Apache 8-K 2016 Q1 Other Events

Exhibit 99.1

PART I – FINANCIAL INFORMATION

ITEM 1 – FINANCIAL STATEMENTS

APACHE CORPORATION AND SUBSIDIARIES

STATEMENT OF CONSOLIDATED OPERATIONS

(Unaudited)

	For the Quarter Ended March 31,
	2016*			2015*
	(In millions, except per common share data)
REVENUES AND OTHER:
Oil and gas production revenues
Oil revenues	$	822		$	1,293
Gas revenues	223			308
Natural gas liquids revenues	42			58
	1,087			1,659
Other	(3		)	(6		)
Loss on divestitures	(1		)	(18		)
	1,083			1,635
OPERATING EXPENSES:
Lease operating expenses	378			481
Gathering and transportation	52			56
Taxes other than income	11			73
Exploration	95			258
General and administrative	93			84
Depreciation, depletion, and amortization:
Oil and gas property and equipment	636			743
Other assets	42			83
Asset retirement obligation accretion	38			36
Impairments	—			1,912
Transaction, reorganization, and separation	15			54
Financing costs, net	105			124
	1,465			3,904
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	(382		)	(2,269		)
Current income tax provision (benefit)	(10		)	(52		)
Deferred income tax provision (benefit)	(1		)	(1,149		)
NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST	(371		)	(1,068		)
Net loss from discontinued operations, net of tax	—			(238		)
NET LOSS INCLUDING NONCONTROLLING INTEREST	(371		)	(1,306		)
Net income attributable to noncontrolling interest	1			28
NET LOSS ATTRIBUTABLE TO COMMON STOCK	$	(372	)	$	(1,334	)
NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS:
Net loss from continuing operations attributable to common shareholders	$	(372	)	$	(1,096	)
Net loss from discontinued operations	—			(238		)
Net loss attributable to common shareholders	$	(372	)	$	(1,334	)
NET LOSS PER COMMON SHARE:
Basic net loss from continuing operations per share	$	(0.98	)	$	(2.91	)
Basic net loss from discontinued operations per share	—			(0.63		)
Basic net loss per share	$	(0.98	)	$	(3.54	)
DILUTED NET LOSS PER COMMON SHARE:
Diluted net loss from continuing operations per share	$	(0.98	)	$	(2.91	)
Diluted net loss from discontinued operations per share	—			(0.63		)
Diluted net loss per share	$	(0.98	)	$	(3.54	)
WEIGHTED-AVERAGE NUMBER OF COMMON SHARES OUTSTANDING:
Basic	378			377
Diluted	378			377
DIVIDENDS DECLARED PER COMMON SHARE	$	0.25		$	0.25

*Financial information for all periods has been recast to reflect retrospective application of the successful efforts method of accounting. See Note 1.

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)

	For the Three Months Ended March 31,
	2016*			2015*
	(In millions)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net loss including noncontrolling interest	$	(371	)	$	(1,306	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Loss from discontinued operations	—			238
Loss on divestitures	1			18
Exploratory dry hole expense and unproved leasehold impairments	71			203
Depreciation, depletion, and amortization	678			826
Asset retirement obligation accretion	38			36
Impairments	—			1,912
Provision (benefit) from deferred income taxes	(1		)	(1,149		)
Other	55			(3		)
Changes in operating assets and liabilities:
Receivables	135			247
Inventories	10			22
Drilling advances	(17		)	(169		)
Deferred charges and other	(117		)	(60		)
Accounts payable	(75		)	(190		)
Accrued expenses	(141		)	(193		)
Deferred credits and noncurrent liabilities	(27		)	77
NET CASH PROVIDED BY CONTINUING OPERATING ACTIVITIES	239			509
NET CASH PROVIDED BY DISCONTINUED OPERATIONS	—			60
NET CASH PROVIDED BY OPERATING ACTIVITIES	239			569
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(546		)	(1,517		)
Leasehold and property acquisitions	(19		)	(91		)
Additions to gas gathering, transmission, and processing facilities	—			(63		)
Other, net	10			(72		)
NET CASH USED IN CONTINUING INVESTING ACTIVITIES	(555		)	(1,743		)
NET CASH USED IN DISCONTINUED OPERATIONS	—			(252		)
NET CASH USED IN INVESTING ACTIVITIES	(555		)	(1,995		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Commercial paper and bank credit facilities, net	—			1,028
Distributions to noncontrolling interest	(54		)	(21		)
Dividends paid	(95		)	(94		)
Other	2			15
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES	(147		)	928
NET DECREASE IN CASH AND CASH EQUIVALENTS	(463		)	(498		)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	1,467			679
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	1,004		$	181
SUPPLEMENTARY CASH FLOW DATA:
Interest paid, net of capitalized interest	$	141		$	141
Income taxes paid, net of refunds	84			142

*Financial information for all periods has been recast to reflect retrospective application of the successful efforts method of accounting. See Note 1.

The accompanying notes to consolidated financial statements

are an integral part of this statement.

2

APACHE CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(Unaudited)

	March 31, 2016*			December 31, 2015*
	(In millions)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	1,004		$	1,467
Receivables, net of allowance	1,120			1,253
Inventories	547			570
Drilling advances	190			172
Prepaid assets and other	399			290
	3,260			3,752
PROPERTY AND EQUIPMENT:
Oil and gas, on the basis of successful efforts accounting:
Proved properties	42,161			41,728
Unproved properties and properties under development, not being amortized	2,241			2,277
Gathering, transmission and processing facilities	1,048			1,052
Other	1,094			1,093
	46,544			46,150
Less: Accumulated depreciation, depletion, and amortization	(25,985		)	(25,312		)
	20,559			20,838
OTHER ASSETS:
Deferred charges and other	915			910
	$	24,734		$	25,500
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	571		$	618
Other current liabilities (Note 5)	994			1,223
	1,565			1,841
LONG-TERM DEBT	8,718			8,716
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Income taxes	2,533			2,529
Asset retirement obligation	2,586			2,562
Other	332			362
	5,451			5,453
COMMITMENTS AND CONTINGENCIES (Note 9)
EQUITY:
Common stock, $0.625 par, 860,000,000 shares authorized, 411,708,123 and 411,218,105 shares issued, respectively	257			257
Paid-in capital	12,553			12,619
Accumulated deficit	(2,352		)	(1,980		)
Treasury stock, at cost, 33,175,728 and 33,183,930 shares, respectively	(2,888		)	(2,889		)
Accumulated other comprehensive loss	(119		)	(119		)
APACHE SHAREHOLDERS’ EQUITY	7,451			7,888
Noncontrolling interest	1,549			1,602
TOTAL EQUITY	9,000			9,490
	$	24,734		$	25,500

*Financial information for all periods has been recast to reflect retrospective application of the successful efforts method of accounting. See Note 1.

The accompanying notes to consolidated financial statements

are an integral part of this statement.

3

APACHE CORPORATION AND SUBSIDIARIES

STATEMENT OF CONSOLIDATED CHANGES IN EQUITY

(Unaudited)

	Common Stock		Paid-In Capital			Retained Earnings (Accumulated Deficit)			Treasury Stock			Accumulated Other Comprehensive Loss			APACHE SHAREHOLDERS’ EQUITY			Non Controlling Interest			TOTAL EQUITY
	(In millions)
BALANCE AT DECEMBER 31, 2014 previously reported	$	256	$	12,438		$	16,249		$	(2,890	)	$	(116	)	$	25,937		$	2,200		$	28,137
Effect of change in accounting principle	—		152			(7,594		)	—			—			(7,442		)	(154		)	(7,596		)
BALANCE AT DECEMBER 31, 2014 as recast	$	256	$	12,590		$	8,655		$	(2,890	)	$	(116	)	$	18,495		$	2,046		$	20,541
Net income (loss)	—		—			(1,334		)	—			—			(1,334		)	28			(1,306		)
Distributions to noncontrolling interest	—		—			—			—			—			—			(21		)	(21		)
Common dividends ($0.25 per share)	—		—			(94		)	—			—			(94		)	—			(94		)
Common stock activity, net	—		18			—			—			—			18			—			18
Treasury stock activity, net	—		—			—			1			—			1			—			1
BALANCE AT MARCH 31, 2015	$	256	$	12,608		$	7,227		$	(2,889	)	$	(116	)	$	17,086		$	2,053		$	19,139
BALANCE AT DECEMBER 31, 2015 previously reported	$	257	$	12,467		$	(7,153	)	$	(2,889	)	$	(116	)	$	2,566		$	1,662		$	4,228
Effect of change in accounting principle	—		152			5,173			—			(3		)	5,322			(60		)	5,262
BALANCE AT DECEMBER 31, 2015 as recast	$	257	$	12,619		$	(1,980	)	$	(2,889	)	$	(119	)	$	7,888		$	1,602		$	9,490
Net income (loss)	—		—			(372		)	—			—			(372		)	1			(371		)
Distributions to noncontrolling interest	—		—			—			—			—			—			(54		)	(54		)
Common dividends ($0.25 per share)	—		(95		)	—			—			—			(95		)	—			(95		)
Other	—		29			—			1			—			30			—			30
BALANCE AT MARCH 31, 2016	$	257	$	12,553		$	(2,352	)	$	(2,888	)	$	(119	)	$	7,451		$	1,549		$	9,000

Financial information for all periods has been recast to reflect retrospective application of the successful efforts method of accounting. See Note 1.

The accompanying notes to consolidated financial statements

are an integral part of this statement.

4

APACHE CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

These consolidated 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). They reflect all adjustments that 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 consolidated 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 (U.S. GAAP) 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. This Current Report on Form 8-K for the quarter ended March 31, 2016, should be read along with Apache’s Current Report on Form 8-K dated August 4, 2016 for the fiscal year ended December 31, 2015, which contains a summary of the Company’s significant accounting policies and other disclosures.

1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

As of March 31, 2016, Apache’s significant accounting policies are consistent with those discussed in Note 1—Summary of Significant Accounting Policies to the consolidated financial statements contained in Apache’s Current Report on Form 8-K dated August 4, 2016 for the fiscal year ended December 31, 2015.

The Company’s financial statements for prior periods include reclassifications that were made to conform to the current-period presentation. During the second quarter of 2015, Apache completed the sale of its Australian LNG business and oil and gas assets. Results of operations and consolidated cash flows for the divested Australia assets are reflected as discontinued operations in the Company’s financial statements for all periods presented. For more information regarding these divestitures, please refer to Note 3—Acquisitions and Divestitures.

Recast Financial Information for Change in Accounting Principle

In the second quarter of 2016, Apache voluntarily changed its method of accounting for its oil and gas exploration and development activities from the full cost method to the successful efforts method of accounting. The financial information for prior periods has been recast to reflect retrospective application of the successful efforts method, as prescribed by the Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 932 “Extractive Activities—Oil and Gas.” Although the full cost method of accounting for oil and gas exploration and development activities continues to be an accepted alternative, the successful efforts method of accounting is the generally preferred method of the U.S. Securities and Exchange Commission (SEC) and is more widely used in the industry such that the change will improve comparability of the Company's financial statements to its peers. The Company believes the successful efforts method provides a more representational depiction of assets and operating results. The successful efforts method also provides for the Company's investments in oil and gas properties to be assessed for impairment in accordance with ASC 360 "Property, Plant, and Equipment" rather than valuations based on prices and costs prescribed under the full cost method as of the balance sheet date. For more detailed information regarding the effects of the change to the successful efforts method, please refer to Note 2—Change in Accounting Principle. The Company has recast certain historical information for all periods presented, including the Statement of Consolidated Operations, Statement of Consolidated Cash Flows, Consolidated Balance Sheet, Statement of Consolidated Changes in Equity, and related information in Notes 1, 2, 3, 4, 5, 7, 8, 10, 11, and 12.

In addition, the Company retrospectively adopted a new accounting standard update ASU 2015-03 "Simplifying the Presentation of Debt Issuance Costs," which requires debt issuance costs to be presented as a direct deduction from the carrying value of the associated debt liability, consistent with debt discounts. For more information regarding this update, please refer to Note 7—Debt and Financing Costs.

Use of Estimates

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates with regard to these financial statements include the fair value determination of acquired assets and liabilities, the estimate of proved oil and gas reserves and related present value estimates of future net cash flows therefrom, the assessment of asset retirement obligations, the estimates of fair value for long-lived assets and goodwill, and the estimate of income taxes. Actual results could differ from those estimates.

5

Oil and Gas Property

The Company follows the successful efforts method of accounting for its oil and gas property. Under this method of accounting, exploration costs such as exploratory dry holes, exploratory geological and geophysical costs, delay rentals, unproved impairments, and exploration overhead are expensed as incurred. All costs related to production, general corporate overhead, and similar activities are expensed as incurred. If an exploratory well provides evidence to justify potential development of reserves, drilling costs associated with the well are initially capitalized, or suspended, pending a determination as to whether a commercially sufficient quantity of proved reserves can be attributed to the area as a result of drilling. This determination may take longer than one year in certain areas depending on, among other things, the amount of hydrocarbons discovered, the outcome of planned geological and engineering studies, the need for additional appraisal drilling activities to determine whether the discovery is sufficient to support an economic development plan, and government sanctioning of development activities in certain international locations. At the end of each quarter, management reviews the status of all suspended exploratory well costs in light of ongoing exploration activities; in particular, whether the Company is making sufficient progress in its ongoing exploration and appraisal efforts or, in the case of discoveries requiring government sanctioning, whether development negotiations are underway and proceeding as planned. If management determines that future appraisal drilling or development activities are unlikely to occur, associated suspended exploratory well costs are expensed.

Acquisition costs of unproved properties are assessed for impairment at least annually and are transferred to proved oil and gas properties to the extent the costs are associated with successful exploration activities. Significant undeveloped leases are assessed individually for impairment based on the Company’s current exploration plans. Unproved oil and gas properties with individually insignificant lease acquisition costs are amortized on a group basis over the average lease term at rates that provide for full amortization of unsuccessful leases upon lease expiration or abandonment. Costs of expired or abandoned leases are charged to exploration expense, while costs of productive leases are transferred to proved oil and gas properties. Costs of maintaining and retaining unproved properties, as well as amortization of individually insignificant leases and impairment of unsuccessful leases, are included in exploration costs in the statement of consolidated operations.

Costs to develop proved reserves, including the costs of all development wells and related equipment used in the production of crude oil and natural gas, are capitalized. Depreciation of the cost of proved oil and gas properties is calculated using the unit-of-production (UOP) method. The UOP calculation multiplies the percentage of estimated proved reserves produced each quarter by the cost of those reserves. The reserve base used to calculate depreciation for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. With respect to lease and well equipment costs, which include development costs and successful exploration drilling costs, the reserve base includes only proved developed reserves. Estimated future dismantlement, restoration and abandonment costs, net of salvage values, are included in the depreciable cost.

Oil and gas properties are grouped for depreciation in accordance with ASC 932 “Extractive Activities - Oil and Gas.” The basis for grouping is a reasonable aggregation of properties with a common geological structural feature or stratigraphic condition, such as a reservoir or field.

When circumstances indicate that proved oil and gas properties may be impaired, the Company compares unamortized capitalized costs to the expected undiscounted pre-tax future cash flows for the associated assets grouped at the lowest level for which identifiable cash flows are independent of cash flows of other assets. If the expected undiscounted pre-tax future cash flows, based on Apache’s estimate of future crude oil and natural gas prices, operating costs, anticipated production from proved reserves and other relevant data, are lower than the unamortized capitalized cost, the capitalized cost is reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820 “Fair Value Measurement.” If applicable, the Company utilizes accepted bids as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value calculations are typically based on judgmental assessments of future production volumes, commodity prices, operating costs, and capital investment plans, considering all available information at the date of review. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a discount rate believed to be consistent with those applied by market participants. Apache has classified these fair value measurements as Level 3 in the fair value hierarchy.

6

The following table represents non-cash impairments of the carrying value of the Company’s proved and unproved property and equipment for the first quarters of 2016 and 2015:

	Three months ended March 31,
	2016		2015
	(In millions)
Oil and Gas Property:
Proved	$	—	$	1,912
Unproved	42		168

The fair value of the impaired proved properties as of March 31, 2015 was $1.2 billion.

On the statement of consolidated operations, unproved impairments are recorded in exploration expense, and proved impairments are recorded in impairments. Gains and losses on significant divestitures are recognized in the statement of consolidated operations. See Note 3—Acquisitions and Divestitures for more detail.

New Pronouncements Issued But Not Yet Adopted

In March 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2016-09, which seeks to simplify accounting for share-based payment transactions including income tax consequences, classification of awards as either equity or liabilities, and the classification on the statement of cash flows. The new standard requires the Company to recognize the income tax effects of awards in the income statement when the awards vest or are settled. The guidance is effective for fiscal years beginning after December 15, 2016.  Early adoption is permitted and if an entity early adopts the guidance in an interim period, any adjustments must be reflected as of the beginning of the fiscal year that includes that interim period. The Company is currently evaluating the impact of adopting this standard on its consolidated financial statements.

In February 2016, the FASB issued ASU 2016-02, a new lease standard requiring lessees to recognize lease assets and lease liabilities for most leases classified as operating leases under previous U.S. GAAP. The guidance is effective for fiscal years beginning after December 15, 2018 with early adoption permitted. The Company will be required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements. The Company is currently evaluating the impact of adopting this standard on its consolidated financial statements.

In May 2014, the FASB and the International Accounting Standards Board (IASB) issued a joint revenue recognition standard, ASU 2014-09. The new standard removes inconsistencies in existing standards, changes the way companies recognize revenue from contracts with customers, and increases disclosure requirements. The guidance requires companies to recognize revenue to depict the transfer of goods or services to customers in amounts that reflect the consideration to which the company expects to be entitled in exchange for those goods or services. In March 2016, the FASB issued ASU 2016-08, which provides further clarification on the principal versus agent evaluation. The guidance is effective for annual and interim periods beginning after December 15, 2017. The standard is required to be adopted using either the full retrospective approach, with all prior periods presented adjusted, or the modified retrospective approach, with a cumulative adjustment to retained earnings on the opening balance sheet. The Company is currently evaluating the level of effort needed to implement the standard, the impact of adopting this standard on its consolidated financial statements, and whether to use the full retrospective approach or the modified retrospective approach.

7

2. CHANGE IN ACCOUNTING PRINCIPLE

During the second quarter of 2016, the Company voluntarily changed its method of accounting for oil and gas exploration and development activities from the full cost method to the successful efforts method. Accordingly, financial information for prior periods has been recast to reflect retrospective application of the successful efforts method. In general, under successful efforts, exploration expenditures such as exploratory dry holes, exploratory geological and geophysical costs, delay rentals, unproved impairments, and exploration overhead are charged against earnings as incurred, versus being capitalized under the full cost method of accounting. Successful efforts also provides for the assessment of potential property impairments under ASC 360 by comparing the net carrying value of oil and gas properties with associated projected undiscounted pre-tax future net cash flows. If the expected undiscounted pre-tax future net cash flows are lower than the unamortized capitalized costs, the capitalized cost is reduced to fair value. Under the full cost method of accounting, a write-down would be required if the net carrying value of oil and gas properties exceeds a full cost “ceiling,” using an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months. In addition, gains or losses, if applicable, are generally recognized on the dispositions of oil and gas property and equipment under the successful efforts method, as opposed to an adjustment to the net carrying value of the remaining assets under the full cost method. Apache’s consolidated financial statements have been recast to reflect these differences.

The following tables present the effects of the change to the successful efforts method in the statement of consolidated operations:

	Changes to the Statement of Consolidated Operations
For the Quarter Ended March 31, 2016	Under Full Cost			Changes*			As Reported Under Successful Efforts
	(In millions, except per share data)
Oil revenues	$	795		$	27		$	822
Natural gas revenues	223			—			223
NGL revenues	42			—			42
Oil and gas production revenues	1,060			27			1,087
Other	(5		)	2			(3		)
Loss on divestitures	(2		)	1			(1		)
Exploration	—			95			95
Depreciation, depletion, and amortization:
Oil and Gas Property and Equipment
Recurring	552			84			636
Additional	488			(488		)	—
Financing costs, net	90			15			105
Current income tax provision	35			(45		)	(10		)
Deferred income tax provision (benefit)	(181		)	180			(1		)
NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST	(561		)	190			(371		)
Net income (loss) attributable to noncontrolling interest	(72		)	73			1
NET LOSS FROM CONTINUING OPERATIONS ATTRIBUTABLE TO COMMON SHAREHOLDERS	(489		)	117			(372		)
Net loss from discontinued operations	—			—			—
NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS	(489		)	117			(372		)
Per common share
Basic net loss from continuing operations per share	$	(1.29	)	$	0.31		$	(0.98	)
Basic net loss from discontinued operations per share	—			—			—
Basic net loss per share	$	(1.29	)	$	0.31		$	(0.98	)
Diluted net loss from continuing operations per share	$	(1.29	)	$	0.31		$	(0.98	)
Diluted net loss from discontinued operations per share	—			—			—
Diluted net loss per share	$	(1.29	)	$	0.31		$	(0.98	)

8

	Changes to the Statement of Consolidated Operations
For the Quarter Ended March 31, 2015	Under Full Cost			Changes*			As Reported Under Successful Efforts
	(In millions, except per share data)
Oil revenues	$	1,280		$	13		$	1,293
Natural gas revenues	300			8			308
NGL revenues	58			—			58
Oil and gas production revenues	1,638			21			1,659
Other	(8		)	2			(6		)
Loss on divestitures	—			(18		)	(18		)
Exploration	—			258			258
General and administrative	82			2			84
Depreciation, depletion, and amortization:
Oil and Gas Property and Equipment
Recurring	999			(256		)	743
Additional	7,220			(7,220		)	—
Impairments	—			1,912			1,912
Financing costs, net	69			55			124
Current income tax provision (benefit)	(85		)	33			(52		)
Deferred income tax provision (benefit)	(2,935		)	1,786			(1,149		)
NET LOSS FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST	(4,504		)	3,436			(1,068		)
Net income attributable to noncontrolling interest	15			13			28
NET LOSS FROM CONTINUING OPERATIONS ATTRIBUTABLE TO COMMON SHAREHOLDERS	(4,519		)	3,423			(1,096		)
Net loss from discontinued operations	(132		)	(106		)	(238		)
NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS	(4,651		)	3,317			(1,334		)
Per common share
Basic net loss from continuing operations per share	$	(11.99	)	$	9.08		$	(2.91	)
Basic net loss from discontinued operations per share	(0.35		)	(0.28		)	(0.63		)
Basic net loss per share	$	(12.34	)	$	8.80		$	(3.54	)
Diluted net loss from continuing operations per share	$	(11.99	)	$	9.08		$	(2.91	)
Diluted net loss from discontinued operations per share	(0.35		)	(0.28		)	(0.63		)
Diluted net loss per share	$	(12.34	)	$	8.80		$	(3.54	)

The following tables present the effects of the change to the successful efforts method in the statement of consolidated cash flows:

	Changes to the Statement of Consolidated Cash Flows
For the Quarter Ended March 31, 2016	Under Full Cost			Changes*			As Reported Under Successful Efforts
	(In millions)
Net loss including noncontrolling interest	$	(561	)	$	190		$	(371	)
Loss on divestitures, net	2			(1		)	1
Exploratory dry hole expense and unproved leasehold impairments	—			71			71
Depreciation, depletion, and amortization	1,082			(404		)	678
Provision for (benefit from) deferred income taxes	(181		)	180			(1		)
Changes in operating assets and liabilities	(159		)	(73		)	(232		)
Net cash provided by operating activities - continuing operations	276			(37		)	239
Additions to oil and gas property	(583		)	37			(546		)
Net cash used in investing activities - continuing operations	(592		)	37			(555		)
NET INCREASE (DECREASE) IN CASH	(463		)	—			(463		)
BEGINNING CASH BALANCE	1,467			—			1,467
ENDING CASH BALANCE	1,004			—			1,004

9

	Changes to the Statement of Consolidated Cash Flows
For the Quarter Ended March 31, 2015	Under Full Cost			Changes*			As Reported Under Successful Efforts
	(In millions)
Net loss including noncontrolling interest	$	(4,636	)	$	3,330		$	(1,306	)
Loss from discontinued operations	132			106			238
Loss on divestitures, net	—			18			18
Exploratory dry hole expense and unproved leasehold impairments	—			203			203
Depreciation, depletion, and amortization	8,302			(7,476		)	826
Impairments	—			1,912			1,912
Provision for (benefit from) deferred income taxes	(2,935		)	1,786			(1,149		)
Changes in operating assets and liabilities	(319		)	53			(266		)
Net cash provided by operating activities - continuing operations	577			(68		)	509
Net cash provided by operating activities - discontinued operations	73			(13		)	60
Additions to oil and gas property	(1,627		)	110			(1,517		)
Net cash used in investing activities - continuing operations	(1,853		)	110			(1,743		)
Net cash used in investing activities - discontinued operations	(265		)	13			(252		)
NET INCREASE (DECREASE) IN CASH	(540		)	42			(498		)
BEGINNING CASH BALANCE	769			(90		)	679
ENDING CASH BALANCE	229			(48		)	181

The following tables present the effects of the change to the successful efforts method in the consolidated balance sheet:

	Changes to the Consolidated Balance Sheet
March 31, 2016	Under Full Cost			Changes*			As Reported Under Successful Efforts
	(In millions)
Prepaid assets and other	$	361		$	38		$	399
PROPERTY AND EQUIPMENT:
Property and equipment - cost	94,326			(47,782		)	46,544
Less: Accumulated depreciation, depletion, and amortization	(80,784		)	54,799			(25,985		)
PROPERTY AND EQUIPMENT, NET	13,542			7,017			20,559
TOTAL ASSETS	17,679			7,055			24,734
Other current liabilities	1,027			(33		)	994
Income taxes	891			1,642			2,533
Paid-in capital	12,407			146			12,553
Accumulated deficit	(7,642		)	5,290			(2,352		)
Accumulated other comprehensive loss	(116		)	(3		)	(119		)
Noncontrolling interest	1,536			13			1,549
TOTAL EQUITY	3,554			5,446			9,000

	Changes to the Consolidated Balance Sheet
December 31, 2015	Under Full Cost			Changes*			As Reported Under Successful Efforts
	(In millions)
PROPERTY AND EQUIPMENT:
Property and equipment - cost	$	93,825		$	(47,675	)	$	46,150
Less: Accumulated depreciation, depletion, and amortization	(79,706		)	54,394			(25,312		)
PROPERTY AND EQUIPMENT, NET	14,119			6,719			20,838
TOTAL ASSETS	18,781			6,719			25,500
Income taxes	1,072			1,457			2,529
Paid-in capital	12,467			152			12,619
Accumulated deficit (1)	(7,153		)	5,173			(1,980		)
Accumulated other comprehensive loss	(116		)	(3		)	(119		)
Noncontrolling interest	1,662			(60		)	1,602
TOTAL EQUITY	4,228			5,262			9,490

*In conjunction with recasting the financial information for the adoption of the successful efforts method of accounting, we corrected certain immaterial errors

in the North Sea pertaining to the improper calculation of deferred tax liabilities associated with capitalized interest under the full cost method.

⁽¹⁾ The cumulative effect of the change to the successful efforts method on retained earnings (accumulated deficit) as of January 1, 2015 was a decrease of $7.6 billion.

10

3. ACQUISITIONS AND DIVESTITURES

2015 Activity

Canada Divestiture

In April 2015, Apache's subsidiaries completed the sale of its 50 percent interest in the Kitimat LNG project and upstream acreage in the Horn River and Liard natural gas basins to Woodside Petroleum Limited (Woodside). Proceeds at closing were $854 million, of which approximately $344 million were associated with LNG assets and $510 million were associated with upstream assets. The proceeds are subject to post-closing adjustments. For additional details related to post-closing adjustments, please see Note 9—Commitments and Contingencies.

The Kitimat LNG assets classified as held for sale as of December 31, 2014 were impaired $655 million in the fourth quarter of 2014. Apache recognized a $146 million gain on the sale of the upstream assets upon completion of the sale.

Australia Divestitures

Woodside Sale In April 2015, Apache's subsidiaries completed the sale of its interest in the Wheatstone LNG project and associated upstream oil and gas assets to Woodside. Proceeds at closing were $2.8 billion, of which approximately $1.4 billion were associated with LNG assets and $1.4 billion were associated with the upstream assets. The proceeds are subject to post-closing adjustments. For additional details related to post-closing adjustments, please see Note 9—Commitments and Contingencies.

The Wheatstone LNG assets and associated upstream assets were impaired $833 million in the fourth quarter of 2014 and classified as held for sale as of December 31, 2014. An additional impairment of approximately $49 million was recognized in the first quarter of 2015. No additional gain or loss was recognized on the ultimate disposal of the LNG project and upstream assets.

Consortium Sale In June 2015, Apache's subsidiaries completed the sale of the Company's Australian subsidiary Apache Energy Limited (AEL) to a consortium of private equity funds managed by Macquarie Capital Group Limited and Brookfield Asset Management Inc. Total proceeds of $1.9 billion included customary, post-closing adjustments for the period between the effective date, October 1, 2014, and closing. A loss of approximately $139 million was recognized for the sale of AEL.

Upon closing of the sale of substantially all Australian operations, the associated results of operations for the divested Australian assets and the losses on disposal were classified as discontinued operations in all periods presented in this Current Report on Form 8-K. Sales and other operating revenues and loss from discontinued operations related to the Australia dispositions were as follows:

	For the Quarter Ended March 31,
	2016		2015
	(In millions)
Revenues and other from discontinued operations	$	—	$	187
Impairment on Woodside sale	$	—	$	(49	)
Income from divested Australian operations	—		10
Income tax expense	—		(199		)
Loss from Australian discontinued operations, net of tax	$	—	$	(238	)

Leasehold and Property Acquisitions

During the first quarter of 2015, Apache completed $91 million of leasehold and property acquisitions primarily in our North America onshore regions.

Transaction, Reorganization, and Separation

During the first quarter of 2015, Apache recorded $54 million in expense related to various asset transactions, company reorganization, and employee separation.

11

4.   CAPITALIZED EXPLORATORY WELL COSTS

The Company’s capitalized exploratory well costs were $240 million and $245 million at March 31, 2016​ and December 31, 2015, respectively. The decrease is primarily attributable to successful transfers and dry hole write-offs, partially offset by drilling activities. During the three months ended March 31, 2016, changes to exploratory well costs previously capitalized for a period greater than one year since the completion of drilling at December 31, 2015 were not material. Projects with suspended exploratory well costs capitalized for a period greater than one year since the completion of drilling are those identified by management as exhibiting sufficient quantities of hydrocarbons to justify potential development. Management is actively pursuing efforts to assess whether reserves can be attributed to these projects.

5. OTHER CURRENT LIABILITIES

The following table provides detail of our other current liabilities as of March 31, 2016 and December 31, 2015:

	March 31, 2016		December 31, 2015
	(In millions)
Accrued operating expenses	$	125	$	139
Accrued exploration and development	537		637
Accrued compensation and benefits	75		166
Accrued interest	108		144
Accrued income taxes	48		47
Current debt	1		1
Current asset retirement obligation	36		36
Other	64		53
Total Other current liabilities	$	994	$	1,223

6. ASSET RETIREMENT OBLIGATION

The following table describes changes to the Company’s asset retirement obligation (ARO) liability for the three-month period ended March 31, 2016:

	(In millions)
Asset retirement obligation at December 31, 2015	$	2,598
Liabilities incurred	1
Liabilities settled	(15		)
Accretion expense	38
Asset retirement obligation at March 31, 2016	2,622
Less current portion	36
Asset retirement obligation, long-term	$	2,586

12

7. DEBT AND FINANCING COSTS

The following table presents the carrying amounts and estimated fair values of the Company’s outstanding debt as of March 31, 2016 and December 31, 2015:

	March 31, 2016				December 31, 2015
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	(In millions)
Commercial paper and committed bank facilities	$	—	$	—	$	—	$	—
Notes and debentures	8,719		8,561		8,717		8,330
Total Debt	$	8,719	$	8,561	$	8,717	$	8,330

The Company’s debt is recorded at the carrying amount, net of related unamortized discount and debt issuance costs, on its consolidated balance sheet. The carrying amount of the Company’s commercial paper, committed bank facilities, and uncommitted bank lines approximates fair value because the interest rates are variable and reflective of market rates. Apache uses a market approach to determine the fair value of its notes and debentures using estimates provided by an independent investment financial data services firm (a Level 2 fair value measurement).

As of March 31, 2016, the Company had a $3.5 billion five-year revolving credit facility which matures in June 2020. Proceeds from borrowings may be used for general corporate purposes. Apache’s available borrowing capacity under this facility supports its $3.5 billion commercial paper program. The commercial paper program, which is subject to market availability, facilitates Apache borrowing funds for up to 270 days at competitive interest rates. As of March 31, 2016, the Company had no debt outstanding under commercial paper, committed bank facilities, and uncommitted bank lines.

As of March 31, 2016, the Company had a £900 million three-year letter of credit facility which matures in February 2019. The facility is available for letters of credit and loans to cash collateralize letter of credit obligations to the extent letters of credit are unavailable under the facility.

In April 2015, the FASB issued ASU 2015-03 "Simplifying the Presentation of Debt Issuance Costs," which requires debt issuance costs to be presented as a direct deduction from the carrying value of the associated debt liability. The Company adopted this update in the first quarter of 2016 and applied the changes retrospectively for all periods presented. At December 31, 2015, the Company had debt issuance costs of $61 million classified as a long-term asset as a component of "deferred charges and other" on the balance sheet that have been netted against "long-term debt" in these unaudited interim financial statements. As of March 31, 2016, long-term debt is presented net of debt issuance costs of $59 million.

Financing Costs, Net

The following table presents the components of Apache’s financing costs, net:

	For the Quarter Ended March 31,
	2016			2015
	(In millions)
Interest expense	$	116		$	128
Amortization of deferred loan costs	1			2
Capitalized interest	(11		)	(4		)
Interest income	(1		)	(2		)
Financing costs, net	$	105		$	124

13

8. INCOME TAXES

The Company estimates its annual effective income tax rate for continuing operations in recording its quarterly provision for income taxes in the various jurisdictions in which the Company operates. Non-cash write-downs of the carrying value of the Company’s proved oil and gas properties, statutory tax rate changes, and other significant or unusual items are recognized as discrete items in the quarter in which they occur.

During the first quarter of 2016, Apache’s effective income tax rate was primarily impacted by an increase in the valuation allowance on Canadian deferred tax assets. During the first quarter of 2015, Apache’s effective tax rate was primarily impacted by non-cash impairments of the carrying value of the Company's proved oil and gas properties and a $414 million discrete deferred tax benefit associated with a reduction in the U.K. statutory income tax rate from 62 percent to 50 percent.

9. COMMITMENTS AND CONTINGENCIES

Legal Matters

Apache is party to various legal actions arising in the ordinary course of business, including litigation and governmental and regulatory controls. As of March 31, 2016, the Company has an accrued liability of approximately $14 million for all legal contingencies that are deemed to be probable of occurring and can be reasonably estimated. Apache’s estimates are based on information known about the matters and its experience in contesting, litigating, and settling similar matters. Although actual amounts could differ from management’s estimate, none of the actions are believed by management to involve future amounts that would be material to Apache’s financial position, results of operations, or liquidity after consideration of recorded accruals. For material matters that Apache believes an unfavorable outcome is reasonably possible, the Company has disclosed the nature of the matter and a range of potential exposure, unless an estimate cannot be made at this time. It is management’s opinion that the loss for any other litigation matters and claims that are reasonably possible to occur will not have a material adverse effect on the Company’s financial position, results of operations, or liquidity.

For additional information on each of the Legal Matters described below, please see Note 9—Commitments and Contingencies to the consolidated financial statements contained in Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

Argentine Environmental Claims and Argentina Tariff

No material change in the status of the YPF Sociedad Anónima and Pioneer Natural Resources Company indemnities matters has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

Louisiana Restoration

As more fully described in Apache’s Annual Report on Form 10-K for its 2015 fiscal year, numerous surface owners have filed claims or sent demand letters to various oil and gas companies, including Apache, claiming that, under either express or implied lease terms or Louisiana law, the companies 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.

In respect of three lawsuits filed by the Parish of Plaquemines against the Company and other oil and gas producers in the 25th Judicial District Court for the Parish of Plaquemines, State of Louisiana (captioned Parish of Plaquemines v. Rozel Operating Company et al., Docket No. 60-996; Parish of Plaquemines v. Apache Oil Corporation et al., Docket No. 61-000; and Parish of Plaquemines v. HHE Energy Company et al., Docket No. 60-983), in April 2016 the Plaquemines Parish Council reversed course and decided not to dismiss the lawsuits. The Louisiana Attorney General has announced his intention to intervene in the three Plaquemines Parish proceedings and in the Cameron Parish proceedings in the Parish’s 38^th Judicial District Court, captioned Parish of Cameron v. BEPCO, L.P., et al., Docket No. 10-19572; Parish of Cameron v. BP America Production Company et al., Docket No. 10-19576; Parish of Cameron v. Apache Corporation (of Delaware) et al., Docket No. 10-19579; Parish of Cameron v. Atlantic Richfield Company et al., Docket No. 10-19577; Parish of Cameron v. Alpine Exploration Companies, Inc., et al., Docket No. 19580; and Parish of Cameron v. Auster Oil and Gas, Inc., et al, Docket No. 10-19582.

No other material change in the status of these matters has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

14

Apollo Exploration Lawsuit

In a fourth amended petition filed on March 21, 2016, in a case captioned Apollo Exploration, LLC, Cogent Exploration, Ltd. Co. & SellmoCo, LLC v. Apache Corporation, Cause No. CV50538 in the 385th Judicial District Court, Midland County, Texas, plaintiffs have reduced their alleged damages to approximately $500 million (having previously claimed in excess of $1.1 billion) relating to certain purchase and sale agreements, mineral leases, and areas of mutual interest agreements concerning properties located in Hartley, Moore, Potter, and Oldham Counties, Texas. Apache believes that plaintiffs’ claims lack merit, and further that plaintiffs’ alleged damages, even as amended, are grossly inflated. Apache will vigorously oppose the claims. No other material change in the status of these matters has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

Escheat Audits

There has been no other material change with respect to the review of the books and records of the Company and its subsidiaries and related entities by the State of Delaware, Department of Finance (Unclaimed Property), to determine compliance with the Delaware Escheat Laws, since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

Burrup-Related Gas Supply Lawsuits

In the cases captioned Radhika Oswal v. Australia and New Zealand Banking Group Limited (ANZ) et al., No. SCI 2011 4653 and Pankaj Oswal v. Australia and New Zealand Banking Group Limited (ANZ) et al., No. SCI 2012 01995, in the Supreme Court of Victoria, trial is set to commence on May 30, 2016. No other material change in the status of this matter has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

Environmental Matters

As of March 31, 2016, the Company had an undiscounted reserve for environmental remediation of approximately $56 million. The Company is not aware of any environmental claims existing as of March 31, 2016, that have not been provided for or would otherwise have a material impact on its financial position, results of operations, or liquidity. 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 Company’s properties.

With respect to the summons and information containing charges relating to a leak of produced water in the Zama area that occurred on or between October 3 and October 25, 2013, and the summons and information containing charges relating to a leak of produced water in the Belloy Field operating area that occurred on or about January 20, 2014, the Company does not expect the economic impact of these incidents to have a material effect on the Company’s financial position, results of operations, or liquidity. No other material change in the status of these matters has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

LNG Divestiture Dispute

In respect of the purchase by Woodside of the Wheatstone and Kitimat LNG projects and accompanying upstream oil and gas reserves from the Company and its subsidiaries, several court proceedings are pending in the Supreme Court of Western Australia (Case Nos. 2315 of 2015, 2798 of 2015, 1504 of 2016, 1520 of 2016, and 1521 of 2016) concerning or arising out of the Wheatstone sale and purchase agreement, including whether certain amounts are due and owing Apache from Woodside and whether certain of Woodside’s purchase price adjustment claims are time-barred. In addition, Woodside is attempting to commence third party expert determination proceedings at the ICC International Centre for ADR in respect of certain aspects of its purchase price adjustment claims. The Company believes that under the terms of the sale and purchase agreements, Woodside’s requests for payment of purchase price adjustments lack merit and further that Woodside must reimburse Apache certain costs relating to Wheatstone and Kitimat; therefore, the Company has not recorded a liability associated with this dispute. No other material change in the status of these matters has occurred since the filing of Apache’s Annual Report on Form 10-K for the fiscal year ended December 31, 2015.

15

10. CAPITAL STOCK

Net Loss per Common Share

A reconciliation of the components of basic and diluted net loss per common share for the quarters ended March 31, 2016 and 2015 is presented in the table below.

	For the Quarter Ended March 31,
	2016							2015
	Loss			Shares	Per Share			Loss			Shares	Per Share
	(In millions, except per share amounts)
Basic:
Loss from continuing operations	$	(372	)	378	$	(0.98	)	$	(1,096	)	377	$	(2.91	)
Loss from discontinued operations	—			378	—			(238		)	377	(0.63		)
Loss attributable to common stock	$	(372	)	378	$	(0.98	)	$	(1,334	)	377	$	(3.54	)
Effect of Dilutive Securities:
Stock options and other	$	—		—	$	—		$	—		—	$	—
Diluted:
Loss from continuing operations	$	(372	)	378	$	(0.98	)	$	(1,096	)	377	$	(2.91	)
Loss from discontinued operations	—			378	—			(238		)	377	(0.63		)
Loss attributable to common stock	$	(372	)	378	$	(0.98	)	$	(1,334	)	377	$	(3.54	)

The diluted earnings per share calculation excludes options and restricted stock units that were anti-dilutive totaling 7.1 million and 9.1 million for the quarters ended March 31, 2016 and 2015, respectively.

Common Stock Dividends

For the quarters ended March 31, 2016, and 2015, Apache paid $95 million and $94 million, respectively, in dividends on its common stock.

Stock Repurchase Program

Apache’s Board of Directors has authorized the purchase of up to 40 million shares of the Company’s common stock. Shares may be purchased either in the open market or through privately negotiated transactions. The Company initiated the buyback program on June 10, 2013, and through December 31, 2015, had repurchased a total of 32.2 million shares at an average price of $88.96 per share. The Company is not obligated to acquire any specific number of shares and has not purchased any shares during 2016.

16

11. BUSINESS SEGMENT INFORMATION

Apache is engaged in a single line of business. Both domestically and internationally, the Company explores for, develops, and produces natural gas, crude oil, and natural gas liquids. At March 31, 2016, the Company had production in four reporting segments: the United States, Canada, Egypt, and offshore the United Kingdom in the North Sea (North Sea). Apache also pursues exploration interests in other areas that may, over time, result in reportable discoveries and development opportunities. Financial information for each country is presented below:

	United States			Canada			Egypt(1)		North Sea			Other International			Total(3)
	(In millions)
For the Quarter Ended March 31, 2016
Oil and Gas Production Revenues	$	409		$	83		$	392	$	203		$	—		$	1,087
Operating Income (Loss)(2)	$	(159	)	$	(62	)	$	42	$	14		$	—		$	(165	)
Other Income (Expense):
Loss on divestitures, net															(1		)
Other															(3		)
General and administrative															(93		)
Transaction, reorganization, and separation															(15		)
Financing costs, net															(105		)
Loss From Continuing Operations Before Income Taxes															$	(382	)
Total Assets	$	12,726		$	2,118		$	5,527	$	4,314		$	49		$	24,734
For the Quarter Ended March 31, 2015
Oil and Gas Production Revenues	$	660		$	133		$	553	$	313		$	—		$	1,659
Operating Income (Loss)(2)	$	(2,019	)	$	(96	)	$	164	$	(31	)	$	(1	)	$	(1,983	)
Other Income (Expense):
Loss on divestitures, net															(18		)
Other															(6		)
General and administrative															(84		)
Transaction, reorganization, and separation															(54		)
Financing costs, net															(124		)
Loss From Continuing Operations Before Income Taxes															$	(2,269	)
Total Assets	$	19,522		$	4,696		$	6,920	$	4,386		$	645		$	36,169

(1) Includes a noncontrolling interest in Egypt.

(2) Operating Income (Loss) consists of oil and gas production revenues less lease operating expenses, gathering and transportation costs, taxes other than income, exploration costs, depreciation, depletion, and amortization, asset retirement obligation accretion, and impairments. The operating income (loss) of U.S., Canada, Egypt, and North Sea for the first quarter of 2015 includes asset impairments totaling $1.9 billion, $26 million, $8 million, and $104 million, respectively.

(3) Amounts for 2015 have been restated to exclude Australia discontinued operations.

17

12. SUPPLEMENTAL GUARANTOR INFORMATION

In December 1999, Apache Finance Canada issued approximately $300 million of publicly-traded notes due in 2029. The notes are fully and unconditionally guaranteed by Apache. The following condensed consolidating financial statements are provided as an alternative to filing separate financial statements.

Apache Finance Canada is 100 percent owned by Apache Corporation. As such, these condensed consolidating financial statements should be read in conjunction with Apache’s consolidated financial statements and the notes thereto, of which this note is an integral part.

18

APACHE CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS

For the Quarter Ended March 31, 2016

	Apache Corporation			Apache Finance Canada			All Other Subsidiaries of Apache Corporation			Reclassifications & Eliminations		Consolidated
	(In millions)
REVENUES AND OTHER:
Oil and gas production revenues	$	217		$	—		$	870		$	—	$	1,087
Equity in net income of affiliates	(108		)	(26		)	—			134		—
Other	28			12			(43		)	—		(3		)
Gain (loss) on divestiture	(1		)	—			—			—		(1		)
	136			(14		)	827			134		1,083
OPERATING EXPENSES:
Lease operating expenses	78			—			300			—		378
Gathering and transportation	8			—			44			—		52
Taxes other than income	21			—			(10		)	—		11
Exploration	50			—			45			—		95
General and administrative	77			—			16			—		93
Depreciation, depletion, and amortization	156			—			522			—		678
Asset retirement obligation accretion	4			—			34			—		38
Impairments	—			—			—			—		—
Transaction, reorganization, and separation	15			—			—			—		15
Financing costs, net	61			10			34			—		105
	470			10			985			—		1,465
NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	(334		)	(24		)	(158		)	134		(382		)
Provision (benefit) for income taxes	37			2			(50		)	—		(11		)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST	(371		)	(26		)	(108		)	134		(371		)
Net income (loss) from discontinued operations, net of tax	—			—			—			—		—
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	(371		)	(26		)	(108		)	134		(371		)
Net loss attributable to noncontrolling interest	—			—			1			—		1
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$	(371	)	$	(26	)	$	(109	)	$	134	$	(372	)

19

APACHE CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS

For the Quarter Ended March 31, 2015

	Apache Corporation			Apache Finance Canada			All Other Subsidiaries of Apache Corporation			Reclassifications & Eliminations		Consolidated
	(In millions)
REVENUES AND OTHER:
Oil and gas production revenues	$	365		$	—		$	1,294		$	—	$	1,659
Equity in net income (loss) of affiliates	(1,246		)	(53		)	1			1,298		—
Other	(38		)	14			18			—		(6		)
Gain (loss) on divestiture	(13		)	—			(5		)	—		(18		)
	(932		)	(39		)	1,308			1,298		1,635
OPERATING EXPENSES:
Lease operating expenses	124			—			357			—		481
Gathering and transportation	9			—			47			—		56
Taxes other than income	33			—			40			—		73
Exploration	95			—			163			—		258
General and administrative	64			—			20			—		84
Depreciation, depletion, and amortization	262			—			564			—		826
Asset retirement obligation accretion	4			—			32			—		36
Impairments	1,164			—			748			—		1,912
Transaction, reorganization, and separation	54			—			—			—		54
Financing costs, net	99			10			15			—		124
	1,908			10			1,986			—		3,904
NET INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES	(2,840		)	(49		)	(678		)	1,298		(2,269		)
Provision (benefit) for income taxes	(1,506		)	3			302			—		(1,201		)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS INCLUDING NONCONTROLLING INTEREST	(1,334		)	(52		)	(980		)	1,298		(1,068		)
Net loss from discontinued operations, net of tax	—			—			(238		)	—		(238		)
NET INCOME (LOSS) INCLUDING NONCONTROLLING INTEREST	(1,334		)	(52		)	(1,218		)	1,298		(1,306		)
Net income attributable to noncontrolling interest	—			—			28			—		28
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON STOCK	$	(1,334	)	$	(52	)	$	(1,246	)	$	1,298	$	(1,334	)

20

APACHE CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

For the Quarter Ended March 31, 2016

	Apache Corporation			Apache Finance Canada			All Other Subsidiaries of Apache Corporation			Reclassifications & Eliminations			Consolidated
	(In millions)
CASH PROVIDED BY OPERATING ACTIVITIES	$	44		$	11		$	184		$	—		$	239
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(81		)	—			(465		)	—			(546		)
Leasehold and property acquisitions	(19		)	—			—			—			(19		)
Additions to gas gathering, transmission, and processing facilities	1			—			(1		)	—			—
Investment in subsidiaries, net	(6		)	—			—			6			—
Other	(34		)	—			44			—			10
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES	(139		)	—			(422		)	6			(555		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Intercompany borrowings	—			(7		)	13			(6		)	—
Distributions to noncontrolling interest	—			—			(54		)	—			(54		)
Dividends paid	(95		)	—			—			—			(95		)
Other	1			(4		)	5			—			2
NET CASH USED IN FINANCING ACTIVITIES	(94		)	(11		)	(36		)	(6		)	(147		)
NET DECREASE IN CASH AND CASH EQUIVALENTS	(189		)	—			(274		)	—			(463		)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	378			—			1,089			—			1,467
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	189		$	—		$	815		$	—		$	1,004

21

APACHE CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS

For the Quarter Ended March 31, 2015

	Apache Corporation			Apache Finance Canada			All Other Subsidiaries of Apache Corporation			Reclassifications & Eliminations			Consolidated
	(In millions)
CASH PROVIDED BY (USED IN) CONTINUING OPERATING ACTIVITIES	$	(470	)	$	(3	)	$	982		$	—		$	509
CASH PROVIDED BY DISCONTINUED OPERATIONS	—			—			60			—			60
CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES	(470		)	(3		)	1,042			—			569
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to oil and gas property	(697		)	—			(820		)	—			(1,517		)
Leasehold and property acquisitions	(92		)	—			1			—			(91		)
Additions to gas gathering, transmission, and processing facilities	(22		)	—			(41		)	—			(63		)
Investment in subsidiaries, net	105			—			—			(105		)	—
Other	(18		)	—			(54		)	—			(72		)
NET CASH USED IN CONTINUING INVESTING ACTIVITIES	(724		)	—			(914		)	(105		)	(1,743		)
NET CASH USED IN DISCONTINUED OPERATIONS	—			—			(252		)	—			(252		)
NET CASH USED IN INVESTING ACTIVITIES	(724		)	—			(1,166		)	(105		)	(1,995		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Commercial paper and bank credit facilities, net	1,028			—			—			—			1,028
Intercompany borrowings	—			(1		)	(104		)	105			—
Distributions to noncontrolling interest	—			—			(21		)	—			(21		)
Dividends paid	(94		)	—			—			—			(94		)
Other	2			4			9			—			15
NET CASH PROVIDED BY (USED IN) CONTINUING FINANCING ACTIVITIES	936			3			(116		)	105			928
NET CASH USED IN DISCONTINUED OPERATIONS	—			—			—			—			—
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES	936			3			(116		)	105			928
NET DECREASE IN CASH AND CASH EQUIVALENTS	(258		)	—			(240		)	—			(498		)
CASH AND CASH EQUIVALENTS AT BEGINNING OF YEAR	267			—			412			—			679
CASH AND CASH EQUIVALENTS AT END OF PERIOD	$	9		$	—		$	172		$	—		$	181

22

APACHE CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEET

March 31, 2016

	Apache Corporation			Apache Finance Canada			All Other Subsidiaries of Apache Corporation		Reclassifications & Eliminations			Consolidated
	(In millions)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	189		$	—		$	815	$	—		$	1,004
Receivables, net of allowance	314			—			806		—			1,120
Inventories	34			—			513		—			547
Drilling advances	15			—			175		—			190
Deferred tax asset	(28		)	—			28		—			—
Prepaid assets and other	238			—			161		—			399
Intercompany receivable	5,330			—			—		(5,330		)	—
	6,092			—			2,498		(5,330		)	3,260
PROPERTY AND EQUIPMENT, NET	6,529			—			14,030		—			20,559
OTHER ASSETS:
Intercompany receivable	—			14			10,894		(10,908		)	—
Equity in affiliates	15,984			(839		)	452		(15,597		)	—
Deferred charges and other	98			1,000			817		(1,000		)	915
	$	28,703		$	175		$	28,691	$	(32,835	)	$	24,734
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	330		$	4		$	237	$	—		$	571
Other current liabilities	351			7			636		—			994
Intercompany payable	—			—			5,330		(5,330		)	—
	681			11			6,203		(5,330		)	1,565
LONG-TERM DEBT	8,421			297			—		—			8,718
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Intercompany payable	10,908			—			—		(10,908		)	—
Income taxes	67			5			2,461		—			2,533
Asset retirement obligation	274			—			2,312		—			2,586
Other	901			249			182		(1,000		)	332
	12,150			254			4,955		(11,908		)	5,451
COMMITMENTS AND CONTINGENCIES
APACHE SHAREHOLDERS’ EQUITY	7,451			(387		)	15,984		(15,597		)	7,451
Noncontrolling interest	—			—			1,549		—			1,549
TOTAL EQUITY	7,451			(387		)	17,533		(15,597		)	9,000
	$	28,703		$	175		$	28,691	$	(32,835	)	$	24,734

23

APACHE CORPORATION AND SUBSIDIARIES

CONDENSED CONSOLIDATING BALANCE SHEET

December 31, 2015

	Apache Corporation			Apache Finance Canada			All Other Subsidiaries of Apache Corporation		Reclassifications & Eliminations			Consolidated
	(In millions)
ASSETS
CURRENT ASSETS:
Cash and cash equivalents	$	378		$	—		$	1,089	$	—		$	1,467
Receivables, net of allowance	314			—			939		—			1,253
Inventories	34			—			536		—			570
Drilling advances	16			—			156		—			172
Prepaid assets and other	102			—			188		—			290
Intercompany receivable	5,212			—			—		(5,212		)	—
	6,056			—			2,908		(5,212		)	3,752
PROPERTY AND EQUIPMENT, NET	6,546			—			14,292		—			20,838
OTHER ASSETS:
Intercompany receivable	—			—			10,744		(10,744		)	—
Equity in affiliates	16,092			(807		)	446		(15,731		)	—
Deferred charges and other	96			1,001			813		(1,000		)	910
	$	28,790		$	194		$	29,203	$	(32,687	)	$	25,500
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES:
Accounts payable	$	409		$	—		$	209	$	—		$	618
Other current liabilities	539			3			681		—			1,223
Intercompany payable	—			—			5,212		(5,212		)	—
	948			3			6,102		(5,212		)	1,841
LONG-TERM DEBT	8,418			298			—		—			8,716
DEFERRED CREDITS AND OTHER NONCURRENT LIABILITIES:
Intercompany payable	10,744			—			—		(10,744		)	—
Income taxes	(412		)	4			2,937		—			2,529
Asset retirement obligation	271			—			2,291		—			2,562
Other	933			250			179		(1,000		)	362
	11,536			254			5,407		(11,744		)	5,453
COMMITMENTS AND CONTINGENCIES
APACHE SHAREHOLDERS’ EQUITY	7,888			(361		)	16,092		(15,731		)	7,888
Noncontrolling interest	—			—			1,602		—			1,602
TOTAL EQUITY	7,888			(361		)	17,694		(15,731		)	9,490
	$	28,790		$	194		$	29,203	$	(32,687	)	$	25,500

24

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion relates to Apache Corporation and its consolidated subsidiaries and should be read in conjunction with our consolidated financial statements and accompanying notes included under Part I, Item 1, “Financial Statements” of this Current Report on Form 8-K, as well as our consolidated financial statements, accompanying notes and Management’s Discussion and Analysis of Financial Condition and Results of Operations included in our Current Report on Form 8-K dated August 4, 2016 for the fiscal year ended December 31, 2015. Financial information for all periods has been recast to reflect the retrospective application of the successful efforts method of accounting, as discussed under Note 1 in Part I, Item 1 of this Current Report on Form 8-K. Results of operations and consolidated cash flows for our divested Australia assets are reflected as discontinued operations in all periods presented in this Current Report on Form 8-K for the quarter ended March 31, 2016.

Overview

Apache Corporation, a Delaware corporation formed in 1954, is an independent energy company that explores for, develops, and produces natural gas, crude oil, and natural gas liquids. The Company has exploration and production interests in four geographic areas: the United States (U.S.), Canada, Egypt, and offshore the United Kingdom (U.K.) in the North Sea (North Sea). Apache also pursues exploration interests in other areas that may over time result in reportable discoveries and development opportunities.

The downward pressure on crude oil prices that began in late 2014 and extended throughout 2015 continues to impact 2016 results. Apache’s average realized crude oil prices decreased 34 percent for the quarter from the first quarter of 2015. Additionally, natural gas and natural gas liquids prices are significantly lower than the comparable 2015 period. In response to these price declines, Apache continues to focus on matters within our control: capital spending, overhead, and lease operating costs.

• We significantly reduced capital spending in 2016, with first quarter capital spending decreasing approximately 65 percent from the comparable 2015 period. We will continue to adjust our capital spending in response to future commodity price fluctuations, cost realignments, and forecasted operating cash flows.

• We are realizing improved drilling efficiencies and cost reductions in our drilling and completion well costs. For example, in areas in North America where we are actively drilling, average drilling and completion costs on recent wells are down 45 percent compared to average 2014 well costs.

• We continue to monitor total overhead costs with a focus on balancing our operating cost structure with current and expected activity levels. Last year's organizational changes and steps to streamline our operational structure are allowing us to manage overhead levels and respond appropriately. We continue to make progress on our internal initiatives with a focus on reducing annualized rates.

• We have made significant progress reducing lease operating costs, which on a per-unit basis were 21 percent lower than the first quarter of 2015.

• We exited the quarter with $1.0 billion in cash and $3.5 billion in available committed borrowing capacity.

2016 Outlook

Apache remains committed to achieving "cash flow neutrality" in 2016 under our current budget. As planned, we were not cash flow neutral in the first quarter; however, we expect to generate a surplus for the balance of the year. As such, we believe we are on track to exit the year with no significant change in net debt (debt less cash) relative to year-end 2015. In addition, in response to strong performance from our North American assets, we expect less of a production decline from 2015 levels than originally expected and have updated our outlook to a decline in the 6 percent to 10 percent range, after adjusting for divestitures and volumes associated with Egypt's noncontrolling interest and taxes.

Operating Highlights

Significant operating activities for the quarter include the following:

Overall

• Equivalent production decline from first quarter of 2015 levels was 2 percent, despite a significant reduction in capital investments in 2015 and the first quarter of 2016 when compared to historical levels.

25

• Liquids production for the first quarter of 2016 averaged 350 thousand barrels of oil equivalent per day (Mboe/d), with crude oil representing 81 percent of total liquids production. Liquids production decreased 1 percent from the first quarter of 2015.

North America

• Onshore equivalent production was down 3 percent for the quarter relative to the 2015 period. This production performance is notable given a significant reduction in North American onshore exploration and development capital spending during 2015 and the first quarter of 2016.

• First quarter equivalent production from the Permian Basin region, which accounts for more than half of our total onshore North American production, increased 8 percent from the first quarter of 2015 despite significantly fewer wells placed on production during the first quarter of 2016.

International and Offshore

• In Egypt, we averaged 10 rigs and placed 23 wells on production during the quarter. Gross equivalent production increased 3 percent over the first quarter of 2015, driven by an increase of 6 percent in higher margin oil production, which was partially offset by a decline in lower margin natural gas production. On a net basis, equivalent production grew 2 percent from the first quarter of 2015.

• North Sea average daily production decreased by 1 percent for the first three months of 2016 from the first quarter of last year. This quarter’s production was negatively impacted by downtime from unexpected outages on third-party infrastructure, temporarily offsetting the impact of  four successful new wells placed on production in the quarter.

• Despite the impact of the unplanned third party facility downtime in the North Sea, we believe we are on track to achieve our full year International and Offshore production outlook of 170 to 190 Mboe/d.

26

Results of Operations

Oil and Gas Revenues

The table below presents revenues by geographic region and each region’s percent contribution to revenues for the first quarters of 2016 and 2015.

	For the Quarter Ended March 31,
	2016				2015
	$ Value		% Contribution		$ Value		% Contribution
	($ in millions)
Total Oil Revenues:
United States	$	313	38	%	$	510	39	%
Canada	39		5	%	60		5	%
North America	352		43	%	570		44	%
Egypt (1)	296		36	%	446		35	%
North Sea	174		21	%	277		21	%
International (1)	470		57	%	723		56	%
Total (1)	$	822	100	%	$	1,293	100	%
Total Natural Gas Revenues:
United States	$	62	28	%	$	103	33	%
Canada	41		18	%	67		22	%
North America	103		46	%	170		55	%
Egypt (1)	93		42	%	104		34	%
North Sea	27		12	%	34		11	%
International (1)	120		54	%	138		45	%
Total (1)	$	223	100	%	$	308	100	%
Total Natural Gas Liquids (NGL)
Revenues:
United States	$	34	81	%	$	47	81	%
Canada	3		7	%	6		10	%
North America	37		88	%	53		91	%
Egypt (1)	3		7	%	3		5	%
North Sea	2		5	%	2		4	%
International (1)	5		12	%	5		9	%
Total (1)	$	42	100	%	$	58	100	%
Total Oil and Gas Revenues:
United States	$	409	37	%	$	660	40	%
Canada	83		8	%	133		8	%
North America	492		45	%	793		48	%
Egypt (1)(2)	392		36	%	553		33	%
North Sea	203		19	%	313		19	%
International (1)	595		55	%	866		52	%
Total (1)	$	1,087	100	%	$	1,659	100	%
Discontinued Operations:
Oil Revenues	$	—			$	81
Natural Gas Revenues	—				87
NGL Revenues	—				—
Total	$	—			$	168

(1) Includes revenues attributable to a noncontrolling interest in Egypt.

27

Production

The table below presents the first-quarter 2016 and 2015 production and the relative increase or decrease from the prior period.

	For the Quarter Ended March 31,
	2016	Increase (Decrease)		2015
Oil Volume – b/d
United States	115,859	(9	)%	126,639
Canada	14,463	(14	)%	16,875
North America	130,322	(9	)%	143,514
Egypt(1)(2)	98,259	3	%	95,076
North Sea	56,962	(8	)%	61,699
International	155,221	(1	)%	156,775
Total	285,543	(5	)%	300,289
Natural Gas Volume – Mcf/d
United States	409,761	(6	)%	435,818
Canada	266,438	(7	)%	287,556
North America	676,199	(7	)%	723,374
Egypt(1)(2)	397,598	—	%	396,602
North Sea	70,795	40	%	50,445
International	468,393	5	%	447,047
Total	1,144,592	(2	)%	1,170,421
NGL Volume – b/d
United States	55,700	18	%	47,221
Canada	6,503	11	%	5,853
North America	62,203	17	%	53,074
Egypt(1)(2)	1,288	15	%	1,119
North Sea	1,409	59	%	886
International	2,697	35	%	2,005
Total	64,900	18	%	55,079
BOE per day(3)
United States	239,853	(3	)%	246,497
Canada	65,372	(7	)%	70,653
North America	305,225	(4	)%	317,150
Egypt(2)	165,813	2	%	162,295
North Sea	70,170	(1	)%	70,993
International	235,983	1	%	233,288
Total	541,208	(2	)%	550,438
Discontinued Operations:
Oil (b/d)	—			20,905
Natural Gas (Mcf/d)	—			230,691
NGL (b/d)	—			—
BOE/d	—			59,353

(1) Gross oil, natural gas, and NGL production in Egypt for the first quarters of 2016 and 2015 were as follows:

	For the Quarter Ended March 31,
	2016	2015
Oil (b/d)	209,847	197,785
Natural Gas (Mcf/d)	846,047	861,933
NGL (b/d)	2,145	2,321

(2) Includes production volumes per day attributable to a noncontrolling interest in Egypt for the first quarters of 2016 and 2015 as follows:

	For the Quarter Ended March 31,
	2016	2015
Oil (b/d)	32,676	31,692
Natural Gas (Mcf/d)	132,503	132,201
NGL (b/d)	429	373

(3) The table shows production on a barrel of oil equivalent basis (boe) in which natural gas is converted to an equivalent barrel of oil based on a 6:1 energy equivalent ratio. This ratio is not reflective of the price ratio between the two products.

28

Pricing

The table below presents first-quarter 2016 and 2015 pricing and the relative increase or decrease from the prior periods.

	For the Quarter Ended March 31,
	2016		Increase (Decrease)		2015
Average Oil Price - Per barrel
United States	$	29.77	(33	)%	$	44.73
Canada	29.40		(26	)%	39.76
North America	29.73		(33	)%	44.14
Egypt	33.04		(37	)%	52.06
North Sea	33.50		(33	)%	49.95
International	33.21		(35	)%	51.23
Total	31.62		(34	)%	47.84
Average Natural Gas Price - Per Mcf
United States	$	1.65	(37	)%	$	2.63
Canada	1.69		(34	)%	2.58
North America	1.67		(36	)%	2.61
Egypt	2.58		(12	)%	2.92
North Sea	4.24		(43	)%	7.40
International	2.83		(17	)%	3.43
Total	2.14		(27	)%	2.93
Average NGL Price - Per barrel
United States	$	6.61	(40	)%	$	11.00
Canada	5.58		(50	)%	11.09
North America	6.50		(41	)%	11.01
Egypt	26.92		(25	)%	35.85
North Sea	18.13		(27	)%	24.74
International	22.33		(28	)%	30.94
Total	7.16		(39	)%	11.74
Discontinued Operations:
Oil price ($/Bbl)	$	—			$	43.17
Natural Gas price ($/Mcf)	—				4.19
NGL price ($/Bbl)	—				—

Crude Oil Revenues Crude oil revenues for the first quarter of 2016 totaled $822 million, a $471 million decrease from the comparative 2015 quarter. A 5 percent decrease in average daily production reduced first-quarter 2016 revenues by $33 million compared to the prior-year quarter, while 34 percent lower average realized prices decreased revenues by $438 million. Crude oil prices realized in the first quarter of 2016 averaged $31.62 per barrel, compared with $47.84 per barrel in the comparative prior-year quarter. Crude oil accounted for 76 percent of oil and gas production revenues and 53 percent of worldwide production in the first quarter of 2016.

Worldwide oil production decreased 14.7 Mb/d to 285.5 Mb/d, primarily a result of reduced drilling activity in response to low commodity prices. Decreases from natural decline were partially offset by new production in the North Sea’s Beryl field and in Egypt.

Natural Gas Revenues Gas revenues for the first quarter of 2016 totaled $223 million, an $85 million decrease from the comparative 2015 quarter, driven by 27 percent lower average realized prices. Worldwide natural gas production was essentially flat between the periods. Natural gas accounted for 21 percent of our oil and gas production revenues and 35 percent of our equivalent production.

29

NGL Revenues NGL revenues for the first quarter of 2016 totaled $42 million, a $16 million decrease from the comparative 2015 quarter. An 18 percent increase in average daily production increased first-quarter 2016 revenues by $7 million, while 39 percent lower average realized prices decreased revenues by $23 million. NGLs accounted for 3 percent of our oil and gas production revenues and 12 percent of our equivalent production.

Worldwide production of NGLs increased 9.8 Mb/d to 64.9 Mb/d in the first quarter of 2016, primarily the result of new production from completion activity in our North American onshore areas, gas processing plant downtime in the prior year period, and changes to existing gas processing arrangements.

Operating Expenses

The table below presents a comparison of our expenses on an absolute dollar basis and a boe basis. Our discussion may reference expenses on a boe basis, on an absolute dollar basis or both, depending on their relevance. Operating expenses include costs attributable to a noncontrolling interest in Egypt but, for the quarter ended March 31, 2015, exclude discontinued operations in Australia.

	For the Quarter Ended March 31,
	2016		2015		2016		2015
	(In millions)				(Per boe)
Lease operating expense	$	378	$	481	$	7.67	$	9.70
Gathering and transportation	52		56		1.06		1.12
Taxes other than income	11		73		0.23		1.48
Exploration	95		258		1.93		5.22
General and administrative	93		84		1.90		1.70
Depreciation, depletion, and amortization:
Oil and gas property and equipment	636		743		12.91		15.01
Other assets	42		83		0.85		1.68
Asset retirement obligation accretion	38		36		0.76		0.74
Impairments	—		1,912		—		38.59
Transaction, reorganization, and separation	15		54		0.31		1.09
Financing costs, net	105		124		2.11		2.49
Total	$	1,465	$	3,904	$	29.73	$	78.82

Lease Operating Expenses (LOE) LOE decreased $103 million, or 21 percent for the quarter on an absolute dollar basis relative to the comparable period of 2015. On a per-unit basis, LOE decreased 21 percent to $7.67 per boe for the first quarter of 2016 as compared to the prior-year period. These reductions reflect the impact of our continued focus on costs, a decrease in cost types that trend downward in lower commodity price environments, the timing of workovers and other expenditures in the Permian and North Sea, and the favorable impact of the strengthening U.S. dollar period over period.

Gathering and Transportation Gathering and transportation costs totaled $52 million in the first quarter of 2016, a decrease of $4 million from the first quarter of 2015 on lower production volumes and rate changes primarily in our North American onshore properties.

Taxes other than Income Taxes other than income totaled $11 million for the first quarter of 2016, a decrease of $62 million from the comparative prior-year period. The North Sea Petroleum Revenue Tax (PRT) is assessed on qualifying fields in the U.K. North Sea. For the first quarter of 2016, U.K. PRT was $41 million lower than the 2015 period as a result of lower revenues during the first quarter of 2016, a lower PRT rate, and additional qualifying costs reducing prior-year PRT. Severance tax expense and ad valorem tax expense decreased $11 million and $8 million, respectively, on lower oil production and commodity prices during the first quarter compared to the prior year period.

On March 24, 2016, the U.K. government released Finance Bill 2016, which provides tax relief to exploration and production (E&P) companies operating in the North Sea. The bill is expected to receive Royal Assent later this year. Under the bill, the U.K. PRT rate will be reduced to zero from the current 35 percent rate and will be effective January 1, 2016. Upon enactment, PRT expense ceases prospectively. As a further result of this change, the Company expects to record a charge of approximately $290 million (after-tax) for PRT benefits that are no longer expected to be realizable from future abandonment activities.

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Exploration Expense Exploration expense includes unproved leasehold impairments, exploration dry hole expense, geological and geophysical expenses, and the costs of maintaining and retaining unproved leasehold properties. Exploration expenses in the first quarter of 2016decreased$163 million, or 63 percent, compared to the first quarter of 2015, as a result of a reduction in unproved leasehold impairments and reduced drilling activity in response to lower commodity prices. The following table presents a summary of exploration expense:

	For the Quarter Ended March 31,
	2016		2015
	(In millions)
Unproved leasehold impairments	$	42	$	168
Dry hole expense	29		34
Geological and geophysical expense	5		30
Exploration overhead and other	19		26
	$	95	$	258

General and Administrative (G&A) Expenses Despite our continued focus on cost reduction efforts, G&A expense for the quarter was $9 million higher than the first quarter of 2015, which included $14 million in reductions from lower than expected incentive compensation payouts and lower stock based compensation expense. Absent these benefits to the first-quarter 2015 G&A, this quarter's G&A expense would have been $5 million lower.

Depreciation, Depletion, and Amortization (DD&A) Oil and gas property DD&A expense of $636 million in the first quarter of 2016 decreased $107 million compared to the first quarter of 2015. The Company's oil and gas property DD&A rate decreased $2.10 per boe in the first quarter of 2016 compared to the first quarter of 2015. The primary factor driving both lower absolute dollar expense and lower DD&A per boe rates was the reduction in the Company's oil and gas properties as a result of impairments to proved properties in 2015.

Impairments During the first quarter of 2016, the Company did not record any material asset impairments of oil and gas proved properties, compared to $1.9 billion of impairments in the first quarter of 2015.

Transaction, Reorganization, and Separation The Company incurred $15 million for the first quarter of 2016 related to company reorganization costs. The costs incurred for the year includes approximately $11 million for employee separation and $4 million for consolidation of office space and other reorganization efforts.

Financing Costs, Net Financing costs incurred during the period comprised the following:

	For the Quarter Ended March 31,
	2016			2015
	(In millions)
Interest expense	$	116		$	128
Amortization of deferred loan costs	1			2
Capitalized interest	(11		)	(4		)
Interest income	(1		)	(2		)
Financing costs, net	$	105		$	124

Net financing costs decreased $19 million in the first quarter of 2016 compared to the same prior-year period on lower interest expense.

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Provision for Income Taxes The Company estimates its annual effective income tax rate for continuing operations in recording its quarterly provision for income taxes in the various jurisdictions in which the Company operates. Non-cash impairments of the carrying value of the Company’s proved and unproved oil and gas properties, statutory tax rate changes, and other significant or unusual items are recognized as discrete items in the quarter in which they occur.

During the first quarter of 2016, Apache’s effective income tax rate was primarily impacted by an increase in the valuation allowance on Canadian deferred tax assets. During the first quarter of 2015, Apache’s effective tax rate was primarily impacted by non-cash impairments of the carrying value of the Company's proved oil and gas properties and a $414 million discrete deferred tax benefit associated with a reduction in the U.K. statutory income tax rate from 62 percent to 50 percent.

On March 24, 2016, the U.K. government released Finance Bill 2016. The bill is expected to receive Royal Assent later this year. Under the bill, the U.K. corporate income tax rate will be reduced from 50 percent to 40 percent, effective January 1, 2016. Under U.S. GAAP, the effect of a change in tax rate will be recognized at the date of enactment (i.e., the date when the bill receives Royal Assent). As such, the proposed rate change is not reflected in the current financial statements. Upon the bill receiving Royal Assent, the Company will record a deferred tax benefit of approximately $239 million related to the remeasurement of the Company's December 31, 2015 U.K. deferred income tax liability.

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Capital Resources and Liquidity

Operating cash flows are the Company’s primary source of liquidity. We may also elect to utilize available committed borrowing capacity, access to both debt and equity capital markets, or proceeds from the sale of nonstrategic assets for all other liquidity and capital resource needs.

Apache’s operating cash flows, both in the short-term and the long-term, are impacted by highly volatile oil and natural gas prices, as well as costs and sales volumes. Significant changes in commodity prices impact our revenues, earnings, and cash flows. These changes potentially impact our liquidity if costs do not trend with changes in commodity prices. Historically, costs have trended with commodity prices, albeit with a lag. Sales volumes also impact cash flows; however, they have a less volatile impact in the short-term.

Apache’s long-term operating cash flows are dependent on reserve replacement and the level of costs required for ongoing operations. Cash investments are required to fund activity necessary to offset the inherent declines in production and proved crude oil and natural gas reserves. Future success in maintaining and growing reserves and production is highly dependent on the success of our drilling program and our ability to add reserves economically. Deterioration in commodity prices also impacts estimated quantities of proved reserves. In the first quarter of 2016, we recognized negative reserve revisions of approximately 5 percent of our year-end 2015 estimated proved reserves as a result of lower prices. If realized prices for the remainder of 2016 approximate commodity future prices as of March 31, 2016, the Company is reasonably likely to report additional negative revisions, currently estimated at 4 to 6 percent of year-end 2015 estimated proved reserves.

We believe the liquidity and capital resource alternatives available to Apache, combined with proactive measures to adjust our capital budget to reflect lower commodity prices and anticipated operating cash flows, will be adequate to fund short-term and long-term operations, including our capital spending program, repayment of debt maturities, payment of dividends, and any amount that may ultimately be paid in connection with commitments and contingencies.

For additional information, please see Part II, Item 1A, “Risk Factors” of the Previously Filed Quarterly Report and Part I, Items 1 and 2, “Business and Properties,” and Item 1A, “Risk Factors,” in our Annual Report on Form 10-K for our 2015 fiscal year.

Sources and Uses of Cash

The following table presents the sources and uses of our cash and cash equivalents for the periods presented.

	For the Three months ended March 31,
	2016			2015
	(In millions)
Sources of Cash and Cash Equivalents:
Net cash provided by continuing operating activities	$	239		$	509
Net commercial paper and bank loan borrowings	—			1,028
Other	12			—
	251			1,537
Uses of Cash and Cash Equivalents:
Capital expenditures(1)	$	546		$	1,580
Leasehold and property acquisitions	19			91
Net cash used by Australia discontinued operations	—			192
Dividends paid	95			94
Distributions to noncontrolling interest	54			21
Other	—			57
	714			2,035
Increase (decrease) in cash and cash equivalents	$	(463	)	$	(498	)

(1) The table presents capital expenditures on a cash basis; therefore, the amounts may differ from those discussed elsewhere in this document, which include accruals.

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Net Cash Provided by Continuing Operating Activities Operating cash flows are our primary source of capital and liquidity and are impacted, both in the short-term and the long-term, by volatile oil and natural gas prices. The factors that determine operating cash flow are largely the same as those that affect net earnings, with the exception of non-cash expenses such as DD&A, exploratory dry hole expense, asset impairments, asset retirement obligation (ARO) accretion, and deferred income tax expense, which affect earnings but do not affect cash flows.

Net cash provided by continuing operating activities for the first three months of 2016 totaled $239 million, a decrease of $270 million from the first three months of 2015. The decrease primarily reflects lower commodity prices.

For a detailed discussion of commodity prices, production, and expenses, refer to the “Results of Operations” of this Item 2. For additional detail on the changes in operating assets and liabilities and the non-cash expenses that do not impact net cash provided by operating activities, please see the statement of consolidated cash flows in Part I, Item 1, Financial Statements of this Current Report on Form 8-K.

Capital Expenditures Worldwide exploration and development (E&D) expenditures for the first three months of 2016 totaled $546 million, compared to $1.5 billion for the first three months of 2015. Apache operated an average of 24 drilling rigs during the first quarter of 2016.

Apache also completed leasehold and property acquisitions totaling $19 million and $91 million during the first three months of 2016 and 2015, respectively. Our 2016 acquisition investments continue to focus on adding new leasehold positions to our North American onshore portfolio.

Apache’s investment in gas gathering, transmission, and processing facilities totaled $63 million in the first three months of 2015. No meaningful expenses were incurred during 2016.

Dividends For the three-month periods ended March 31, 2016 and 2015, the Company paid $95 million and $94 million, respectively, in dividends on its common stock.

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Liquidity

The following table presents a summary of our key financial indicators at the dates presented:

	March 31, 2016		December 31, 2015
	(In millions)
Cash and cash equivalents	$	1,004	$	1,467
Total debt	8,719		8,717
Equity	9,000		9,490
Available committed borrowing capacity	3,500		3,500

Cash and cash equivalents The Company had $1.0 billion in cash and cash equivalents as of March 31, 2016, compared to $1.5 billion at December 31, 2015. At March 31, 2016, approximately $810 million of the cash was held by foreign subsidiaries. The cash held by foreign subsidiaries should not be subject to additional U.S. income taxes if repatriated. The majority of the cash is invested in highly liquid, investment grade securities with maturities of three months or less at the time of purchase.

Debt As of March 31, 2016, outstanding debt, which consisted of notes and debentures, totaled $8.7 billion. As of March 31, 2016, Apache had $416,000 of notes due June 2016 and $483,000 of notes due March 2017 classified as short-term debt on the consolidated balance sheet.

Available committed borrowing capacity In June 2015, the Company entered into a $3.5 billion five-year revolving credit facility which matures in June 2020. Proceeds from borrowings may be used for general corporate purposes. Apache’s available borrowing capacity under this facility supports its $3.5 billion commercial paper program. The commercial paper program, which is subject to market availability, facilitates Apache borrowing funds for up to 270 days at competitive interest rates. As of March 31, 2016, the Company had no debt outstanding under commercial paper, committed bank facilities, and uncommitted bank lines.

In February 2016, the Company entered into a three-year letter of credit facility providing £900 million in commitments, with options to increase commitments to £1.075 billion and extend the term by one year. The facility is available for letters of credit and loans to cash collateralize letter of credit obligations to the extent letters of credit are unavailable under the facility. The facility’s representations and warranties, covenants, and events of default are substantially similar to those in the Company’s $3.5 billion revolving credit facility. Commissions are payable on outstanding letters of credit and borrowings bear interest (at a base rate or LIBOR), plus a margin. Letter of credit commissions, the interest margin, and the facility fee vary depending on the Company’s senior unsecured long-term debt rating. The Company has not requested any letters of credit or borrowings under this facility as of the date of the Previously Filed Quarterly Report. This facility is available for the Company’s letter of credit needs, particularly those which may arise in respect of abandonment obligations assumed in various North Sea acquisitions.

The Company was in compliance with the terms of all credit facilities as of March 31, 2016.

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ITEM 3 – QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Commodity Risk

The Company’s revenues, earnings, cash flow, capital investments and, ultimately, future rate of growth are highly dependent on the prices we receive for our crude oil, natural gas, and NGLs, which have historically been very volatile because of unpredictable events such as economic growth or retraction, weather, political climate, and global supply and demand. Our average crude oil realizations have decreased 34 percent to $31.62 per barrel in the first quarter of 2016 from $47.84 per barrel in the comparable period of 2015. Our average natural gas price realizations have decreased 27 percent to $2.14 per Mcf in the first quarter of 2016 from $2.93 per Mcf in the comparable period of 2015.

We periodically enter into derivative positions on a portion of our projected oil and natural gas production through a variety of financial and physical arrangements intended to manage fluctuations in cash flows resulting from changes in commodity prices. Apache periodically uses futures contracts, swaps, and options to mitigate commodity price risk. Apache does not hold or issue derivative instruments for trading purposes. As of March 31, 2016, Apache had no open commodity derivative positions.

Foreign Currency Risk

The Company’s cash flow stream relating to certain international operations is based on the U.S. dollar equivalent of cash flows measured in foreign currencies. In Canada, oil and gas prices and costs, such as equipment rentals and services, are generally denominated in Canadian dollars but heavily influenced by U.S. markets. Our North Sea production is sold under U.S. dollar contracts, and the majority of costs incurred are paid in British 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. Revenue and disbursement transactions denominated in Canadian dollars and British pounds are converted to U.S. dollar equivalents based on 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 Company’s provision for income tax expense on the statement of consolidated operations. A foreign currency net gain or loss of $133 million would result from a 10 percent weakening or strengthening, respectively, in the Canadian dollar and British pound as of March 31, 2016.

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