e10vq
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
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þ |
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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934 |
For the Quarterly Period Ended March 31, 2008
OR
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o |
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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)
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Delaware
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41-0747868 |
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(State or Other Jurisdiction of
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(I.R.S. Employer |
Incorporation or Organization)
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Identification Number) |
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Suite 100, One Post Oak Central
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77056-4400 |
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2000 Post Oak Boulevard, Houston, TX
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(Zip Code) |
(Address of Principal Executive Offices)
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Registrants 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):
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Large accelerated filer: þ
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Accelerated filer: o
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Non-accelerated filer: o
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Smaller reporting company: o |
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(Do not check if a smaller reporting company) |
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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 Registrants common stock, outstanding as of March 31, 2008 |
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333,588,922 |
TABLE OF CONTENTS
PART I FINANCIAL INFORMATION
ITEM 1 FINANCIAL STATEMENTS
APACHE CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED OPERATIONS
(Unaudited)
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For the Quarter Ended March 31, |
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2008 |
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2007 |
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(In thousands, except per common share data) |
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REVENUES AND OTHER: |
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Oil and gas production revenues |
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$ |
3,177,949 |
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$ |
2,023,067 |
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Other |
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9,792 |
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(20,192 |
) |
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3,187,741 |
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2,002,875 |
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OPERATING EXPENSES: |
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Depreciation, depletion and amortization |
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620,489 |
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530,913 |
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Asset retirement obligation accretion |
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26,497 |
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24,064 |
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Lease operating expenses |
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454,638 |
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382,107 |
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Gathering and transportation |
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40,976 |
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31,263 |
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Taxes other than income |
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242,578 |
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109,970 |
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General and administrative |
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82,423 |
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67,862 |
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Financing costs, net |
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44,253 |
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42,063 |
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1,511,854 |
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1,188,242 |
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INCOME BEFORE INCOME TAXES |
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1,675,887 |
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814,633 |
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Current income tax provision |
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487,800 |
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186,522 |
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Deferred income tax provision |
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166,574 |
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135,162 |
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NET INCOME |
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1,021,513 |
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492,949 |
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Preferred stock dividends |
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1,420 |
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1,420 |
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INCOME ATTRIBUTABLE TO COMMON STOCK |
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$ |
1,020,093 |
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$ |
491,529 |
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NET INCOME PER COMMON SHARE: |
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Basic |
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$ |
3.06 |
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$ |
1.48 |
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Diluted |
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$ |
3.03 |
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$ |
1.47 |
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The accompanying notes to consolidated financial statements
are an integral part of this statement.
1
APACHE CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED CASH FLOWS
(Unaudited)
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For the Quarter Ended |
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March 31, |
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2008 |
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2007 |
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(In thousands) |
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CASH FLOWS FROM OPERATING ACTIVITIES: |
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Net income |
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$ |
1,021,513 |
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$ |
492,949 |
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Adjustments to reconcile net income to net cash
provided by operating activities: |
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Depreciation, depletion and amortization |
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620,489 |
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530,913 |
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Provision for deferred income taxes |
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166,574 |
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135,162 |
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Asset retirement obligation accretion |
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26,497 |
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24,064 |
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Other |
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9,611 |
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9,372 |
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Changes in operating assets and liabilities: |
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(Increase) decrease in receivables |
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(38,356 |
) |
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45,365 |
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(Increase) decrease in inventories |
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76,311 |
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(8,250 |
) |
(Increase) decrease in drilling advances and other |
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(911 |
) |
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(4,502 |
) |
(Increase) decrease in deferred charges and other |
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(8,914 |
) |
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3,304 |
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Increase (decrease) in accounts payable |
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55,869 |
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(3,296 |
) |
Increase (decrease) in accrued expenses |
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(111,511 |
) |
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(156,217 |
) |
Increase (decrease) in advances from gas purchasers |
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(9,449 |
) |
Increase (decrease) in deferred credits and noncurrent liabilities |
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(8,768 |
) |
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4,144 |
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NET CASH PROVIDED BY OPERATING ACTIVITIES |
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1,808,404 |
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1,063,559 |
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CASH FLOWS FROM INVESTING ACTIVITIES: |
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Additions to oil and gas property |
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(1,165,729 |
) |
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(1,109,095 |
) |
Acquisition of U.S. Permian Basin properties |
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(1,000,000 |
) |
Additions to gas gathering, transmission and processing facilities |
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(80,704 |
) |
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(96,427 |
) |
Restricted cash |
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(228,134 |
) |
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Proceeds from sale of oil and gas properties |
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192,932 |
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6,477 |
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Other, net |
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(123,264 |
) |
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(30,149 |
) |
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NET CASH USED IN INVESTING ACTIVITIES |
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(1,404,899 |
) |
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(2,229,194 |
) |
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CASH FLOWS FROM FINANCING ACTIVITIES: |
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Commercial paper and money market borrowings, net |
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(87,043 |
) |
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(298,128 |
) |
Fixed-rate debt borrowings |
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1,494,045 |
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Payments on fixed-rate debt |
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(353 |
) |
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(3,000 |
) |
Dividends paid |
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(84,672 |
) |
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(51,032 |
) |
Common stock activity |
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8,653 |
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5,821 |
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Treasury stock activity, net |
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(616 |
) |
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1,949 |
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Cost of debt and equity transactions |
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(288 |
) |
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(13,389 |
) |
Other |
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18,031 |
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5,313 |
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NET CASH PROVIDED BY FINANCING ACTIVITIES |
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(146,288 |
) |
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1,141,579 |
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NET INCREASE/(DECREASE) IN CASH AND CASH EQUIVALENTS |
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257,217 |
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(24,056 |
) |
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CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR |
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125,823 |
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140,524 |
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CASH AND CASH EQUIVALENTS AT END OF PERIOD |
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$ |
383,040 |
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$ |
116,468 |
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SUPPLEMENTARY CASH FLOW DATA: |
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Interest paid, net of capitalized interest |
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$ |
52,237 |
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$ |
13,263 |
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Income taxes paid, net of refunds |
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368,614 |
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136,757 |
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The accompanying notes to consolidated financial statements
are an integral part of this statement.
2
APACHE CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)
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March 31, |
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December 31, |
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2008 |
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2007 |
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(In thousands) |
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ASSETS |
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CURRENT ASSETS: |
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Cash and cash equivalents |
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$ |
383,040 |
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$ |
125,823 |
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Receivables, net of allowance |
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1,972,318 |
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1,936,977 |
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Inventories |
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490,423 |
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|
461,211 |
|
Drilling advances |
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112,873 |
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112,840 |
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Derivative instruments |
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448 |
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20,889 |
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Prepaid assets and other |
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94,001 |
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94,511 |
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3,053,103 |
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2,752,251 |
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PROPERTY AND EQUIPMENT: |
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Oil and gas, on the basis of full cost accounting: |
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Proved properties |
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35,778,792 |
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34,645,710 |
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Unproved properties and properties under
development, not being amortized |
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1,473,476 |
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1,439,726 |
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Gas gathering, transmission and processing facilities |
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2,287,157 |
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2,206,453 |
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Other |
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|
421,685 |
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|
416,149 |
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|
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39,961,110 |
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38,708,038 |
|
Less: Accumulated depreciation, depletion and amortization |
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(14,095,724 |
) |
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|
(13,476,445 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
25,865,386 |
|
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25,231,593 |
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|
|
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|
|
|
|
|
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OTHER ASSETS: |
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|
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Restricted cash |
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228,134 |
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|
|
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Goodwill, net |
|
|
189,252 |
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|
|
189,252 |
|
Deferred charges and other |
|
|
480,200 |
|
|
|
461,555 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
29,816,075 |
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|
$ |
28,634,651 |
|
|
|
|
|
|
|
|
The accompanying notes to consolidated financial statements
are an integral part of this statement.
3
APACHE CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(Unaudited)
|
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|
|
|
|
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|
|
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March 31, |
|
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December 31, |
|
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|
2008 |
|
|
2007 |
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|
(In thousands) |
|
LIABILITIES AND SHAREHOLDERS EQUITY |
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CURRENT LIABILITIES: |
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Accounts payable |
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$ |
683,581 |
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$ |
617,937 |
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Accrued operating expense |
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|
112,917 |
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|
112,453 |
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Accrued exploration and development |
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|
708,596 |
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|
600,165 |
|
Accrued compensation and benefits |
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|
135,072 |
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|
|
172,542 |
|
Accrued interest |
|
|
73,153 |
|
|
|
78,187 |
|
Accrued income taxes |
|
|
154,854 |
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|
|
73,184 |
|
Current debt |
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|
227,588 |
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|
|
215,074 |
|
Asset retirement obligation |
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|
271,476 |
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|
309,777 |
|
Derivative instruments |
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|
435,561 |
|
|
|
286,226 |
|
Other |
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|
197,684 |
|
|
|
199,471 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
3,000,482 |
|
|
|
2,665,016 |
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|
|
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LONG-TERM DEBT |
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3,911,924 |
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|
4,011,605 |
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DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES: |
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Income taxes |
|
|
3,953,792 |
|
|
|
3,924,983 |
|
Asset retirement obligation |
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|
1,553,814 |
|
|
|
1,556,909 |
|
Derivative instruments |
|
|
563,287 |
|
|
|
381,791 |
|
Other |
|
|
752,769 |
|
|
|
716,368 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,823,662 |
|
|
|
6,580,051 |
|
|
|
|
|
|
|
|
|
|
|
|
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|
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COMMITMENTS
AND CONTINGENCIES (Note 8) |
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SHAREHOLDERS EQUITY: |
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|
Preferred stock, no par value, 5,000,000 shares authorized
Series B, 5.68% Cumulative, $100 million aggregate
liquidation value, 100,000 shares issued and
outstanding |
|
|
98,387 |
|
|
|
98,387 |
|
Common stock, $0.625 par, 430,000,000 shares authorized,
341,906,506 and 341,322,088 shares issued, respectively |
|
|
213,691 |
|
|
|
213,326 |
|
Paid-in capital |
|
|
4,369,172 |
|
|
|
4,367,149 |
|
Retained earnings |
|
|
12,394,428 |
|
|
|
11,457,592 |
|
Treasury stock, at cost, 8,317,584 and 8,394,945 shares,
respectively |
|
|
(236,066 |
) |
|
|
(238,264 |
) |
Accumulated other comprehensive loss |
|
|
(759,605 |
) |
|
|
(520,211 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
16,080,007 |
|
|
|
15,377,979 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
29,816,075 |
|
|
$ |
28,634,651 |
|
|
|
|
|
|
|
|
The accompanying notes to consolidated financial statements
are an integral part of this statement.
4
APACHE CORPORATION AND SUBSIDIARIES
STATEMENT OF CONSOLIDATED SHAREHOLDERS EQUITY
(Unaudited)
|
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Accumulated |
|
|
|
|
|
|
|
|
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|
|
Series B |
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|
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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, 2006 |
|
|
|
|
|
|
$ |
98,387 |
|
|
$ |
212,365 |
|
|
$ |
4,269,795 |
|
|
$ |
8,898,577 |
|
|
$ |
(256,739 |
) |
|
$ |
(31,332 |
) |
|
$ |
13,191,053 |
|
Comprehensive income (loss): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
$ |
492,949 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
492,949 |
|
|
|
|
|
|
|
|
|
|
|
492,949 |
|
Commodity hedges, net of income tax
benefit of $87,020 |
|
|
(161,815 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(161,815 |
) |
|
|
(161,815 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income |
|
$ |
331,134 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Dividends: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,420 |
) |
|
|
|
|
|
|
|
|
|
|
(1,420 |
) |
Common ($.15 per share) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(49,654 |
) |
|
|
|
|
|
|
|
|
|
|
(49,654 |
) |
Common shares issued |
|
|
|
|
|
|
|
|
|
|
|
199 |
|
|
|
10,288 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10,487 |
|
Treasury shares issued, net |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,170 |
|
|
|
|
|
|
|
2,928 |
|
|
|
|
|
|
|
4,098 |
|
Compensation expense |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10,359 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
10,359 |
|
FIN 48 adoption |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(48,502 |
) |
|
|
|
|
|
|
|
|
|
|
(48,502 |
) |
Other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
48 |
|
|
|
252 |
|
|
|
|
|
|
|
|
|
|
|
300 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BALANCE AT MARCH 31, 2007 |
|
|
|
|
|
|
$ |
98,387 |
|
|
$ |
212,564 |
|
|
$ |
4,291,660 |
|
|
$ |
9,292,202 |
|
|
$ |
(253,811 |
) |
|
$ |
(193,147 |
) |
|
$ |
13,447,855 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BALANCE AT DECEMBER 31, 2007 |
|
|
|
|
|
|
$ |
98,387 |
|
|
$ |
213,326 |
|
|
$ |
4,367,149 |
|
|
$ |
11,457,592 |
|
|
$ |
(238,264 |
) |
|
$ |
(520,211 |
) |
|
$ |
15,377,979 |
|
Comprehensive income (loss): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Net income |
|
$ |
1,021,513 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,021,513 |
|
|
|
|
|
|
|
|
|
|
|
1,021,513 |
|
Commodity hedges, net of income tax
benefit of $123,133 |
|
|
(239,394 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(239,394 |
) |
|
|
(239,394 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Comprehensive income |
|
$ |
782,119 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Dividends: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Preferred |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,420 |
) |
|
|
|
|
|
|
|
|
|
|
(1,420 |
) |
Common ($.25 per share) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(83,271 |
) |
|
|
|
|
|
|
|
|
|
|
(83,271 |
) |
Common shares issued |
|
|
|
|
|
|
|
|
|
|
|
365 |
|
|
|
5,957 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,322 |
|
Treasury shares issued, net |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(545 |
) |
|
|
|
|
|
|
2,198 |
|
|
|
|
|
|
|
1,653 |
|
Compensation expense |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
13,592 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
13,592 |
|
Other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(16,981 |
) |
|
|
14 |
|
|
|
|
|
|
|
|
|
|
|
(16,967 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
BALANCE AT MARCH 31, 2008 |
|
|
|
|
|
|
$ |
98,387 |
|
|
$ |
213,691 |
|
|
$ |
4,369,172 |
|
|
$ |
12,394,428 |
|
|
$ |
(236,066 |
) |
|
$ |
(759,605 |
) |
|
$ |
16,080,007 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The accompanying notes to consolidated financial statements
are an integral part of this statement.
5
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 Companys most recent annual report on Form 10-K.
Reclassifications
Certain prior-period amounts have been reclassified to conform with current-year
presentations.
1. ACQUISITIONS AND DIVESTITURES
2008 Activity
Divestitures On January 29, 2008, the Company completed the sale of its interest in Ship
Shoal blocks 349 and 359 on the outer continental shelf of the Gulf of Mexico to W&T Offshore, Inc.
for $116 million, subject to normal post-closing adjustments.
On January 31, 2008, the Company completed the sale of non-strategic oil and gas properties in
the Permian Basin of West Texas to Vanguard Permian, LLC for $78 million, subject to normal
post-closing adjustments.
Subsequent Event On April 2, 2008, the Company completed the sale of non-strategic Canadian
properties to Central Global Resources for $112 million, subject to normal post-closing
adjustments.
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 of March 31, 2008, the total outstanding positions of Apaches
natural gas and crude oil cash flow hedges were as follows:
Collars
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
Production |
|
|
|
|
|
|
|
|
|
|
|
|
|
Average |
|
Fair Value |
Period |
|
Instrument Type |
|
Total Volumes |
|
Floor/Ceiling |
|
Asset/(Liability) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(In thousands) |
2008 |
|
US Gas Collars |
|
|
70,125,000 |
|
|
MMBtu |
|
|
$7.27 / 10.31 |
|
|
$ |
(50,872 |
) |
|
|
Canadian Gas Collars |
|
|
24,750,000 |
|
|
GJ |
|
|
6.41 / 10.04 |
|
|
|
(9,134 |
) |
|
|
Oil Collars |
|
|
9,762,500 |
|
|
Bbl |
|
|
64.12 / 78.96 |
|
|
|
(220,352 |
) |
|
2009 |
|
US Gas Collars |
|
|
18,250,000 |
|
|
MMBtu |
|
|
7.35 / 10.19 |
|
|
|
(16,980 |
) |
|
|
Canadian Gas Collars |
|
|
29,200,000 |
|
|
GJ |
|
|
6.32 / 9.83 |
|
|
|
(12,878 |
) |
|
|
Oil Collars |
|
|
8,591,000 |
|
|
Bbl |
|
|
61.13 / 77.07 |
|
|
|
(190,399 |
) |
|
2010 |
|
US Gas Collars |
|
|
1,350,000 |
|
|
MMBtu |
|
|
7.17 / 10.58 |
|
|
|
(1,402 |
) |
|
|
Oil Collars |
|
|
6,016,000 |
|
|
Bbl |
|
|
62.11 / 77.44 |
|
|
|
(118,165 |
) |
|
2011 |
|
Oil Collars |
|
|
4,377,000 |
|
|
Bbl |
|
|
65.83 / 84.41 |
|
|
|
(63,679 |
) |
|
2012 |
|
Oil Collars |
|
|
1,456,000 |
|
|
Bbl |
|
|
66.88 / 85.52 |
|
|
|
(19,397 |
) |
6
Options
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Production |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value |
Period |
|
Instrument Type |
|
Total Volumes |
|
Strike Price |
|
Asset/(Liability) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(In thousands) |
2008 |
|
Gas Put Option |
|
|
5,500,000 |
|
|
MMBtu |
|
$ |
8.75 |
|
|
$ |
1,419 |
|
|
2010 |
|
Oil Call Option |
|
|
368,000 |
|
|
Bbl |
|
|
129.50 |
|
|
|
1,656 |
|
|
2011 |
|
Oil Call Option |
|
|
1,095,000 |
|
|
Bbl |
|
|
134.17 |
|
|
|
5,144 |
|
|
2012 |
|
Oil Call Option |
|
|
364,000 |
|
|
Bbl |
|
|
138.00 |
|
|
|
1,973 |
|
Fixed-Price Swaps
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Weighted |
|
|
Production |
|
|
|
|
|
|
|
|
|
|
|
|
|
Average |
|
Fair Value |
Period |
|
Instrument Type |
|
Total Volumes |
|
Fixed-Price |
|
Asset/(Liability) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(In thousands) |
2008 |
|
Fixed-Price Oil Swap |
|
|
3,300,000 |
|
|
Bbl |
|
$ |
69.21 |
|
|
$ |
(99,090 |
) |
|
2009 |
|
Fixed-Price Oil Swap |
|
|
368,000 |
|
|
Bbl |
|
|
67.95 |
|
|
|
(9,681 |
) |
|
2010 |
|
Fixed-Price Oil Swap |
|
|
2,018,000 |
|
|
Bbl |
|
|
70.87 |
|
|
|
(45,304 |
) |
|
2011 |
|
Fixed-Price Oil Swap |
|
|
3,285,000 |
|
|
Bbl |
|
|
71.16 |
|
|
|
(70,025 |
) |
|
2012 |
|
Fixed-Price Oil Swap |
|
|
2,926,000 |
|
|
Bbl |
|
|
71.34 |
|
|
|
(59,140 |
) |
|
2013 |
|
Fixed-Price Oil Swap |
|
|
1,086,000 |
|
|
Bbl |
|
|
71.34 |
|
|
|
(21,518 |
) |
U.S. natural gas prices in the table above represent a weighted average of several contracts
entered into on a per million British thermal units (MMBtu) basis and are settled against a
combination of indices, including NYMEX Henry Hub, Panhandle Eastern Pipe Line and Houston Ship
Channel. The Canadian natural gas prices in the table above represent a weighted average of AECO
Index prices. These gas collars are entered into on a per gigajoule (GJ) basis, are converted to
U.S. dollars utilizing a March 31, 2008 exchange rate, and are settled against the AECO Index.
Crude oil prices in the table above primarily represent a weighted average of NYMEX WTI Cushing
Index prices on contracts entered into on a per barrel (Bbl) basis.
A reconciliation of the components of accumulated other comprehensive income (loss) in the
Statement of Consolidated Shareholders Equity related to Apaches commodity derivative activity is
presented in the table below:
|
|
|
|
|
|
|
|
|
|
|
Before tax |
|
|
After tax |
|
|
|
(In thousands) |
|
Unrealized loss on derivatives at December 31, 2007 |
|
$ |
(638,752 |
) |
|
$ |
(411,678 |
) |
Net losses realized into earnings |
|
|
92,653 |
|
|
|
59,634 |
|
Net change in derivative fair value |
|
|
(455,180 |
) |
|
|
(299,028 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Unrealized loss on derivatives at March 31, 2008 |
|
$ |
(1,001,279 |
) |
|
$ |
(651,072 |
) |
|
|
|
|
|
|
|
Based on market prices as of March 31, 2008, the Companys
unrealized loss in other comprehensive income totaled $1 billion
($651 million after tax). 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 $1 billion estimated unrealized loss on
derivatives as of March 31, 2008, approximately $437 million ($284 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.
7
3. DEBT
The Companys March 31, 2008 debt-to-capitalization ratio was 20 percent, down from 22 percent
at December 31, 2007.
In February 2008 the Company requested amendments to its existing $1.5 billion U.S. five-year
revolving credit facility to (a) extend the maturity date one year to May 28, 2013 and (b) remove
certain restrictions on our Australian entities including their ability to incur liens and issue
guarantees. The Company also requested amendments to its $450 million U.S. credit facility, $150
million Australian credit facility and $150 million Canadian credit facility to (a) extend the
maturity date one year to May 12, 2013, (b) remove certain restrictions on our Australian entities
including their ability to incur liens and issue guarantees, and (c) specific to the Australian
credit facility, giving the Company the option of increasing the size
of the facility up to a maximum amount of $400 million
from the current limit of $300 million by adding commitments from new or existing lenders.
Lenders approved the amendments removing certain restrictions on our Australian entities,
including their ability to incur liens and issue guarantees as well as the amendment allowing the
Company to increase the size of Australian credit facility to a maximum of $400 million. At March 31, 2008,
lenders had extended the maturity date on all of the credit facilities except for $50 million of
the $1.5 billion U.S. credit facility and $40 million
of the $450 million U.S. credit facility. In
April 2008, both U.S. amounts were extended and the Company increased the Australian credit
facility by $50 million to $200 million, leaving
$200 million, half the maximum amount.
Financing Costs, Net
Financing costs incurred during the periods noted are composed of the following:
|
|
|
|
|
|
|
|
|
|
|
For the Quarter Ended March 31, |
|
|
|
2008 |
|
|
2007 |
|
|
|
(In thousands) |
|
Interest expense |
|
$ |
69,307 |
|
|
$ |
65,732 |
|
Amortization of deferred loan costs |
|
|
851 |
|
|
|
694 |
|
Capitalized interest |
|
|
(21,577 |
) |
|
|
(21,776 |
) |
Interest income |
|
|
(4,328 |
) |
|
|
(2,587 |
) |
|
|
|
|
|
|
|
Financing costs, net |
|
$ |
44,253 |
|
|
$ |
42,063 |
|
|
|
|
|
|
|
|
4. INCOME TAXES
The Company estimates its annual effective income tax rate in recording its quarterly
provision for income taxes in the various jurisdictions in which the Company operates. Statutory
tax rate changes and other significant or unusual items are recognized as discrete items in the
quarter in which they occur.
Apache and its subsidiaries are subject to U.S. federal income tax as well as income tax in
various state and foreign jurisdictions. The Companys tax reserves are related to tax years that
may be subject to examination by the relevant taxing authority.
The Company is in Administrative Appeals with the United States Internal Revenue Service (IRS)
regarding the 2002 and 2003 tax years and under IRS audit for the 2004 and 2005 tax years. The
Company is also under audit in various states and in most of the Companys foreign jurisdictions as
part of its normal course of business.
8
5. CAPITAL STOCK
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, |
|
|
|
2008 |
|
|
2007 |
|
|
|
Income |
|
|
Shares |
|
|
Per Share |
|
|
Income |
|
|
Shares |
|
|
Per Share |
|
|
|
(In thousands, except per share amounts) |
|
Basic: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income attributable to common stock |
|
$ |
1,020,093 |
|
|
|
333,393 |
|
|
$ |
3.06 |
|
|
$ |
491,529 |
|
|
|
331,213 |
|
|
$ |
1.48 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Effect of Dilutive Securities: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Stock options and other |
|
|
|
|
|
|
3,156 |
|
|
|
|
|
|
|
|
|
|
|
2,089 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Diluted: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income attributable to common stock,
including assumed conversions |
|
$ |
1,020,093 |
|
|
|
336,549 |
|
|
$ |
3.03 |
|
|
$ |
491,529 |
|
|
|
333,302 |
|
|
$ |
1.47 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
The diluted earnings per share calculation excluded 30,500 and 1.6 million average shares of
common stock that were anti-dilutive for the quarters ending March 31, 2008 and 2007, respectively.
Common and Preferred Stock Dividends
During the first quarter of 2008 and 2007, Apache paid $83 million and $50 million,
respectively, in dividends on its common stock. The increase in the first-quarter 2008 common
stock dividends compared to the amount paid in the same period last year, including a special
cash dividend of 10 cents per common share paid March 18, 2008. 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.
Stock-Based Compensation
2005 Share Appreciation Plan On May 5, 2005, the Companys stockholders approved the 2005
Share Appreciation Plan that provided incentives for employees to double Apaches share price to
$108 by the end of 2008, with an interim goal of $81 to be achieved by the end of 2007. To achieve
the trigger price, the Companys stock price had to close at or above the stated threshold for 10
days out of any 30 consecutive trading days by the end of the stated period.
On June 14, 2007, Apaches share price exceeded the interim threshold for the required
10-days. As such, Apache will issue approximately one million shares of its common stock, after
minimum tax withholding requirements, in four equal installments. The first installment was issued
in July 2007. Subsequent installments will be issued in 2008, 2009 and 2010 to employees remaining
with the Company during that period.
On February 29, 2008, Apaches share price exceeded the second threshold for the required
10-days. As such, Apache will issue approximately two million shares of its common stock, after
minimum tax withholding requirements, in four equal installments. The first installment was issued
in March 2008. Subsequent installments will be issued in 2009, 2010 and 2011 to employees
remaining with the Company during that period.
2008
Share Appreciation Program On May 7, 2008, the Stock Option
Plan Committee of the Companys board of directors, pursuant to
the Apache Corporation 2007 Omnibus Equity Compensation Plan, approved the 2008
Share Appreciation Program (the Program) that provides incentives for employees to increase Apaches share price to
$216 by the end of 2012, with an initial goal of $162 to be achieved
by the end of 2010. To
achieve the trigger price, the Companys stock price must close at or above the stated threshold
for 10 trading days out of any 30 consecutive trading days by the end of the stated period. Under the
Program, if the first threshold is achieved, approximately 1.1 million shares would be awarded for an
intrinsic cost of $180 million. Achieving the second threshold
would result in awards of approximately 1.7
million shares for an intrinsic cost of $359 million.
Shares ultimately issued to employees would be
reduced by the required minimum tax withholding. Awards under the
Program are payable in five equal installments, beginning on a date
not more than 30 days after a threshold is attained for the required
measurement period and on the four succeeding anniversaries of the
attainment date.
Current
accounting practices dictate that, regardless of whether these
thresholds are ultimately achieved, the Company will recognize, over time, the
fair value cost determined at the grant date based on numerous assumptions,
including an estimate of the likelihood that Apaches stock
price will achieve these thresholds and the expected forfeiture rate.
As a result, the Company will recognize expense and capitalized costs
of approximately $191 million over the expected service life of the
plan.
The
weighted average fair value, based on a Monte Carlo Simulation
Model, was $82.14 per share, determined by using expected volatility
of 26.97 percent, an expected dividend yield of 0.50 percent, and a
risk free interest rate of 2.46 percent.
9
On May 7, 2008,
the Stock Option Plan Committee of Apache's board of directors
awarded its chief executive officer up to 250,000
restricted stock units, 50,000 of which will vest on July 1, 2009. The remaining 200,000 shares will vest ratably
on the first business day of each of 2010, 2011, 2012 and 2013. Upon vesting, the Company will issue one
share of the Company's common stock as settlement for each restricted stock unit. Thirty thousand of the
shares vesting each year will not be eligible for sale by the executive until such time as he retires or
otherwise terminates employment with the Company. The restricted
stock unit agreement, dated May 8,
2008, is included as Exhibit 10.4 to this quarterly report on Form 10-Q and incorporated herein by reference.
6. BUSINESS SEGMENT INFORMATION
Apache has production in six countries: the United States (Gulf Coast and Central regions),
Canada, Egypt, Australia, offshore the United Kingdom (U.K.) in the North Sea, and Argentina.
Early in the second quarter of 2008, we finalized contracts for two exploration blocks in Chile.
Financial information by country is presented below:
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
United |
|
|
|
|
|
|
|
|
|
|
|
|
|
U.K. |
|
|
|
|
|
Other |
|
|
|
|
States |
|
Canada |
|
Egypt |
|
Australia |
|
North Sea |
|
Argentina |
|
International |
|
Total |
|
|
|
|
|
(In thousands)
|
For the Quarter Ended
March 31, 2008 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and Gas Production Revenues |
|
$ |
1,369,468 |
|
|
$ |
406,262 |
|
|
$ |
671,898 |
|
|
$ |
124,099 |
|
|
$ |
516,376 |
|
|
$ |
89,846 |
|
|
$ |
|
|
|
$ |
3,177,949 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income (1) |
|
$ |
783,119 |
|
|
$ |
180,724 |
|
|
$ |
532,628 |
|
|
$ |
44,919 |
|
|
$ |
231,829 |
|
|
$ |
19,552 |
|
|
$ |
|
|
|
$ |
1,792,771 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Income (Expense): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
9,792 |
|
General and administrative |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(82,423 |
) |
Financing costs, net |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(44,253 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income Before Income Taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
1,675,887 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets |
|
$ |
12,515,032 |
|
|
$ |
7,459,446 |
|
|
$ |
3,708,017 |
|
|
$ |
2,076,730 |
|
|
$ |
2,330,861 |
|
|
$ |
1,715,456 |
|
|
$ |
10,532 |
|
|
$ |
29,816,075 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Quarter Ended
March 31, 2007 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and Gas Production Revenues |
|
$ |
861,317 |
|
|
$ |
320,170 |
|
|
$ |
396,607 |
|
|
$ |
104,184 |
|
|
$ |
273,608 |
|
|
$ |
67,181 |
|
|
$ |
|
|
|
$ |
2,023,067 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Operating Income (1) |
|
$ |
373,556 |
|
|
$ |
128,306 |
|
|
$ |
273,909 |
|
|
$ |
42,724 |
|
|
$ |
115,748 |
|
|
$ |
10,507 |
|
|
$ |
|
|
|
$ |
944,750 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other Income (Expense): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(20,192 |
) |
General and administrative |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(67,862 |
) |
Financing costs, net |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(42,063 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income Before Income Taxes |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
814,633 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total Assets |
|
$ |
12,663,370 |
|
|
$ |
5,978,178 |
|
|
$ |
2,603,969 |
|
|
$ |
1,442,133 |
|
|
$ |
1,894,525 |
|
|
$ |
1,459,814 |
|
|
$ |
11,818 |
|
|
$ |
26,053,807 |
|
|
|
|
|
|
|
1) |
|
Operating Income consists of oil and gas production revenues less depreciation, depletion and
amortization, asset retirement obligation accretion, lease operating expenses, gathering and
transportation costs, and taxes other than income. |
10
7. ASSET RETIREMENT OBLIGATION
The following table describes changes to the Companys asset retirement obligation (ARO)
liability for the quarter ended March 31, 2008:
|
|
|
|
|
|
|
2008 |
|
|
|
(In thousands) |
|
Asset retirement obligation at December 31, 2007 |
|
$ |
1,866,686 |
|
Liabilities incurred |
|
|
85,072 |
|
Liabilities settled |
|
|
(152,965 |
) |
Accretion expense |
|
|
26,497 |
|
|
|
|
|
|
|
|
|
|
Asset retirement obligation at March 31, 2008 |
|
|
1,825,290 |
|
Less current portion |
|
|
271,476 |
|
|
|
|
|
Asset retirement obligation, long-term |
|
$ |
1,553,814 |
|
|
|
|
|
The asset retirement obligation reflects the estimated present value of the amount of
dismantlement, removal, site reclamation and similar activities associated with our oil and gas
properties. The Company utilizes current retirement costs to estimate the expected cash outflows
for retirement obligations. To determine the current present value of this obligation, some key
assumptions the Company must estimate include the ultimate productive life of the properties, a
risk adjusted discount rate, and an inflation factor. To the extent future revisions to these
assumptions impact the present value of the existing ARO liability, a corresponding adjustment is
made to the oil and gas property balance.
Liabilities
settled primarily relate to individual properties plugged and abandoned during the
period. Most of the activity was in the Gulf of Mexico, a portion of which relates to
the continued abandonment activity on platforms lost in 2005 during Hurricanes
Katrina and Rita.
8.
COMMITMENTS AND CONTINGENCIES
Legal Matters
Grynberg As more fully described in Note 9 of the financial statements in our annual report
on Form 10-K for our 2007 fiscal year, in 1997, Jack J. Grynberg began filing lawsuits against
other natural gas producers, gatherers, and pipelines claiming that the defendants have under paid
royalty to the federal government and Indian tribes by mis-measurement of the volume and heating
content of natural gas and are responsible for acts of others who mis-measured natural gas. The
claims against Apache were dismissed, though Mr. Grynberg has appealed the dismissal. No material
changes in this matter have occurred since the filing of our most recent annual report on Form
10-K.
Argentine Environmental Claims In connection with the Pioneer acquisition in 2006, the
Company acquired a subsidiary of Pioneer in Argentina (PNRA) that is involved in various
administrative proceedings with environmental authorities in the Neuquén Province relating to
permits for and discharges from operations in that province. In addition, 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 relating to various environmental and remediation
claims. All of these matters are more fully described in Note 9 of the financial statements in our
annual report on Form 10-K for our 2007 fiscal year. No material change in the status of these
matters has occurred since the filing of our most recent annual report on Form 10-K.
Louisiana Restoration As more fully described in Note 9 of the financial statements in our
annual report on Form 10-K for our 2007 fiscal year, numerous surface owners have filed claims or
sent demand letters to various oil and gas companies, including Apache, claiming that, under either
expressed or implied lease terms or Louisiana law, they are liable for damage measured by the cost
of restoration of leased premises to their original condition as well as damages for contamination
and cleanup. No material change in the status of these matters has occurred since the filing of
our most recent annual report on Form 10-K.
Hurricane Related Litigation As more fully described in Note 9 of the financial statements in
our annual report on Form 10-K for our 2007 fiscal year, in a case styled Ned Comer, et al vs.
Murphy Oil USA, Inc., et al, Case No: 1:05-cv-00436; U.S.D.C., United States District Court,
Southern District of Mississippi., Mississippi property
11
owners allege that hurricanes meteorological effects increased in frequency and intensity due
to global warming, and there will be continued future damage from increasing intensity of storms
and sea level rises. They claim this was caused by the various defendants (oil and gas companies,
electric and coal companies, and chemical manufacturers). No material change in the status of this
matter has occurred since the filing of our most recent annual report on Form 10-K.
Other Matters The Company is involved in other litigation and is subject to government and
regulatory controls in the normal course of business. The Company has an accrued liability of
approximately $11 million for other legal contingencies that are probable of occurring and can be
reasonably estimated. It is managements 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 Companys financial position or results of operations.
Environmental Matters
As of March 31, 2008, the Company had an undiscounted reserve for environmental remediation of
approximately $26 million. The Company is not aware of any environmental claims existing as of
March 31, 2008, which have not been provided for or would otherwise have a material impact on its
financial position or results of operations. There can be no assurance, however, that current
regulatory requirements will not change, or past non-compliance with environmental laws will not be
discovered on the Companys properties.
Decommission of Downed Platforms
In January 2008, Apache, BP plc and Chevron Corporation entered into a contract with Well
Control, Inc, to decommission certain downed platforms and related well facilities located offshore
Louisiana in the Gulf of Mexico for a fixed fee of $750 million. Apaches portion is 37.5 percent,
or $281 million, which is included as part of the Companys
accrued asset retirement obligation.
9. FAIR VALUE MEASUREMENTS
The Company adopted SFAS No. 157, Fair Value Measurements, as of the beginning of 2008.
SFAS No. 157 defines fair value, and establishes disclosure requirements for assets and liabilities
presented at fair value on the consolidated balance sheet. The statement also provides a hierarchy
that prioritizes and defines the types of inputs used to measure fair value. Level 1 inputs
consist of unadjusted quoted prices for identical instruments in active markets, and have the
highest priority. Level 2 inputs consist of quoted prices for similar instruments. Level 3
valuations are derived from inputs which are significant and unobservable, and have the lowest
priority.
The following table presents the Companys material assets and liabilities measured at fair
value for each hierarchy level as of March 31, 2008.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Fair Value Measurements Using |
|
|
|
|
Level 1 |
|
Level 2 |
|
Level 3 |
|
Total Fair |
|
|
Inputs |
|
Inputs |
|
Inputs |
|
Value |
|
|
|
|
|
|
(In thousands) |
|
|
|
|
Assets: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivative instruments |
|
$ |
|
|
|
|
448 |
|
|
|
|
|
|
$ |
448 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Liabilities: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Derivative instruments |
|
$ |
|
|
|
|
998,848 |
|
|
|
|
|
|
$ |
998,848 |
|
12
Derivative instruments are valued using forward commodity price curves provided by reputable
third-party brokers. Some of our derivative instruments are not actively quoted in the market, and
are valued using Level 2 inputs.
10. RECENTLY ISSUED ACCOUNTING STANDARDS NOT YET ADOPTED
In March 2008, the Financial Accounting Standards Board (FASB) issued SFAS No. 161
Disclosures about Derivative Instruments and Hedging Activities. The statement amends SFAS No.
133 Accounting for Derivative Instruments and Hedging Activities. SFAS No. 161 changes the
disclosure requirements for derivative instruments and hedging activities. Entities are required
to provide enhanced disclosures about how and why an entity uses derivative instruments, how
derivative instruments and related hedged items are accounted for under SFAS No. 133 and how
derivative instruments and related hedged items affect an entitys financial position, financial
performance, and cash flows. SFAS No. 161 is effective for financial statements issued for fiscal
years beginning after November 15, 2008. We are currently evaluating the provisions of
SFAS No. 161 and assessing the impact, if any, it may have on the Company.
In December 2007, the FASB issued a revision to SFAS No. 141 Business Combinations
(SFAS No. 141(R)). The revision broadens the definition of a business combination to include all
transactions or other events in which control of one or more businesses is obtained. Further, the
statement establishes principles and requirements for how an acquirer recognizes assets acquired,
liabilities assumed and any non-controlling interests acquired. SFAS No. 141(R) is effective for
business combination transactions for which the acquisition date is on or after the beginning of
the first reporting period beginning on or after December 15, 2008. Early adoption is prohibited.
Apache is currently evaluating the provisions of SFAS No. 141(R) and assessing the impact, if any,
it may have on the Company.
Also in December 2007, the FASB issued SFAS No. 160 Noncontrolling Interests in Consolidated
Financial Statements. This statement amends Accounting Research Bulletin No. 51, Consolidated
Financial Statements. SFAS No. 160 establishes accounting and reporting standards for the
noncontrolling interests in a subsidiary and for the deconsolidation of a subsidiary. It clarifies
that a noncontrolling interest in a subsidiary, sometimes called a minority interest, is an
ownership interest in the consolidated entity that should be reported as equity in the consolidated
financial statements. Additionally, the amounts of consolidated net income attributable to both
the parent and the noncontrolling interest must be reported separately on the face of the income
statement. SFAS No. 160 is effective for fiscal years, and interim periods within those fiscal
years, beginning on or after December 15, 2008. Early adoption is prohibited. We are currently
evaluating the provisions of SFAS No. 160 and assessing the impact, if any, it may have on the
Company.
11. SUPPLEMENTAL GUARANTOR INFORMATION
Apache Finance Pty Ltd. (Apache Finance Australia) and Apache Finance Canada Corporation
(Apache Finance Canada) are subsidiaries of Apache that have issued publicly traded securities, and
the following condensed consolidating financial statements are 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 Apaches consolidated financial statements. As such, these condensed
consolidating financial statements should be read in conjunction with the financial statements of
Apache Corporation and Subsidiaries and notes.
13
APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS
For the Quarter Ended March 31, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
All Other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Apache |
|
|
Apache |
|
|
Subsidiaries |
|
|
|
|
|
|
|
|
|
Apache |
|
|
Apache |
|
|
Finance |
|
|
Finance |
|
|
of Apache |
|
|
Reclassifications |
|
|
|
|
|
|
Corporation |
|
|
North America |
|
|
Australia |
|
|
Canada |
|
|
Corporation |
|
|
& Eliminations |
|
|
Consolidated |
|
|
|
(In thousands) |
|
REVENUES AND OTHER: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas production revenues |
|
$ |
1,353,405 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
1,842,319 |
|
|
$ |
(17,775 |
) |
|
$ |
3,177,949 |
|
Equity in net income (loss) of affiliates |
|
|
643,089 |
|
|
|
8,050 |
|
|
|
10,926 |
|
|
|
89,593 |
|
|
|
(2,491 |
) |
|
|
(749,167 |
) |
|
|
|
|
Other |
|
|
(34 |
) |
|
|
|
|
|
|
|
|
|
|
14,657 |
|
|
|
(3,909 |
) |
|
|
(922 |
) |
|
|
9,792 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,996,460 |
|
|
|
8,050 |
|
|
|
10,926 |
|
|
|
104,250 |
|
|
|
1,835,919 |
|
|
|
(767,864 |
) |
|
|
3,187,741 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OPERATING EXPENSES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization. |
|
|
288,516 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
331,973 |
|
|
|
|
|
|
|
620,489 |
|
Asset retirement obligation accretion |
|
|
17,777 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
8,720 |
|
|
|
|
|
|
|
26,497 |
|
Lease operating expenses |
|
|
213,325 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
241,313 |
|
|
|
|
|
|
|
454,638 |
|
Gathering and transportation |
|
|
10,127 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
48,624 |
|
|
|
(17,775 |
) |
|
|
40,976 |
|
Taxes other than income |
|
|
54,209 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
188,369 |
|
|
|
|
|
|
|
242,578 |
|
General and administrative |
|
|
66,883 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
16,462 |
|
|
|
(922 |
) |
|
|
82,423 |
|
Financing costs, net |
|
|
37,473 |
|
|
|
|
|
|
|
4,497 |
|
|
|
14,113 |
|
|
|
(11,830 |
) |
|
|
|
|
|
|
44,253 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
688,310 |
|
|
|
|
|
|
|
4,497 |
|
|
|
14,113 |
|
|
|
823,631 |
|
|
|
(18,697 |
) |
|
|
1,511,854 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
INCOME (LOSS) BEFORE INCOME TAXES |
|
|
1,308,150 |
|
|
|
8,050 |
|
|
|
6,429 |
|
|
|
90,137 |
|
|
|
1,012,288 |
|
|
|
(749,167 |
) |
|
|
1,675,887 |
|
Provision (benefit) for income taxes |
|
|
286,637 |
|
|
|
|
|
|
|
(1,621 |
) |
|
|
159 |
|
|
|
369,199 |
|
|
|
|
|
|
|
654,374 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET INCOME |
|
|
1,021,513 |
|
|
|
8,050 |
|
|
|
8,050 |
|
|
|
89,978 |
|
|
|
643,089 |
|
|
|
(749,167 |
) |
|
|
1,021,513 |
|
Preferred stock dividends |
|
|
1,420 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,420 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
INCOME ATTRIBUTABLE TO COMMON STOCK |
|
$ |
1,020,093 |
|
|
$ |
8,050 |
|
|
$ |
8,050 |
|
|
$ |
89,978 |
|
|
$ |
643,089 |
|
|
$ |
(749,167 |
) |
|
$ |
1,020,093 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
14
APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS
For the Quarter Ended March 31, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
All Other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Apache |
|
|
Apache |
|
|
Subsidiaries |
|
|
|
|
|
|
|
|
|
Apache |
|
|
Apache |
|
|
Finance |
|
|
Finance |
|
|
of Apache |
|
|
Reclassifications |
|
|
|
|
|
|
Corporation |
|
|
North America |
|
|
Australia |
|
|
Canada |
|
|
Corporation |
|
|
& Eliminations |
|
|
Consolidated |
|
|
|
(In thousands) |
|
REVENUES AND OTHER: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas production revenues |
|
$ |
837,548 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
1,231,734 |
|
|
$ |
(46,215 |
) |
|
$ |
2,023,067 |
|
Equity in net income (loss) of affiliates |
|
|
296,573 |
|
|
|
4,480 |
|
|
|
7,830 |
|
|
|
38,010 |
|
|
|
(12,911 |
) |
|
|
(333,982 |
) |
|
|
|
|
Other |
|
|
306 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(20,498 |
) |
|
|
|
|
|
|
(20,192 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,134,427 |
|
|
|
4,480 |
|
|
|
7,830 |
|
|
|
38,010 |
|
|
|
1,198,325 |
|
|
|
(380,197 |
) |
|
|
2,002,875 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OPERATING EXPENSES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Depreciation, depletion and amortization. |
|
|
226,892 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
304,021 |
|
|
|
|
|
|
|
530,913 |
|
Asset retirement obligation accretion |
|
|
17,638 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,426 |
|
|
|
|
|
|
|
24,064 |
|
Lease operating expenses |
|
|
196,313 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
232,009 |
|
|
|
(46,215 |
) |
|
|
382,107 |
|
Gathering and transportation |
|
|
8,989 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
22,274 |
|
|
|
|
|
|
|
31,263 |
|
Taxes other than income |
|
|
32,135 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
77,835 |
|
|
|
|
|
|
|
109,970 |
|
General and administrative |
|
|
52,329 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
15,533 |
|
|
|
|
|
|
|
67,862 |
|
Financing costs, net |
|
|
34,372 |
|
|
|
|
|
|
|
4,513 |
|
|
|
14,112 |
|
|
|
(10,934 |
) |
|
|
|
|
|
|
42,063 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
568,668 |
|
|
|
|
|
|
|
4,513 |
|
|
|
14,112 |
|
|
|
647,164 |
|
|
|
(46,215 |
) |
|
|
1,188,242 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
INCOME (LOSS) BEFORE INCOME TAXES |
|
|
565,759 |
|
|
|
4,480 |
|
|
|
3,317 |
|
|
|
23,898 |
|
|
|
551,161 |
|
|
|
(333,982 |
) |
|
|
814,633 |
|
Provision (benefit) for income taxes |
|
|
72,810 |
|
|
|
|
|
|
|
(1,163 |
) |
|
|
(4,551 |
) |
|
|
254,588 |
|
|
|
|
|
|
|
321,684 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET INCOME |
|
|
492,949 |
|
|
|
4,480 |
|
|
|
4,480 |
|
|
|
28,449 |
|
|
|
296,573 |
|
|
|
(333,982 |
) |
|
|
492,949 |
|
Preferred stock dividends |
|
|
1,420 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,420 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
INCOME ATTRIBUTABLE TO COMMON STOCK |
|
$ |
491,529 |
|
|
$ |
4,480 |
|
|
$ |
4,480 |
|
|
$ |
28,449 |
|
|
$ |
296,573 |
|
|
$ |
(333,982 |
) |
|
$ |
491,529 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
15
APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Quarter Ended March 31, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 |
|
$ |
234,070 |
|
|
$ |
|
|
|
$ |
(5,381 |
) |
|
$ |
(2,119 |
) |
|
$ |
1,581,834 |
|
|
$ |
|
|
|
$ |
1,808,404 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Additions to oil and gas property |
|
|
39,109 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,240,040 |
) |
|
|
|
|
|
|
(1,200,931 |
) |
Additions to gas gathering,
transmission and processing
facilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(80,704 |
) |
|
|
|
|
|
|
(80,704 |
) |
Investment in subsidiaries, net |
|
|
(131,108 |
) |
|
|
(3,500 |
) |
|
|
|
|
|
|
|
|
|
|
(5,662 |
) |
|
|
140,270 |
|
|
|
|
|
Other, net |
|
|
(4,548 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(118,716 |
) |
|
|
|
|
|
|
(123,264 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET CASH USED IN INVESTING ACTIVITIES |
|
|
(96,547 |
) |
|
|
(3,500 |
) |
|
|
|
|
|
|
|
|
|
|
(1,445,122 |
) |
|
|
140,270 |
|
|
|
(1,404,899 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Debt borrowings |
|
|
92,691 |
|
|
|
|
|
|
|
1,880 |
|
|
|
369 |
|
|
|
126,235 |
|
|
|
(101,561 |
) |
|
|
119,614 |
|
Payments on debt |
|
|
(165,300 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(41,372 |
) |
|
|
|
|
|
|
(206,672 |
) |
Dividends paid |
|
|
(84,672 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(84,672 |
) |
Common stock activity |
|
|
8,653 |
|
|
|
3,500 |
|
|
|
3,500 |
|
|
|
|
|
|
|
31,709 |
|
|
|
(38,709 |
) |
|
|
8,653 |
|
Treasury stock activity, net |
|
|
(616 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(616 |
) |
Cost of debt and equity transactions |
|
|
(288 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(288 |
) |
Other |
|
|
17,693 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
17,693 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET CASH PROVIDED BY (USED IN) FINANCING
ACTIVITIES |
|
|
(131,839 |
) |
|
|
3,500 |
|
|
|
5,380 |
|
|
|
369 |
|
|
|
116,572 |
|
|
|
(140,270 |
) |
|
|
(146,288 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET INCREASE (DECREASE) IN CASH AND
CASH EQUIVALENTS |
|
|
5,684 |
|
|
|
|
|
|
|
(1 |
) |
|
|
(1,750 |
) |
|
|
253,284 |
|
|
|
|
|
|
|
257,217 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH AND CASH EQUIVALENTS AT
BEGINNING OF YEAR |
|
|
3,626 |
|
|
|
|
|
|
|
1 |
|
|
|
1,751 |
|
|
|
120,445 |
|
|
|
|
|
|
|
125,823 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH AND CASH EQUIVALENTS AT
END OF PERIOD |
|
$ |
9,310 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
1 |
|
|
$ |
373,729 |
|
|
$ |
|
|
|
$ |
383,040 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
16
APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
For the Quarter Ended March 31, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 |
|
$ |
352,318 |
|
|
$ |
|
|
|
$ |
(3,562 |
) |
|
$ |
(641 |
) |
|
$ |
715,444 |
|
|
$ |
|
|
|
$ |
1,063,559 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM INVESTING ACTIVITIES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Additions to oil and gas property |
|
|
(479,825 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(629,270 |
) |
|
|
|
|
|
|
(1,109,095 |
) |
Acquisition of U.S. Permian Basin properties |
|
|
(1,000,000 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1,000,000 |
) |
Additions to gas gathering, transmission and
processing facilities |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(96,427 |
) |
|
|
|
|
|
|
(96,427 |
) |
Non-cash portion of net oil and gas property additions |
|
|
12,478 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(12,478 |
) |
|
|
|
|
|
|
|
|
Investment in subsidiaries, net |
|
|
(28,669 |
) |
|
|
(3,500 |
) |
|
|
|
|
|
|
|
|
|
|
(4,555 |
) |
|
|
36,724 |
|
|
|
|
|
Other, net |
|
|
(3,008 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(20,664 |
) |
|
|
|
|
|
|
(23,672 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET CASH USED IN INVESTING ACTIVITIES |
|
|
(1,499,024 |
) |
|
|
(3,500 |
) |
|
|
|
|
|
|
|
|
|
|
(763,394 |
) |
|
|
36,724 |
|
|
|
(2,229,194 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH FLOWS FROM FINANCING ACTIVITIES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Debt borrowings |
|
|
2,730,165 |
|
|
|
|
|
|
|
64 |
|
|
|
641 |
|
|
|
38,220 |
|
|
|
(22,289 |
) |
|
|
2,746,801 |
|
Payments on debt |
|
|
(1,530,500 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(23,384 |
) |
|
|
|
|
|
|
(1,553,884 |
) |
Dividends paid |
|
|
(51,032 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(51,032 |
) |
Common stock activity |
|
|
5,821 |
|
|
|
3,500 |
|
|
|
3,500 |
|
|
|
|
|
|
|
7,435 |
|
|
|
(14,435 |
) |
|
|
5,821 |
|
Treasury stock activity, net |
|
|
1,949 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,949 |
|
Cost of debt and equity transactions |
|
|
(13,389 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(13,389 |
) |
Other |
|
|
5,313 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
5,313 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET CASH PROVIDED BY (USED IN) FINANCING
ACTIVITIES |
|
|
1,148,327 |
|
|
|
3,500 |
|
|
|
3,564 |
|
|
|
641 |
|
|
|
22,271 |
|
|
|
(36,724 |
) |
|
|
1,141,579 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
NET INCREASE (DECREASE) IN CASH AND
CASH EQUIVALENTS |
|
|
1,621 |
|
|
|
|
|
|
|
2 |
|
|
|
|
|
|
|
(25,679 |
) |
|
|
|
|
|
|
(24,056 |
) |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH AND CASH EQUIVALENTS AT
BEGINNING OF YEAR |
|
|
4,148 |
|
|
|
|
|
|
|
|
|
|
|
1 |
|
|
|
136,375 |
|
|
|
|
|
|
|
140,524 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CASH AND CASH EQUIVALENTS AT
END OF PERIOD |
|
$ |
5,769 |
|
|
$ |
|
|
|
$ |
2 |
|
|
$ |
1 |
|
|
$ |
110,696 |
|
|
$ |
|
|
|
$ |
116,468 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
17
APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEET
As of March 31, 2008
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
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 |
|
$ |
9,310 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
1 |
|
|
$ |
373,629 |
|
|
$ |
|
|
|
$ |
382,940 |
|
Receivables, net of allowance |
|
|
923,127 |
|
|
|
|
|
|
|
|
|
|
|
845 |
|
|
|
1,048,346 |
|
|
|
|
|
|
|
1,972,318 |
|
Inventories |
|
|
23,777 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
466,647 |
|
|
|
|
|
|
|
490,424 |
|
Drilling advances and others |
|
|
135,162 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
72,159 |
|
|
|
|
|
|
|
207,321 |
|
Short-term investment |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
100 |
|
|
|
|
|
|
|
100 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,091,376 |
|
|
|
|
|
|
|
|
|
|
|
846 |
|
|
|
1,960,881 |
|
|
|
|
|
|
|
3,053,103 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
PROPERTY AND EQUIPMENT, NET |
|
|
11,884,797 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
13,980,589 |
|
|
|
|
|
|
|
25,865,386 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OTHER ASSETS: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Intercompany receivable, net |
|
|
1,180,244 |
|
|
|
|
|
|
|
(171,859 |
) |
|
|
(253,619 |
) |
|
|
(754,766 |
) |
|
|
|
|
|
|
|
|
Restricted cash |
|
|
228,134 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
228,134 |
|
Goodwill, net |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
189,252 |
|
|
|
|
|
|
|
189,252 |
|
Equity in affiliates |
|
|
10,656,425 |
|
|
|
494,186 |
|
|
|
713,330 |
|
|
|
2,228,928 |
|
|
|
(180,912 |
) |
|
|
(13,911,957 |
) |
|
|
|
|
Deferred charges and other |
|
|
235,862 |
|
|
|
|
|
|
|
|
|
|
|
1,003,589 |
|
|
|
240,749 |
|
|
|
(1,000,000 |
) |
|
|
480,200 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
25,276,838 |
|
|
$ |
494,186 |
|
|
$ |
541,471 |
|
|
$ |
2,979,744 |
|
|
$ |
15,435,793 |
|
|
$ |
(14,911,957 |
) |
|
$ |
29,816,075 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND SHAREHOLDERS EQUITY |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CURRENT LIABILITIES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Short-term debt |
|
$ |
66,300 |
|
|
$ |
|
|
|
$ |
99,911 |
|
|
$ |
|
|
|
$ |
61,377 |
|
|
$ |
|
|
|
$ |
227,588 |
|
Accounts payable |
|
|
471,603 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
211,978 |
|
|
|
|
|
|
|
683,581 |
|
Other accrued expenses |
|
|
495,009 |
|
|
|
|
|
|
|
(14,713 |
) |
|
|
51,898 |
|
|
|
1,557,119 |
|
|
|
|
|
|
|
2,089,313 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,032,912 |
|
|
|
|
|
|
|
85,198 |
|
|
|
51,898 |
|
|
|
1,830,474 |
|
|
|
|
|
|
|
3,000,482 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LONG-TERM DEBT |
|
|
3,264,011 |
|
|
|
|
|
|
|
|
|
|
|
647,014 |
|
|
|
899 |
|
|
|
|
|
|
|
3,911,924 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
DEFERRED CREDITS AND OTHER
NONCURRENT LIABILITIES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income taxes |
|
|
1,591,625 |
|
|
|
|
|
|
|
(37,913 |
) |
|
|
4,602 |
|
|
|
2,395,478 |
|
|
|
|
|
|
|
3,953,792 |
|
Advances from gas purchasers |
|
|
6,449 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
6,449 |
|
Asset retirement obligation |
|
|
957,689 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
596,125 |
|
|
|
|
|
|
|
1,553,814 |
|
Derivative instruments |
|
|
1,333,636 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(770,349 |
) |
|
|
|
|
|
|
563,287 |
|
Other |
|
|
1,487,641 |
|
|
|
|
|
|
|
|
|
|
|
9,070 |
|
|
|
249,609 |
|
|
|
(1,000,000 |
) |
|
|
746,320 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
5,377,040 |
|
|
|
|
|
|
|
(37,913 |
) |
|
|
13,672 |
|
|
|
2,470,863 |
|
|
|
(1,000,000 |
) |
|
|
6,823,662 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
COMMITMENTS AND CONTINGENCIES |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
SHAREHOLDERS EQUITY |
|
|
15,602,875 |
|
|
|
494,186 |
|
|
|
494,186 |
|
|
|
2,267,160 |
|
|
|
11,133,557 |
|
|
|
(13,911,957 |
) |
|
|
16,080,007 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
25,276,838 |
|
|
$ |
494,186 |
|
|
$ |
541,471 |
|
|
$ |
2,979,744 |
|
|
$ |
15,435,793 |
|
|
$ |
(14,911,957 |
) |
|
$ |
29,816,075 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
18
APACHE CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEET
As of December 31, 2007
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
All Other |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Apache |
|
|
|
|
|
Subsidiaries |
|
|
|
|
|
|
|
|
|
Apache |
|
|
Apache |
|
|
Finance |
|
|
Apache |
|
|
of Apache |
|
|
Reclassifications |
|
|
|
|
|
|
Corporation |
|
|
North America |
|
|
Australia |
|
|
Finance Canada |
|
|
Corporation |
|
|
& Eliminations |
|
|
Consolidated |
|
|
|
(In thousands) |
|
ASSETS |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CURRENT ASSETS: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Cash and cash equivalents |
|
$ |
3,626 |
|
|
$ |
|
|
|
$ |
1 |
|
|
$ |
1,751 |
|
|
$ |
120,445 |
|
|
$ |
|
|
|
$ |
125,823 |
|
Receivables, net of allowance |
|
|
883,022 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,053,955 |
|
|
|
|
|
|
|
1,936,977 |
|
Inventories |
|
|
25,445 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
435,766 |
|
|
|
|
|
|
|
461,211 |
|
Drilling advances and other |
|
|
140,335 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
87,905 |
|
|
|
|
|
|
|
228,240 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,052,428 |
|
|
|
|
|
|
|
1 |
|
|
|
1,751 |
|
|
|
1,698,071 |
|
|
|
|
|
|
|
2,752,251 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
PROPERTY AND EQUIPMENT, NET |
|
|
11,858,362 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
13,373,231 |
|
|
|
|
|
|
|
25,231,593 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
OTHER ASSETS: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Intercompany receivable, net |
|
|
1,080,893 |
|
|
|
|
|
|
|
(170,000 |
) |
|
|
(253,268 |
) |
|
|
(657,625 |
) |
|
|
|
|
|
|
|
|
Goodwill, net |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
189,252 |
|
|
|
|
|
|
|
189,252 |
|
Equity in affiliates |
|
|
8,924,250 |
|
|
|
451,161 |
|
|
|
670,908 |
|
|
|
2,137,603 |
|
|
|
(168,977 |
) |
|
|
(12,014,945 |
) |
|
|
|
|
Deferred charges and other |
|
|
211,399 |
|
|
|
|
|
|
|
|
|
|
|
1,003,668 |
|
|
|
246,488 |
|
|
|
(1,000,000 |
) |
|
|
461,555 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
23,127,332 |
|
|
$ |
451,161 |
|
|
$ |
500,909 |
|
|
$ |
2,889,754 |
|
|
$ |
14,680,440 |
|
|
$ |
(13,014,945 |
) |
|
$ |
28,634,651 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LIABILITIES AND SHAREHOLDERS EQUITY |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
CURRENT LIABILITIES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Accounts payable |
|
$ |
414,733 |
|
|
$ |
|
|
|
$ |
|
|
|
$ |
|
|
|
$ |
203,204 |
|
|
$ |
|
|
|
$ |
617,937 |
|
Other accrued expenses |
|
|
1,170,670 |
|
|
|
|
|
|
|
(12,994 |
) |
|
|
39,438 |
|
|
|
634,891 |
|
|
|
|
|
|
|
1,832,005 |
|
Current debt |
|
|
139,100 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
75,974 |
|
|
|
|
|
|
|
215,074 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
1,724,503 |
|
|
|
|
|
|
|
(12,994 |
) |
|
|
39,438 |
|
|
|
914,069 |
|
|
|
|
|
|
|
2,665,016 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
LONG-TERM DEBT |
|
|
3,263,820 |
|
|
|
|
|
|
|
99,890 |
|
|
|
646,996 |
|
|
|
899 |
|
|
|
|
|
|
|
4,011,605 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
DEFERRED CREDITS AND OTHER
NONCURRENT LIABILITIES: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Income taxes |
|
|
1,582,346 |
|
|
|
|
|
|
|
(37,148 |
) |
|
|
5,630 |
|
|
|
2,374,155 |
|
|
|
|
|
|
|
3,924,983 |
|
Advances from gas purchasers |
|
|
12,004 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
12,004 |
|
Asset retirement obligation |
|
|
962,287 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
594,622 |
|
|
|
|
|
|
|
1,556,909 |
|
Derivative instruments |
|
|
346,408 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
35,383 |
|
|
|
|
|
|
|
381,791 |
|
Other |
|
|
1,446,414 |
|
|
|
|
|
|
|
|
|
|
|
9,317 |
|
|
|
248,633 |
|
|
|
(1,000,000 |
) |
|
|
704,364 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
4,349,459 |
|
|
|
|
|
|
|
(37,148 |
) |
|
|
14,947 |
|
|
|
3,252,793 |
|
|
|
(1,000,000 |
) |
|
|
6,580,051 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
COMMITMENTS AND CONTINGENCIES |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
SHAREHOLDERS EQUITY |
|
|
13,789,550 |
|
|
|
451,161 |
|
|
|
451,161 |
|
|
|
2,188,373 |
|
|
|
10,512,679 |
|
|
|
(12,014,945 |
) |
|
|
15,377,979 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
$ |
23,127,332 |
|
|
$ |
451,161 |
|
|
$ |
500,909 |
|
|
$ |
2,889,754 |
|
|
$ |
14,680,440 |
|
|
$ |
(13,014,945 |
) |
|
$ |
28,634,651 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
19
ITEM 2 MANAGEMENTS 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 Companys most recent annual
report on Form 10-K.
Apache Corporation (Apache) is an independent energy company whose principle business includes
exploration, development and production of crude oil, natural gas and natural gas liquids. We
operate in six countries: the United States, Canada, Egypt, Australia, offshore the United Kingdom
in the North Sea, and Argentina. Early in the second quarter of 2008, we finalized contracts for
two exploration blocks in Chile. Quarterly earnings
were our second best on record, trailing only fourth-quarter 2007 earnings. In the first quarter,
we invested $1.2 billion in exploration and development, with several encouraging discoveries in
our core growth areas of Australia, Canada and Egypt. We also divested over $300 million of
non-strategic oil and gas properties during the quarter and early in the second quarter of 2008.
First Quarter 2008 vs. First Quarter 2007
Apache
earned just over $1.0 billion, $3.03 per diluted common share, in the first quarter of
2008, more than double the $492 million ($1.47 per share) earned in the same quarter last year.
Cash flow from operating activities totaled $1.8 billion, compared to $1.1 billion last year, an
increase of 70 percent.
Quarter-over-quarter increases in equivalent production and prices increased oil and gas
revenues 57 percent over last years first quarter, to $3.2 billion. Crude oil realizations
averaged $89.25 a barrel, 60 percent above 2007 first-quarter prices, while natural gas
realizations averaged $6.42 per thousand cubic feet (Mcf), up 23 percent. Even though historically
high commodity prices continue to increase industry demand and competition for services, thereby
pressuring costs, this quarters pre-tax margin was the best in our history, 96 percent higher
than the 2007 quarter. For a more detailed discussion of our revenue and cost components, please
refer to Results of Operations in this Item 2.
|
|
|
|
|
|
|
|
|
Pre-tax Margins |
|
|
For the Quarter Ended March 31, |
|
|
2008 |
|
2007 |
|
|
(In thousands, except margin) |
Income before Income Taxes |
|
$ |
1,675,887 |
|
|
$ |
814,633 |
|
Barrels of oil equivalent produced |
|
|
50,744 |
|
|
|
48,267 |
|
Margin per boe produced |
|
$ |
33.03 |
|
|
$ |
16.88 |
|
Operating Highlights
Egypt
|
¨ |
|
On January 24, 2008, the Company announced that the Hydra-1X exploration well in the
Shushan C Concession in Egypts Western Desert test-flowed 41.6 million cubic feet (MMcf)
of natural gas and 1,313 barrels of condensate per day from the Deep Jurassic formation and
encountered 64 feet of pay in the overlying AEB-6 formation on the way down that
test-flowed 35 MMcf and 1,500 barrels of condensate per day. We are currently drilling an
appraisal well to ascertain reserve potential. The Company has a 100 percent interest in
this concession. The Hydra-1X will be produced through future expansion of Apaches
Western Desert gas facilities. |
|
|
¨ |
|
Expansion of our Salam gas plant is on schedule and we continue to expect first
gas through the plant by the end of the year. This expansion is projected to add an
estimated 90 to 100 MMcf/d and 4,500 barrels of oil per day (b/d) of net capacity to
Apache. |
|
|
¨ |
|
Development of our three water-flood projects continues with 21 producers
and 23 injection wells drilled during the quarter. |
20
Australia
|
¨ |
|
Appraisal of the Julimar-Brunello area on Australias Northwest Shelf progressed with
three successful appraisal wells drilled since year-end. On January 24, the Company
announced the Brulimar-1 discovery which encountered 113 feet of net pay in the Upper
Triassic Mungaroo sandstone. On April 8, we announced the Julimar Southeast-1 discovery
which logged 195 feet of net pay across five intervals of the Triassic Mungaroo sandstone.
On May 1, we announced the Julimar Northwest-1 discovery which logged 43 feet of net pay in
the J-17 Triassic Mungaroo sandstone. We have now drilled six discoveries in the complex.
We plan to complete our appraisal program this summer and pursue a development strategy in
the second half of the year. Apache owns a 65 percent interest in and operates the
Julimar-Brunello complex. |
|
|
¨ |
|
During the first quarter, we completed a three-dimensional (3-D) seismic program in
Gippsland Basin of Australia, identifying a multiple prospect drilling program. The acreage, which
we believe is an under-explored area, is located near producing fields. We drilled three
shallow commitment wells in the quarter, all of which were unsuccessful. However, the
remaining prospects, which are in deeper water, are the
primary objective of the program. During the second half of the year, we will begin
drilling the 12 deeper water prospects. |
|
|
¨ |
|
On April 8, 2008, we announced the Halyard-1 discovery on Australias WA-13-L block,
which test-flowed 68 MMcf/d. We are considering running a subsea gathering line from
Halyard to an existing pipeline at our East Spar field, 20 miles to the southeast, to
transport the gas to Varanus Island for processing. Using our existing infrastructure
would accelerate development of the field and first sales. The pipeline has capacity of
200 MMcf/d. Apache has a 55 percent interest in and operates the block. |
|
|
¨ |
|
We have several large development projects underway in Australia. The Van Gogh and
Pyrenees developments remain on schedule to deliver first production in 2009 and 2010,
respectively, with projected net rates of 20,000 b/d each. Our Reindeer development
program is also on track to deliver approximately 60 MMcf/d net to Apache beginning in 2010
and we are in negotiations to contract the gas to a purchaser onshore. Efforts at Reindeer during the remainder of 2008 will consist of finalizing the
gas sales contract, drilling three development wells and beginning the detailed
engineering phase of the project. |
United States
|
¨ |
|
On January 29, 2008, the Company completed the sale of its interest in Ship Shoal blocks
349 and 359 on the outer continental shelf of the Gulf of Mexico to W&T Offshore, Inc. for
$116 million, subject to normal post-closing adjustments. |
|
|
¨ |
|
On January 31, 2008, the Company completed the sale of non-strategic oil and gas
properties in the Permian Basin of West Texas to Vanguard Permian, LLC for $78 million,
subject to normal post-closing adjustments. |
|
|
¨ |
|
The U.S. increased oil production to 100,679 b/d, a 35 percent increase over the
comparable prior year quarter with the addition of Permian Basin properties acquired at the end of the
first quarter of 2007, new drilling and recompletion activity, and production restored from
hurricane damaged properties. |
Canada
|
¨ |
|
On April 2, 2008, the Company announced that it had completed the sale of non-strategic
Canadian properties to Central Global Resources for $112 million, subject to normal
post-closing adjustments. |
|
|
¨ |
|
On April 8, 2008, Apache announced that three successful horizontal wells drilled in the
Ootla shale-gas play in northeast British Columbia test-flowed at rates of 8.8 MMcf, 6.1
MMcf, and 5.3 MMcf of gas per day. Apache has a 50 percent interest in approximately
400,000 gross acres in this play. Apache operates approximately one-half of this position. |
21
Financial Highlights
First-Quarter 2008 compared to First-Quarter 2007.
|
¨ |
|
Earnings of $1.0 billion, double last years $492 million. |
|
|
¨ |
|
Cash provided by operating activities of $1.8 billion, up 70 percent. |
|
|
¨ |
|
Oil and gas revenues of $3.2 billion, up 57 percent. Oil revenue alone increased nearly $1 billion. |
|
|
¨ |
|
Oil price realizations averaged a record $89.25 per barrel, up $33.38 per barrel; gas
price realizations averaged $6.42 per Mcf, up $1.20 per Mcf. |
|
|
¨ |
|
Exploration and development capital expenditures totaled $1.2 billion, up 14 percent. |
Results of Operations
Revenues
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Quarter Ended March 31, |
|
|
|
2008 |
|
|
Contribution |
|
|
2007 |
|
|
Contribution |
|
Revenues (in thousands): |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil |
|
$ |
2,119,720 |
|
|
|
67 |
% |
|
$ |
1,159,929 |
|
|
|
57 |
% |
Natural gas |
|
|
997,654 |
|
|
|
31 |
% |
|
|
826,761 |
|
|
|
41 |
% |
Natural gas liquids |
|
|
60,575 |
|
|
|
2 |
% |
|
|
36,377 |
|
|
|
2 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
3,177,949 |
|
|
|
100 |
% |
|
$ |
2,023,067 |
|
|
|
100 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
22
Production and Pricing
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Quarter Ended March 31, |
|
|
|
|
|
|
|
|
|
|
|
Increase |
|
|
|
2008 |
|
|
2007 |
|
|
(Decrease) |
|
Oil Volume Barrels per day: |
|
|
|
|
|
|
|
|
|
|
|
|
United States |
|
|
100,679 |
|
|
|
74,652 |
|
|
|
34.86 |
% |
Canada |
|
|
17,347 |
|
|
|
19,032 |
|
|
|
(8.85 |
)% |
Egypt |
|
|
62,551 |
|
|
|
60,371 |
|
|
|
3.61 |
% |
Australia |
|
|
9,420 |
|
|
|
12,141 |
|
|
|
(22.41 |
)% |
North Sea |
|
|
58,771 |
|
|
|
53,671 |
|
|
|
9.50 |
% |
Argentina |
|
|
12,225 |
|
|
|
10,797 |
|
|
|
13.23 |
% |
|
|
|
|
|
|
|
|
|
|
|
Total (1) |
|
|
260,993 |
|
|
|
230,664 |
|
|
|
13.15 |
% |
|
|
|
|
|
|
|
|
|
|
|
Average Oil Price Per barrel: |
|
|
|
|
|
|
|
|
|
|
|
|
United States |
|
$ |
83.58 |
|
|
$ |
55.89 |
|
|
|
49.54 |
% |
Canada |
|
|
93.21 |
|
|
|
53.62 |
|
|
|
73.83 |
% |
Egypt |
|
|
97.85 |
|
|
|
56.64 |
|
|
|
72.76 |
% |
Australia |
|
|
101.67 |
|
|
|
66.96 |
|
|
|
51.84 |
% |
North Sea |
|
|
95.83 |
|
|
|
56.35 |
|
|
|
70.06 |
% |
Argentina |
|
|
45.13 |
|
|
|
40.61 |
|
|
|
11.13 |
% |
Total (2) |
|
|
89.25 |
|
|
|
55.87 |
|
|
|
59.75 |
% |
Natural Gas Volume Mcf per day: |
|
|
|
|
|
|
|
|
|
|
|
|
United States |
|
|
744,014 |
|
|
|
739,828 |
|
|
|
.57 |
% |
Canada |
|
|
360,750 |
|
|
|
383,020 |
|
|
|
(5.81 |
)% |
Egypt |
|
|
242,977 |
|
|
|
243,485 |
|
|
|
(.21 |
)% |
Australia |
|
|
191,180 |
|
|
|
194,961 |
|
|
|
(1.94 |
)% |
North Sea |
|
|
2,605 |
|
|
|
1,889 |
|
|
|
37.90 |
% |
Argentina |
|
|
165,133 |
|
|
|
198,239 |
|
|
|
(16.70 |
)% |
|
|
|
|
|
|
|
|
|
|
|
Total (3) |
|
|
1,706,659 |
|
|
|
1,761,422 |
|
|
|
(3.11 |
)% |
|
|
|
|
|
|
|
|
|
|
|
Average Natural Gas Price Per Mcf: |
|
|
|
|
|
|
|
|
|
|
|
|
United States |
|
$ |
8.36 |
|
|
$ |
6.96 |
|
|
|
20.11 |
% |
Canada |
|
|
7.56 |
|
|
|
6.44 |
|
|
|
17.39 |
% |
Egypt |
|
|
5.20 |
|
|
|
4.06 |
|
|
|
28.08 |
% |
Australia |
|
|
2.12 |
|
|
|
1.77 |
|
|
|
19.77 |
% |
North Sea |
|
|
16.31 |
|
|
|
8.30 |
|
|
|
96.51 |
% |
Argentina |
|
|
1.84 |
|
|
|
1.14 |
|
|
|
61.40 |
% |
Total (4) |
|
|
6.42 |
|
|
|
5.22 |
|
|
|
22.99 |
% |
Natural Gas Liquids (NGL) Barrels per day: |
|
|
|
|
|
|
|
|
|
|
|
|
United States |
|
|
7,240 |
|
|
|
7,195 |
|
|
|
.63 |
% |
Canada |
|
|
2,235 |
|
|
|
2,232 |
|
|
|
.13 |
% |
Argentina |
|
|
2,720 |
|
|
|
2,635 |
|
|
|
3.23 |
% |
|
|
|
|
|
|
|
|
|
|
|
Total |
|
|
12,195 |
|
|
|
12,062 |
|
|
|
1.10 |
% |
|
|
|
|
|
|
|
|
|
|
|
Average NGL Price Per barrel: |
|
|
|
|
|
|
|
|
|
|
|
|
United States |
|
$ |
57.37 |
|
|
$ |
35.02 |
|
|
|
63.82 |
% |
Canada |
|
|
53.35 |
|
|
|
31.47 |
|
|
|
69.53 |
% |
Argentina |
|
|
48.18 |
|
|
|
31.10 |
|
|
|
54.92 |
% |
Total |
|
|
54.58 |
|
|
|
33.51 |
|
|
|
62.88 |
% |
|
|
|
(1) |
|
Approximately 17 percent of first-quarter 2008 production was subject to financial
derivative hedges, 14 percent in 2007. |
|
(2) |
|
Reflects per barrel reduction of $4.09 in first-quarter 2008 and a $.76 increase in
2007 from financial derivative hedging activities. |
|
(3) |
|
Approximately 18 percent of first-quarter 2008 production was subject to financial
derivative hedges, 14 percent in 2007. |
|
(4) |
|
Reflects per Mcf increase of $.03 in first-quarter 2008 and $.07 in 2007 from financial
derivative hedging activities. |
23
Contributions to Oil and Natural Gas Revenues
The following table presents each segments oil revenues and gas revenues as a percentage of
total oil revenues and gas revenues, respectively.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil Revenues |
|
Gas Revenues |
|
|
For the Quarter Ended |
|
For the Quarter Ended |
|
|
March 31, |
|
March 31, |
|
|
2008 |
|
2007 |
|
2008 |
|
2007 |
United States |
|
|
36 |
% |
|
|
32 |
% |
|
|
57 |
% |
|
|
56 |
% |
Canada |
|
|
7 |
% |
|
|
8 |
% |
|
|
25 |
% |
|
|
27 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
North America |
|
|
43 |
% |
|
|
40 |
% |
|
|
82 |
% |
|
|
83 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Egypt |
|
|
26 |
% |
|
|
27 |
% |
|
|
11 |
% |
|
|
11 |
% |
Australia |
|
|
4 |
% |
|
|
6 |
% |
|
|
4 |
% |
|
|
4 |
% |
North Sea |
|
|
24 |
% |
|
|
24 |
% |
|
|
|
|
|
|
|
|
Argentina |
|
|
3 |
% |
|
|
3 |
% |
|
|
3 |
% |
|
|
2 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
|
100 |
% |
|
|
100 |
% |
|
|
100 |
% |
|
|
100 |
% |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
First Quarter 2008 Compared to First Quarter 2007
Crude Oil Revenues First-quarter crude oil revenues increased $960 million on a 60 percent
increase in average realized price and a 13 percent increase in daily production.
U.S. oil revenues were $390 million higher, driven by a 50 percent increase in realized crude
oil prices and a 35 percent increase in daily production. Higher prices generated $272 million
more of revenues when compared to the 2007 period. Hedging activity reduced 2008 revenues by $97
million compared to a $16 million gain in the comparable 2007 period. Production increases
generated an additional $231 million in revenues, reflecting a 37 percent increase in Gulf Coast
region production and a 31 percent increase in Central region production. Gulf Coast region
production gains were associated with drilling and recompletion activity and production restored
from hurricane damaged properties. Central region production was up on an active drilling program
and additional volumes from Permian Basin properties acquired at the end of first-quarter 2007.
Egypts crude oil revenues increased $249 million on a 73 percent increase in realized price
and a four percent increase in daily crude oil production. Egypts 2008 price realizations, which
were up $41.21 to $97.85 per barrel, added $224 million to revenues while production gains added
the balance. Development drilling drove the production growth.
North
Sea oil revenues increased $241 million with a 70 percent higher realized price
generating an additional $191 million of revenues. Oil price realizations averaged $95.83, up
$39.48 per barrel. A combination of new wells and increased production efficiency resulting from
topside facilities work increased production 10 percent, to
58,771 b/d, increasing revenues by $50
million.
Canadas revenues increased $55 million. Realized prices were up 74 percent, adding $68
million in revenue and daily production declined nine percent reducing revenue by $13 million.
Canadas oil prices averaged $93.21 per barrel, up from $53.62. The lower production resulted from
natural decline in a number of fields.
Australias oil revenues increased $14 million. Additional revenues of $38 million generated
from a 52 percent increase in realized prices were partially offset by a 22 percent decline in
daily production. Australias realized prices averaged $101.67 per barrel, the highest in the
Company. Natural decline at Harriet, Stag, Legendre, Doric, Lee, West Cycad and Bambra fields
reduced production. An additional interest acquired in the Legendre field in March of 2007, and
liquids associated with Wonnich Deep gas well, lessened the impact of natural decline.
Argentinas crude oil revenues increased $11 million on a 13 percent increase in production
and an 11 percent increase in realized price. The higher production was related to successful
drilling, workover and recompletion activities.
Natural Gas Revenues First-quarter natural gas revenues increased $171 million, with $192
million of additional revenues generated from a 23 percent increase in realized natural gas prices
slightly reduced by a three percent decline in production. All core gas producing regions saw
higher natural gas revenues.
24
U.S. natural gas revenues increased $103 million. Higher realized prices added $101 million
to 2008 revenues and production growth contributed another $9 million. Hedging gains were $3
million, $7 million less than first-
quarter 2007. Natural gas prices averaged $8.36 per Mcf, up $1.40 from the comparable
year-ago quarter. Central region daily production was up 10 percent on drilling and recompletion
activities and incremental volumes from the Permian Basin properties acquired at the end of March
2007. Gulf Coast daily production was five percent lower on natural decline which more than offset
gains from drilling and recompletion activities and production restored from hurricane damaged
properties.
Egypt contributed an additional $26 million to consolidated natural gas revenues primarily
from a 28 percent increase in realized prices. Egypts price realizations were up $1.14 to $5.20
per Mcf.
Canadas natural gas revenues increased $26 million with a 17 percent increase in realized
natural gas price contributing $39 million of additional revenues. Gas price realizations climbed
$1.12 to $7.56 per Mcf. Natural gas production declined six percent, reducing revenues by $13
million. Lower production resulted from natural decline in numerous areas.
Argentinas natural gas revenues increased $7 million on a 61 percent increase in realized
price, which generated an additional $12 million in revenues. Argentinas price increased $.70 to
$1.84 per Mcf. A 17 percent decline in production reduced revenues $5 million. The production
decline was primarily caused by re-injection of gas in Tierra Del Fuego related to gas export and
pipeline restrictions and by declines in new Neuquén Basin wells.
Australias natural gas revenues were $6 million higher on a 20 percent price increase, offset
slightly by a two percent decline in production. Australias price averaged $2.12, up $.35 per
Mcf. Production was down on reduced customer demand.
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 expenses either on a boe
basis or on an absolute dollar basis, or both, depending on their relevance.
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
For the Quarter Ended March 31, |
|
|
For the Quarter Ended March 31, |
|
|
|
2008 |
|
|
2007 |
|
|
2008 |
|
|
2007 |
|
|
|
(In millions) |
|
|
(Per Boe) |
|
Depreciation, depletion and amortization: |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Oil and gas property and equipment |
|
$ |
583 |
|
|
$ |
497 |
|
|
$ |
11.50 |
|
|
$ |
10.29 |
|
Other assets |
|
|
37 |
|
|
|
34 |
|
|
|
.73 |
|
|
|
.71 |
|
Asset retirement obligation accretion |
|
|
27 |
|
|
|
24 |
|
|
|
.52 |
|
|
|
.50 |
|
Lease operating expenses |
|
|
455 |
|
|
|
382 |
|
|
|
8.96 |
|
|
|
7.92 |
|
Gathering and transportation |
|
|
41 |
|
|
|
31 |
|
|
|
.81 |
|
|
|
.65 |
|
Taxes other than income |
|
|
243 |
|
|
|
110 |
|
|
|
4.78 |
|
|
|
2.28 |
|
General and administrative expenses |
|
|
82 |
|
|
|
68 |
|
|
|
1.62 |
|
|
|
1.40 |
|
Financing costs, net |
|
|
44 |
|
|
|
42 |
|
|
|
.87 |
|
|
|
.87 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Total |
|
$ |
1,512 |
|
|
$ |
1,188 |
|
|
$ |
29.79 |
|
|
$ |
24.62 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
First Quarter 2008 Compared to First Quarter 2007
Depreciation, Depletion and Amortization (DD&A) The following table details the changes in
DD&A of oil and gas properties for the first quarter of 2008.
|
|
|
|
|
|
|
For the Quarter |
|
|
|
Ended |
|
|
|
March 31, 2008 |
|
|
|
(In millions) |
|
2007 DD&A |
|
$ |
497 |
|
Volume change |
|
|
29 |
|
Rate change |
|
|
57 |
|
|
|
|
|
2008 DD&A |
|
$ |
583 |
|
|
|
|
|
Full-cost DD&A expense of $583 million increased $86 million on an absolute dollar basis; $57
million on rate and $29 million from higher volumes. The Companys full-cost DD&A rate increased
$1.21 to $11.50 per boe. The increase in rate reflects drilling and finding costs that continue to
exceed our historical cost basis. The higher industry-wide costs, which also impact estimates of future development costs, are
driven by increased demand for drilling services, a consequence of both higher oil and gas prices.
25
Lease Operating Expenses (LOE) Our 2008 first-quarter LOE increased 19 percent on an absolute
dollar basis, however, only 13 percent on a per unit basis as four percent production growth
mitigated the impact of higher costs.
Our LOE rate increased $1.04 per boe as follows:
|
§ |
|
Higher workover activity, primarily on Permian Basin oil properties acquired at the
end of the first quarter of 2007, added $.45 |
|
|
§ |
|
A weaker U.S. dollar added $.30 per boe. Over the
past 12 months, the U.S. dollar
weakened 16 percent against the Canadian and Australian dollars, and one percent
against the British Pound. |
|
|
§ |
|
A non-cash charge to increase our OIL insurance early withdrawal penalty (incurred
if the Company terminates its membership in OIL; an insurance mutual) added $.11 per
boe. |
|
|
§ |
|
Stock-based compensation increased $.05 per boe on a 12 percent increase in stock
price during the first quarter of 2008 compared to six percent increase in the
comparative quarter of 2007. |
|
|
§ |
|
Last year included $.66 per boe of hurricane repair costs. |
|
|
§ |
|
The balance of the increase is related to higher operating costs in all regions,
driven by rising commodity prices, the acquisition of higher cost oil properties in the
U.S. Permian Basin and an additional interest in the higher cost Legendre oil field in
Australia. |
Gathering and Transportation Gathering and transportation costs totaled $41 million in the
first-quarter 2008, up $10 million. 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, |
|
|
|
2008 |
|
|
2007 |
|
|
|
(In millions) |
|
U.S |
|
$ |
10 |
|
|
$ |
9 |
|
Canada |
|
|
18 |
|
|
|
11 |
|
North Sea |
|
|
8 |
|
|
|
6 |
|
Egypt |
|
|
4 |
|
|
|
4 |
|
Argentina |
|
|
1 |
|
|
|
1 |
|
|
|
|
|
|
|
|
Total Gathering and Transportation |
|
$ |
41 |
|
|
$ |
31 |
|
|
|
|
|
|
|
|
The increase in Canada resulted primarily from the impact of higher transportation tariffs and
foreign exchange rates. North Sea costs were up on increased volumes and higher transportation
tariffs.
Taxes other than Income Taxes other than income totaled $243 million, an increase of $133
million. A detail of these taxes follows:
|
|
|
|
|
|
|
|
|
|
|
For the Quarter Ended |
|
|
|
March 31, |
|
|
|
2008 |
|
|
2007 |
|
|
|
(In millions) |
|
U.K. PRT |
|
$ |
165 |
|
|
$ |
61 |
|
Severance taxes |
|
|
47 |
|
|
|
29 |
|
Ad valorem taxes |
|
|
22 |
|
|
|
13 |
|
Canadian taxes |
|
|
4 |
|
|
|
5 |
|
Other |
|
|
5 |
|
|
|
2 |
|
|
|
|
|
|
|
|
Total Taxes other than Income |
|
$ |
243 |
|
|
$ |
110 |
|
|
|
|
|
|
|
|
North Sea Petroleum Revenue Tax (PRT) is assessed on net profits from subject fields in the
United Kingdom (U.K.) North Sea. U.K. PRT was $104 million more than the 2007 period on a 166
percent increase in net profits driven by higher production and prices. Severance taxes are
incurred primarily on onshore properties in the U.S. and certain properties in Australia and
Argentina. The increase in severance taxes resulted from higher taxable revenues in the U.S. and
Australia, consistent with the higher realized oil and natural gas prices. Ad valorem taxes
26
are
assessed on U.S. and Canadian properties. The $9 million increase resulted from higher taxable
valuations associated with increases in oil and natural gas prices and the acquisition of Permian
Basin properties late in the first quarter of 2007.
General and Administrative Expenses General and administrative expenses (G&A) were $14
million higher. On a boe basis, G&A averaged $1.62, up $.22 per boe. Higher stock based compensation, driven by
Apaches stock price appreciation, and increases in employee incentive-based bonuses added $.17 to our 2008 rate. The
balance of the increase in rate was related to additional fringe benefit costs, much of which came
about because of the incentive plans, as well as higher insurance costs. Apaches stock price
increased 12 percent during the first quarter of 2008 compared to six percent in the comparative
2007 quarter.
Provision for Income Taxes During interim periods, income tax expense is based on the
estimated effective income tax rate that is expected for the entire fiscal year. There were no
significant changes in statutory tax rates in the major jurisdictions in which the Company operates
during the first quarter of 2008 or 2007.
The provision for income taxes increased $333 million to $654 million, more than twice the
prior-year taxes, as income before taxes doubled on significantly higher oil and gas production
revenues. The effective income tax rate in the first quarter of 2008 was 39.0 percent compared to
39.5 percent in the first quarter of 2007. Apache recorded a $13 million reduction to tax expense
related to foreign currency fluctuations during the first quarter of 2008 compared to $2 million of
additional tax expense for the same 2007 period.
Capital Resources and Liquidity
Sources and Uses of Cash
The following table presents the sources and uses of our cash and cash equivalents for the
periods presented. The table presents capital expenditures on a cash basis; therefore, the amounts
differ from the amounts of capital expenditures, including accruals that are referred to elsewhere
in this document.
|
|
|
|
|
|
|
|
|
|
|
For the Quarter Ended |
|
|
|
March 31, |
|
|
|
2008 |
|
|
2007 |
|
|
|
(In millions) |
|
Sources of Cash and Cash Equivalents: |
|
|
|
|
|
|
|
|
Net Cash Provided by Operating Activities |
|
$ |
1,808 |
|
|
$ |
1,064 |
|
Sales of property and equipment |
|
|
193 |
|
|
|
6 |
|
Fixed-rate debt borrowings |
|
|
|
|
|
|
1,494 |
|
Common stock issuances |
|
|
9 |
|
|
|
6 |
|
Other |
|
|
18 |
|
|
|
6 |
|
|
|
|
|
|
|
|
|
|
|
2,028 |
|
|
|
2,576 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Uses of Cash and Cash Equivalents: |
|
|
|
|
|
|
|
|
Capital expenditures |
|
|
1,247 |
|
|
|
1,205 |
|
Restricted cash |
|
|
228 |
|
|
|
|
|
Acquisition U.S. Permian Basin properties |
|
|
|
|
|
|
1,000 |
|
Net commercial paper and money market repayments |
|
|
87 |
|
|
|
298 |
|
Payments of fixed-rate debt |
|
|
|
|
|
|
3 |
|
Dividends |
|
|
85 |
|
|
|
51 |
|
Cost of debt and equity transactions |
|
|
|
|
|
|
13 |
|
Other |
|
|
124 |
|
|
|
30 |
|
|
|
|
|
|
|
|
|
|
|
1,771 |
|
|
|
2,600 |
|
|
|
|
|
|
|
|
Increase (decrease) in cash and cash equivalents |
|
$ |
257 |
|
|
$ |
(24 |
) |
|
|
|
|
|
|
|
Net Cash Provided by Operating Activities Apaches net cash provided by operating activities
for the first quarter of 2008 totaled $1.8 billion, up $745 million from the same period in 2007.
For a detailed discussion of commodity prices, production, costs and expenses, refer to the
Results of Operations of this Item 2, Managements Discussion and Analysis of Financial Condition
and Results of Operations.
Historically, fluctuations in commodity prices have been the primary reason for the Companys
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. Apaches 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.
27
Capital Expenditures Capital expenditures totaled $1.4 billion for the first three months of
2008, compared to $2.3 billion for the comparable period last year. Acquisition capital in the
first-quarter 2007 exceeded $1 billion marking the difference between the two comparable periods.
The following table presents a summary of the Companys capital expenditures by country for the
three months ended March 31, 2008 and 2007.
|
|
|
|
|
|
|
|
|
|
|
For the Quarter Ended |
|
|
|
March 31, |
|
|
|
2008 |
|
|
2007 |
|
|
|
(In thousands) |
|
Exploration and Development: |
|
|
|
|
|
|
|
|
United States |
|
$ |
427,361 |
|
|
$ |
467,349 |
|
Canada |
|
|
223,896 |
|
|
|
201,501 |
|
Egypt |
|
|
187,185 |
|
|
|
145,062 |
|
Australia |
|
|
229,516 |
|
|
|
75,496 |
|
North Sea |
|
|
118,363 |
|
|
|
146,626 |
|
Argentina |
|
|
63,248 |
|
|
|
56,210 |
|
|
|
|
|
|
|
|
|
|
|
1,249,569 |
|
|
|
1,092,244 |
|
Acquisitions Oil and Gas Properties |
|
|
7,947 |
|
|
|
1,005,199 |
|
Asset Retirement Costs |
|
|
85,072 |
|
|
|
74,821 |
|
Capitalized Interest |
|
|
21,577 |
|
|
|
21,776 |
|
Gathering Transmission and Processing Facilities |
|
|
76,304 |
|
|
|
96,428 |
|
|
|
|
|
|
|
|
Total Capital Expenditures |
|
$ |
1,440,469 |
|
|
$ |
2,290,468 |
|
|
|
|
|
|
|
|
Exploration and
development (E&D) expenditures were up $157 million, or 14 percent, from the
2007 comparable quarter to $1.2 million. The U.S. accounted for 34 percent of
total E&D activity in first-quarter 2008, down from 43 percent in
the prior years comparable quarter. Expenditures in the U.S. were
down $40 million on lower drilling activity and less investment in platforms and production
facilities located in the Gulf of Mexico. Canada accounted for 18 percent of worldwide E&D
expenditures for both periods presented. Canadas E&D expenditures were up $22 million on
increased drilling activity. Australias portion of 2008
activity jumped to 18 percent from seven
percent because of an increase in drilling, relative to the 2007 period, and costs associated with
several platform and production facility development projects we initiated in early 2008. Australias
E&D expenditures totaled nearly $230 million, three-times 2007 spending. Egypt spent $42 million
more in the 2008 quarter on higher levels of drilling activity. North Sea E&D expenditures were
down $28 million on lower drilling activity.
Dividends Common
stock dividends paid during the first quarter of 2008 rose to $83 million,
including a special cash dividend of 10 cents
per common share paid on March 18, 2008. During the
first quarter of 2008 and 2007, Apache paid $1.4 million in dividends on its Series B Preferred
Stock issued in August 1998.
Liquidity
|
|
|
|
|
|
|
|
|
|
|
March 31, |
|
|
December 31, |
|
|
|
2008 |
|
|
2007 |
|
Millions of dollars except as indicated |
|
|
|
|
|
|
|
|
Cash |
|
$ |
383 |
|
|
$ |
126 |
|
Restricted cash |
|
$ |
228 |
|
|
$ |
|
|
Total debt |
|
$ |
4,140 |
|
|
$ |
4,227 |
|
Shareholders equity |
|
$ |
16,080 |
|
|
$ |
15,378 |
|
Available committed borrowing capacity |
|
$ |
2,186 |
|
|
$ |
2,115 |
|
Floating-rate debt/total debt |
|
|
3 |
% |
|
|
5 |
% |
Percent of total debt to capitalization |
|
|
20 |
% |
|
|
22 |
% |
Restricted Cash The Company classifies cash balances as restricted cash when cash is
restricted as to withdrawal or usage. As of March 31, 2008, the Company had approximately $228
million of property divestiture proceeds classified as restricted cash, and held in escrow to use
in a like-kind exchange under Section 1031 of the U.S. federal tax code. The Company intends to
use these funds to acquire noncurrent assets. Accordingly, the restricted cash is classified as
long term on the balance sheet.
28
Debt and Credit Facilities The Companys March 31, 2008 debt-to-capitalization ratio was 20
percent, down from 22 percent at December 31, 2007.
In February 2008 the Company requested amendments to its existing $1.5 billion U.S. five-year
revolving credit facility to (a) extend the maturity date one year to May 28, 2013 and (b) remove
certain restrictions on our Australian entities including their ability to incur liens and issue
guarantees. The Company also requested
amendments to its $450 million U.S. credit facility, $150 million Australian credit facility
and $150 million Canadian credit facility to (a) extend the maturity date one year to May 12, 2013,
(b) remove certain restrictions on our Australian entities including their ability to incur liens
and issue guarantees, and (c) specific to the Australian credit facility, giving the Company the
option of increasing the size of the facility up to a maximum amount
of $400 million from the current limit of $300 million by adding commitments
from new or existing lenders.
Lenders approved the amendments removing certain restrictions on our Australian entities,
including their ability to incur liens and issue guarantees as well as the amendment allowing the
Company to increase the size of Australian credit facility to a maximum of $400 million. The
lenders also extended the maturity date on all of the credit facilities except for $50 million of
the $1.5 billion U.S. credit facility and $40 million
of the $450 million U.S. credit facility. In
April 2008, both U.S. amounts were extended and the Company increased the Australian credit
facility by $50 million to $200 million, half the maximum amount.
The Company has available a $1.95 billion commercial paper program which enables Apache to
borrow funds for up to 270 days at competitive interest rates. As of March 31, 2008, Apache had
$64 million of commercial paper outstanding. Our weighted-average interest rate for commercial
paper was 3.91 percent and 5.36 percent for the first quarter of 2008 and 2007, respectively. If
the Company is unable to issue commercial paper following a significant credit downgrade or
dislocation in the market, the Companys U.S. credit facilities are available as a 100 percent
backstop. The Company had available borrowing capacity under our total credit facilities of
approximately $2.2 billion at March 31, 2008.
The Company was in compliance with the terms of all credit facilities as of March 31, 2008.
ITEM 3 QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Commodity Risk
We periodically enter into hedging activities on a portion of our projected oil and natural
gas production through a variety of financial and physical arrangements intended to support oil and
natural gas prices at targeted levels and to manage our overall exposure to oil and gas price
fluctuations. Apache may use futures contracts, swaps, options and fixed-price physical contracts
to hedge its commodity prices. Realized gains or losses from the Companys price risk management
activities are recognized in oil and gas production revenues when the associated production occurs.
Apache does not generally hold or issue derivative instruments for trading purposes.
Apache historically only hedged long-term oil and gas prices related to a portion of its
expected production associated with acquisitions; however, in 2006 and 2007, the Companys Board of
Directors authorized management to hedge a portion of production generated from the Companys
drilling program. Approximately 18 percent of our first-quarter 2008 natural gas and 17 percent of
our crude oil production was subjected to financial derivative hedges. Hedges in place for the
remainder of 2008 are expected to cover similar percentages of production.
On March 31, 2008, the Company had open natural gas derivative hedges in a liability position
with a fair value of $87 million. A 10 percent increase in natural gas prices would reduce the
fair value by approximately $68 million, while a 10 percent decrease in prices would increase the
fair value by approximately $60 million. The Company also had open oil derivatives in a liability
position with a fair value of $911 million. A 10 percent increase in oil prices would increase the
liability by approximately $392 million, while a 10 percent decrease in prices would decrease the
liability by approximately $379 million. These fair value changes assume volatility based on
prevailing market parameters at March 31, 2008. See Note 2 Hedging and Derivative Instruments of
the Notes to consolidated financial statements in this quarterly report on Form 10-Q for notional
volumes and terms associated with the Companys 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 97 percent of the Companys debt. At March 31, 2008, total debt
included $128 million of floating-rate debt. As a result, Apaches annual interest costs in 2008
will fluctuate based on short-term interest rates on what is presently approximately 3 percent of
our total debt outstanding at March 31, 2008. The impact on cash flow of a 10 percent change in the
floating interest rate would be approximately $0.2 million per quarter on March 31, 2008.
29
Foreign Currency Risk
The Companys 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 the majority of the gas production is sold under
fixed-price Australian dollar contracts. Approximately half of the costs incurred for Australian
operations are paid in U.S. dollars. In Canada, the majority of oil and gas
production is sold under Canadian dollar contracts. The majority of the costs incurred are
paid in Canadian dollars. The North Sea production is sold under U.S. dollar contracts and the
majority of costs incurred are paid in U.K. pounds. In Egypt, all oil and gas production is sold
under U.S. dollar contracts and the majority of the costs incurred are denominated in U.S. dollars.
Argentine revenues and expenditures are largely denominated in U.S. dollars, but converted into
Argentine pesos at the time of payment. Revenue and disbursement transactions denominated in
Australian dollars, Canadian dollars, British pounds, Egyptian pounds and Argentine pesos are
converted to U.S. dollar equivalents based on the average exchange rates during the period.
Foreign currency gains and losses also arise when monetary assets and monetary liabilities
denominated in foreign currencies are translated at the end of each month. Currency gains and
losses are included as either a component of Other under Revenues and Other, or, as is the case
when we re-measure our foreign tax liabilities, as a component of the Companys provision for
income tax expense on the Statement of Consolidated Operations.
Forward-Looking Statements And Risk
Certain statements in this quarterly report on Form 10-Q, 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 Companys 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
Companys financial position, results of operations and cash flows.
ITEM 4 CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
G. Steven Farris, the Companys President, Chief Executive Officer and Chief Operating
Officer, and Roger B. Plank, the Companys Executive Vice President and Chief Financial Officer,
evaluated the effectiveness of our disclosure controls and procedures as of March 31, 2008, 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 Companys disclosure controls and procedures 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 within the time
periods specified in the Commissions rules and forms and communicated to our management, including
our chief executive officer and chief financial officer, to allow timely decisions regarding
required disclosure.
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.
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.
30
PART II OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
Please refer to Part I, Item 3 of our Annual Report on Form 10-K for the fiscal year
ended December 31, 2007 (filed with the SEC on February 29, 2008) for a description of
material legal proceedings.
ITEM 1A. RISK FACTORS
During the quarter ending March 31, 2008, there were no material changes from the risk
factors as previously disclosed in the Companys Annual Report on Form 10-K for the year
ended December 31, 2007.
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
None
ITEM 3. DEFAULTS UPON SENIOR SECURITIES
None
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
None
ITEM 5. OTHER INFORMATION
Material Compensatory Arrangements
On May 7, 2008, the stock option plan committee of the board of directors (the Committee) approved two new compensatory arrangements pursuant to the Apache Corporation 2007 Omnibus Equity Compensation Plan (the Omnibus Plan).
2008 Share Appreciation Program
Pursuant to the Omnibus Plan, the Committee authorized and approved the 2008 Share Appreciation Program and estimated conditional grants of 2,773,000 shares of Company common stock to eligible participants under the 2008 Share Appreciation Program.
The primary purpose
of the 2008 Share Appreciation Program, like the Companys prior share appreciation plans,
is to provide incentives to our employees to work toward significant increases in stockholder
value. The conditional grants will vest upon attainment of an initial price threshold of $162 per
share of Company common stock prior to year end 2010 and a final price threshold of $216 per
share of Company common stock prior to year end 2012. The achievement of the $216 price threshold
would represent approximately $36 billion of growth in market value for the currently outstanding
shares of the Companys common stock, since attainment of the prior stock appreciation
plan price threshold in February 2008. If achieved, the conditional grants to our employees
would have an estimated total value of approximately two percent of such projected growth in market
capitalization. Consistent with prior share appreciation plans, more than 90 percent of the
incentives under the 2008 Share Appreciation Program would be paid to non-executive employees.
There are three categories of employees eligible to receive grants under the 2008 Share Appreciation Program. The first category is comprised of all executive officers, key technical professionals and senior managers. The second category is comprised of mid-level managers, supervisors and key administrative professionals. The third category is
comprised of entry level professionals, office administrative staff and field operators. For the $162 price threshold, the number of shares granted to an employee was determined by multiplying the recipients annual base salary by one times the recipients base salary for the first category, one-half times the recipients base salary for the second category, and one-fourth times the recipients base salary for the third category, and dividing the product by $162. For the $216 price threshold, the number of shares granted to an employee was determined by multiplying a recipients annual base salary by two times the recipients base salary for the first category, one times the recipients base salary for the second category, and one-half times the recipients base salary for the third category, and dividing the product by $216. The Committee, in its discretion, is authorized to reduce future conditional grants (to new employees, for example) to prorate benefits as it deems appropriate.
If a price threshold is reached for any ten trading days during any period of 30 consecutive trading days before the applicable threshold deadline, the shares (adjusted for required tax withholdings) will be paid out to recipients in five equal installments, with the first installment payable no later than 30 days after the expiration of such 10-day period. The remaining installments will be paid on the first, second, third, and fourth anniversaries of the attainment date.
A detailed description of the 2008 Share Appreciation Program is included as Exhibit 10.3 to this quarterly report on Form 10-Q and incorporated herein by reference.
Award of Restricted Stock Units to Chief Executive Officer
Pursuant to the Omnibus Plan, the Committee awarded G. Steven Farris, Apaches president and chief executive officer, 250,000 restricted stock units on May 7, 2008. 50,000 of such restricted stock units will vest on July 1, 2009, and 50,000 will vest on the first business day of each of 2010, 2011, 2012 and 2013.
Upon vesting, the Company will issue Mr. Farris one share of the Companys common stock as settlement for each restricted stock unit.
30,000 of the shares vesting each year will be subject to the restriction that none of such 30,000 shares will be eligible for sale by Mr. Farris
until such time as he retires as chief executive officer or otherwise
terminates employment with the Company. The restricted stock unit agreement, dated
May 8, 2008, is included as Exhibit 10.4 to this quarterly report on Form 10-Q and incorporated herein by reference.
31
ITEM 6. EXHIBITS
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*10.1
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Form of Request for Approval of Extension of Maturity Date and
Amendment, dated as of February 18, 2008, among Registrant, the Lenders named
therein, JPMorgan Chase Bank, as Administrative Agent, Citibank, N.A. and Bank of
America, N.A., as Co-Syndication Agents, and BNP Paribas and UBS Loan Finance LLC,
as Co-Documentation Agents. |
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*10.2
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Form of Request for Approval of Extension of Maturity Date and
Amendment, dated February 18, 2008, among Registrant, Apache Canada Ltd., Apache
Energy Limited, the Lenders named therein, JPMorgan Chase Bank, N.A., as Global
Administrative Agent, and the other agents party thereto. |
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*10.3 |
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2008
Share Appreciation Program Specifications |
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*10.4 |
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Restricted
Stock Unit Award Agreement, dated May 8, 2008, between Apache
Corporation and G. Steven Farris. |
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*12.1
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Statement of computation of ratio of earnings to fixed charges and
combined fixed charges and preferred stock dividends. |
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*31.1
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Certification (pursuant to Rule 13a-14(a) or Rule 15d-14(a) of the
Exchange Act) by Chief Executive Officer. |
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*31.2
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Certification (pursuant to Rule 13a-14(a) or Rule 15d-14(a) of the
Exchange Act) by Chief Financial Officer. |
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*32.1
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Section 1350 Certification (pursuant to Sarbanes-Oxley Section 906)
by Chief Executive Officer and Chief Financial Officer. |
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* |
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Filed herewith |
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Management contracts or compensatory plans or arrangements |
32
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly
caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
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APACHE CORPORATION
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Dated: May 9, 2008 |
/s/ ROGER B. PLANK
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Roger B. Plank |
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Executive Vice President and Chief Financial Officer |
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Dated: May 9, 2008 |
/s/ REBECCA A. HOYT
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Rebecca A. Hoyt |
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Vice President and Controller
(Chief Accounting Officer) |
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EXHIBIT INDEX
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*10.1
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-
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Form of Request for Approval of Extension of Maturity Date and
Amendment, dated as of February 18, 2008, among Registrant, the Lenders named
therein, JPMorgan Chase Bank, as Administrative Agent, Citibank, N.A. and Bank of
America, N.A., as Co-Syndication Agents, and BNP Paribas and UBS Loan Finance LLC,
as Co-Documentation Agents. |
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*10.2
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-
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Form of Request for Approval of Extension of Maturity Date and
Amendment, dated February 18, 2008, among Registrant, Apache Canada Ltd., Apache
Energy Limited, the Lenders named therein, JPMorgan Chase Bank, N.A., as Global
Administrative Agent, and the other agents party thereto. |
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*10.3 |
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2008
Share Appreciation Program Specifications |
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*10.4 |
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Restricted
Stock Unit Award Agreement, dated May 8, 2008, between Apache
Corporation and G. Steven Farris. |
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*12.1
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-
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Statement of computation of ratio of earnings to fixed charges and
combined fixed charges and preferred stock dividends. |
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*31.1
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-
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Certification (pursuant to Rule 13a-14(a) or Rule 15d-14(a) of the
Exchange Act) by Chief Executive Officer. |
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*31.2
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-
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Certification (pursuant to Rule 13a-14(a) or Rule 15d-14(a) of the
Exchange Act) by Chief Financial Officer. |
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*32.1
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-
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Section 1350 Certification (pursuant to Sarbanes-Oxley Section 906)
by Chief Executive Officer and Chief Financial Officer. |
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* |
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Filed herewith |
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Management contracts or compensatory plans or arrangements |