of basic and diluted net income per common share is presented in the table below:
                                                 
    For the Quarter Ended March 31,  
    2006     2005  
    Income     Shares     Per Share     Income     Shares     Per Share  
            (In thousands, except per share amounts)                  
Basic:
                                               
Income attributable to common stock
  $ 659,501       330,416     $ 2.00     $ 559,063       328,037     $ 1.70  
 
                                           
 
                                               
Effect of Dilutive Securities:
                                               
Stock options and other
          4,053                     6,001          
 
                                       
 
                                               
Diluted:
                                               
Income attributable to common stock, including assumed conversions
  $ 659,501       334,469     $ 1.97     $ 559,063       334,038     $ 1.67  
 
                                   

8


Table of Contents

6. STOCK-BASED COMPENSATION
     The Company adopted SFAS No. 123-R “Share-Based Payment” in 2004. This accounting statement requires the expensing of all options and other stock-based compensation that vest during the year based on the fair value determined at the date of grant. In addition, the Company also has stock appreciation rights outstanding that are cash-based and expensed based on the fair value determined at the end of each reporting period. For the three-month periods ended March 31, 2006 and 2005, total stock-based compensation cost reflected in income was $6 million ($4 million after tax) and $19 million ($12 million after tax), respectively. In addition, the related stock-based compensation cost capitalized as part of oil and gas properties was $2 million and $10 million for the three-month periods ended March 31, 2006 and 2005, respectively.
7. SUPPLEMENTAL CASH FLOW INFORMATION
     The following table provides supplemental disclosure of cash flow information:
                 
    For the Quarter Ended
    March 31,
    2006   2005
    (In thousands)
Cash paid during the period for:
               
Interest (net of amounts capitalized)
  $ 13,341     $ 15,702  
Income taxes (net of refunds)
    280,358       218,818  
8. PENSION AND POST-RETIREMENT BENEFITS
     Apache has a non-contributory defined benefit pension plan that provides retirement benefits for certain North Sea employees meeting established age and service requirements. The pension plan is closed to new employees. Apache also has a post-retirement benefit plan which provides benefits for substantially all of its U.S. employees. The post-retirement benefit plan provides medical benefits up until age 65 and is contributory.
Net Periodic Cost
     The following table presents the plans’ net periodic benefit cost for the quarters ended March 31, 2006 and 2005:
                                 
    Pension Benefits     Postretirement Benefits  
    For the Three Months Ended March 31,  
    2006     2005     2006     2005  
            (In thousands)          
Components of net periodic benefit cost:
                               
Service cost
  $ 1,700     $ 1,638     $ 400     $ 275  
Interest cost
    1,234       1,163       250       175  
Expected return on plan assets
    (1,360 )     (1,256 )     ––        
Amortization of transition obligation
                13       13  
Amortization of actuarial (gain)/loss
                87       62  
 
                       
Net periodic benefit cost
  $ 1,574     $ 1,545     $ 750     $ 525  
 
                       
Employer Contributions
     As previously disclosed in our financial statements for the year ended December 31, 2005, we expect to contribute $5 million to the pension plan and $321,000 to the post-retirement benefit plan in 2006. As of March 31, 2006, approximately $1 million of contributions have been made to the plans.

9


Table of Contents

9. BUSINESS SEGMENT INFORMATION
     Apache has interests in seven countries: the United States, Canada, Egypt, Australia, the United Kingdom (UK), China and Argentina. The Company evaluates segment performance based on profit and loss from oil and gas operations before income and expense items incidental to oil and gas operations and income taxes. Apache’s reportable segments are managed separately because of their geographic locations. Financial information by reportable segment is presented below:
                                                         
    United                             UK     Other        
    States     Canada     Egypt     Australia     North Sea     International     Total  
                            (In thousands)                          
For the Quarter Ended March 31, 2006
                                                       
Oil and Gas Production Revenues
  $ 693,685     $ 381,309     $ 398,470     $ 94,311     $ 353,841     $ 28,682     $ 1,950,298  
                 
Operating Income (1)
  $ 357,439     $ 216,748     $ 304,331     $ 48,547     $ 151,329     $ 14,550     $ 1,092,944  
                       
 
                                                       
Other Income (Expense):
                                                       
Other
                                                    48,804  
General and administrative
                                                    (45,672 )
Financing costs, net
                                                    (22,814 )
 
                                                     
Income Before Income Taxes
                                                  $ 1,073,262  
 
                                                     
Total Assets
  $ 9,112,847     $ 5,257,647     $ 2,530,666     $ 1,302,364     $ 1,641,706     $ 153,873     $ 19,999,103  
                 
 
                                                       
For the Quarter Ended March 31, 2005
                                                       
Oil and Gas Production Revenues
  $ 661,212     $ 278,721     $ 299,720     $ 94,780     $ 257,717     $ 34,499     $ 1,626,649  
                 
Operating Income (1)
  $ 369,046     $ 153,644     $ 222,992     $ 49,928     $ 135,825     $ 13,505     $ 944,940  
                       
 
                                                       
Other Income (Expense):
                                                       
Other
                                                    35,639  
General and administrative
                                                    (50,411 )
Financing costs, net
                                                    (31,588 )
Income Before Income Taxes
                                                  $ 898,580  
 
                                                     
Total Assets
  $ 7,467,839     $ 3,967,800     $ 2,103,270     $ 1,196,402     $ 1,363,273     $ 158,484     $ 16,257,068  
                 
 
1)   Operating Income consists of oil and gas production revenues less depreciation, depletion and amortization, asset retirement obligation accretion, lease operating costs, gathering and transportation costs, and severance and other taxes.
10. ASSET RETIREMENT OBLIGATIONS
     The following table describes changes to the Company’s asset retirement obligation (ARO) liability for the quarter ended March 31, 2006 (in thousands):
         
Asset retirement obligation as of December 31, 2005
  $ 1,455,915  
Liabilities incurred
    25,347  
Liabilities settled
    (26,086 )
Accretion expense
    20,645  
 
     
Asset retirement obligation as of March 31, 2006
  $ 1,475,821  
 
     
     Liabilities incurred primarily relate to abandonment obligations assumed in connection with current drilling activity and various small acquisitions closed during the period. Liabilities settled during the period primarily relate to properties plugged and abandoned or sold during the period.
11. LITIGATION
Texaco China B.V.
     Apache recorded a reserve in the second quarter of 2004 to fully reflect a pre-tax $71 million international arbitration award to Texaco China B.V. (Texaco China). The arbitration award was subject to interest at nine percent until May 6, 2005, the date following the federal district court ruling discussed below. On May 6, 2005, the interest rate dropped to 3.33 percent. Apache accrued $3.2 million of interest expense in 2004, $3.8 million in 2005 and

10


Table of Contents

$593,000 in the first quarter of 2006. In September 2001, Texaco China initiated an arbitration proceeding against Apache China Corporation LDC (Apache China), later adding Apache Bohai Corporation LDC (Apache Bohai) to the arbitration. In the arbitration Texaco China claimed damages, plus interest, arising from Apache Bohai’s alleged failure to drill three wells, prior to re-assignment of the interest to Texaco China. Apache believes that the finding of the arbitrator is unsupported by the facts and the law, and Apache filed an application to vacate the award in federal court. Texaco China filed an application to confirm the award in the same court. On May 5, 2005, the federal district court ruled in favor of Texaco China. The Company has appealed that decision to the circuit court of appeals. In January 2005, while awaiting the decision of the U.S. federal courts, Texaco China also filed a proceeding against Apache China and Apache Bohai in the People’s Republic of China to recognize the award, apparently seeking the same relief as sought in U.S. federal court. The parties subsequently agreed to stay enforcement of the arbitration award in China and elsewhere pending the final, determinative outcome of all possible appeals in the U.S. federal courts. A hearing on the appeal was held in April 2006, however, the Court of Appeals has not yet provided its decision.
Predator
     In December 2000, certain subsidiaries of the Company and Murphy Oil Corporation (Murphy) filed a lawsuit in Canada charging The Predator Corporation Ltd. (Predator) and others with misappropriation and misuse of confidential well data to obtain acreage offsetting a significant natural gas discovery in the Ladyfern area of northeast British Columbia made by Apache Canada Ltd. (Apache Canada) and Murphy during 2000. In February 2001, Predator filed a counterclaim seeking more than C$6 billion and later reduced this amount to approximately C$3.6 billion. In September 2004, the Canadian court granted Apache Canada’s motion for summary judgment on the counterclaim, dismissing more than C$3 billion of Predator’s claims against Apache Canada and Murphy, and dismissing all claims against both Murphy’s president and Apache Canada’s president. Predator appealed the summary judgment. On February 28, 2006, the Court of Appeal of Alberta dismissed Predator’s appeal. Predator has informed Apache that it will not seek review by the Supreme Court of Canada. The trial court also granted Apache Canada’s request for costs and disbursements in the approximate amount of C$700,000, which Predator has paid. The Canadian court has also granted Predator’s request to add some new mismanagement of operations claims to its counterclaim, which now totals approximately C$365 million. A trial on Apache and Murphy’s claims against Predator, as well as Predator’s surviving counterclaims against Murphy and Apache Canada began on April 24, 2006 and is expected to continue at least through the end of May 2006. While management believes Predator’s counterclaim against Apache Canada is without merit, an adverse judgment is possible. Exposure related to this lawsuit is not currently determinable.
Egypt Tax Authority
     As of the end of 2004, the Egyptian Tax Authority (ETA) had issued claims for back taxes against various Apache subsidiaries in Egypt totaling approximately $113.4 million (at current exchange rates) relating to periods as far back as 1994. In July 2005, the ETA made a new claim for approximately $85 million of additional taxes for the 1994-99 tax years. On January 30, 2006, ETA cancelled the new claim in its entirety, with no liability to Apache. On March 16, 2006, ETA cancelled one of the two remaining tax claims in its entirety, with no liability to Apache.
     There is a single remaining ETA claim, relating to the Khalda concession agreement, in the approximate amount of $15.4 million (at current exchange rates). With respect to the remaining claim, while an adverse judgment against Apache is possible, Egyptian concession agreements clearly provide that the Egyptian General Petroleum Corporation is responsible for the payment of all taxes related to the operation of the concessions. Apache believes that the claim of the ETA is unsupported by either the facts or the language of the Khalda concession agreement, which has the force of law in Egypt. Apache’s subsidiary, Apache Khalda Corporation LDC, has contested liability with respect to that claim by filing an action in Egyptian civil court. In addition, pursuant to a 2005 change in the Egyptian tax law, Apache has petitioned the Committee for the Reconsideration of Final Assessment for reconsideration of the original claims. The Committee for the Reconsideration of Final Assessment, which is the final appeal committee in the Tax Authority and is empowered to overrule Tax Authority claims, has accepted Apache’s petition for reconsideration. A decision by the Committee is expected sometime during the second quarter of 2006. Apache plans to vigorously pursue its remedies with respect to this remaining claim.
Argentine Environmental Claims
     In connection with the Pioneer Acquisition, the Company acquired a subsidiary of Pioneer in Argentina (“PNRA”) that is involved in various administrative proceedings with environmental authorities in the Neuquén

11


Table of Contents

Province relating to permits for and discharges from operations in that province. PNRA is cooperating with the proceedings, although it from time to time challenges whether certain assessed fines, which could exceed $100,000, are appropriate. The authorities have suspended and delayed the issuance of environmental permits for new wells and some existing wells in the Neuquén Province, pending conduct of an environmental audit and inventory of all wells, which may be followed by a remediation plan. PNRA was named in a suit initiated against oil companies operating in the Neuquén basin entitled Asociación de Superficiarios de la Patagonia v. YPF S.A., et. al., originally filed on August 21, 2003, in the Argentine National Supreme Court of Justice. The plaintiffs, a private group of landowners, have also named the national government and several provinces as third parties. The lawsuit alleges injury to the environment generally by the oil and gas industry. The plaintiffs principally seek from all defendants, jointly, (i) the remediation of the contaminated sites, of the superficial and underground waters, and of the soil that was degraded as a result of deforestation, (ii) if the remediation is not possible, payment of an indemnification for the material and moral damages, estimated by the plaintiff to be of an aggregate amount of approximately $5.5 billion claimed from all defendants operating in the Neuquén basin, of which PNRA is a small portion, (iii) adoption of all of the necessary measures to prevent future environmental damages, and (iv) the creation of a private restoration fund to provide coverage for remediation of potential future environmental damages. Much of the alleged damage relates to operations by the Argentine state oil company, which conducted oil and gas operations throughout Argentina prior to its privatization, which began in 1990. While the plaintiffs will seek to make all oil and gas companies operating in the Neuquén basin jointly liable for each others’ actions, PNRA will defend on an individual basis and attempt to require the plaintiffs to delineate damages by company. PNRA intends to defend itself vigorously in the case. It is not certain exactly how or what the court will do in this matter as it is the first of its kind. No prediction can be made whether PNRA may incur liabilities related to the environmental claims. PNRA’s exposure related to this lawsuit is not currently determinable.
General
     The Company is involved in other litigation and is subject to governmental and regulatory controls arising in the ordinary course of business. The Company has an accrued liability of approximately $2 million for other legal contingencies that are probable of occurring and can be reasonably estimated. It is management’s opinion that the loss for any such other litigation matters and claims that are reasonably possible to occur will not have a material adverse affect on the Company’s financial position or results of operations.
12. SUBSEQUENT EVENT
     On April 19, 2006, the Company announced that its Board of Directors authorized the purchase of up to 15 million shares of the Company’s common stock. The market value on the date of the announcement was approximately $1 billion. The Company may buy shares from time to time on the open market, in privately negotiated transactions, or a combination of both. The timing and amounts of any purchases will be at the discretion of Apache’s management. The Company initiated the purchase program on May 1, 2006, after the Company’s first-quarter 2006 earnings information was disseminated in the market. Through May 8, 2006 the Company had purchased 1,500,000 of the shares authorized by its Board of Directors.
13. SUPPLEMENTAL GUARANTOR INFORMATION
     Apache Finance Pty Ltd. (Apache Finance Australia) and Apache Finance Canada Corporation (Apache Finance Canada) are subsidiaries of Apache that have issuances of publicly traded securities and require the following condensed consolidating financial statements be provided as an alternative to filing separate financial statements.
     Each of the companies presented in the condensed consolidating financial statements has been fully consolidated in Apache’s consolidated financial statements. As such, the condensed consolidating financial statements should be read in conjunction with the financial statements of Apache Corporation and Subsidiaries and notes.

12


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS
For the Quarter Ended March 31, 2006
                                                         
                                    All Other              
                            Apache     Subsidiaries              
    Apache     Apache     Apache     Finance     of Apache     Reclassifications        
    Corporation     North America     Finance Australia     Canada     Corporation     & Eliminations     Consolidated  
    (In thousands)  
REVENUES AND OTHER:
                                                       
Oil and gas production revenues
  $ 666,299     $     $     $     $ 1,349,184     $ (65,185 )   $ 1,950,298  
Equity in net income (loss) of affiliates
    441,811       6,760       9,555       71,778       (12,166 )     (517,738 )      
Other
    69,875                         (21,071 )           48,804  
 
                                         
 
    1,177,985       6,760       9,555       71,778       1,315,947       (582,923 )     1,999,102  
 
                                         
 
                                                       
OPERATING EXPENSES:
                                                       
Depreciation, depletion and amortization
    150,692                         221,885             372,577  
Asset retirement obligation accretion
    15,083                         5,562             20,645  
Lease operating costs
    131,736                         225,063       (65,185 )     291,614  
Gathering and transportation costs
    7,710                         18,394             26,104  
Severance and other taxes
    27,609                         118,805             146,414  
General and administrative
    37,310                         8,362             45,672  
Financing costs, net
    19,924             4,583       14,111       (15,804 )           22,814  
 
                                         
 
    390,064             4,583       14,111       582,267       (65,185 )     925,840  
 
                                         
 
                                                       
INCOME (LOSS) BEFORE INCOME TAXES
    787,921       6,760       4,972       57,667       733,680       (517,738 )     1,073,262  
Provision (benefit) for income taxes
    127,000             (1,788 )     (4,740 )     291,869             412,341  
 
                                         
 
                                                       
NET INCOME
    660,921       6,760       6,760       62,407       441,811       (517,738 )     660,921  
Preferred stock dividends
    1,420                                     1,420  
 
                                         
INCOME ATTRIBUTABLE TO COMMON STOCK
  $ 659,501     $ 6,760     $ 6,760     $ 62,407     $ 441,811     $ (517,738 )   $ 659,501  
 
                                         

13


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS
For the Quarter Ended March 31, 2005
                                                         
                                    All Other              
                            Apache     Subsidiaries              
    Apache     Apache     Apache     Finance     of Apache     Reclassifications        
    Corporation     North America     Finance Australia     Canada     Corporation     & Eliminations     Consolidated  
    (In thousands)  
REVENUES AND OTHER:
                                                       
Oil and gas production revenues
  $ 650,906     $     $     $     $ 1,046,614     $ (70,871 )   $ 1,626,649  
Equity in net income (loss) of affiliates
    345,079       9,485       12,462       50,260       (12,352 )     (404,934 )      
Other
    30,185                         5,454             35,639  
 
                                         
 
    1,026,170       9,485       12,462       50,260       1,039,716       (475,805 )     1,662,288  
 
                                         
 
                                                       
OPERATING EXPENSES:
                                                       
Depreciation, depletion and amortization
    149,384                         190,029             339,413  
Asset retirement obligation accretion
    7,834                         5,325             13,159  
Lease operating costs
    104,955                         199,087       (70,871 )     233,171  
Gathering and transportation costs
    7,949                         15,831             23,780  
Severance and other taxes
    20,077                         52,109             72,186  
General and administrative
    40,317                         10,094             50,411  
Financing costs, net
    19,919             4,512       14,110       (6,953 )           31,588  
 
                                         
 
    350,435             4,512       14,110       465,522       (70,871 )     763,708  
 
                                         
 
                                                       
INCOME (LOSS) BEFORE INCOME TAXES
    675,735       9,485       7,950       36,150       574,194       (404,934 )     898,580  
Provision (benefit) for income taxes
    115,252             (1,535 )     (4,735 )     229,115             338,097  
 
                                         
 
                                                       
NET INCOME
    560,483       9,485       9,485       40,885       345,079       (404,934 )     560,483  
Preferred stock dividends
    1,420                                     1,420  
 
                                         
INCOME ATTRIBUTABLE TO COMMON STOCK
  $ 559,063     $ 9,485     $ 9,485     $ 40,885     $ 345,079     $ (404,934 )   $ 559,063  
 
                                         

14


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Quarter Ended March 31, 2006
                                                         
                                    All Other              
                    Apache     Apache     Subsidiaries              
    Apache     Apache     Finance     Finance     of Apache     Reclassifications        
    Corporation     North America     Australia     Canada     Corporation     & Eliminations     Consolidated  
    (In thousands)  
CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES
  $ 401,155     $     $ (3,699 )   $ (1,575 )   $ 647,403     $     $ 1,043,284  
 
                                         
 
                                                       
CASH FLOWS FROM INVESTING ACTIVITIES:
                                                       
Additions to property and equipment
    (328,668 )                       (683,371 )           (1,012,039 )
Acquisition of Amerada Hess properties
    (230,080 )                                   (230,080 )
Proceeds from sale of Egyptian properties
                            409,197             409,197  
Investment in subsidiaries, net
    18,046       (3,500 )                 (5,264 )     (9,282 )      
Other, net
    26,817                         (80,399 )           (53,582 )
 
                                         
NET CASH USED IN INVESTING ACTIVITIES
    (513,885 )     (3,500 )                 (359,837 )     (9,282 )     (886,504 )
 
                                         
 
                                                       
CASH FLOWS FROM FINANCING ACTIVITIES:
                                                       
Debt borrowings
    158,199             199       1,575       (22,468 )     20,768       158,273  
Payments on debt
    (3,800 )                                   (3,800 )
Dividends paid
    (34,433 )                                   (34,433 )
Common stock activity
    3,238       3,500       3,500             4,486       (11,486 )     3,238  
Treasury stock activity, net
    936                                     936  
Cost of debt and equity transactions
    (182 )                                   (182 )
Other
    (5,657 )                                   (5,657 )
 
                                         
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES
    118,301       3,500       3,699       1,575       (17,982 )     9,282       118,375  
 
                                         
 
                                                       
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
    5,571                         269,584             275,155  
 
                                                       
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
    3,785             2       1       225,072             228,860  
 
                                         
 
                                                       
CASH AND CASH EQUIVALENTS AT END OF PERIOD
  $ 9,356     $     $ 2     $ 1     $ 494,656     $     $ 504,015  
 
                                         

15


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Quarter Ended March 31, 2005
                                                         
                                    All Other              
                    Apache     Apache     Subsidiaries              
    Apache     Apache     Finance     Finance     of Apache     Reclassifications        
    Corporation     North America     Australia     Canada     Corporation     & Eliminations     Consolidated  
    (In thousands)  
CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES
  $ 345,817     $     $ (3,624 )   $ (77 )   $ 494,056     $     $ 836,172  
 
                                         
 
                                                       
CASH FLOWS FROM INVESTING ACTIVITIES:
                                                       
Additions to property and equipment.
    (220,438 )                       (569,912 )           (790,350 )
Investment in subsidiaries, net
    (103,628 )     (3,500 )                 (3,689 )     110,817        
Other, net
    49,147                         (16,699 )           32,448  
 
                                         
NET CASH USED IN INVESTING ACTIVITIES
    (274,919 )     (3,500 )                 (590,300 )     110,817       (757,902 )
 
                                         
 
                                                       
CASH FLOWS FROM FINANCING ACTIVITIES:
                                                       
Debt borrowings
    6,793             124       77       98,943       (99,075 )     6,862  
Payments on debt
    (62,700 )                       (830 )           (63,530 )
Dividends paid
    (27,631 )                                   (27,631 )
Common stock activity
    7,771       3,500       3,500             4,742       (11,742 )     7,771  
Treasury stock activity, net
    (2,085 )                                   (2,085 )
Cost of debt and equity transactions
    (78 )                                   (78 )
Other
    10,679                                     10,679  
 
                                         
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES
    (67,251 )     3,500       3,624       77       102,855       (110,817 )     (68,012 )
 
                                         
 
                                                       
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
    3,647                         6,611             10,258  
 
                                                       
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR
    597             2       3       110,491             111,093  
 
                                         
 
                                                       
CASH AND CASH EQUIVALENTS AT END OF PERIOD
  $ 4,244     $     $ 2     $ 3     $ 117,102     $     $ 121,351  
 
                                         

16


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEET
As of March 31, 2006
                                                         
                                    All Other              
                    Apache     Apache     Subsidiaries              
    Apache     Apache     Finance     Finance     of Apache     Reclassifications        
    Corporation     North America     Australia     Canada     Corporation     & Eliminations     Consolidated  
    (In thousands)  
ASSETS
                                                       
 
                                                       
CURRENT ASSETS:
                                                       
Cash and cash equivalents
  $ 9,356     $     $ 2     $ 1     $ 494,656     $     $ 504,015  
Receivables, net of allowance
    660,716                         786,254             1,446,970  
Inventories
    28,781                         197,980             226,761  
Drilling advances and others
    95,417                         84,111             179,528  
 
                                         
 
    794,270             2       1       1,563,001             2,357,274  
 
                                         
 
                                                       
PROPERTY AND EQUIPMENT, NET
    8,098,560                         9,217,967             17,316,527  
 
                                         
 
                                                       
OTHER ASSETS:
                                                       
Intercompany receivable, net
    1,035,760             (4,077 )     (255,775 )     (775,908 )            
Goodwill, net
                            189,252             189,252  
Equity in affiliates
    6,270,078       324,391       566,499       1,698,511       (1,196,936 )     (7,662,543 )      
Deferred charges and other
    56,839                   4,222       74,989             136,050  
 
                                         
 
  $ 16,255,507     $ 324,391     $ 562,424     $ 1,446,959     $ 9,072,365     $ (7,662,543 )   $ 19,999,103  
 
                                         
 
                                                       
LIABILITIES AND SHAREHOLDERS’ EQUITY
                                                       
CURRENT LIABILITIES:
                                                       
Short-term debt
  $ 154,300     $     $     $     $ 3,274     $     $ 157,574  
Accounts payable
    372,094                         297,277             669,371  
Other accrued expenses
    766,755             4,956       51,741       485,227             1,308,679  
 
                                         
 
    1,293,149             4,956       51,741       785,778             2,135,624  
 
                                         
 
                                                       
LONG-TERM DEBT
    1,271,530             269,469       646,876       1,251             2,189,126  
 
                                         
 
                                                       
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
                                                       
Income taxes
    1,232,118             (36,392 )     4,659       1,578,524             2,778,909  
Advances from gas purchasers
    62,400                                     62,400  
Asset retirement obligation
    914,858                         400,800             1,315,658  
Derivative instruments
    92,207                         (1 )           92,206  
Other
    132,749                         35,935             168,684  
 
                                         
 
    2,434,332             (36,392 )     4,659       2,015,258             4,417,857  
 
                                         
 
                                                       
COMMITMENTS AND CONTINGENCIES
                                                       
 
                                                       
SHAREHOLDERS’ EQUITY
    11,256,496       324,391       324,391       743,683       6,270,078       (7,662,543 )     11,256,496  
 
                                         
 
  $ 16,255,507     $ 324,391     $ 562,424     $ 1,446,959     $ 9,072,365     $ (7,662,543 )   $ 19,999,103  
 
                                         

17


Table of Contents

APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEET
As of December 31, 2005
                                                         
                                    All Other              
                                    Subsidiaries              
    Apache     Apache     Apache     Apache     of Apache     Reclassifications        
    Corporation     North America     Finance Australia     Finance Canada     Corporation     & Eliminations     Consolidated  
    (In thousands)  
ASSETS
                                                       
CURRENT ASSETS:
                                                       
Cash and cash equivalents
  $ 3,785     $     $ 2     $ 1     $ 225,072     $     $ 228,860  
Receivables, net of allowance
    516,208                         928,337             1,444,545  
Inventories
    30,276                         179,394             209,670  
Drilling advances and other
    188,607                         90,395             279,002  
 
                                         
 
    738,876             2       1       1,423,198             2,162,077  
 
                                         
 
                                                       
PROPERTY AND EQUIPMENT, NET
    7,680,469                         9,110,871             16,791,340  
 
                                         
 
                                                       
OTHER ASSETS:
                                                       
Intercompany receivable, net
    1,058,228             (3,936 )     (254,216 )     (800,076 )            
Goodwill, net
                            189,252             189,252  
Equity in affiliates
    5,833,283       315,460       558,215       1,609,007       (1,183,600 )     (7,132,365 )      
Deferred charges and other
    44,974                   4,301       79,852             129,127  
 
                                         
 
  $ 15,355,830     $ 315,460     $ 554,281     $ 1,359,093     $ 8,819,497     $ (7,132,365 )   $ 19,271,796  
 
                                         
LIABILITIES AND SHAREHOLDERS’ EQUITY
                                                       
CURRENT LIABILITIES:
                                                       
Accounts payable
  $ 378,247     $     $     $ 946     $ 335,405     $     $ 714,598  
Accrued expenses and other
    687,125             5,619       38,343       740,879             1,471,966  
 
                                         
 
    1,065,372             5,619       39,289       1,076,284             2,186,564  
 
                                         
 
                                                       
LONG-TERM DEBT
    1,271,431             269,411       646,860       4,252             2,191,954  
 
                                         
 
                                                       
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
                                                       
Income taxes
    1,140,457             (36,209 )     4,782       1,471,599             2,580,629  
Advances from gas purchasers
    68,768                                     68,768  
Asset retirement obligation
    972,024                         390,334             1,362,358  
Oil and gas derivative instruments
    152,430                                     152,430  
Other
    144,133                         43,745             187,878  
 
                                         
 
    2,477,812             (36,209 )     4,782       1,905,678             4,352,063  
 
                                         
 
                                                       
COMMITMENTS AND CONTINGENCIES
                                                       
 
                                                       
SHAREHOLDERS’ EQUITY
    10,541,215       315,460       315,460       668,162       5,833,283       (7,132,365 )     10,541,215  
 
                                         
 
  $ 15,355,830     $ 315,460     $ 554,281     $ 1,359,093     $ 8,819,497     $ (7,132,365 )   $ 19,271,796  
 
                                         

18


Table of Contents

ITEM 2 —   MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
     These financial statements should be read in conjunction with the financial statements and the summary of significant accounting policies and notes included in the Company’s most recent annual report on Form 10-K.
Overview
     Apache Corporation (Apache or the Company) reported first-quarter 2006 earnings of $660 million, 18 percent higher than the $559 million reported in the first quarter of 2005. Cash provided by operating activities totaled $1 billion, $207 million more than the first quarter of 2005. The improvements in earnings and cash flow reflect higher price realizations for both crude oil and natural gas and an eight percent increase in average daily gas production. Crude oil production was eight percent below the comparable 2005 quarter, primarily from Gulf of Mexico production remaining shut-in because of Hurricanes Katrina and Rita. The improvement in prices more than offset the impact of generally rising costs on net income. Robust commodity prices in the oil and gas industry generally drive an increase in demand for services and thus are typically accompanied by higher service costs. Also, while we benefit from high oil and natural gas prices, those same high prices impact many of our lease operating expense components, such as chemicals, fuel and power. A more detailed discussion of these and other expense components can be found under the Costs section of this Item 2.
     Our 2006 first-quarter crude oil price realizations were up in all regions, averaging $57.41 per barrel on a consolidated basis, 25 percent higher than the first quarter of 2005. Continuing geopolitical tensions throughout the world and rising demand from developing nations, coupled with a reported precarious supply and demand balance, have often been pointed to as the catalysts driving crude oil prices higher, even in the face of rising U.S. crude oil inventory levels. Going forward, many other factors could impact both the price we receive for our crude oil and our ultimate net profit. On April 24, 2006, the U.S. administration announced suspension of oil deliveries into the Strategic Petroleum Reserve. While the volumes associated with this policy shift are a pittance of daily U.S. demand, the symbolism, coupled with a growing hostility toward energy companies by the U.S. Congress, could have an impact on the price we receive for some of our crude oil and our profits. Calls for legislative action continue to grow, including price controls, a windfall profits tax and incentives to switch to alternative fuels. We believe any such legislation would be counter-productive by lessening the incentive to drill for new reserves, thereby exacerbating rather than helping meet the challenge of rising worldwide demand. However, 73 percent of Apache’s oil production in the first quarter was diversified outside of the United States. Natural gas realizations during the first quarter of 2006 averaged $6.37 per thousand cubic feet (Mcf) on a worldwide basis, 20 percent more than the same quarter in 2005. While the direction of natural gas price is more influenced by local conditions and events, at least some of the potential legislative action mentioned above could impact the price we receive for natural gas we supply in the U.S. In the first quarter, 56 percent of our gas production was outside the U.S. and 27 percent was outside North America.
     Other 2006 first-quarter financial and operating results include:
    Our oil and gas production revenues of $1.95 billion were 20 percent, or $324 million higher, than the 2005 first quarter. The higher revenues were driven by higher oil and natural gas prices and increased gas production.
 
    Debt at quarter’s end was 17.3 percent of total capitalization, 5.4 percent less than the 22.7 percent at the end of the first quarter of 2005. In addition, the Company had $504 million of cash on hand.
 
    Natural gas production averaged a record 1,359 million cubic feet per day (MMcf/d) with double-digit growth in all of our core natural gas producing regions except the Gulf Coast, where production was 17 percent lower, primarily because of lingering shut-ins from the 2005 hurricanes. Estimated first quarter production shut-in because of the hurricanes averaged 49 MMcf/d.
 
    Egypt’s production was up 37 percent to 213 MMcf/d with most of the improvement associated with our Khalda Concession Qasr field which commenced production during the third quarter of 2005.
 
    Australia’s natural gas production increased 40 MMcf/d, or 35 percent, to 154 MMcf/d compared to the prior-year equivalent quarter. The increase was related to production from the John Brookes field, which commenced during the second half of 2005.

19


Table of Contents

    Natural gas production averaged 247 MMcf/d from our U.S. Central Region, improving 18 percent from the 2005 first quarter primarily on productive drilling results.
 
    Canada’s production was up 39 MMcf/d from the prior-year quarter to 386 MMcf/d primarily on production Apache established on the ExxonMobil Grant Lands and new wells in the Nevis and Consort areas.
 
    Worldwide crude oil production averaged 220,460 barrels per day (b/d), 20,083 b/d less than the 2005 period. Estimated first quarter production shut-in in our Gulf Coast region because of the hurricanes averaged 17,822 b/d.
 
    Australia’s daily oil production was 25 percent below the prior-year period as natural decline, particularly in the Legendre and Linda fields, and loss of liquids from the East Spar field, more than offset production from the John Brookes, Mohave and Rose fields. Production from the latter three fields commenced in mid-to-late 2005. Production from the East Spar field ceased in early 2005. Production averaged 11,911 b/d during the 2006 first quarter compared to 15,976 b/d in the 2005 quarter.
 
    U.S. Central Region crude oil production averaged 30,311 b/d, a 4,571 barrel improvement over the prior-year quarter. Production from the Amerada Hess properties acquired in January 2006 and productive drilling results drove the gains.
     On April 25, 2006, we closed the acquisition of Pioneer Natural Resources’ (Pioneer) operations in Argentina and on April 19, 2006, we signed an agreement to acquire British Petroleum’s (BP) remaining producing properties on the Outer Continental Shelf of the Gulf of Mexico. We expect these two transactions to be additive to future earnings and cash flow with minimal impact on our oil and natural gas production mix. These transactions are discussed in more detail below in this Item 2.
     Capital Expenditures:
     Capital expenditures, exclusive of acquisitions, totaled $1 billion for the first three months of 2006, 14 percent higher than the comparable period last year. Expenditures for exploration and production activity accounted for approximately 90 percent, or $918 million, of the capital spending, a $126 million increase over last year’s first quarter. The remaining balance of capital spending was primarily for gathering, marketing and processing facilities which totaled $92 million, comparable with last year.
    In the U.S., the Company spent $320 million on exploration and development activity, including recompletions and production platforms and facilities. The Company drilled 112 wells in its Central region and 18 wells in the Gulf Coast region, 13 offshore and 5 onshore.
 
    Canada’s exploration and development capital totaled $376 million. The region drilled 344 wells, primarily in the Zama, Northeast British Columbia and ExxonMobil Grant Land areas. The capital investments also included recompletion activity and production facilities. Another $60 million was spent on gas gathering, transmission and processing facilities.
 
    Egypt drilled five exploration wells, resulting in three discoveries, 22 development/extension wells and completed various recompletions. Capital expenditures for exploration and development activity totaled $100 million. Gas gathering, transmission and processing facilities capital totaled $31 million.
 
    North Sea capital of $82 million included platform and production facility modifications, recompletions and new drilling activity.
 
    Australia’s capital for exploration and development totaled $34 million for the quarter.
     Acquisitions and Divestitures:
    On January 5, 2006, the Company completed its purchase of Amerada Hess’s interest in eight fields located in the Permian Basin of West Texas and New Mexico for $269 million, subject to post-closing adjustments.

20


Table of Contents

      Apache estimates that these fields contained proved reserves of 27 million barrels of liquid hydrocarbons and 27 billion cubic feet of natural gas as of year-end 2005. The Company had previously announced on October 13, 2005 that it had agreed to purchase Amerada Hess’s interest for $404 million. The price and number of properties involved in this transaction were reduced as a result of third parties exercising their preferential rights.
 
    On January 6, 2006, the Company completed the sale of its 55 percent interest in the deepwater section of Egypt’s West Mediterranean Concession to Amerada Hess for $413 million. Apache did not have any oil and gas reserves recorded for these properties. Apache first announced this transaction on October 13, 2005.
     Impact of 2005 Hurricanes:
     The hurricanes that struck the Gulf of Mexico in 2005 continue to impact the Company’s U.S. gulf coast operations, both onshore and offshore Louisiana and Texas. The hurricanes reduced Apache’s first quarter 2006 average annual daily production of natural gas by an estimated 49 MMcf/d and of crude oil by 17,822 b/d. As of March 31, 2006, approximately 40 MMcf/d of net natural gas production and 14,400 b/d of net crude oil production per day remained shut-in. While we have made significant progress in restoring production, a portion of the production will likely remain shut-in for the remainder of the year.
     The lost production resulted in an estimated $134 million reduction of crude oil and natural gas revenues during the quarter. The shut-in production, however, reduced depletion expense by $23 million for the period. The Company also accrued the remaining $71 million of business interruption insurance claims during the first quarter of 2006 in “Other” under “Revenues and Other” of the Statement of Consolidated Operations.
     As described in our 2005 Form 10-K, numerous operated and non-operated offshore production platforms and onshore facilities sustained damage as a result of the storms. The Company continues to incur costs to repair or abandon these properties, but total cost estimates remain consistent with prior periods. A portion of these costs incurred will be recovered through insurance proceeds. The estimated $492 million of abandonment obligations resulted in additional first quarter depletion expense of approximately $8 million and increased accretion expense of an additional $7 million.
     The Company continues to carry property damage insurance of $250 million per event in coverage provided through Oil Insurance Limited (OIL). However, in response to large losses caused by Hurricanes Katrina and Rita, OIL reassessed its 2006 surcharge for withdrawing from the mutual. The Company recorded an additional $12 million in OIL liability for this assessment during the first quarter. Premiums for OIL membership have remained similar to prior year charges. Unfortunately, we have noticed reduced insurance capacity for windstorm damage in the Gulf of Mexico and substantially increased premium rates. As a result, there is no assurance that Apache will be able to arrange equivalent insurance to cover its Gulf of Mexico exposures at a reasonable cost when the current policies expire.
     2006 Second-Quarter Events:
    On April 25, 2006, the Company completed the purchase of Pioneer’s operations in Argentina for $675 million. This transaction was first announced on January 17, 2006. Apache estimates the transaction includes proved reserves of 22 million barrels (MMbbls) of liquid hydrocarbons and 297 billion cubic feet (Bcf) of natural gas. The oil and gas assets are located in the Neuquen, San Jorge and Austral basins of Argentina. Net current production is approximately 9,000 b/d of liquid hydrocarbons and 125 MMcf/d of natural gas. The assets include five operated and three non-operated gas processing plants and 112 miles of operated pipelines in the Neuquen Basin. Also included are 2,200 square miles of 3-D seismic data.
 
    On April 19, 2006, the Company announced that it had finalized an agreement to acquire BP’s remaining producing properties on the Outer Continental Shelf of the Gulf of Mexico for $1.3 billion in cash. The properties include 18 producing fields (11 of which are operated) covering 92 blocks with estimated proved reserves of 27 million barrels of liquid hydrocarbons and 185 Bcf of natural gas. Some of the fields are subject to exercise of preferential rights to purchase by other interest owners. The transaction, which is subject to government approvals, is expected to close by the end of the second quarter.

21


Table of Contents

    On April 19, 2006, the Company announced that its Board of Directors authorized the purchase of up to 15 million shares of the Company’s common stock. The market value on the date of the announcement was approximately $1 billion. The Company may buy shares from time to time on the open market, in privately negotiated transactions, or a combination of both. The timing and amounts of any purchases will be at the discretion of Apache’s management. The Company initiated the program on May 1, 2006, after the Company’s first-quarter 2006 earnings information was disseminated in the market. Through May 8, 2006 the Company had purchased 1,500,000 of the shares authorized by its Board of Directors.

22


Table of Contents

Results of Operations
Revenues
     The table below presents oil and gas production revenues, production and average prices received from sales of natural gas, oil and natural gas liquids.
                         
    For the Quarter Ended March 31,  
                    Increase  
    2006     2005     (Decrease)  
Revenues (in thousands):
                       
Oil
  $ 1,138,998     $ 996,997       14.24 %
Natural gas
    779,399       600,950       29.69 %
Natural gas liquids
    31,901       28,702       11.15 %
 
                   
Total
  $ 1,950,298     $ 1,626,649       19.90 %
 
                   
Oil Volume – Barrels per day:
                       
United States
    59,290       73,630       (19.48 %)
Canada
    21,691       23,277       (6.81 %)
Egypt
    57,292       54,579       4.97 %
Australia
    11,911       15,976       (25.44 %)
North Sea
    64,445       61,870       4.16 %
China
    4,559       10,507       (56.61 %)
Argentina
    1,272       704       80.68 %
 
                   
Total
    220,460       240,543       (8.35 %)
 
                   
Average Oil Price – Per barrel:
                       
United States
  $ 50.22     $ 44.00       14.14 %
Canada
    54.17       47.14       14.91 %
Egypt
    60.89       48.77       24.85 %
Australia
    66.39       52.99       25.29 %
North Sea
    60.66       46.10       31.58 %
China
    58.12       33.91       71.39 %
Argentina
    39.30       33.97       15.69 %
Total
    57.41       46.05       24.67 %
Natural Gas Volume – Mcf per day:
                       
United States
    601,045       637,803       (5.76 %)
Canada
    385,982       346,742       11.32 %
Egypt
    212,874       155,328       37.05 %
Australia
    153,659       113,734       35.10 %
North Sea
    2,269       2,178       4.18 %
Argentina
    3,143       3,473       (9.50 %)
 
                   
Total
    1,358,972       1,259,258       7.92 %
 
                   
Average Natural Gas Price – Per Mcf:
                       
United States
  $ 7.41     $ 6.04       22.68 %
Canada
    7.73       5.59       38.28 %
Egypt
    4.41       4.30       2.56 %
Australia
    1.67       1.82       (8.24 %)
North Sea
    9.98       5.30       88.30 %
Argentina
    1.19       0.91       30.77 %
Total
    6.37       5.30       20.19 %
Natural Gas Liquids (NGL) – Barrels per day:
                       
United States
    7,553       9,104       (17.04 %)
Canada
    2,178       2,419       (9.96 %)
 
                   
Total
    9,731       11,523       (15.55 %)
 
                   
Average NGL Price – Per barrel:
                       
United States
  $ 36.52     $ 28.26       29.23 %
Canada
    36.10       25.46       41.79 %
Total
    36.43       27.68       31.61 %

23


Table of Contents

     Crude Oil Revenues
     First-quarter crude oil revenues increased $142 million from the comparable 2005 quarter on a $11.36 per barrel increase in average realized oil price, which more than offset an eight percent decline in daily production. All segments reported increases in realized crude oil price, with the North Sea and Egypt also benefiting from production growth compared to first quarter 2005.
     The North Sea’s first-quarter 2006 crude oil revenues were $95 million higher than the comparable quarter of 2005, reflecting higher price realizations and a four percent increase in production. The higher price realizations generated additional revenues of $81 million when compared to the same quarter in 2005, while the higher production added $14 million. The production growth reflects a successful drilling program and improved run-time.
     Egypt contributed additional revenues of $74 million in the first quarter of 2006 compared to the same quarter in 2005. This increase in revenue was primarily attributable to a 25 percent increase in crude oil price, with a 2,713 b/d increase in production generating $15 million of the increase in revenues. The production increase relates to discoveries at the East Bahariya, Umbarka and onshore West Mediterranean concessions plus additional Khalda sales through Qasr facilities.
     Canada’s first-quarter 2006 revenues increased $7 million over first quarter 2005 on a 15 percent increase in price, which offset a seven percent, or 1,586 b/d, decrease in oil production. Canada production was impacted by natural decline in the Zama, Midale, Virginia Hills and House Mountain operated areas, as well as natural decline on non-operated Karr Simonette which were partially offset by new drills in various fields.
     U.S. first-quarter 2006 crude oil revenues decreased $24 million compared to the same quarter of 2005. This decrease was the result of a 19 percent decrease in production while our crude oil price for first-quarter 2006 was 14 percent higher than the comparable 2005 quarter. The first-quarter 2006 average realized price includes an unfavorable $4.91 per barrel hedge loss. (See Note 2, Hedging and Derivative Instruments, of this Form 10-Q.) The U.S. production was impacted by hurricane downtime, natural decline and facility downtime which was partly offset by new drills and recompletions.
     China’s first-quarter 2006 revenues decreased $8 million compared to the first quarter of 2005 with $23 million of additional revenues related to a 71 percent increase in crude oil price, offset by a 57 percent decrease in net production. Apache’s volumes were down due to partner advances being fully recovered in the second half of 2005, thereby reducing Apache’s net entitlement volumes.
     Australia’s first quarter 2006 crude oil revenues decreased $5 million compared to the first quarter 2005. This decrease reflects a 25 percent decline in production partially offset by a 25 percent increase in price. The decrease in daily oil production resulted from inefficiencies in gas lift compression and decline in the Legendre field, lower liquids associated with ceased and declining production from East Spar and Linda gas fields and the impact of five cyclones in the first quarter of 2006. These declines were partially offset by condensate production associated with commencement of the John Brookes field and successful results from the Stag work and optimization program. Also, contributing were the Mohave, Artreus and Bambra fields, all of which began production during the second half of 2005.
     Approximately eight percent of our worldwide crude oil production was subject to financial derivative hedging for the first quarter of 2006 compared to six percent in 2005. Currently, all of our crude oil derivative positions have been designated against U.S. production. These financial derivative instruments reduced our first-quarter 2006 and 2005 worldwide realized price $1.32 and $.34 per barrel, respectively. (See Note 2, Hedging and Derivative Instruments, of this Form 10-Q for a summary of the current derivative positions and terms.)
     Natural Gas Revenues
     Our first-quarter 2006 natural gas revenues increased $178 million from the prior-year quarter as a 20 percent increase in our realized natural gas price generated an additional $121 million in gas revenues for the quarter. An eight percent increase in natural gas production added $57 million to first-quarter 2006 revenues, relative to the comparable prior-year quarter. While all of our reportable segments, except for Australia, realized an increase in natural gas price, the increase in the U.S. and Canada had the most significant impact on first quarter revenues.

24


Table of Contents

North Sea, Egypt and Australia also contributed increased gas revenues from higher production, while the additional price-driven revenues generated in the U.S. were partially offset by a six percent decline in production.
     U.S. first-quarter 2006 natural gas revenues were $54 million higher than the same quarter of 2005. U.S. first quarter natural gas prices, which were up 23 percent, contributed $79 million of additional revenues, while a six percent production decline, lowered revenues $25 million, when compared to the comparable prior-year quarter. While U.S. production was down quarter-over-quarter because of the hurricanes, natural declines and facility downtime, production gains in other areas, including an 18 percent gain in the Central region, offset some of the hurricane impact. The Central region was up on active drilling and recompletion programs and acquisitions.
     Canada’s first-quarter 2006 natural gas revenues increased $94 million over the comparable quarter of 2005. This increase related to a 38 percent increase in price and an 11 percent increase in production. Production increased 39,240 Mcf/d, as a result of successful drilling efforts at the Nevis, Zama, Consort areas and the ExxonMobil lands, which more than offset natural declines in the Ladyfern and other Northeast British Columbia areas.
     Egypt contributed an additional $24 million to first-quarter 2006 consolidated natural gas revenues compared to the same quarter of 2005. This increase is attributable to a favorable three percent price movement and a 37 percent increase in production. Egypt’s production growth was associated with nearly full production from the Khalda Concession’s Qasr field.
     Australia’s 2006 first quarter natural gas revenues were $5 million higher than the respective prior-year period. Australia’s natural gas production increased 35 percent compared to first-quarter 2005, while the price decreased eight percent over the 2005 quarter. The impact on revenues was minimal, given the relatively low natural gas price. The production increase related to commencement of production from the John Brookes field.
     Although a majority of our worldwide gas sales contracts are indexed to prevailing market prices, approximately nine percent and 10 percent of our first-quarter 2006 and 2005 U.S. natural gas production, respectively, was subject to long-term, fixed-price physical contracts. These fixed-price contracts reduced first-quarter 2006 and 2005 worldwide realized prices $.21 and $.11 per Mcf, respectively. Additionally, nearly all of our Australian natural gas production is subject to long-term, fixed-price supply contracts that are periodically adjusted for changes in Australia’s consumer price index. Since these contracts are denominated in Australian dollars, the resulting revenues are impacted by changes in the value of the Australian dollar relative to the U.S. dollar.
     Approximately eight percent and 12 percent of our worldwide natural gas production was subject to financial derivative hedges for the first-quarter of 2006 and 2005, respectively. Currently, all of our natural gas derivative positions have been designated against Gulf of Mexico production. These derivative financial instruments reduced our first-quarter 2006 and 2005 consolidated realized prices $.17 and $.02 per Mcf, respectively. (See Note 2, Hedging and Derivative Instruments, of this Form 10-Q for a summary of our current derivative positions and terms.)
Costs
     The table below presents a comparison of our expenses on an absolute dollar basis and an equivalent unit of production (boe) basis. Our discussion may reference either expenses on a boe basis or expenses on an absolute dollar basis, or both, depending on their relevance.
                                 
    For the Quarter Ended March 31,     For the Quarter Ended March 31,  
    2006     2005     2006     2005  
    (In millions)     (Per Boe)  
Depreciation, depletion and amortization:
                               
Oil and gas property and equipment
  $ 346     $ 320     $ 8.42     $ 7.69  
Other assets
    26       20       .64       .47  
Asset retirement obligation accretion
    21       13       .50       .32  
Lease operating costs
    292       233       7.09       5.61  
Gathering and transportation costs
    26       24       .64       .57  
Severance and other taxes
    146       72       3.56       1.74  
General and administrative expenses
    46       50       1.11       1.21  
Financing costs, net
    23       32       .57       .76  
 
                       
Total
  $ 926     $ 764     $ 22.53     $ 18.37  
 
                       

25


Table of Contents

Depreciation, Depletion and Amortization (DD&A)
     First-quarter 2006 full-cost DD&A expense of $346 million was $26 million higher than the comparative quarter of 2005. The Company’s 2006 first-quarter full-cost DD&A rate increased $.73 per boe, to $8.42, from the same quarter last year reflecting rising industry-wide drilling and finding costs, especially in the U.S. and Canada. The increase in costs, including increased estimates of future development costs, is related to increased demand for drilling services, a consequence of both higher oil and gas prices and the need to repair damage caused by the hurricanes Katrina and Rita. The increase in DD&A was mitigated by a decline in Egypt resulting from the sale of Egypt’s West Mediterranean concession.
     Lease Operating Costs (LOE)
     LOE increased $59 million from the first quarter of last year to $292 million in the first quarter of 2006. The increase was primarily associated with North America and was driven by higher service costs and increased insurance expense attributable to damages incurred in the 2005 hurricane season.
     First-quarter 2006 LOE per boe of $7.09 was $1.48 higher than the same quarter in 2005. Approximately one-third of the increase was associated with the volumes shut-in because of the hurricanes and a non-cash hurricane-related charge that is incurred only if the Company elects to terminate its membership in OIL, an insurance mutual with 80-plus members.
     The remaining increase in the per unit rate was attributable to higher service costs associated with rising commodity prices, driving increases in repair and maintenance costs, ad valorem costs, contract labor, and the impact of a weaker U.S. dollar on Canadian LOE. Historically, electricity, fuel and ad valorem costs have been directly impacted by rising commodity prices. Other service costs have historically risen as a result of increased activity, and hence demand, in high commodity price environments. On a region basis, the U.S. added $1.01, Canada $.33, the North Sea $.08 and China $.06 to our consolidated rate. Higher fuel and service costs drove the increase in the North Sea, while China’s increase in LOE per boe was a result of a decline in production volumes as partner advances were fully recovered in the second half of 2005, thereby reducing the Company’s net entitlement.
     For a more detailed discussion of production, refer to “Results of Operations – Revenues” of this Management’s Discussion and Analysis of Financial Condition and Results of Operations.
     Gathering and Transportation Costs
     Gathering and transportation costs totaled $26 million in the first quarter of 2006, up $2 million from the 2005 comparative quarter. The following table presents gathering and transportation costs paid by Apache to third-party carriers for each of the periods presented.
                 
    For the Quarter Ended  
    March 31,  
    2006     2005  
    (In millions)  
U.S.
  $ 8     $ 8  
Canada
    9       8  
North Sea
    7       7  
Egypt
    2       1  
 
           
Total Gathering and Transportation
  $ 26     $ 24  
 
           
     For the first quarter of 2006 and 2005, these costs were primarily related to the transportation of natural gas in our North American operations and transportation of oil in the North Sea.

26


Table of Contents

     Severance and Other Taxes
     First quarter 2006 severance and other taxes totaled $146 million, $74 million greater than the prior-year quarter. A detail of these taxes follows:
                 
    For the Quarter Ended  
    March 31,  
    2006     2005  
    (In millions)  
Severance taxes
  $ 31     $ 30  
U.K. PRT
    108       37  
Canadian taxes
    5       5  
Other
    2        
 
           
Total Severance and Other Taxes
  $ 146     $ 72  
 
           
     North Sea Petroleum Revenue Tax (PRT) is assessed on net profits from subject fields in the United Kingdom (U.K.) North Sea. The increase is attributable to a production increase of four percent, a 32 percent increase in oil realizations and a 15 percent decrease in deductible costs. Severance taxes are incurred in the U.S. and Australia. U.S. severance taxes increased $7 million in line with higher production revenues. Australia severance taxes were $7 million lower reflecting lower excise taxes on production from Legendre, which declined period over period.
     General and Administrative Expenses
     General and administrative expenses (G&A) were $4 million lower compared to the first quarter of 2005. The reduced cost is related to the relative impact of Apache’s stock-based compensation which was greater in the 2005 quarter than the 2006 quarter.
     Provision for Income Taxes
     First-quarter 2006 income tax expense was $74 million greater than the prior-year quarter. The additional income tax expense was driven by higher taxable income related to increased revenues. A slightly higher effective tax rate also contributed to the higher taxes. The effective rate in the 2006 quarter was 38.4 percent compared to 37.6 percent in the 2005 quarter.
Capital Resources and Liquidity
Financial Indicators
                 
    March 31,   December 31,
    2006   2005
Millions of dollars except as indicated
               
Cash
  $ 504     $ 229  
Current ratio
    1.10       .99  
Total debt
  $ 2,347     $ 2,192  
Shareholders’ equity
  $ 11,256     $ 10,541  
Percent of total debt to capitalization
    17 %     17 %
Floating-rate debt/total debt
    7 %      
Overview
     Apache’s primary uses of cash are exploration, development and acquisition of oil and gas properties, costs and expenses necessary to maintain continued operations, repayment of principal and interest on outstanding debt and payment of dividends.
     The Company funds its exploration and development activities primarily through net cash provided by operating activities (cash flow) and budgets capital expenditures based on projected cash flow. Our cash flow, both in the short-term and long-term, is impacted by highly volatile oil and natural gas prices, production levels, industry trends impacting operating expenses and drilling costs and our ability to continue to acquire or find high-margin

27


Table of Contents

reserves at competitive prices. For these reasons, we only forecast, for internal use by management, an annual cash flow. Longer term cash flow and capital spending projections are not used by management to operate our business. The annual cash flow forecasts are revised monthly in response to changing market conditions and production projections. Apache routinely adjusts capital expenditure budgets in response to the adjusted cash flow forecasts and market trends in drilling and acquisitions costs.
     The Company has historically utilized internally generated cash flow, committed and uncommitted credit facilities and access to both debt and equity capital markets for all other liquidity and capital resources needs. Apache’s ability to access the debt capital market is supported by its investment grade credit ratings. Apache’s senior unsecured debt is currently rated investment grade by Moody’s, Standard and Poor’s and Fitch with ratings of A3, A- and A, respectively. Because of the liquidity and capital resources alternatives available to Apache, including internally generated cash flows, Apache’s management believes that its short-term and long-term liquidity is adequate to fund operations, including its capital spending program, repayment of debt maturities and any amounts that may ultimately be paid in connection with contingencies.
     Given the Company’s current capital resource and liquidity position, an announcement was made in April 2006 that the Board of Directors authorized the purchase of up to 15 million shares of the Company’s common stock, currently valued at $1 billion. Shares may be purchased either in the open market or through privately negotiated transactions. The Company anticipates that any purchases will be made with excess cash flows and short-term borrowing, but the Company is not obligated to acquire any specific number of shares. The Company initiated the program on May 1, 2006, after the Company’s first-quarter 2006 earnings information was disseminated in the market. Through May 8, 2006 the Company had repurchased 1,500,000 of the shares authorized by its Board of Directors.
     The Company’s ratio of current assets to current liabilities was 1.10 at March 31, 2006, compared to .99 at December 31, 2005. The increase in the ratio is the result of an increase in current assets of $195 million and a decrease in current liabilities of $51 million. The increase in current assets was driven by an increase in cash, which more than doubled, slightly offset by a decrease in Prepaid Assets and Other. Timing of payments resulted in fluctuations occurring in all current liability categories.
Net Cash Provided by Operating Activities
     Apache’s net cash provided by operating activities for the first quarter of 2006 totaled $1 billion, up from $836 million for the same period in 2005. The increase in 2006 cash flow is attributed primarily to the significant increase in commodity prices, which generated additional oil and gas revenues. The Company’s average realized crude oil price increased 25 percent, a reflection of generally higher worldwide prices. The Company also saw a 20 percent increase in natural gas prices. Additional revenues generated from an eight percent increase in gas production also contributed to the increased cash flows. These increases were partially offset by higher LOE, U.K. PRT and higher income taxes, all of which are generally up because of higher commodity prices. The Company reviews production costs for each core area on a monthly basis and pursues alternatives in maintaining efficient levels of costs and expenses. For a more detailed discussion of commodity prices, production, costs and expenses, refer to the “Results of Operations” of this Item 2, Management’s Discussion and Analysis of Financial Condition and Results of Operations.
     Historically, fluctuations in commodity prices have been the primary reason for the Company’s short-term changes in cash flow from operating activities. Sales volume changes have also impacted cash flow in the short-term, but have not been as volatile as commodity prices. Apache’s long-term cash flow from operating activities is dependent on commodity prices, reserve replacement and the level of costs and expenses required for continued operations.
Debt
     During the first quarter of 2006, we continued to maintain our financial flexibility and build on our solid financial position. While our debt-to-capitalization ratio on March 31, 2006 remained constant from December 31, 2005 at 17 percent, cash on hand rose $275 million to $504 million. On March 31, 2006, the Company had long-term debt of $2.2 billion, consistent with our December 31, 2005 balance. The Company’s outstanding debt consisted of notes and debentures maturing in the years 2007 through 2096.

28


Table of Contents

     The Company has available a $1.20 billion commercial paper program which enables Apache to borrow funds for up to 270 days at competitive interest rates. Our weighted-average interest rate for commercial paper was 4.51 percent and 2.52 percent for the first quarter of 2006 and 2005, respectively. As of March 31, 2006, available borrowing capacity under our total credit facilities was $1.3 billion. If the Company is unable to issue commercial paper following a significant credit downgrade or dislocation in the market, the Company’s U.S. credit facilities are available as a 100 percent backstop.
     The Company was in compliance with the terms of the credit facilities as of March 31, 2006. Our $504 million in cash and cash equivalents on hand at March 31, 2006, was up $275 million from the $229 million available at the end of 2005.
     The Company is currently amending its existing 5-year revolving U.S. credit facility which is scheduled to mature on May 28, 2009. The amendment is expected to: 1) extend the maturity to May 28, 2011, 2) increase the size of the facility from $750 million to $1.5 billion and 3) reduce the facility fees and reduce the margin over LIBOR on loans. The company is also asking the lenders to extend the maturity dates of the $450 million U.S. credit facility, the $150 million Canadian facility and the $150 million Australian facility, for an additional year from May 12, 2010 to May 12, 2011. Once the amendment to the credit facility is final, the Company plans to increase its commercial paper program to $1.95 billion from $1.20 billion.
Stock Transactions
     The Company has used access to equity capital markets to fund significant acquisitions.
Oil and Gas Capital Expenditures
     The Company funded its exploration and production capital expenditures, including gathering, transportation and marketing facilities, of $1 billion and $884 million in the first quarter of 2006 and 2005, respectively, primarily with internally generated cash flow of $1 billion and $836 million, respectively, and its lines of credit and commercial paper program.
     The following table presents a summary of the Company’s capital expenditures for each of our reportable segments for the three months ended March 31, 2006 and 2005.
                 
    For the Quarter Ended  
    March 31,  
    2006     2005  
    (In thousands)  
Exploration and development:
               
United States
  $ 320,309     $ 213,285  
Canada
    375,851       316,149  
Egypt
    99,668       78,104  
Australia
    33,560       57,441  
North Sea
    82,001       118,856  
Other International
    6,318       7,946  
 
           
 
  $ 917,707     $ 791,781  
 
           
Capitalized Interest
  $ 14,193     $ 13,409  
 
           
Gas gathering, transmission and processing facilities
  $ 92,398     $ 92,635  
 
           
Acquisitions:
               
Oil and gas properties
  $ 256,840     $ 19,949  
 
           
Cash Dividend Payments
     The Company has paid cash dividends on its common stock for 41 consecutive years through 2005. Future dividend payments will depend on the Company’s level of earnings, financial requirements and other relevant factors. Common dividends paid during the first quarter of 2006 rose to $33 million, reflecting a slight increase in common shares outstanding and the 25 percent higher common stock dividend rate. The Company increased its quarterly cash

29


Table of Contents

dividend 25 percent, to 10 cents per share from eight cents per share, effective with the November 2005 dividend payment. During the first quarter of 2006, Apache paid $1.4 million in dividends on its Series B Preferred Stock issued in August 1998.
Contractual Obligations
     We are subject to various financial obligations and commitments in the normal course of operations. These contractual obligations represent known future cash payments that we are required to make and relate primarily to long-term debt, operating leases, pipeline transportation commitments and international commitments. The Company expects to fund these contractual obligations with cash generated from operating activities.
     Apache is also subject to various contingent obligations that become payable only if certain events or rulings were to occur. The inherent uncertainty surrounding the timing of and monetary impact associated with these events or rulings prevents any meaningful accurate measurement, which is necessary to assess any impact on future liquidity. Such obligations include environmental contingencies and potential settlements resulting from litigation. Apache’s management feels that it has adequately reserved for its contingent obligations. The Company has reserved approximately $11 million for environmental remediation. The Company has also reserved approximately $14 million for various legal liabilities, in addition to $71 million, plus accrued interest of $7.6 million for the Texaco China B.V. litigation.
     The Company’s future liquidity could be impacted by a significant downgrade of its credit ratings by Moody’s, Standard and Poor’s, and Fitch; however, we do not believe that such a sharp downgrade is reasonably likely. The Company’s credit facilities do not require the Company to maintain a minimum credit rating. In addition, generally under our commodity hedge agreements, Apache may be required to post margin or terminate outstanding positions if the Company’s credit ratings decline significantly. The negative covenants associated with our debt are outlined in greater detail in Item 7, Management’s Discussion and Analysis of Financial Condition and Results of Operations, “Capital Resources and Liquidity, Debt” in the Company’s 2005 Form 10-K.
Off-Balance Sheet Arrangements
     Apache does not currently utilize any off-balance sheet arrangements with unconsolidated entities to enhance liquidity and capital resource positions.
ITEM 3 – QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Commodity Risk
     The major market risk exposure is in the pricing applicable to our oil and gas production. Realized pricing is primarily driven by the prevailing worldwide price for crude oil and spot prices applicable to our United States and Canadian natural gas production. Prices received for oil and gas production have been and remain volatile and unpredictable. Average monthly oil price realizations, including the impact of fixed-price contracts and hedges, ranged from a low of $56.24 per barrel to a high of $58.88 per barrel during the first quarter of 2006. Average monthly gas price realizations, including the impact of fixed-price contracts and hedges, ranged from a monthly low of $5.34 per Mcf to a monthly high of $8.05 per Mcf during the same period. Based on the Company’s worldwide oil production levels, a $1.00 per barrel change in the weighted-average realized price of oil would increase or decrease revenues by $20 million. Based on the Company’s worldwide gas production levels, a $.10 per Mcf change in the weighted-average realized price of gas would increase or decrease revenues by $12 million.
     We periodically enter into hedges in conjunction with selected acquisitions to protect against commodity price volatility. These hedges effectively reduce price risk on a portion of our projected oil and natural gas production from acquisitions.
     Apache has historically only hedged long-term oil and gas prices related to a portion of its expected production associated with acquisitions. As such, the Company’s use of hedging activity remains at a correspondingly low level. In the first quarter of 2006, financial derivative hedges represented approximately eight percent of the total worldwide natural gas production and total worldwide crude oil production. Hedges in place are entirely related to U.S. production and represent approximately eight percent of worldwide production for natural gas and crude oil for the remainder of 2006.

30


Table of Contents

     On March 31, 2006, the Company had open natural gas derivative positions with a fair value of $(132) million. A 10 percent increase in natural gas prices would change the fair value by $(53) million. A 10 percent decrease in prices would change the fair value by $52 million. The Company also had open oil derivative positions with a fair value of $(160) million on March 31, 2006. A 10 percent increase in crude oil prices would change the fair value by $(65) million. A 10 percent decrease in prices would change the fair value by $64 million. See Note 2, Hedging and Derivative Instruments of this Form 10-Q, for notional volumes associated with the Company’s derivative contracts.
Interest Rate Risk
     The Company considers its interest rate risk exposure to be minimal as a result of fixing interest rates on approximately 93 percent of the Company’s debt. At March 31, 2006, total debt included $154 million of floating-rate debt. As a result, Apache’s annual interest costs in 2006 will fluctuate based on short-term interest rates on what is presently approximately seven percent of our total debt outstanding at March 31, 2006. The impact on cash flow of a 10 percent change in the floating interest rate would be approximately $192,000 per quarter on quarter’s end debt balances.
Foreign Currency Risk
     The Company’s cash flow stream relating to certain international operations is based on the U.S. dollar equivalent of cash flows measured in foreign currencies. In Australia, oil production is sold under U.S. dollar contracts and natural gas production is sold under fixed-price Australian dollar contracts. Over half the costs incurred for Australian operations are paid in Australian dollars. In Canada, the majority of oil and natural gas production is sold under Canadian dollar contracts. The majority of the costs incurred are paid in Canadian dollars. The North Sea oil production is sold under U.S. dollar contracts and the majority of costs incurred are paid in British pounds. In contrast, all oil and natural gas production in Egypt is sold for U.S. dollars and the majority of the costs incurred are denominated in U.S. dollars. Revenue and disbursement transactions denominated in Australian dollars, Canadian dollars and British pounds are converted to U.S. dollar equivalents based on the exchange rate as of the transaction date.
     A 10 percent change in the Australian and Canadian dollars and the British pound as of March 31, 2006 would result in a foreign currency net gain or loss of approximately $131 million. This is primarily driven from foreign currency effects on the Company’s deferred tax liability positions in its international operations.
     The information set forth under “Commodity Risk,” “Interest Rate Risk” and “Foreign Currency Risk” in Item 7A of our annual report on Form 10-K for the year ended December 31, 2005, is incorporated herein by reference. Information about market risks for the quarter ended March 31, 2006, does not differ materially from the disclosure in our 2005 Form 10-K, except as noted above.
Forward-Looking Statements And Risk
     Certain statements in this report, including statements of the future plans, objectives, and expected performance of the Company, are forward-looking statements that are dependent upon certain events, risks and uncertainties that may be outside the Company’s control, and which could cause actual results to differ materially from those anticipated. Some of these include, but are not limited to, the market prices of oil and gas, economic and competitive conditions, inflation rates, legislative and regulatory changes, financial market conditions, political and economic uncertainties of foreign governments, future business decisions, and other uncertainties, all of which are difficult to predict.
     There are numerous uncertainties inherent in estimating quantities of proved oil and gas reserves and in projecting future rates of production and the timing of development expenditures. The total amount or timing of actual future production may vary significantly from reserves and production estimates. The drilling of exploratory wells can involve significant risks, including those related to timing, success rates and cost overruns. Lease and rig availability, complex geology and other factors can affect these risks. Although Apache may make use of futures contracts, swaps, options and fixed-price physical contracts to mitigate risk, fluctuations in oil and natural gas prices or a prolonged continuation of low prices, may adversely affect the Company’s financial position, results of operations and cash flows.

31


Table of Contents

ITEM 4 – CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
     G. Steven Farris, the Company’s President, Chief Executive Officer and Chief Operating Officer, and Roger B. Plank, the Company’s Executive Vice President and Chief Financial Officer, evaluated the effectiveness of our disclosure controls and procedures as of March 31, 2006, the end of the period covered by this report. Based on that evaluation and as of the date of that evaluation, these officers concluded that the Company’s disclosure controls were effective, providing effective means to ensure that information we are required to disclose under applicable laws and regulations is recorded, processed, summarized and reported in a timely manner. We also made no significant changes in internal controls over financial reporting during the quarter ending March 31, 2006, that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.
     We periodically review the design and effectiveness of our disclosure controls, including compliance with various laws and regulations that apply to our operations both inside and outside the United States. We make modifications to improve the design and effectiveness of our disclosure controls, and may take other corrective action, if our reviews identify deficiencies or weaknesses in our controls.
Management’s Report on Internal Control over Financial Reporting
     The management report called for by Item 308(a) of Regulation S-K is incorporated herein by reference to Report of Management on Internal Control Over Financial Reporting, included on Page F-1 in Item 15 of the Company’s 2005 Form 10-K.
     The independent auditors attestation report called for by Item 308(b) of Regulation S-K is incorporated by reference to Report of Independent Registered Public Accounting Firm on Internal Control Over Financial Reporting, included on Page F-3 in Item 15 of the Company’s 2005 Form 10-K.
Changes in Internal Control over Financial Reporting
     There was no change in our internal controls over financial reporting during the period covered by this quarterly Report on Form 10-Q that materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

32


Table of Contents

PART II — OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
    The information set forth in Note 10 to the Consolidated Financial Statements contained in the Company’s annual report on Form 10-K for the year ended December 31, 2005 (filed with the SEC on March 14, 2006) is incorporated herein by reference.
ITEM 2.   CHANGES IN SECURITIES, USE OF PROCEEDS AND ISSUER PURCHASES OF EQUITY SECURITIES
    None
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
    None
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
    None
ITEM 5. OTHER INFORMATION
    None

33


Table of Contents

ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
  (a)   Exhibits
     
10.1 -
  Apache Corporation 401(k) Savings Plan, effective as of January 1, 2006.
 
   
10.2 -
  Apache Corporation Money Purchase Retirement Plan, effective as of January 1, 2006.
 
   
12.1 -
  Statement of computation of ratio of earnings to fixed charges and combined fixed charges and preferred stock dividends.
 
   
31.1 -
  Certification of Chief Executive Officer.
 
   
31.2 -
  Certification of Chief Financial Officer.
 
   
32.1 -
  Certification of Chief Executive Officer and Chief Financial Officer.
  (b)   Reports filed on Form 8-K
 
      The following current report on Form 8-K was filed by Apache during the fiscal quarter ended March 31, 2006:
 
      Item 8.01 – Other Events – dated January 17, 2006, filed January 18, 2006
 
      On January 17, 2006, Apache announced that it had agreed to purchase Pioneer Natural Resources’ oil and gas operations in Argentina for a total purchase price of $675 million, subject to the exercise of third party preferential purchase rights.
 
      Also on January 17, 2006, Apache announced that it had completed two transactions with Amerada Hess that were first announced in October 2005. In one transaction, Apache completed the sale of its 55 percent interest in the deepwater section of Egypt’s West Mediterranean Concession to Amerada Hess for $413 million. In a separate transaction, Apache also completed its purchase of Amerada Hess’ interests in eight fields located in the Permian Basin of West Texas and New Mexico for $269 million.

34


Table of Contents

SIGNATURES
     Pursuant to the requirements of Section 13 or 15(d) 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.
     
 
  APACHE CORPORATION
 
   
Dated: May 9, 2006
  / s / ROGER B. PLANK
 
   
 
  Roger B. Plank
 
  Executive Vice President and Chief Financial Officer
 
   
Dated: May 9, 2006
  / s / THOMAS L. MITCHELL
 
   
 
  Thomas L. Mitchell
 
  Vice President and Controller
 
  (Chief Accounting Officer)

 


Table of Contents

EXHIBIT INDEX
     
Exhibits    
10.1 -
  Apache Corporation 401(k) Savings Plan, effective as of January 1, 2006.
 
   
10.2 -
  Apache Corporation Money Purchase Retirement Plan, effective as of January 1, 2006.
 
   
12.1 -
  Statement of computation of ratio of earnings to fixed charges and combined fixed charges and preferred stock dividends.
 
   
31.1 -
  Certification of Chief Executive Officer.
 
   
31.2 -
  Certification of Chief Financial Officer.
 
   
32.1 -
  Certification of Chief Executive Officer and Chief Financial Officer.

34