Concho Resources (CXO) 10-Q 2012 Q3 Quarterly report

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2012

or

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

For the transition period from to

Commission file number: 1-33615

Concho Resources Inc.

(Exact name of registrant as specified in its charter)

Delaware	76-0818600
(State or other jurisdiction	(I.R.S. Employer
of incorporation or organization)	Identification No.)
One Concho Center
600 West Illinois Avenue
Midland, Texas	79701
(Address of principal executive offices)	(Zip code)

(432) 683-7443

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o  

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer þ	Accelerated filer o
Non-accelerated filer   o (Do not check if a smaller reporting company)	Smaller reporting company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ  

Number of shares of the registrant’s common stock outstanding at November 5, 2012: 104,591,717 shares

TABLE OF CONTENTS

PART I – FINANCIAL INFORMATION ………………………………………………………………………….. iii 

Item 1. Consolidated Financial Statements (Unaudited) ………………………………………………………….   iii

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations ……………  42

Item 3. Quantitative and Qualitative Disclosures About Market Risk ……………………………………………   64

Item 4. Controls and Procedures ………………………………………………………………………………….      66

PART II – OTHER INFORMATION ………………………………………………………………………………        67

Item 1. Legal Proceedings ………………………………………………………………………………………...       67

Item 1A. Risk Factors …………………………………………………………………………………………….      67

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds ……………………………………………     67

Item 6. Exhibits ……………………………………………………………………………………………………      68

i

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

Various statements contained in or incorporated by reference into this report that express a belief, expectation, or intention, or that are not statements of historical fact, are forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 (the “Securities Act”) and Section 21E of the Securities Exchange Act of 1934 (the “Exchange Act”). These forward-looking statements include statements, projections and estimates concerning our operations, performance, business strategy, oil and natural gas reserves, drilling program, capital expenditures, liquidity and capital resources, the timing and success of specific projects, outcomes and effects of litigation, claims and disputes, derivative activities and potential financing. Forward-looking statements are generally accompanied by words such as “estimate,” “project,” “predict,” “believe,” “expect,” “anticipate,” “potential,” “could,” “may,” “foresee,” “plan,” “goal” or other words that convey the uncertainty of future events or outcomes. Forward-looking statements are not guarantees of performance. We have based these forward-looking statements on our current expectations and assumptions about future events. These statements are based on certain assumptions and analyses made by us in light of our experience and our perception of historical trends, current conditions and expected future developments as well as other factors we believe are appropriate under the circumstances. Actual results may differ materially from those implied or expressed by the forward-looking statements. These forward-looking statements speak only as of the date of this report, or if earlier, as of the date they were made. We disclaim any obligation to update or revise these statements unless required by law, and we caution you not to rely on them unduly. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties relating to, among other matters, the risks discussed in our Annual Report on Form 10-K for the year ended December 31, 2011 and in this report, as well as those factors summarized below:

·sustained or further declines in the prices we receive for our oil and natural gas;

·uncertainties about the estimated quantities of oil and natural gas reserves;

·drilling and operating risks, including risks related to properties where we do not serve as the operator and risks related to hydraulic fracturing activities;

·the adequacy of our capital resources and liquidity including, but not limited to, access to additional borrowing capacity under our credit facility;

·the effects of government regulation, permitting and other legal requirements, including new legislation or regulation of hydraulic fracturing;

·difficult and adverse conditions in the domestic and global capital and credit markets;

·risks related to the concentration of our operations in the Permian Basin of Southeast New Mexico and West Texas;

·shortages of oilfield equipment, supplies, services and qualified personnel and increased costs for such equipment, supplies, services and personnel;

·potential financial losses or earnings reductions from our commodity price management program;

·risks and liabilities associated with acquired properties or businesses;

·uncertainties about our ability to successfully execute our business and financial plans and strategies;

·uncertainties about our ability to replace reserves and economically develop our current reserves;

·general economic and business conditions, either internationally or domestically or in the jurisdictions in which we operate;

·competition in the oil and natural gas industry; and

·uncertainty concerning our assumed or possible future results of operations.

Reserve engineering is a process of estimating underground accumulations of oil and natural gas that cannot be measured in an exact way. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data and price and cost assumptions made by our reserve engineers. In addition, the results of drilling, testing and production activities may justify revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ from the quantities of oil and natural gas that are ultimately recovered.   

ii

PART I – FINANCIAL INFORMATION

Item 1.  Consolidated Financial Statements (Unaudited)

Consolidated Balance Sheets at September 30, 2012 and December 31, 2011 ……...……….……...……….……...…………	1
Consolidated Statements of Operations for the Three and Nine Months Ended September 30, 2012 and 2011 ……...……….	2
Consolidated Statement of Stockholders' Equity for the Nine Months Ended September 30, 2012 …………………………...	3
Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2012 and 2011…………………………	4
Condensed Notes to Consolidated Financial Statements ……………………………………………………………………….	5

iii

Concho Resources Inc.
Consolidated Balance Sheets
Unaudited
					September 30,		December 31,
(in thousands, except share and per share amounts)					2012		2011
Assets
Current assets:
	Cash and cash equivalents ...................................................................................................................................................................................................................			$	291	$	342
	Accounts receivable, net of allowance for doubtful accounts:
		Oil and natural gas ...........................................................................................................................................................................................................................			212,037		213,921
		Joint operations and other ..............................................................................................................................................................................................................			225,225		153,746
	Derivative instruments ...........................................................................................................................................................................................................................				35,793		1,698	��
	Deferred income taxes ...........................................................................................................................................................................................................................				-		28,793
	Prepaid costs and other .........................................................................................................................................................................................................................				23,522		12,523
			Total current assets......................................................................................................................................................................................................................		496,868		411,023
Property and equipment:
	Oil and natural gas properties, successful efforts method ..............................................................................................................................................................				9,724,422		7,347,460
	Accumulated depletion and depreciation ..........................................................................................................................................................................................				(1,542,056)		(1,116,545)
		Total oil and natural gas properties, net ......................................................................................................................................................................................			8,182,366		6,230,915
	Other property and equipment, net .....................................................................................................................................................................................................				97,946		59,203
		Total property and equipment, net................................................................................................................................................................................................			8,280,312		6,290,118
Funds held in escrow ...................................................................................................................................................................................................................................					-		17,394
Deferred loan costs, net ..............................................................................................................................................................................................................................					80,843		65,641
Intangible asset - operating rights, net .....................................................................................................................................................................................................					32,263		33,425
Inventory ......................................................................................................................................................................................................................................................					27,664		19,419
Noncurrent derivative instruments ...........................................................................................................................................................................................................					6,560		7,944
Other assets ...................................................................................................................................................................................................................................................					8,507		4,612
Total assets ...................................................................................................................................................................................................................................................				$	8,933,017	$	6,849,576
Liabilities and Stockholders’ Equity
Current liabilities:
	Accounts payable:
		Trade ..................................................................................................................................................................................................................................................		$	18,206	$	23,341
		Related parties...................................................................................................................................................................................................................................			227		11
	Bank overdrafts ......................................................................................................................................................................................................................................				40,524		39,241
	Revenue payable ....................................................................................................................................................................................................................................				142,388		146,061
	Accrued and prepaid drilling costs .......................................................................................................................................................................................................				340,245		293,919
	Derivative instruments............................................................................................................................................................................................................................				2,015		56,218
	Deferred income taxes ...........................................................................................................................................................................................................................				11,402		-
	Other current liabilities ...........................................................................................................................................................................................................................				145,161		142,686
			Total current liabilities ................................................................................................................................................................................................................		700,168		701,477
Long-term debt ............................................................................................................................................................................................................................................					3,600,983		2,080,141
Deferred income taxes.................................................................................................................................................................................................................................					1,148,383		1,002,295
Noncurrent derivative instruments ...........................................................................................................................................................................................................					2,141		32,254
Asset retirement obligations and other long-term liabilities .................................................................................................................................................................					98,904		52,670
Commitments and contingencies (Note J) ..............................................................................................................................................................................................
Stockholders’ equity:
	Common stock, $0.001 par value; 300,000,000 authorized; 104,666,566 and 103,756,222
		shares issued at September 30, 2012 and December 31, 2011, respectively ........................................................................................................................			105		104
	Additional paid-in capital .....................................................................................................................................................................................................................				1,973,774		1,925,757
	Retained earnings ...................................................................................................................................................................................................................................				1,415,276		1,058,874
	Treasury stock, at cost; 81,393 and 55,990 shares at September 30, 2012 and December 31,
		2011, respectively ............................................................................................................................................................................................................................			(6,717)		(3,996)
			Total stockholders’ equity..........................................................................................................................................................................................................		3,382,438		2,980,739
Total liabilities and stockholders’ equity .................................................................................................................................................................................................				$	8,933,017	$	6,849,576
The accompanying notes are an integral part of these consolidated financial statements.

Concho Resources Inc.
Consolidated Statements of Operations
Unaudited
			Three Months Ended				Nine Months Ended
			September 30,				September 30,
(in thousands, except per share amounts)				2012		2011		2012		2011
Operating revenues:
	Oil sales .............................................................................................................................................................................................................................................		$	407,062	$	332,659	$	1,182,022	$	957,833
	Natural gas sales ................................................................................................................................................................................................................................			90,485		121,809		256,126		303,707
		Total operating revenues ..................................................................................................................................................................................................................		497,547		454,468		1,438,148		1,261,540
Operating costs and expenses:
	Oil and natural gas production ...........................................................................................................................................................................................................			96,666		84,050		276,505		217,285
	Exploration and abandonments .........................................................................................................................................................................................................			6,958		3,498		27,335		4,624
	Depreciation, depletion and amortization ...........................................................................................................................................................................................			157,621		115,730		434,940		304,899
	Accretion of discount on asset retirement obligations ........................................................................................................................................................................			1,420		751		3,455		2,170
	Impairments of long-lived assets .......................................................................................................................................................................................................			-		-		-		76
	General and administrative (including non-cash based compensation of $7,959 and
		$4,673 for the three months ended September 30, 2012 and 2011, respectively,
		and $21,434 and $13,866 for the nine months ended  September 30, 2012 and
		2011, respectively …………….........................................................................................................................................................................................................		34,873		22,873		94,228		66,883
	(Gain) loss on derivatives not designated as hedges ..........................................................................................................................................................................			135,415		(385,222)		(109,542)		(296,962)
		Total operating costs and expenses ..................................................................................................................................................................................................		432,953		(158,320)		726,921		298,975
Income from operations ...................................................................................................................................................................................................................				64,594		612,788		711,227		962,565
Other income (expense):
	Interest expense .................................................................................................................................................................................................................................			(51,337)		(32,881)		(129,073)		(84,201)
	Other, net ...........................................................................................................................................................................................................................................			(3,114)		(2,503)		(4,917)		(4,590)
		Total other expense ..........................................................................................................................................................................................................................		(54,451)		(35,384)		(133,990)		(88,791)
Income from continuing operations before income taxes ................................................................................................................................................................				10,143		577,404		577,237		873,774
	Income tax expense ...........................................................................................................................................................................................................................			(4,155)		(221,199)		(220,835)		(334,000)
Income from continuing operations .................................................................................................................................................................................................				5,988		356,205		356,402		539,774
Income from discontinued operations, net of tax .............................................................................................................................................................................				-		-		-		91,188
Net income ........................................................................................................................................................................................................................................			$	5,988	$	356,205	$	356,402	$	630,962
Basic earnings per share:
	Income from continuing operations ...................................................................................................................................................................................................		$	0.06	$	3.47	$	3.46	$	5.27
	Income from discontinued operations, net of tax ...............................................................................................................................................................................			-		-		-		0.88
		Net income .......................................................................................................................................................................................................................................	$	0.06	$	3.47	$	3.46	$	6.15
	Weighted average shares used in basic earnings per share..................................................................................................................................................................			103,292		102,733		103,088		102,517
Diluted earnings per share:
	Income from continuing operations ...................................................................................................................................................................................................		$	0.06	$	3.44	$	3.43	$	5.21
	Income from discontinued operations, net of tax ...............................................................................................................................................................................			-		-		-		0.88
		Net income  ......................................................................................................................................................................................................................................	$	0.06	$	3.44	$	3.43	$	6.09
	Weighted average shares used in diluted earnings per share ...............................................................................................................................................................			104,040		103,696		103,898		103,613
The accompanying notes are an integral part of these consolidated financial statements.

2

Concho Resources Inc.
Consolidated Statement of Stockholders’ Equity
Unaudited
							Additional							Total
			Common Stock				Paid-in		Retained	Treasury Stock			Stockholders’
(in thousands)			Shares		Amount		Capital		Earnings	Shares		Amount		Equity
BALANCE AT DECEMBER 31, 2011 ...........................................................................................................................................................................................			103,756	$	104	$	1,925,757	$	1,058,874	56	$	(3,996)	$	2,980,739
	Net income......................................................................................................................................................................................................................................		-		-		-		356,402	-		-		356,402
	Stock options exercised ..................................................................................................................................................................................................................		496		1		8,061		-	-		-		8,062
	Grants of restricted stock ...............................................................................................................................................................................................................		466		-		-		-	-		-		-
	Cancellation of restricted stock .......................................................................................................................................................................................................		(51)		-		-		-	-		-		-
	Stock-based compensation .............................................................................................................................................................................................................		-		-		21,434		-	-		-		21,434
	Excess tax benefits related to stock-based
		compensation.................................................................................................................................................................................................................................	-		-		18,522		-	-		-		18,522
	Purchase of treasury stock .............................................................................................................................................................................................................		-		-		-		-	25		(2,721)		(2,721)
BALANCE AT SEPTEMBER 30, 2012 ..........................................................................................................................................................................................			104,667	$	105	$	1,973,774	$	1,415,276	81	$	(6,717)	$	3,382,438
The accompanying notes are an integral part of these consolidated financial statements.

3

Concho Resources Inc.
Consolidated Statements of Cash Flows
Unaudited
					Nine Months Ended
					September 30,
(in thousands)					2012		2011
CASH FLOWS FROM OPERATING ACTIVITIES:
	Net income.......................................................................................................................................................................................................................................				$	356,402	$	630,962
	Adjustments to reconcile net income to net cash provided by operating activities:
		Depreciation, depletion and amortization ..............................................................................................................................................................................				434,940		304,899
		Impairments of long-lived assets .............................................................................................................................................................................................				-		76
		Accretion of discount on asset retirement obligations ..........................................................................................................................................................				3,455		2,170
		Exploration and abandonments, including dry holes ...........................................................................................................................................................				15,224		807
		Non-cash compensation expense ............................................................................................................................................................................................				21,434		13,866
		Deferred income taxes ...............................................................................................................................................................................................................				204,804		312,199
		Loss on sale of assets, net...........................................................................................................................................................................................................				285		3,129
		Gain on derivatives not designated as hedges .......................................................................................................................................................................				(109,542)		(296,962)
		Discontinued operations ............................................................................................................................................................................................................				-		(82,118)
		Other non-cash items ..................................................................................................................................................................................................................				9,066		309
	Changes in operating assets and liabilities, net of acquisitions:
			Accounts receivable .................................................................................................................................................................................................................			(54,752)		(125,091)
			Prepaid costs and other ...........................................................................................................................................................................................................			(14,894)		(8,420)
			Inventory ...................................................................................................................................................................................................................................			(8,528)		1,204
			Accounts payable .....................................................................................................................................................................................................................			(4,919)		(34,334)
			Revenue payable ......................................................................................................................................................................................................................			(3,673)		86,199
			Other current liabilities .............................................................................................................................................................................................................			(3,666)		(29,909)
				Net cash provided by operating activities ........................................................................................................................................................................		845,636		778,986
CASH FLOWS FROM INVESTING ACTIVITIES:
	Capital expenditures on oil and natural gas properties ...........................................................................................................................................................					(2,334,246)		(1,046,208)
	Additions to other property and equipment ..............................................................................................................................................................................					(47,489)		(29,954)
	Proceeds from the sale of assets ..................................................................................................................................................................................................					4,419		196,252
	Funds held in escrow ......................................................................................................................................................................................................................					17,394		-
	Settlements paid on derivatives not designated as hedges .....................................................................................................................................................					(7,485)		(77,835)
				Net cash used in investing activities ..................................................................................................................................................................................		(2,367,407)		(957,745)
CASH FLOWS FROM FINANCING ACTIVITIES:
	Proceeds from issuance of debt ...................................................................................................................................................................................................					3,856,500		2,079,000
	Payments of debt ...........................................................................................................................................................................................................................					(2,336,000)		(1,949,500)
	Exercise of stock options ..............................................................................................................................................................................................................					8,062		7,661
	Excess tax benefit from stock-based compensation ...............................................................................................................................................................					18,522		23,222
	Payments for loan costs ................................................................................................................................................................................................................					(23,926)		(24,466)
	Purchase of treasury stock ...........................................................................................................................................................................................................					(2,721)		(1,946)
	Bank overdrafts .............................................................................................................................................................................................................................					1,283		44,578
				Net cash provided by financing activities ........................................................................................................................................................................		1,521,720		178,549
				Net decrease in cash and cash equivalents ......................................................................................................................................................................		(51)		(210)
Cash and cash equivalents at beginning of period ..................................................................................................................................................................						342		384
Cash and cash equivalents at end of period .............................................................................................................................................................................					$	291	$	174
SUPPLEMENTAL CASH FLOWS:
	Cash paid for interest and fees, net of $73 capitalized interest in 2011 ..............................................................................................................................				$	115,731	$	60,752
	Cash paid for income taxes .........................................................................................................................................................................................................				$	18,569	$	15,610
The accompanying notes are an integral part of these consolidated financial statements.

4

Note A. Organization and nature of operations

Concho Resources Inc. (the “Company”) is a Delaware corporation formed on February 22, 2006. The Company’s principal business is the acquisition, development and exploration of oil and natural gas properties primarily located in the Permian Basin region of Southeast New Mexico and West Texas.

Note B. Summary of significant accounting policies

Principles of consolidation.  The consolidated financial statements of the Company include the accounts of the Company and its wholly-owned subsidiaries. In addition, a third-party has formed entities to effectuate a tax-free exchange of assets for the Company.  The Company has 100 percent control over the decisions of the entities, but has no direct ownership. The third-party conveys ownership to the Company upon completion of the tax-free exchange process. The Company consolidates the financial statements of these entities. All material intercompany balances and transactions have been eliminated.

Discontinued operations. In March 2011, the Company sold its Bakken assets for cash consideration of approximately $195.9 million and recognized a pre-tax gain on the sale of assets of approximately $142.0 million. The Company has reflected the results of operations of these divested assets as discontinued operations, rather than as a component of continuing operations. See Note M for additional information regarding these divestitures and their discontinued operations.

Use of estimates in the preparation of financial statements.  Preparation of financial statements in conformity with generally accepted accounting principles in the United States of America (“U.S. GAAP”) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from these estimates. Depletion of oil and natural gas properties is determined using estimates of proved oil and natural gas reserves. There are numerous uncertainties inherent in the estimation of quantities of proved reserves and in the projection of future rates of production and the timing of development expenditures. Similarly, evaluations for impairment of proved and unproved oil and natural gas properties are subject to numerous uncertainties including, among others, estimates of future recoverable reserves and commodity price outlooks. Other significant estimates include, but are not limited to, the asset retirement obligations, fair value of derivative financial instruments, fair value measurements for business combinations and fair value of stock-based compensation.

Interim financial statements. The accompanying consolidated financial statements of the Company have not been audited by the Company’s independent registered public accounting firm, except that the consolidated balance sheet at December 31, 2011 is derived from audited consolidated financial statements.  In the opinion of management, the accompanying consolidated financial statements reflect all adjustments necessary to present fairly the Company’s financial position at September 30, 2012, its results of operations for the three and nine months ended September 30, 2012 and 2011, and its cash flows for the nine months ended September 30, 2012 and 2011. All such adjustments are of a normal recurring nature. In preparing the accompanying consolidated financial statements, management has made certain estimates and assumptions that affect reported amounts in the consolidated financial statements and disclosures of contingencies. Actual results may differ from those estimates. The results for interim periods are not necessarily indicative of annual results.

Certain disclosures have been condensed or omitted from these consolidated financial statements. Accordingly, these consolidated financial statements should be read with the audited consolidated financial statements and notes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2011.

6

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Deferred loan costs. Deferred loan costs are stated at cost, net of amortization, which is computed using the effective interest and straight-line methods. The Company had deferred loan costs of $80.8 million and $65.6 million, net of accumulated amortization of $35.5 million and $26.8 million, at September 30, 2012 and December 31, 2011, respectively.

Future amortization expense of deferred loan costs at September 30, 2012 was as follows:

(in thousands)
Remaining 2012 .................................................................................................................................................................................................................................		$	3,234
2013.......................................................................................................................................................................................................................................................			13,136
2014.......................................................................................................................................................................................................................................................			13,476
2015.......................................................................................................................................................................................................................................................			13,842
2016.......................................................................................................................................................................................................................................................			8,554
Thereafter ............................................................................................................................................................................................................................................			28,601
	Total ....................................................................................................................................................................................................................................................	$	80,843

Intangible assets.  The Company has capitalized certain operating rights acquired in an acquisition. The gross operating rights, which have no residual value, are amortized over the estimated economic life of 25 years. Impairment will be assessed if indicators of potential impairment exist or when there is a material change in the remaining useful economic life. The following table reflects the gross and net intangible assets at September 30, 2012 and December 31, 2011:

			September 30,		December 31,
(in thousands)			2012		2011
Gross intangible - operating rights ...........................................................................................................................................................		$	38,717	$	38,717
Accumulated amortization ......................................................................................................................................................................			(6,454)		(5,292)
	Net intangible - operating rights ...........................................................................................................................................................	$	32,263	$	33,425

The following table reflects amortization expense for the three and nine months ended September 30, 2012 and 2011:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in thousands)	2012		2011		2012		2011
Amortization expense ........................................................................................................................................................................................	$	388	$	388	$	1,162	$	1,162

7

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

The following table reflects the estimated aggregate amortization expense for each of the periods presented below at September 30, 2012:

(in thousands)
Remaining 2012 .................................................................................................................................................................................................................................		$	388
2013.......................................................................................................................................................................................................................................................			1,549
2014.......................................................................................................................................................................................................................................................			1,549
2015.......................................................................................................................................................................................................................................................			1,549
2016.......................................................................................................................................................................................................................................................			1,549
Thereafter ............................................................................................................................................................................................................................................			25,679
	Total ....................................................................................................................................................................................................................................................	$	32,263

Oil and natural gas sales and imbalances. Oil and natural gas revenues are recorded at the time of delivery of such products to pipelines for the account of the purchaser or at the time of physical transfer of such products to the purchaser. The Company follows the sales method of accounting for oil and natural gas sales, recognizing revenues based on the Company’s share of actual proceeds from the oil and natural gas sold to purchasers. Oil and natural gas imbalances are generated on properties for which two or more owners have the right to take production “in-kind” and, in doing so, take more or less than their respective entitled percentage. Imbalances are tracked by well, but the Company does not record any receivable from or payable to the other owners unless the imbalance has reached a level at which it exceeds the remaining reserves in the respective well. If reserves are insufficient to offset the imbalance and the Company is in an overtake position, a liability is recorded for the amount of shortfall in reserves valued at a contract price or the market price in effect at the time the imbalance is generated. If the Company is in an undertake position, a receivable is recorded for an amount that is reasonably expected to be received, not to exceed the current market value of such imbalance.

Treasury stock. Treasury stock purchases are recorded at cost.  Upon reissuance, the cost of treasury shares held is reduced by the average purchase price per share of the aggregate treasury shares held.

General and administrative expense. The Company receives fees for the operation of jointly-owned oil and natural gas properties and records such reimbursements as reductions of general and administrative expense. Such fees totaled approximately $4.4 million and $3.6 million for the three months ended September 30, 2012 and 2011, respectively, and $12.5 million and $9.3 million for the nine months ended September 30, 2012 and 2011, respectively.

Recent accounting pronouncements. In December 2011, the Financial Accounting Standards Board (the “FASB”) issued amendments to enhance disclosures required by U.S. GAAP by requiring improved information about financial instruments and derivative instruments that are either (i) offset in accordance with the current definition of “right of setoff” or the current balance sheet netting for derivative instruments allowed under current U.S. GAAP or (ii) subject to an enforceable master netting arrangement or similar agreement, irrespective of whether they are offset in accordance with either the definition of “right of setoff” or the current balance sheet netting for derivative instruments. This information will enable users of an entity’s financial statements to evaluate the effect or potential effect of netting arrangements on an entity’s financial position, including the effect or potential effect of rights of setoff associated with certain financial instruments and derivative instruments in the scope of the update.

8

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

An entity is required to apply the amendments for annual reporting periods beginning on or after January 1, 2013, and interim periods within those annual periods. An entity should provide the disclosures required by those amendments retrospectively for all comparative periods presented. The Company plans to adopt this update on January 1, 2013 and does not expect it to have a significant impact on the consolidated financial statements.

Note C. Exploratory well costs

The Company capitalizes exploratory well costs until a determination is made that the well has either found proved reserves or that it is impaired. The capitalized exploratory well costs are carried in unproved oil and natural gas properties. See Note R for the proved and unproved components of oil and natural gas properties.  If the exploratory well is determined to be impaired, the well costs are charged to expense. 

The following table reflects the Company’s capitalized exploratory well activity during the three and nine months ended September 30, 2012:

		Three Months Ended			Nine Months Ended
(in thousands)		September 30, 2012			September 30, 2012
Beginning capitalized exploratory well costs ..................................................................................................................			$	92,679	$	107,767
	Additions to exploratory well costs pending the determination of proved reserves ............................................			399,727		554,648
	Reclassifications due to determination of proved reserves .....................................................................................			(331,068)		(501,077)
	Exploratory well costs charged to expense .................................................................................................................			(2,188)		(2,188)
Ending capitalized exploratory well costs .......................................................................................................................			$	159,150	$	159,150

The following table provides an aging at September 30, 2012 and December 31, 2011 of capitalized exploratory well costs based on the date drilling was completed:

			September 30,		December 31,
(in thousands)			2012		2011
Exploratory wells in progress .................................................................................................................................................................		$	20,739	$	24,963
Capitalized exploratory well costs that have been capitalized for a period of one year or less ...............................................			138,411		82,804
Capitalized exploratory well costs that have been capitalized for a period greater than one year .........................................			-		-
	Total capitalized exploratory well costs ...........................................................................................................................................	$	159,150	$	107,767

At September 30, 2012, the Company had 104 gross exploratory wells either drilling or waiting on results from completion and testing, of which 49 wells were in the New Mexico Shelf area, 43 wells were in the Delaware Basin area and 12 wells were in the Texas Permian area.

9

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Note D. Acquisitions 

Three Rivers Acquisition. In July 2012, the Company acquired certain producing and non-producing assets from Three Rivers Operating Company LLC and certain affiliated entities (collectively, the “Three Rivers Acquisition”) for cash consideration of approximately $997.0 million, subject to customary post-closing adjustments.  The Three Rivers Acquisition was primarily funded with borrowings under the Company’s credit facility. The Company’s results of operations prior to July 2012 do not include results from the Three Rivers Acquisition.

The amounts reflected in the Company’s financial statements reflect management’s initial estimates of the fair values of the acquired assets and liabilities. Adjustments to the estimated asset values will be made once the final valuations are complete. The following table reflects the initial estimated fair value associated with the Three Rivers Acquisition:

(in thousands)
Fair value of net assets:
	Proved oil and natural gas properties.....................................................................................................................................................................		$	690,552
	Unproved oil and natural gas properties................................................................................................................................................................			334,687
		Total assets acquired.............................................................................................................................................................................................		1,025,239
	Current liabilities, including current portion of asset retirement obligations ..................................................................................................			(2,229)
	Asset retirement obligations assumed....................................................................................................................................................................			(26,002)
		Fair value of net assets acquired.........................................................................................................................................................................	$	997,008
Fair value of consideration paid for net assets:
	Cash consideration....................................................................................................................................................................................................		$	997,008

10

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

PDC Acquisition. In February 2012, the Company acquired certain producing and non-producing assets from Petroleum Development Corporation (the “PDC Acquisition”) for cash consideration of approximately $189.2 million.  The PDC Acquisition was primarily funded with borrowings under the Company’s credit facility. The Company’s results of operations prior to March 2012 do not include results from the PDC Acquisition.

The following table reflects the fair value of the acquired assets and liabilities associated with the PDC Acquisition:

(in thousands)
Fair value of net assets:
	Current assets .....................................................................................................................................................................................................................		$	2,366
	Proved oil and natural gas properties ............................................................................................................................................................................			159,314
	Unproved oil and natural gas properties .......................................................................................................................................................................			29,687
		Total assets acquired ....................................................................................................................................................................................................		191,367
	Current liabilities ................................................................................................................................................................................................................			(123)
	Asset retirement obligations assumed ...........................................................................................................................................................................			(2,050)
		Fair value of net assets acquired ................................................................................................................................................................................	$	189,194
Fair value of consideration paid for net assets:
	Cash consideration ...........................................................................................................................................................................................................		$	189,194

11

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

OGX Acquisition. In November 2011, the Company acquired three entities affiliated with OGX Holdings II, LLC (collectively, the “OGX Acquisition”) for cash consideration of approximately $252.0 million. The OGX Acquisition was primarily funded with borrowings under the Company’s credit facility. The Company’s results of operations prior to December 2011 do not include results from the OGX Acquisition.

The following table reflects the fair value of the acquired assets and liabilities associated with the OGX Acquisition:

(in thousands)
Fair value of net assets:
	Current assets, net of cash acquired of $205...........................................................................................................................................................			$	5,579
	Proved oil and natural gas properties .......................................................................................................................................................................				98,383
	Unproved oil and natural gas properties ..................................................................................................................................................................				164,798
		Total assets acquired ..............................................................................................................................................................................................			268,760
	Current liabilities ...........................................................................................................................................................................................................				(16,438)
	Asset retirement obligations .......................................................................................................................................................................................				(321)
			Fair value of net assets acquired ....................................................................................................................................................................	$	252,001
Fair value of consideration paid for net assets:
	Cash consideration, net of cash acquired of $205 ................................................................................................................................................			$	252,001

Pro forma data. The following unaudited pro forma combined condensed financial data for the three months ended September 30, 2011 and the nine months ended September 30, 2012 and 2011, were derived from the historical financial statements of the Company giving effect to the Three Rivers Acquisition, as if it had occurred on January 1, 2011. The results of operations since the closing of the Three Rivers Acquisition in July 2012 are included in the Company’s results of operations for the three and nine months ended September 30, 2012. The pro forma financial data does not include the results of operations for the OGX Acquisition or PDC Acquisition, as their results of operations were not deemed material. The unaudited pro forma combined condensed financial data has been included for comparative purposes only and is not necessarily indicative of the results that might have occurred had the Three Rivers Acquisition taken place as of the date indicated and is not intended to be a projection of future results.

		Three Months Ended				Nine Months Ended
			September 30,			September 30,
(in thousands, except per share amounts)			2011			2012		2011
			(unaudited)
Operating revenues ......................................................................................................................................................................................................................................			$	493,047	$	1,507,851	$	1,375,193
Net income ....................................................................................................................................................................................................................................................			$	357,114	$	346,180	$	640,026
Earnings per common share:
	Basic ...................................................................................................................................................................................................................................................		$	3.48	$	3.36	$	6.24
	Diluted ................................................................................................................................................................................................................................................		$	3.44	$	3.33	$	6.18

12

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Note E. Asset retirement obligations

The Company’s asset retirement obligations represent the estimated present value of the estimated cash flows the Company will incur to plug, abandon and remediate its producing properties at the end of their productive lives, in accordance with applicable state laws. The Company does not provide for a market risk premium associated with asset retirement obligations because a reliable estimate cannot be determined. The Company has no assets that are legally restricted for purposes of settling asset retirement obligations.

The Company’s asset retirement obligation transactions during the three and nine months ended September 30, 2012 and 2011 are summarized in the table below:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(in thousands)			2012		2011		2012		2011
Asset retirement obligations, beginning of period ..............................................................................................................................................		$	68,089	$	45,195	$	59,685	$	43,326
	Liabilities incurred from new wells ........................................................................................................................................................................		3,053		1,970		6,319		5,209
	Liabilities assumed in acquisitions ........................................................................................................................................................................		26,986		-		29,113		148
	Accretion expense for continuing operations .....................................................................................................................................................		1,420		751		3,455		2,170
	Accretion expense for discontinued operations .................................................................................................................................................		-		-		-		8
	Disposition of wells ..................................................................................................................................................................................................		-		-		(66)		(412)
	Liabilities settled upon plugging and abandoning wells ....................................................................................................................................		(272)		-		(514)		(686)
	Revision of estimates ..............................................................................................................................................................................................		3,151		(430)		4,435		(2,277)
Asset retirement obligations, end of period .........................................................................................................................................................		$	102,427	$	47,486	$	102,427	$	47,486

Note F. Incentive plans

Defined contribution plan. The Company sponsors a 401(k) defined contribution plan for the benefit of substantially all employees. Currently, the Company matches 100 percent of employee contributions, not to exceed 10 percent of the employee’s annual salary. The Company’s contributions to the plans for the three months ended September 30, 2012 and 2011, were approximately $1.1 million and $0.4 million, respectively, and approximately $3.0 million and $1.3 million for the nine months ended September 30, 2012 and 2011, respectively.

13

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Stock incentive plan. The Company’s 2006 Stock Incentive Plan, as amended and restated (the “Plan”), provides for granting stock options, restricted stock awards and performance awards to employees and individuals associated with the Company. The following table shows the number of existing awards and awards available under the Plan at September 30, 2012:

		Number of
		Common Shares
Approved and authorized awards ...............................................................................................................................................................................		7,500,000
Stock option grants, net of forfeitures ........................................................................................................................................................................		(3,463,720)
Restricted stock grants, net of forfeitures ..................................................................................................................................................................		(1,985,301)
Treasury shares ...............................................................................................................................................................................................................		81,393
	Awards available for future grant ..........................................................................................................................................................................	2,132,372

Restricted stock awards.  All restricted shares are treated as issued and outstanding in the accompanying consolidated balance sheets. If an employee terminates employment prior to the restriction lapse date, the awarded shares are forfeited and cancelled and are no longer considered issued and outstanding. A summary of the Company’s restricted stock award activity for the nine months ended September 30, 2012 is presented below:

			Number of		Grant Date
			Restricted		Fair Value
			Shares		Per Share
Restricted stock:
	Outstanding at December 31, 2011 ..............................................................................................................................................................................		912,013
		Shares granted ..................................................................................................................................................................................................................	465,748	$	98.39
		Shares cancelled / forfeited ............................................................................................................................................................................................	(50,703)
		Lapse of restrictions ........................................................................................................................................................................................................	(223,039)
	Outstanding at September 30, 2012..............................................................................................................................................................................		1,104,019

14

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

The following table summarizes information about stock-based compensation for the Company’s restricted stock awards activity under the Plan for the three and nine months ended September 30, 2012 and 2011:

			Three Months Ended				Nine  Months Ended
			September 30,				September 30,
(in thousands)				2012		2011		2012		2011
Grant date fair value for awards during the period:
	Employee grants ...............................................................................................................................................................................................................................		$	1,180	$	13,393	$	27,306	$	16,969
	Officer and director grants...............................................................................................................................................................................................................			290		475		18,521		9,525
		Total ....................................................................................................................................................................................................................................................	$	1,470	$	13,868	$	45,827	$	26,494
Stock-based compensation expense from restricted stock:
	Employee grants ...............................................................................................................................................................................................................................		$	3,854	$	1,761	$	9,617	$	5,412
	Officer and director grants...............................................................................................................................................................................................................			4,077		2,734		11,653		7,727
		Total ....................................................................................................................................................................................................................................................	$	7,931	$	4,495	$	21,270	$	13,139
Income taxes and other information:
	Income tax benefit related to restricted stock .............................................................................................................................................................................		$	3,032	$	1,718	$	8,131	$	5,023
	Deductions in current taxable income related to restricted stock ............................................................................................................................................		$	1,043	$	1,097	$	22,581	$	13,109

Stock option awards.  A summary of the Company’s stock option award activity under the Plan for the nine months ended September 30, 2012 is presented below:

					Weighted
					Average
			Number of		Exercise
			Options		Price
Stock options:
	Outstanding at December 31, 2011 .........................................................................................................................................................................		930,178	$	18.10
		Options exercised ........................................................................................................................................................................................................	(495,299)	$	16.28
	Outstanding at September 30, 2012.........................................................................................................................................................................		434,879	$	20.18
	Vested at end of period...............................................................................................................................................................................................		404,702	$	20.12

15

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

The following table summarizes information about the Company’s vested stock options outstanding at September 30, 2012:

			Weighted
			Average		Weighted
	Range of		Remaining		Average
	Exercise	Number	Contractual		Exercise		Intrinsic
	Prices	Vested	Life		Price		Value
							(in thousands)
Vested options:
	$8.00.....................................................................................................................................................................................................................................................	15,224	1.87 years	$	8.00	$	1,321
	$12.00..................................................................................................................................................................................................................................................	45,911	3.09 years	$	12.00		3,799
	$12.50 - $15.50..................................................................................................................................................................................................................................	77,500	3.93 years	$	14.91		6,188
	$20.00 - $23.00..................................................................................................................................................................................................................................	206,312	5.66 years	$	21.56		15,101
	$28.00 - $37.27..................................................................................................................................................................................................................................	59,755	5.67 years	$	31.25		3,794
		404,702	4.89 years	$	20.12	$	30,203

The following table summarizes information about stock-based compensation for stock options for the three and nine months ended September 30, 2012 and 2011:

			Three Months Ended					Nine Months Ended
			September 30,					September 30,
(in thousands)					2012		2011		2012		2011
Stock-based compensation expense from stock options:
	Employee grants ...............................................................................................................................................................................................................................			$	7	$	20	$	24	$	65
	Officer and director grants ..............................................................................................................................................................................................................				21		158		140		662
		Total ....................................................................................................................................................................................................................................................		$	28	$	178	$	164	$	727
Income taxes and other information:
	Income tax benefit related to stock options ................................................................................................................................................................................			$	10	$	68	$	63	$	278
	Deductions in current taxable income related to stock options exercised ..............................................................................................................................			$	23,332	$	5,270	$	39,420	$	57,425

16

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Future stock-based compensation expense. The following table reflects the future stock-based compensation expense to be recorded for all the stock-based compensation awards that were outstanding at September 30, 2012:

			Restricted		Stock
(in thousands)			Stock		Options		Total
Remaining 2012 .................................................................................................................................................................................................................................		$	8,589	$	22	$	8,611
2013 ......................................................................................................................................................................................................................................................			25,834		15		25,849
2014 ......................................................................................................................................................................................................................................................			16,124		-		16,124
2015 ......................................................................................................................................................................................................................................................			4,902		-		4,902
2016.......................................................................................................................................................................................................................................................			638		-		638
	Total ....................................................................................................................................................................................................................................................	$	56,087	$	37	$	56,124

Note G. Disclosures about fair value of financial instruments

The Company uses a valuation framework based upon inputs that market participants use in pricing an asset or liability, which are classified into two categories: observable inputs and unobservable inputs.  Observable inputs represent market data obtained from independent sources, whereas unobservable inputs reflect a company’s own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. These two types of inputs are further prioritized into the following fair value input hierarchy:

Level 1:      Unadjusted quoted prices in active markets that are accessible at the measurement date for identical, unrestricted assets or liabilities. The Company considers active markets to be those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis.

Level 2:      Quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that the Company values using observable market data. Substantially all of these inputs are observable in the marketplace throughout the full term of the derivative instrument, can be derived from observable data, or supported by observable levels at which transactions are executed in the marketplace. Level 2 instruments primarily include non-exchange traded derivatives such as over-the-counter commodity price swaps, basis swaps, investments and interest rate swaps. The Company’s valuation models are primarily industry-standard models that consider various inputs including: (i) quoted forward prices for commodities, (ii) time value and (iii) current market and contractual prices for the underlying instruments, as well as other relevant economic measures. The Company utilizes its counterparties’ valuations to assess the reasonableness of its prices and valuation techniques.

Level 3:      Measured based on prices or valuation models that require inputs that are both significant to the fair value measurement and less observable from objective sources (i.e., supported by little or no market activity). Level 3 instruments primarily include derivative instruments, such as commodity price collars and floors, as well as investments. The Company’s valuation models are primarily industry-standard models that consider various inputs including: (i) quoted forward prices for commodities, (ii) time value, (iii) volatility factors and (iv) current market and contractual prices for the underlying instruments, as well as other relevant economic measures.  Although the Company utilizes its counterparties’ valuations to assess the reasonableness of its prices and valuation techniques, the Company does not have sufficient corroborating market evidence to support classifying these assets and liabilities as Level 2.

17

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

The fair value input hierarchy level to which an asset or liability measurement in its entirety falls is determined based on the lowest level input that is significant to the measurement in its entirety. The following table presents the Company’s assets and liabilities that are measured at fair value on a recurring basis at September 30, 2012, for each of the fair value hierarchy levels:

			Fair Value Measurements at Reporting Date Using
					Significant
			Quoted Prices in		Other		Significant
			Active Markets for		Observable		Unobservable		Fair Value at
			Identical Assets		Inputs		Inputs		September 30,
(in thousands)			(Level 1)		(Level 2)		(Level 3)		2012
	Assets:
		Commodity derivative price swap contracts .................................................................................................................................................	$	-	$	86,022	$	-	$	86,022
				-		86,022		-		86,022
	Liabilities:
		Commodity derivative price swap contracts .................................................................................................................................................		-		(47,825)		-		(47,825)
				-		(47,825)		-		(47,825)
	Net financial assets .................................................................................................................................................................................................		$	-	$	38,197	$	-	$	38,197

Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following table presents the carrying amounts and fair values of the Company’s financial instruments at September 30, 2012 and December 31, 2011:

			September 30, 2012				December 31, 2011
			Carrying		Fair		Carrying		Fair
(in thousands)			Value		Value		Value		Value
	Assets:
		Derivative instruments ......................................................................................................................................................................................................	$	42,353	$	42,353	$	9,642	$	9,642
	Liabilities:
		Derivative instruments.......................................................................................................................................................................................................	$	4,156	$	4,156	$	88,472	$	88,472
		Credit facility ......................................................................................................................................................................................................................	$	804,000	$	783,468	$	583,500	$	532,805
		8.625% senior notes due 2017 ........................................................................................................................................................................................	$	296,983	$	327,424	$	296,641	$	324,080
		7.0% senior notes due 2021 .............................................................................................................................................................................................	$	600,000	$	672,000	$	600,000	$	644,400
		6.5% senior notes due 2022 .............................................................................................................................................................................................	$	600,000	$	661,500	$	600,000	$	627,000
		5.5% senior notes due 2022 .............................................................................................................................................................................................	$	600,000	$	625,500	$	-	$	-
		5.5% senior notes due 2023 .............................................................................................................................................................................................	$	700,000	$	731,500	$	-	$	-

18

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Cash and cash equivalents, accounts receivable, other current assets, accountspayable, interest payable and other current liabilities. The carrying amounts approximate fair value due to the short maturity of these instruments.

Credit facility.  The fair value of the Company’s credit facility is estimated by discounting the principal and interest payments at the Company’s credit-adjusted discount rate at the reporting date.

Senior notes. The fair values of the Company’s senior notes are based on quoted market prices.

Derivative instruments. The fair value of the Company’s derivative instruments is estimated by management considering various factors, including closing exchange and over-the-counter quotations and the time value of the underlying commitments.  Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The following table summarizes (i) the valuation of each of the Company’s financial instruments by required fair value hierarchy levels and (ii) the gross fair value by the appropriate balance sheet classification,even when the derivative instruments are subject to netting arrangements and qualify for net presentation in the Company’s consolidated balance sheets at September 30, 2012 and December 31, 2011:

					Fair Value Measurements Using
									Significant				Total
					Quoted Prices in				Other		Significant		Fair Value
					Active Markets for				Observable		Unobservable		at
					Identical Assets				Inputs		Inputs		September 30,
(in thousands)					(Level 1)				(Level 2)		(Level 3)		2012
	Assets (a)
		Current:(b)
			Commodity derivative price swap contracts ................................................................................................................................................			$	-	$	60,174	$	-	$	60,174
							-		60,174		-		60,174
		Noncurrent:(c)
			Commodity derivative price swap contracts ................................................................................................................................................				-		25,848		-		25,848
							-		25,848		-		25,848
	Liabilities (a)
		Current:(b)
			Commodity derivative price swap contracts ................................................................................................................................................				-		(26,396)		-		(26,396)
							-		(26,396)		-		(26,396)
		Noncurrent:(c)
			Commodity derivative price swap contracts ................................................................................................................................................				-		(21,429)		-		(21,429)
							-		(21,429)		-		(21,429)
	Net financial assets .................................................................................................................................................................................................					$	-	$	38,197	$	-	$	38,197
	(b) Total current financial assets, gross basis ..........................................................................................................................................................................................											$	33,778
	(c) Total noncurrent financial assets, gross basis ...................................................................................................................................................................................												4,419
				Net financial assets  .....................................................................................................................................................................................................................................								$	38,197

19

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

										Fair Value Measurements Using
														Significant								Total
										Quoted Prices in				Other				Significant				Fair Value
										Active Markets for				Observable				Unobservable				at
										Identical Assets				Inputs				Inputs				December 31,
(in thousands)										(Level 1)				(Level 2)				(Level 3)				2011
	Assets (a)
			Current:(b)
				Commodity derivative price swap contracts ..........................................................................................................................................................................							$	-	$	28,485			$	-			$	28,485
												-		28,485				-				28,485
			Noncurrent:(c)
				Commodity derivative price swap contracts ..........................................................................................................................................................................								-		19,122				-				19,122
												-		19,122				-				19,122
	Liabilities (a)
			Current:(b)
				Commodity derivative price swap contracts ..........................................................................................................................................................................								-		(83,005)				-				(83,005)
												-		(83,005)				-				(83,005)
			Noncurrent:(c)
				Commodity derivative price swap contracts ..........................................................................................................................................................................								-		(43,432)				-				(43,432)
												-		(43,432)				-				(43,432)
	Noncurrent:(c)										$	-	$	(78,830)			$	-			$	(78,830)
	(b) Total current financial liabilities, gross basis .....................................................................................................................................................................................																				$	(54,520)
	(c) Total noncurrent financial liabilities, gross basis ..............................................................................................................................................................................																					(24,310)
						Net financial liabilities .................................................................................................................................................................................................................................															$	(78,830)
		(a)			The fair value of derivative instruments reported in the Company’s consolidated balance sheets is subject to netting arrangements and qualifies for net presentation. The following table reports the net basis derivative fair values as reported in the consolidated balance sheets at September 30, 2012 and December 31, 2011:
																September 30,				December 31,
					(in thousands)											2012				2011
					Consolidated Balance Sheets Classification:
							Current derivative contracts:
								Assets .............................................................................................................................................................................................................................................................							$	35,793			$	1,698
								Liabilities .........................................................................................................................................................................................................................................................								(2,015)				(56,218)
									Net current ....................................................................................................................................................................................................................................						$	33,778			$	(54,520)
							Noncurrent derivative contracts:
								Assets .............................................................................................................................................................................................................................................................							$	6,560			$	7,944
								Liabilities .........................................................................................................................................................................................................................................................								(2,141)				(32,254)
									Net noncurrent ..............................................................................................................................................................................................................................						$	4,419			$	(24,310)

20

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Certain assets and liabilities are reported at fair value on a nonrecurring basis in the Company’s consolidated balance sheets.  The following methods and assumptions were used to estimate the fair values: 

Impairments of long-lived assets – The Company reviews its long-lived assets to be held and used, including proved oil and natural gas properties, whenever events or circumstances indicate that the carrying value of those assets may not be recoverable. An impairment loss is indicated if the sum of the expected undiscounted future net cash flows is less than the carrying amount of the assets. In this circumstance, the Company recognizes an impairment loss for the amount by which the carrying amount of the asset exceeds the estimated fair value of the asset. The Company reviews its oil and natural gas properties by depletion base or by individual well for those wells not constituting part of a depletion base. For each property determined to be impaired, an impairment loss equal to the difference between the carrying value of the properties and the estimated fair value (discounted future cash flows) of the properties would be recognized at that time. Estimating future cash flows involves the use of judgments, including estimation of the proved and unproved oil and natural gas reserve quantities, timing of development and production, expected future commodity prices, capital expenditures and production costs.

The Company periodically reviews its proved oil and natural gas properties for impairment. Impairment expense is caused primarily due to declines in commodity prices and well performance. The Company did not recognize any impairment charges for the three months ended September 30, 2011 or for the three or nine months ended September 30, 2012. The following table reports the carrying amounts, estimated fair values and impairment expense of long-lived assets for continuing operations for the nine months ended September 30, 2011:

		Carrying		Estimated		Impairment
(in thousands)		Amount		Fair Value		Expense
Nine Months Ended September 30, 2011.......................................................................................................................	$	77	$	1	$	76

Asset retirement obligations – The Company estimates the fair value of Asset Retirement Obligations (“AROs”) based on discounted cash flow projections using numerous estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an ARO; amounts and timing of settlements; the credit-adjusted risk-free rate to be used and inflation rates. See Note E for a summary of changes in AROs.

21

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

The following table sets forth the measurement information for assets measured at fair value on a nonrecurring basis:

		Fair Value Measurements Using
		Quoted Prices				Significant
		in Active				Other		Significant
		Markets for				Observable		Unobservable		Total
		Identical Assets				Inputs		Inputs		Impairment
(in thousands)		(Level 1)				(Level 2)		(Level 3)		Loss
Three Months Ended September 30, 2012
	Impairment of long-lived assets .....................................................................................................................................................		$	-	$	-	$	-	$	-
	Asset retirement obligations incurred or assumed........................................................................................................................			-		-		30,039
Three Months Ended September 30, 2011
	Impairment of long-lived assets .....................................................................................................................................................		$	-	$	-	$	-	$	-
	Asset retirement obligations incurred or assumed........................................................................................................................			-		-		1,970
Nine Months Ended September 30, 2012
	Impairment of long-lived assets .....................................................................................................................................................		$	-	$	-	$	-	$	-
	Asset retirement obligations incurred or assumed........................................................................................................................			-		-		35,432
Nine Months Ended September 30, 2011
	Impairment of long-lived assets .....................................................................................................................................................		$	-	$	-	$	1	$	76
	Asset retirement obligations incurred or assumed........................................................................................................................			-		-		5,357

Note H. Derivative financial instruments

The Company uses derivative financial contracts to manage its exposure to commodity price and interest rate fluctuations. Commodity hedges are used to (i) reduce the effect of the volatility of price changes on the oil and natural gas the Company produces and sells, (ii) support the Company’s capital budget and expenditure plans and (iii) support the economics associated with acquisitions. The Company does not enter into derivative financial instruments for speculative or trading purposes. The Company may also enter into physical delivery contracts to effectively provide commodity price hedges. Because these contracts are not expected to be net cash settled, they are considered to be normal sales contracts and not derivatives. Therefore, these contracts are not recorded in the Company’s consolidated financial statements.

Currently, the Company does not designate its derivative instruments to qualify for hedge accounting.  Accordingly, the Company reflects changes in the fair value of its derivative instruments in its statements of operations as they occur.

22

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Commodity derivative contracts at September 30, 2012. The following table sets forth the Company’s outstanding derivative contracts at September 30, 2012. When aggregating multiple contracts, the weighted average contract price is disclosed.

				First		Second		Third		Fourth
				Quarter		Quarter		Quarter		Quarter		Total
Oil Swaps: (a)
	2012:
		Volume (Bbl) ........................................................................................................................................................................................................................								3,676,500		3,676,500
		Price per Bbl ..........................................................................................................................................................................................................................							$	96.01	$	96.01
	2013:
		Volume (Bbl) ........................................................................................................................................................................................................................		3,362,000		3,122,000		2,939,000		2,792,000		12,215,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	96.28	$	96.25	$	95.86	$	95.55	$	96.01
	2014:
		Volume (Bbl) ........................................................................................................................................................................................................................		2,616,000		2,523,000		453,000		451,000		6,043,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	93.68	$	92.19	$	86.55	$	86.53	$	91.99
	2015:
		Volume (Bbl) ........................................................................................................................................................................................................................		420,000		420,000		119,000		117,000		1,076,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	85.91	$	85.91	$	89.44	$	89.43	$	86.69
	2016:
		Volume (Bbl) ........................................................................................................................................................................................................................		108,000		108,000		108,000		105,000		429,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	88.32	$	88.32	$	88.32	$	88.28	$	88.31
	2017:
		Volume (Bbl) ........................................................................................................................................................................................................................		84,000		84,000		-		-		168,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	87.00	$	87.00	$	-	$	-	$	87.00
Natural Gas Swaps: (b)
	2012:
		Volume (MMBtu) ................................................................................................................................................................................................................								75,000		75,000
		Price per MMBtu ..................................................................................................................................................................................................................							$	6.54	$	6.54
(a) The index prices for the oil price swaps are based on the NYMEX – West Texas Intermediate monthly average futures price.
(b) The index prices for the natural gas price swaps are based on the NYMEX – Henry Hub last trading day futures price.

23

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

The following table summarizes the gains and losses reported in earnings related to the commodity and interest rate derivative instruments for the three and nine months ended September 30, 2012 and 2011:

						Three Months Ended				Nine Months Ended
						September 30,				September 30,
(in thousands)							2012		2011		2012		2011
Gain (loss) on derivatives not designated as hedges:
	Cash (payments on) receipts from derivatives not designated as hedges:
		Commodity derivatives:
			Oil ....................................................................................................................................................................................................................................................................			$	15,859	$	(8,051)	$	(8,374)	$	(88,679)
			Natural gas ....................................................................................................................................................................................................................................................				280		6,263		889		17,468
		Interest rate derivatives ..............................................................................................................................................................................................................................					-		-		-		(6,624)
		..........................................................................................................................................................................................................................	..........................................................................................................................................................................................................................
	Mark-to-market gain (loss):
		Commodity derivatives:
			Oil ....................................................................................................................................................................................................................................................................				(151,260)		390,327		117,760		381,385
			Natural gas ....................................................................................................................................................................................................................................................				(294)		(3,317)		(733)		(12,342)
		Interest rate derivatives ..............................................................................................................................................................................................................................					-		-		-		5,754
				Total gain (loss) on derivatives not designated
					as hedges ........................................................................................................................................................................................	$	(135,415)	$	385,222	$	109,542	$	296,962

All of the Company’s derivative contracts at September 30, 2012 are expected to settle by June 30, 2017.

Note I. Debt 

The Company’s debt consisted of the following at September 30, 2012 and December 31, 2011:

				September 30,		December 31,
(in thousands)				2012		2011
Credit facility ......................................................................................................................................................................................................................			$	804,000	$	583,500
8.625% unsecured senior notes due 2017 .....................................................................................................................................................................				300,000		300,000
7.0% unsecured senior notes due 2021 ..........................................................................................................................................................................				600,000		600,000
6.5% unsecured senior notes due 2022 ..........................................................................................................................................................................				600,000		600,000
5.5% unsecured senior notes due 2022 ..........................................................................................................................................................................				600,000		-
5.5% unsecured senior notes due 2023 ..........................................................................................................................................................................				700,000		-
Unamortized original issue discount, net .......................................................................................................................................................................				(3,017)		(3,359)
	Less: current portion ......................................................................................................................................................................................................			-		-
		Total long-term debt .............................................................................................................................................................................................	$	3,600,983	$	2,080,141

24

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Credit facility. The Company’s credit facility, as amended (the “Credit Facility”), has a maturity date of April 25, 2016. The Company’s borrowing base is $3.0 billion until the next scheduled borrowing base redetermination in April 2013, and commitments from the Company’s bank group total $2.5 billion. Between scheduled borrowing base redeterminations, the Company and the lenders (requiring a 66 2/3 percent vote), may each request one special redetermination.

Advances on the Credit Facility bear interest, at the Company’s option, based on (i) the prime rate of JPMorgan Chase Bank (“JPM Prime Rate”) (3.25 percent at September 30, 2012) or (ii) a Eurodollar rate (substantially equal to the LIBOR). At September 30, 2012, the interest rates of Eurodollar rate advances and JPM Prime Rate advances varied, with interest margins ranging from 150 to 250 basis points and 50 to 150 basis points per annum, respectively, depending on the debt balance outstanding. At September 30, 2012, the Company paid commitment fees on the unused portion of the available commitments ranging from 37.5 to 50 basis points per annum.

The Credit Facility also includes a same-day advance facility under which the Company may borrow funds from the administrative agent. Same-day advances cannot exceed $25 million, and the maturity dates cannot exceed fourteen days. The interest rate on this facility is the JPM Prime Rate plus the applicable interest margin.

The Company’s obligations under the Credit Facility are secured by a first lien on substantially all of its oil and natural gas properties. In addition, all of the Company’s subsidiaries are guarantors and have had their equity pledged to secure borrowings under the Credit Facility.

The Credit Facility contains various restrictive covenants and compliance requirements which include:

·maintenance of certain financial ratios, including (i) maintenance of a quarterly ratio of total debt to consolidated earnings before interest expense, income taxes, depletion, depreciation, and amortization, exploration expense and other noncash income and expenses to be no greater than 4.0 to 1.0, and (ii) maintenance of a ratio of current assets to current liabilities, excluding noncash assets and liabilities related to financial derivatives and asset retirement obligations and including the unfunded amounts under the Credit Facility, to be not less than 1.0 to 1.0;

·limits on the incurrence of additional indebtedness and certain types of liens;

·restrictions as to mergers, combinations and dispositions of assets; and

·restrictions on the payment of cash dividends.

Senior notes. Interest on the Company’s senior notes is paid in arrears semi-annually. The senior notes are fully and unconditionally guaranteed on a senior unsecured basis by certain subsidiaries of the Company. In August 2012, the Company issued $700 million aggregate principal amount of 5.5% senior notes due 2023 at par which mature on April 1, 2023.

At September 30, 2012, the Company was in compliance with the covenants under its debt instruments.

25

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Future interest from original issue discount at September 30, 2012 was as follows:

(in thousands)
Remaining 2012 .................................................................................................................................................................................................................................		$	120
2013.......................................................................................................................................................................................................................................................			507
2014.......................................................................................................................................................................................................................................................			557
2015.......................................................................................................................................................................................................................................................			612
2016.......................................................................................................................................................................................................................................................			672
Thereafter ............................................................................................................................................................................................................................................			549
	Total ....................................................................................................................................................................................................................................................	$	3,017

Principal maturities of debt.Principal maturities of long-term debt outstanding at September 30, 2012 were as follows:

(in thousands)
2012.......................................................................................................................................................................................................................................................		$	-
2013.......................................................................................................................................................................................................................................................			-
2014.......................................................................................................................................................................................................................................................			-
2015.......................................................................................................................................................................................................................................................			-
2016.......................................................................................................................................................................................................................................................			804,000
Thereafter ............................................................................................................................................................................................................................................			2,800,000
	Total ....................................................................................................................................................................................................................................................	$	3,604,000

26

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Interest expense.  The following amounts have been incurred and charged to interest expense for the three and nine months ended September 30, 2012 and 2011:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(in thousands)			2012		2011		2012		2011
Cash payments for interest .........................................................................................................................................................................................		$	48,203	$	28,683	$	115,731	$	60,825
Amortization of original issue discount ....................................................................................................................................................................			117		106		342		24
Amortization of deferred loan origination costs .....................................................................................................................................................			3,114		2,644		8,724		8,997
Write-off of deferred loan origination costs and original issue premium ...........................................................................................................			-		-		-		(8,513)
Net changes in accruals ...............................................................................................................................................................................................			(97)		1,448		4,276		22,941
	Interest costs incurred .........................................................................................................................................................................................		51,337		32,881		129,073		84,274
Less: capitalized interest ..............................................................................................................................................................................................			-		-		-		(73)
	Total interest expense .........................................................................................................................................................................................	$	51,337	$	32,881	$	129,073	$	84,201

Note J. Commitments and contingencies

Severance agreements.The Company has entered into severance and change in control agreements with all of its officers.  The current annual salaries for the Company’s officers covered under such agreements total approximately $5.4 million.

Indemnifications.  The Company has agreed to indemnify its directors and officers with respect to claims and damages arising from certain acts or omissions taken in such capacity.

Legal actions.  The Company is a party to proceedings and claims incidental to its business.  While many of these matters involve inherent uncertainty, the Company believes that the amount of the liability, if any, ultimately incurred with respect to any such proceedings or claims will not have a material adverse effect on the Company’s consolidated financial position as a whole or on its liquidity, capital resources or future results of operations. The Company will continue to evaluate proceedings and claims involving the Company on a regular basis and will establish and adjust any reserves as appropriate to reflect its assessment of the then current status of the matters.

27

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Contractual drilling commitments.  The Company periodically enters into contractual arrangements under which the Company is committed to expend funds to drill wells in the future, including agreements to secure drilling rig services, which require the Company to make future minimum payments to the rig operators.  The Company records drilling commitments in the periods in which well capital is incurred or rig services are provided. The following table summarizes the Company’s future drilling commitments at September 30, 2012:

	Payments Due By Period
		Total		Less than		1-3		3-5		More than
(in thousands)				1 year		years		years		5 years
Contractual drilling commitments ..............................................................................................................................................	$	16,400	$	13,796	$	2,604	$	-	$	-

Operating leases. The Company leases vehicles, equipment and office facilities under non-cancellable operating leases. Lease payments associated with these operating leases for each of the three months ended September 30, 2012 and 2011 were approximately $1.3 million and $0.9 million, respectively, and approximately $3.6 million and $2.6 million for the nine months ended September 30, 2012 and 2011, respectively.

Future minimum lease commitments under non-cancellable operating leases at September 30, 2012 were as follows:

(in thousands)
Remaining 2012 .................................................................................................................................................................................................................................		$	1,269
2013.......................................................................................................................................................................................................................................................			4,618
2014.......................................................................................................................................................................................................................................................			3,608
2015.......................................................................................................................................................................................................................................................			2,407
2016.......................................................................................................................................................................................................................................................			1,702
Thereafter ............................................................................................................................................................................................................................................			442
	Total ....................................................................................................................................................................................................................................................	$	14,046

Note K. Income taxes

The Company uses an asset and liability approach for financial accounting and reporting for income taxes. The Company’s objectives of accounting for income taxes are to recognize (i) the amount of taxes payable or refundable for the current year and (ii) deferred tax liabilities and assets for the future tax consequences of events that have been recognized in its financial statements or tax returns. The Company and its subsidiaries file a federal corporate income tax return on a consolidated basis.  The tax returns and the amount of taxable income or loss are subject to examination by federal and state taxing authorities. At September 30, 2012 and December 31, 2011, the Company had current income taxes receivable of approximately $6.4 million and $3.9 million, respectively, and current income taxes payable of approximately $0.7 million and $0.8 million, respectively.

The Company continually assesses both positive and negative evidence to determine whether it is more likely than not that deferred tax assets can be realized prior to their expiration. Management monitors company-specific, oil and natural gas industry and worldwide economic factors and assesses the likelihood that the Company’s net operating loss carryforwards (“NOLs”), if any, and

28

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

other deferred tax attributes in the United States, state, and local tax jurisdictions will be utilized prior to their expiration. At September 30, 2012 and December 31, 2011, the Company had no valuation allowances related to its deferred tax assets.

At September 30, 2012, the Company did not have any significant uncertain tax positions requiring recognition in the financial statements.  The tax years 2009 through 2011 remain subject to examination by the major tax jurisdictions.

Income tax provision.  The Company’s income tax provision and amounts separately allocated were attributable to the following items for the three and nine months ended September 30, 2012 and 2011:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(in thousands)			2012		2011		2012		2011
Income from continuing operations.........................................................................................................................................		$	4,155	$	221,199	$	220,835	$	334,000
Income from discontinued operations ....................................................................................................................................			-		-		-		56,529
Changes in stockholders' equity:
	Excess tax benefits related to stock-based compensation ......................................................................................		(8,129)		(2,105)		(18,522)		(23,222)
		$	(3,974)	$	219,094	$	202,313	$	367,307

The Company’s income tax provision attributable to income from continuing operations consisted of the following for the three and nine months ended September 30, 2012 and 2011:

					Three Months Ended				Nine Months Ended
					September 30,				September 30,
(in thousands)						2012		2011		2012		2011
Current:
	U.S. federal .............................................................................................................................................................................................................................				$	1,330	$	9,826	$	13,574	$	19,378
	U.S. state and local ................................................................................................................................................................................................................					580		1,141		2,457		2,423
		Total current income tax provision..................................................................................................................................................................................				1,910		10,967		16,031		21,801
Deferred:
	U.S. federal .............................................................................................................................................................................................................................					2,134		182,698		178,400		271,297
	U.S. state and local ................................................................................................................................................................................................................					111		27,534		26,404		40,902
		Total deferred income tax provision ...............................................................................................................................................................................				2,245		210,232		204,804		312,199
			Total income tax provision attributable to income from
				continuing operations......................................................................................................................................................................................................	$	4,155	$	221,199	$	220,835	$	334,000

29

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

The reconciliation between the income tax expense computed by multiplying pretax income from continuing operations by the United States federal statutory rate and the reported amounts of income tax expense from continuing operations is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(in thousands)			2012		2011		2012		2011
Income at U.S. federal statutory rate...............................................................................................................................................................................		$	3,550	$	202,091	$	202,033	$	305,821
State income taxes (net of federal tax effect)................................................................................................................................................................			329		18,592		18,640		28,115
Statutory depletion...............................................................................................................................................................................................................			(91)		(110)		(207)		(296)
Nondeductible expense & other.........................................................................................................................................................................................			367		626		369		360
	Income tax expense ..............................................................................................................................................................................................	$	4,155	$	221,199	$	220,835	$	334,000
Effective tax rate .................................................................................................................................................................................................................			41.0%		38.3%		38.3%		38.2%

The Company’s income tax provision attributable to income from discontinued operations consisted of the following for the nine months ended September 30, 2011:

				Nine Months Ended
(in thousands)				September 30, 2011
Current:
	U.S. federal .............................................................................................................................................................................................................................			$	(1,192)
	U.S. state and local ................................................................................................................................................................................................................				4
		Total current income tax benefit .....................................................................................................................................................................................			(1,188)
Deferred:
	U.S. federal .............................................................................................................................................................................................................................				50,373
	U.S. state and local ................................................................................................................................................................................................................				7,344
		Total deferred income tax provision ...............................................................................................................................................................................			57,717
			Total income tax provision attributable to income from discontinued operations ...........................................................................................	$	56,529

30

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Note L. Related party transactions

The following tables summarize charges incurred with and payments made to the Company’s related parties and reported in the consolidated statements of operations, as well as outstanding payables included in the consolidated balance sheets for the periods presented:

	Three Months Ended				Nine Months Ended
	September 30,				September 30,
(in thousands)		2012		2011		2012		2011
Royalty interests paid to a director of the Company (a) .................................................................	$	525	$	37	$	1,820	$	99
Amounts paid under consulting agreement with Steven L. Beal (b) ..............................................	$	60	$	60	$	180	$	180

		September 30,		December 31,
(in thousands)		2012			2011
Amounts included in accounts payable - related parties:
	Royalty interests of a director of the Company (a) .....................................................................................	$	227	$	154

(a)Royalties are paid on certain properties to a partnership of which one of the Company’s directors is the general partner and owns a 3.5 percent partnership interest. The tables above summarize the amounts paid to such partnership and amounts due at period end.

(b)On June 30, 2009, Steven L. Beal, the Company’s then-president and chief operating officer, retired from such positions. On June 9, 2009, the Company entered into a consulting agreement (the “Consulting Agreement”) with Mr. Beal, under which Mr. Beal began serving as a consultant to the Company on July 1, 2009. Either the Company or Mr. Beal may terminate the consulting relationship at any time by giving ninety days written notice to the other party; however, the Company may terminate the relationship immediately for cause. During the term of the consulting relationship, Mr. Beal will receive a consulting fee of $20,000 per month and a monthly reimbursement for his medical and dental coverage costs. If Mr. Beal dies during the term of the Consulting Agreement, his estate will receive a $60,000 lump sum payment. As part of the consulting agreement, certain of Mr. Beal’s stock-based awards were modified to permit vesting and exercise under the original terms of the stock-based awards as if Mr. Beal were still an employee of the Company while he is performing consulting services for the Company. The tables above summarize the Company’s activities pursuant to the consulting agreement with Mr. Beal.

31

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Note M. Discontinued operations

In March 2011, the Company sold its Bakken assets for cash consideration of approximately $195.9 million and recognized a pre-tax gain on the sale of assets of approximately $142.0 million. The Company reflected the result of operations of this divestiture as discontinued operations, rather than as a component of continuing operations. The following table represents the components of the Company’s discontinued operations for the nine months ended September 30, 2011:

			Nine Months Ended
(in thousands)			September 30, 2011
Operating revenues:
	Oil sales ...........................................................................................................................................................................................................................................		$	9,456
	Natural gas sales ...........................................................................................................................................................................................................................			68
		Total operating revenues...........................................................................................................................................................................................................		9,524
Operating costs and expenses:
	Oil and natural gas production ...................................................................................................................................................................................................			1,642
	Depreciation, depletion and amortization (a) ..........................................................................................................................................................................			2,107
	Accretion of discount on asset retirement obligations (a) .....................................................................................................................................................			8
		Total operating costs and expenses........................................................................................................................................................................................		3,757
Income from operations ............................................................................................................................................................................................................				5,767
Other income (expense):
	Gain on disposition of assets, net (a) .........................................................................................................................................................................................			141,950
Income from discontinued operations before income taxes .............................................................................................................................................				147,717
Income tax benefit (expense):
	Current ............................................................................................................................................................................................................................................			1,188
	Deferred (a) ....................................................................................................................................................................................................................................			(57,717)
Income from discontinued operations, net of tax ................................................................................................................................................................			$	91,188
(a) Represents the significant non-cash components of discontinued operations.

32

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Note N. Net income per share

Basic net income per share is computed by dividing net income applicable to common shareholders by the weighted average number of common shares treated as outstanding for the period.

The computation of diluted net income per share reflects the potential dilution that could occur if securities or other contracts to issue common stock that are dilutive to income were exercised or converted into common stock or resulted in the issuance of common stock that would then share in the earnings of the Company. These amounts include unexercised stock options and restricted stock. Potentially dilutive effects are calculated using the treasury stock method.

The following table is a reconciliation of the basic weighted average common shares outstanding to diluted weighted average common shares outstanding for the three and nine months ended September 30, 2012 and 2011:

			Three Months Ended		Nine Months Ended
			September 30,		September 30,
(in thousands)			2012	2011	2012	2011
Weighted average common shares outstanding:
	Basic ...................................................................................................................................................................................................................................................		103,292	102,733	103,088	102,517
		Dilutive common stock options ..................................................................................................................................................................................................	323	503	399	605
		Dilutive restricted stock ................................................................................................................................................................................................................	425	460	411	491
	Diluted ................................................................................................................................................................................................................................................		104,040	103,696	103,898	103,613

The following table is a summary of the common stock options and restricted stock which were not included in the computation of diluted net income per share, as inclusion of these items would be antidilutive:

		Three Months Ended		Nine Months Ended
		September 30,		September 30,
(in thousands)		2012	2011	2012	2011
Number of antidilutive common shares:
	Antidilutive common stock options .......................................................................................................................................................	-	-	-	-
	Antidilutive restricted stock .....................................................................................................................................................................	31	60	126	36

33

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Note O. Other current liabilities

The following table provides the components of the Company’s other current liabilities at September 30, 2012 and December 31, 2011:

				September 30,		December 31,
(in thousands)				2012		2011
Other current liabilities:
	Accrued production costs ................................................................................................................................................................................................................		$	58,276	$	47,437
	Payroll related matters .....................................................................................................................................................................................................................			12,257		18,433
	Accrued interest ................................................................................................................................................................................................................................			57,009		52,733
	Asset retirement obligations ............................................................................................................................................................................................................			3,953		7,445
	Other ...................................................................................................................................................................................................................................................			13,666		16,638
		Other current liabilities .................................................................................................................................................................................................................	$	145,161	$	142,686

Note P.  Subsidiary guarantors

Certain of the Company’s wholly-owned and controlled subsidiaries have fully and unconditionally guaranteed the Company’s senior notes. See Note I for a summary of the Company’s senior notes. In accordance with practices accepted by the United States Securities and Exchange Commission, the Company has prepared Condensed Consolidating Financial Statements in order to quantify the assets, results of operations and cash flows of such subsidiaries as subsidiary guarantors. One of the entities included in the Company’s consolidated financial statements was formed to effectuate a tax-free exchange of assets. This entity does not guarantee the Company’s senior notes and is referred to as a “Non-Guarantor Subsidiary” in the tables below.

The following Condensed Consolidating Balance Sheets at September 30, 2012 and December 31, 2011, Condensed Consolidating Statements of Operations for the three and nine months ended September 30, 2012 and 2011, and Condensed Consolidating Statements of Cash Flows for the nine months ended September 30, 2012 and 2011, present financial information for Concho Resources Inc. as the Parent on a stand-alone basis (carrying any investments in subsidiaries under the equity method), financial information for the subsidiary guarantors on a stand-alone basis (carrying any investment in non-guarantor subsidiaries under the equity method), financial information for the subsidiary non-guarantor on a stand-alone basis and the consolidation and elimination entries necessary to arrive at the information for the Company on a consolidated basis. All current and deferred income taxes are recorded on Concho Resources Inc., as the subsidiaries are flow-through entities for income tax purposes. The subsidiary guarantors and subsidiary non-guarantor are not restricted from making distributions to the Company.

34

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Condensed Consolidating Balance Sheet
September 30, 2012
			Parent		Subsidiary		Subsidiary		Consolidating
(in thousands)			Issuer		Guarantors		Non-Guarantor		Entries		Total
ASSETS
Accounts receivable - related parties ..........................................................................................................................................................................................		$	6,352,530	$	1,271,564	$	-	$	(7,624,094)	$	-
Other current assets ........................................................................................................................................................................................................................			45,186		451,682		-		-		496,868
Oil and natural gas properties, net ...............................................................................................................................................................................................			-		7,637,254		545,112		-		8,182,366
Property and equipment, net ........................................................................................................................................................................................................			-		97,946		-		-		97,946
Investment in subsidiaries .............................................................................................................................................................................................................			2,990,980		-		-		(2,990,980)		-
Other long-term assets ...................................................................................................................................................................................................................			87,403		68,434		-		-		155,837
	Total assets ..................................................................................................................................................................................................................................	$	9,476,099	$	9,526,880	$	545,112	$	(10,615,074)	$	8,933,017
LIABILITIES AND EQUITY
Accounts payable - related parties ..............................................................................................................................................................................................		$	1,271,564	$	5,809,039	$	543,718	$	(7,624,094)	$	227
Other current liabilities ...................................................................................................................................................................................................................			70,589		629,331		20		-		699,940
Other long-term liabilities ..............................................................................................................................................................................................................			1,150,525		93,109		5,795		-		1,249,429
Long-term debt ...............................................................................................................................................................................................................................			3,600,983		-		-		-		3,600,983
Equity ...............................................................................................................................................................................................................................................			3,382,438		2,995,401		(4,421)		(2,990,980)		3,382,438
	Total liabilities and equity ........................................................................................................................................................................................................	$	9,476,099	$	9,526,880	$	545,112	$	(10,615,074)	$	8,933,017

35

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Condensed Consolidating Balance Sheet
December 31, 2011
			Parent		Subsidiary		Consolidating
(in thousands)			Issuer		Guarantors		Entries		Total
ASSETS
Accounts receivable - related parties ..........................................................................................................................................................................................		$	4,983,923	$	706,905	$	(5,690,828)	$	-
Other current assets ........................................................................................................................................................................................................................			34,229		376,794		-		411,023
Oil and natural gas properties, net ...............................................................................................................................................................................................			-		6,230,915		-		6,230,915
Property and equipment, net ........................................................................................................................................................................................................			-		59,203		-		59,203
Investment in subsidiaries .............................................................................................................................................................................................................			2,394,050		-		(2,394,050)		-
Other long-term assets ...................................................................................................................................................................................................................			73,587		74,848		-		148,435
	Total assets ..................................................................................................................................................................................................................................	$	7,485,789	$	7,448,665	$	(8,084,878)	$	6,849,576
LIABILITIES AND EQUITY
Accounts payable - related parties ..............................................................................................................................................................................................		$	1,271,524	$	4,419,315	$	(5,690,828)	$	11
Other current liabilities ...................................................................................................................................................................................................................			118,836		582,630		-		701,466
Other long-term liabilities ..............................................................................................................................................................................................................			1,034,549		52,670		-		1,087,219
Long-term debt ...............................................................................................................................................................................................................................			2,080,141		-		-		2,080,141
Equity ...............................................................................................................................................................................................................................................			2,980,739		2,394,050		(2,394,050)		2,980,739
	Total liabilities and equity ........................................................................................................................................................................................................	$	7,485,789	$	7,448,665	$	(8,084,878)	$	6,849,576

Condensed Consolidating Statement of Operations
Three Months Ended September 30, 2012
			Parent		Subsidiary		Subsidiary		Consolidating
(in thousands)			Issuer		Guarantors		Non-Guarantor		Entries		Total
Total operating revenues .........................................................................................................................................................................................................		$	-	$	490,205	$	7,342	$	-	$	497,547��
Total operating costs and expenses .......................................................................................................................................................................................			(135,637)		(291,596)		(5,720)		-		(432,953)
	Income (loss) from operations ............................................................................................................................................................................................		(135,637)		198,609		1,622		-		64,594
Interest expense ........................................................................................................................................................................................................................			(51,337)		-		-		-		(51,337)
Other, net ....................................................................................................................................................................................................................................			197,117		2,309		(6,043)		(196,497)		(3,114)
	Income before income taxes ...............................................................................................................................................................................................		10,143		200,918		(4,421)		(196,497)		10,143
Income tax expense .................................................................................................................................................................................................................			(4,155)		-		-		-		(4,155)
	Net income ..............................................................................................................................................................................................................................	$	5,988	$	200,918	$	(4,421)	$	(196,497)	$	5,988

36

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Condensed Consolidating Statement of Operations
Three Months Ended September 30, 2011
			Parent		Subsidiary		Consolidating
(in thousands)			Issuer		Guarantors		Entries		Total
Total operating revenues .........................................................................................................................................................................................................		$	-	$	454,468	$	-	$	454,468
Total operating costs and expenses .......................................................................................................................................................................................			383,660		(225,340)		-		158,320
	Income from operations .......................................................................................................................................................................................................		383,660		229,128		-		612,788
Interest expense ........................................................................................................................................................................................................................			(32,881)		-		-		(32,881)
Other, net ....................................................................................................................................................................................................................................			226,625		(2,503)		(226,625)		(2,503)
	Income before income taxes ...............................................................................................................................................................................................		577,404		226,625		(226,625)		577,404
Income tax expense .................................................................................................................................................................................................................			(221,199)		-		-		(221,199)
	Net income ..............................................................................................................................................................................................................................	$	356,205	$	226,625	$	(226,625)	$	356,205

Condensed Consolidating Statement of Operations
Nine Months Ended September 30, 2012
			Parent		Subsidiary		Subsidiary		Consolidating
(in thousands)			Issuer		Guarantors		Non-Guarantor		Entries		Total
Total operating revenues .........................................................................................................................................................................................................		$	-	$	1,430,806	$	7,342	$	-	$	1,438,148
Total operating costs and expenses .......................................................................................................................................................................................			108,776		(829,977)		(5,720)		-		(726,921)
	Income from operations .......................................................................................................................................................................................................		108,776		600,829		1,622		-		711,227
Interest expense ........................................................................................................................................................................................................................			(129,073)		-		-		-		(129,073)
Other, net ....................................................................................................................................................................................................................................			597,534		522		(6,043)		(596,930)		(4,917)
	Income before income taxes ...............................................................................................................................................................................................		577,237		601,351		(4,421)		(596,930)		577,237
Income tax expense .................................................................................................................................................................................................................			(220,835)		-		-		-		(220,835)
	Net income ..............................................................................................................................................................................................................................	$	356,402	$	601,351	$	(4,421)	$	(596,930)	$	356,402

37

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Condensed Consolidating Statement of Operations
Nine Months Ended September 30, 2011
			Parent		Subsidiary		Consolidating
(in thousands)			Issuer		Guarantors		Entries		Total
Total operating revenues .........................................................................................................................................................................................................		$	-	$	1,261,540	$	-	$	1,261,540
Total operating costs and expenses .......................................................................................................................................................................................			295,972		(594,947)		-		(298,975)
	Income from continuing operations ...................................................................................................................................................................................		295,972		666,593		-		962,565
Interest expense ........................................................................................................................................................................................................................			(84,201)		-		-		(84,201)
Other, net ....................................................................................................................................................................................................................................			809,720		(4,690)		(809,620)		(4,590)
	Income from continuing operations before income taxes .............................................................................................................................................		1,021,491		661,903		(809,620)		873,774
Income tax expense .................................................................................................................................................................................................................			(334,000)		-		-		(334,000)
	Income from continuing operations ...................................................................................................................................................................................		687,491		661,903		(809,620)		539,774
Income (loss) from discontinued operations, net of tax ....................................................................................................................................................			(56,529)		147,717		-		91,188
	Net income ..............................................................................................................................................................................................................................	$	630,962	$	809,620	$	(809,620)	$	630,962

Condensed Consolidating Statement of Cash Flows
Nine Months Ended September 30, 2012
					Parent		Subsidiary		Subsidiary		Consolidating
(in thousands)					Issuer		Guarantors		Non-Guarantor		Entries		Total
Net cash flows provided by (used in)
	operating activities .....................................................................................................................................................................................................................			$	(1,512,952)	$	2,355,751	$	2,837	$	-	$	845,636
Net cash flows used in investing
	activities .......................................................................................................................................................................................................................................				(7,485)		(1,816,184)		(543,738)		-		(2,367,407)
Net cash flows provided by (used in)
	financing activities .....................................................................................................................................................................................................................				1,520,437		(539,618)		540,901		-		1,521,720
		Net decrease in cash and cash
			equivalents ..............................................................................................................................................................................................................................		-		(51)		-		-		(51)
		Cash and cash equivalents at
			beginning of period ................................................................................................................................................................................................................		-		342		-		-		342
		Cash and cash equivalents at
			end of period ...........................................................................................................................................................................................................................	$	-	$	291	$	-	$	-	$	291

38

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Condensed Consolidating Statement of Cash Flows
Nine Months Ended September 30, 2011
			Parent		Subsidiary		Consolidating
(in thousands)			Issuer		Guarantors		Entries		Total
Net cash flows provided by (used in) operating activities .........................................................................................		$	(60,598)	$	839,584	$	-	$	778,986
Net cash flows used in investing activities ...................................................................................................................			(73,419)		(884,326)		-		(957,745)
Net cash flows provided by financing activities .........................................................................................................			133,971		44,578		-		178,549
	Net decrease in cash and cash equivalents ................................................................................................................		(46)		(164)		-		(210)
	Cash and cash equivalents at beginning of period ...................................................................................................		46		338		-		384
	Cash and cash equivalents at end of period ..............................................................................................................	$	-	$	174	$	-	$	174

39

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Note Q.  Subsequent events

New commodity derivative contracts.In October 2012, the Company entered into the following additional oil price swaps to hedge additional amounts of its estimated future production:

				First		Second		Third		Fourth
				Quarter		Quarter		Quarter		Quarter		Total
Oil Swaps: (a)
	2012:
		Volume (Bbl) ........................................................................................................................................................................................................................								475,000		475,000
		Price per Bbl ..........................................................................................................................................................................................................................							$	91.60	$	91.60
	2013:
		Volume (Bbl) ........................................................................................................................................................................................................................		385,000		295,000		239,000		196,000		1,115,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	93.16	$	93.16	$	93.16	$	93.15	$	93.16
	2014:
		Volume (Bbl) ........................................................................................................................................................................................................................		219,000		181,000		420,000		420,000		1,240,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	91.97	$	91.85	$	91.50	$	91.50	$	91.64
(a) The index prices for the oil price swaps are based on the NYMEX – West Texas Intermediate monthly average futures price.

40

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Divestiture.  In November 2012, the Company entered into a definitive agreement to sell certain of its non-core assets, a portion of which were acquired in the Three Rivers Acquisition, for approximately $520 million, subject to customary closing adjustments. No assurances can be given that this divestment will close, which is dependent on numerous factors including, but not limited to, market conditions.

The Company’s statements of operations for the three and nine months ended September 30, 2012 and 2011 reflect the following results of operations for the assets subject to the definitive agreement. 

			Three Months Ended				Nine Months Ended
			September 30,				September 30,
(in thousands)				2012		2011		2012		2011
Operating revenues:
	Oil sales ...........................................................................................................................................................................................................................................		$	26,616	$	26,297	$	82,518	$	73,671
	Natural gas sales ...........................................................................................................................................................................................................................			5,588		5,896		13,342		14,440
		Total operating revenues ..........................................................................................................................................................................................................		32,204		32,193		95,860		88,111
Operating costs and expenses:
	Oil and natural gas production ...................................................................................................................................................................................................			8,701		7,743		24,863		21,504
	Depreciation, depletion and amortization (a) ..........................................................................................................................................................................			9,623		6,318		26,412		20,126
	Accretion of discount on asset retirement obligations (a) .....................................................................................................................................................			336		126		629		395
	General and administrative (b) ...................................................................................................................................................................................................			(619)		(572)		(1,766)		(1,682)
		Total operating costs and expenses ........................................................................................................................................................................................		18,041		13,615		50,138		40,343
Income before income taxes .....................................................................................................................................................................................................				14,163		18,578		45,722		47,768
Income tax benefit (expense):
	Current ............................................................................................................................................................................................................................................			(4,576)		(3,494)		(14,773)		(8,983)
	Deferred (a) ....................................................................................................................................................................................................................................			(521)		(3,367)		(1,682)		(8,658)
Net income .....................................................................................................................................................................................................................................			$	9,066	$	11,717	$	29,267	$	30,127
(a)  Represents the significant non-cash amounts.
(b)  Represents the fees received from third-parties for operating oil and natural gas properties that were sold. The Company reflects
	these fees as a reduction of general and administrative expenses.

41

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

Note R.  Supplementary information

Capitalized costs

			September 30,		December 31,
(in thousands)			2012		2011
Oil and natural gas properties:
	Proved ..............................................................................................................................................................................................................................................		$	8,566,155	$	6,551,396
	Unproved .........................................................................................................................................................................................................................................			1,158,267		796,064
	Less: accumulated depletion .......................................................................................................................................................................................................			(1,542,056)		(1,116,545)
		Net capitalized costs for oil and natural gas properties ......................................................................................................................................................	$	8,182,366	$	6,230,915

Costs incurred for oil and natural gas producing activities(a)

			Three Months Ended				Nine Months Ended
			September 30,				September 30,
(in thousands)			2012		2011		2012		2011
Property acquisition costs:
	Proved ..............................................................................................................................................................................................................................................		$	690,158	$	-	$	855,773	$	69,148
	Unproved .........................................................................................................................................................................................................................................			349,903		42,432		411,110		117,772
Exploration ..........................................................................................................................................................................................................................................				223,569		138,170		567,065		410,089
Development .......................................................................................................................................................................................................................................				187,759		233,062		574,541		567,547
	Total costs incurred for oil and natural gas properties ............................................................................................................................................................		$	1,451,389	$	413,664	$	2,408,489	$	1,164,556
(a)	The costs incurred for oil and natural gas producing activities includes the following amounts of asset retirement obligations:
			Three Months Ended				Nine Months Ended
			September 30,				September 30,
	(in thousands)		2012		2011		2012		2011
	Proved property acquisition costs ...............................................................................................................................................................................................		$	26,986	$	-	$	29,113	$	148
	Exploration costs............................................................................................................................................................................................................................			1,185		198		2,452		838
	Development costs.........................................................................................................................................................................................................................			5,019		1,342		8,302		2,094
		Total asset retirement obligations .............................................................................................................................................................................................	$	33,190	$	1,540	$	39,867	$	3,080

42

Concho Resources Inc.

Condensed Notes to Consolidated Financial Statements

September 30, 2012

Unaudited

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

The following discussion is intended to assist you in understanding our business and results of operations together with our present financial condition. This section should be read in conjunction with our historical consolidated financial statements and notes. As a result of the acquisitions and divestures discussed below, many comparisons between periods may be difficult or impossible.

In July 2012, we acquired certain producing and non-producing assets from Three Rivers Operating Company (the “Three Rivers Acquisition”) for cash consideration of approximately $997.0 million, subject to customary post-closing adjustments. The Three Rivers Acquisition was primarily funded with borrowings under our credit facility. The results of operations prior to July 2012 do not include results from the Three Rivers Acquisition.

In February 2012, we acquired certain producing and non-producing assets from Petroleum Development Corporation (the “PDC Acquisition”) for cash consideration of approximately $189.2 million. The PDC Acquisition was primarily funded with borrowings under our credit facility. The results of operations prior to March 2012 do not include results from the PDC Acquisition.

In November 2011, we acquired three entities affiliated with OGX Holdings II, LLC (collectively the “OGX Acquisition”) for cash consideration of approximately $252.0 million. The OGX Acquisition was primarily funded with borrowings under our credit facility. The results of operations prior to December 2011 do not include results from the OGX Acquisition.

In March 2011, we sold our Bakken assets for cash consideration of approximately $195.9 million and recognized a pre-tax gain on the sale of assets of approximately $142.0 million. We have reflected the results of operations of these divested assets as discontinued operations, rather than as a component of continuing operations. See Note M of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited)” for additional information regarding these divestitures and their discontinued operations. For the first quarter of 2011, these assets produced an average of 1,369 Boe per day.

Certain statements in our discussion below are forward-looking statements. These forward-looking statements involve risks and uncertainties. We caution that a number of factors could cause actual results to differ materially from those implied or expressed by the forward-looking statements. Please see “Cautionary Statement Regarding Forward-Looking Statements.”

Overview

We are an independent oil and natural gas company engaged in the acquisition, development and exploration of producing oil and natural gas properties. Our core operations are primarily focused in the Permian Basin of Southeast New Mexico and West Texas. We refer to our three core operating areas as the (i) New Mexico Shelf, where we primarily target the Yeso and Lower Abo formations, (ii) Delaware Basin, where we primarily target the Bone Spring formation (which includes the Avalon Shale and the Bone Springs sands) and the Wolfcamp shale, and (iii) Texas Permian, where we primarily target the Wolfberry, a term applied to the combined Wolfcamp and Spraberry horizons. Oil comprised 61.7 percent of our 386.5 MMBoe of estimated proved reserves at December 31, 2011 and 60.6 percent of our 21.5 MMBoe of production for the nine months ended September 30, 2012. We seek to operate the wells in which we own an interest, and we operated wells that accounted for 93.0 percent of our proved developed producing PV-10 and 78.8 percent of our 5,504 gross wells at December 31, 2011. By controlling operations, we are able to more effectively manage the cost and timing of exploration and development of our properties, including the drilling and stimulation methods used.

Financial and Operating Performance

Our financial and operating performance for the nine months ended September 30, 2012, as compared to the nine months ended September 30, 2011, included the following highlights:

·Net income was $356.4 million ($3.43per diluted share) for the first nine months of 2012, as compared to net income of $631.0million ($6.09 per diluted share) during the nine months ended September 30, 2011. The decrease in net income was primarily due to:

§$142.0 million pre-tax gain from discontinued operations related to the sale of our Bakken assets in the first quarter of 2011;

§$130.0 million increase in depreciation, depletion and amortization (“DD&A”) expense from continuing operations, primarily due to (i) capitalized costs associated with new wells that were successfully drilled and completed in 2011 and 2012 and (ii) the acquisitions in 2011and 2012; 

43

§$59.2 million increase in oil and natural gas production costs from continuing operations due in part to increased (i) production, partially related to acquisitions in 2011 and 2012 and (ii) oil and natural gas revenues that directly increased our oil and natural gas production taxes;

§a $109.5 million gain on derivatives not designated as hedges for the first nine months of 2012, as compared to a $297.0 million gain on derivatives not designated as hedges during the nine months ended September 30, 2011; and

§$44.9 million increase in interest expense due to (i) a 55 percent increase in the weighted average debt balance outstanding between the periods primarily related to acquisitions and (ii) our senior note issuances in 2011 and 2012 which bear higher interest costs than borrowings under our credit facility;

partially offset by:

§$176.6 million increase in oil and natural gas revenues from continuing operations as a result of a 27percent increase in production offset by a 10 percent decrease in commodity price realizations per Boe (excluding the effects of derivative activities); and

·Average daily sales volumes from continuing operations increased by 26 percent from 62,231 Boe per day during the first nine months of 2011 to 78,643 Boe per day during the first nine months of 2012. The increase is primarily attributable to our successful drilling efforts during 2011 and 2012 and our acquisitions in 2011 and 2012.

·Net cash provided by operating activities increased by approximately $66.6 million to $845.6 million for the first nine months of 2012, as compared to $779.0 million in the first nine months of 2011, primarily due to (i) increased oil and natural gas revenues and (ii) positive variances in working capital changes, offset by increases in related oil and natural gas production costs and other cash related costs.

·Long-term debt increased by approximately $1.5billion during the first nine months of 2012, primarily as a result of the PDC Acquisition and Three Rivers Acquisition in February 2012 and July 2012, respectively.

·At September 30, 2012, availability under our credit facility was approximately $1.7billion. 

Commodity Prices

Our results of operations are heavily influenced by commodity prices. Commodity prices may fluctuate widely in response to relatively minor changes in the supply of and demand for oil and natural gas, market uncertainty and a variety of additional factors that are beyond our control. Factors that may impact future commodity prices, including the price of oil and natural gas, include:

·economic stimulus initiatives in the United States;

·worldwide and continuing economic struggles in Eurozone nations’ economies;

·political and economic developments in the Middle East;

·demand from Asian and European markets;

·the extent to which members of the Organization of Petroleum Exporting Countries and other oil exporting nations are able to continue to manage oil supply through export quotas;

·technological advances affecting energy consumption and energy supply;

·the effect of energy conservation efforts;

·the price and availability of alternative fuels;

·domestic and foreign governmental regulations and taxation;

·the proximity, capacity, cost and availability of pipelines and other transportation facilities;

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·the overall global demand for oil;  and

·overall North American natural gas supply and demand fundamentals, including:

§the United States economy impact,

§weather conditions, and

§liquefied natural gas deliveries to the United States.

Although we cannot predict the occurrence of events that may affect future commodity prices or the degree to which these prices will be affected, the prices for any commodity that we produce will generally approximate current market prices in the geographic region of the production. From time to time, we expect that we may economically hedge a portion of our commodity price risk to mitigate the impact of price volatility on our business. See Note H of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited)” for additional information regarding our commodity derivative positions at September 30, 2012.

Oil and natural gas prices have been subject to significant fluctuations during the past several years. In general, oil prices were relatively stable during the comparable periods of 2012 measured against 2011, while natural gas prices were significantly lower. The following table sets forth the average New York Mercantile Exchange (“NYMEX”) oil and natural gas prices for the three and nine months ended September 30, 2012 and 2011, as well as the high and low NYMEX prices for the same periods:

			Three Months Ended				Nine Months Ended
			September 30,				September 30,
			2012		2011		2012		2011
Average NYMEX prices:
	Oil (Bbl) ................................................................................................................................................................................................................................................		$	92.29	$	89.59	$	96.21	$	95.46
	Natural gas (MMBtu) ........................................................................................................................................................................................................................		$	2.89	$	4.06	$	2.59	$	4.21
High and Low NYMEX prices:
	Oil (Bbl):
		High .......................................................................................................................................................................................................................................................	$	99.00	$	99.87	$	109.77	$	113.93
		Low .......................................................................................................................................................................................................................................................	$	83.75	$	79.20	$	77.69	$	79.20
	Natural gas (MMBtu):
		High .......................................................................................................................................................................................................................................................	$	3.32	$	4.55	$	3.32	$	4.85
		Low .......................................................................................................................................................................................................................................................	$	2.61	$	3.67	$	1.91	$	3.67

Further, the NYMEX oil price and NYMEX natural gas price reached highs and lows of $92.48 and $84.86 per Bbl and $3.70 and $3.32 per MMBtu, respectively, during the period from September 30, 2012 to November 5, 2012. At November 5, 2012, the NYMEX oil price and NYMEX natural gas price were $85.65 per Bbl and $3.55 per MMBtu, respectively.

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Recent Events

2013 capital budget. In November 2012, we announced our 2013 capital budget of approximately $1.6 billion, which we expect will be substantially funded within our cash flow, based on current commodity prices and capital costs. As our size and financial flexibility have grown, we take a longer-term view on spending within our cash flow, and our spending during any specific period may exceed our cash flow for that period. However, our capital budget is largely discretionary, and if we experience sustained oil and natural gas prices significantly below the current levels or substantial increases in our costs, we may reduce our capital spending program to be substantially within our cash flow.

			2013
			Capital
(in millions)			Budget
Drilling and completion costs:
	New Mexico Shelf .............................................................................................................................................................................................................................	$	285
	Delaware Basin .................................................................................................................................................................................................................................		725
	Texas Permian ...................................................................................................................................................................................................................................		342
Acquisition of leasehold acreage and geological and geophysical data ...................................................................................................................................			110
Facilities and other capital in our core operating areas ................................................................................................................................................................			123
	Total ....................................................................................................................................................................................................................................................	$	1,585

Divestiture.  In November 2012, we entered into a definitive agreement to sell certain of our non-core assets, a portion of which were acquired in the Three Rivers Acquisition, for approximately $520 million, subject to customary closing adjustments. No assurances can be given that this divestment will close, which is dependent on numerous factors including, but not limited to, market conditions. For the three months ended September 30, 2012 these assets produced 5,841 Boe per day, which was approximately 57 percent oil.

Credit facility amendment.In October 2012, we amended our credit facility, increasing our borrowing base to $3.0 billion, but maintaining the aggregate lender commitments at $2.5 billion.At September 30, 2012, we had borrowings outstanding under our credit facility of approximately $0.8 billion, and our availability under our credit facility was approximately $1.7 billion.

Senior notes issuance.In August 2012, we issued $700 million aggregate principal amount of 5.5% senior notes due 2023 at par, for which we received net proceeds of approximately $688.6 million. In March 2012, we issued $600 million aggregate principal amount of 5.5% senior notes due 2022 at par, for which we received net proceeds of approximately $590.0 million. We used the net proceeds to repay a portion of the borrowings under our credit facility.

Three Rivers Acquisition. In July 2012, we completed the Three Rivers Acquisition for cash consideration of approximately $997.0 million, subject to customary post-closing adjustments. The Three Rivers Acquisition was primarily funded with borrowings under our credit facility.

PDC Acquisition. In February 2012, we completed the PDC Acquisition for cash consideration of approximately $189.2 million. The PDC Acquisition was primarily funded with borrowings under our credit facility.

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2012 Planned Capital Expenditures

For 2012, we expect capital expenditures to total approximately $1.5 billion, excluding the costs of acquisitions other than customary leasehold purchases of acreage. Based on current commodity prices and capital costs, we believe our 2012 planned capital expenditures, excluding the effects of acquisitions, will exceed our 2012 cash flow, and we expect to fund any such shortfall with borrowings under our credit facility.

The following summarizes our 2012 planned capital expenditures, which do not include acquisitions other than the customary purchase of leasehold acreage:

			2012
			Planned
			Capital
(in millions)			Expenditures
Drilling and completion costs:
	New Mexico Shelf .............................................................................................................................................................................................................................	$	515
	Delaware Basin .................................................................................................................................................................................................................................		482
	Texas Permian ...................................................................................................................................................................................................................................		388
Acquisition of leasehold acreage and geological and geophysical data ...................................................................................................................................			58
Facilities and other capital in our core operating areas ................................................................................................................................................................			63
	Total ....................................................................................................................................................................................................................................................	$	1,506

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Derivative Financial Instruments

Derivative financial instrument exposure.  At September 30, 2012, the fair value of our financial derivatives was a net asset of $38.2million. All of our counterparties to these financial derivatives are parties to our credit facility and have their outstanding debt commitments and derivative exposures collateralized pursuant to our credit facility. Under the terms of our financial derivative instruments and their collateralization under our credit facility, we do not have exposure to potential “margin calls” on our financial derivative instruments. We currently have no reason to believe that our counterparties to these commodity derivative contracts are not financially viable. Our credit facility does not allow us to offset amounts we may owe a lender against amounts we may be owed related to our financial instruments with such party.

In October 2012, we entered into the following additional oil price swaps to hedge additional amounts of our estimated future production:

				First		Second		Third		Fourth
				Quarter		Quarter		Quarter		Quarter		Total
Oil Swaps: (a)
	2012:
		Volume (Bbl) ........................................................................................................................................................................................................................								475,000		475,000
		Price per Bbl ..........................................................................................................................................................................................................................							$	91.60	$	91.60
	2013:
		Volume (Bbl) ........................................................................................................................................................................................................................		385,000		295,000		239,000		196,000		1,115,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	93.16	$	93.16	$	93.16	$	93.15	$	93.16
	2014:
		Volume (Bbl) ........................................................................................................................................................................................................................		219,000		181,000		420,000		420,000		1,240,000
		Price per Bbl ..........................................................................................................................................................................................................................	$	91.97	$	91.85	$	91.50	$	91.50	$	91.64
(a) The index prices for the oil price swaps are based on the NYMEX – West Texas Intermediate monthly average futures price.

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Results of Operations

The following table sets forth summary information concerning our production and operating data from continuing operations for the three and nine months ended September 30, 2012 and 2011. The table below excludes production and operating data that we have classified as discontinued operations, which is more fully described in Note M of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited).” The actual historical data in this table excludes results from (i) the Three Rivers Acquisition for periods prior to July 2012, (ii) the PDC Acquisition for periods prior to March 2012 and (iii) the OGX Acquisition for periods prior to December 2011. Because of normal production declines, increased or decreased drilling activities and the effects of acquisitions or divestitures, the historical information presented below should not be interpreted as being indicative of future results.

					Three Months Ended				Nine Months Ended
					September 30,				September 30,
					2012		2011		2012		2011
Production and operating data:
	Net production volumes:
		Oil (MBbl) .....................................................................................................................................................................................................................................				4,619		3,869		13,053		10,501
		Natural gas (MMcf) ....................................................................................................................................................................................................................				19,122		14,652		50,970		38,929
		Total (MBoe) ................................................................................................................................................................................................................................				7,806		6,311		21,548		16,989
	Average daily production volumes:
		Oil (Bbl) .........................................................................................................................................................................................................................................				50,207		42,054		47,639		38,465
		Natural gas (Mcf) ........................................................................................................................................................................................................................				207,848		159,258		186,022		142,596
		Total (Boe) ....................................................................................................................................................................................................................................				84,848		68,597		78,643		62,231
	Average prices:
		Oil, without derivatives (Bbl) .....................................................................................................................................................................................................			$	88.13	$	85.98	$	90.56	$	91.21
		Oil, with derivatives (Bbl) (a) .....................................................................................................................................................................................................			$	91.56	$	83.90	$	89.91	$	82.77
		Natural gas, without derivatives (Mcf) ....................................................................................................................................................................................			$	4.73	$	8.31	$	5.03	$	7.80
		Natural gas, with derivatives (Mcf) (a) ....................................................................................................................................................................................			$	4.75	$	8.74	$	5.04	$	8.25
		Total, without derivatives (Boe) ...............................................................................................................................................................................................			$	63.74	$	72.01	$	66.74	$	74.26
		Total, with derivatives (Boe) (a) ...............................................................................................................................................................................................			$	65.81	$	71.73	$	66.39	$	70.06
	Operating costs and expenses per Boe:
		Lease operating expenses and workover costs ......................................................................................................................................................................			$	7.15	$	7.42	$	7.30	$	6.72
		Oil and natural gas taxes ............................................................................................................................................................................................................			$	5.24	$	5.90	$	5.53	$	6.07
		Depreciation, depletion and amortization ..............................................................................................................................................................................			$	20.19	$	18.34	$	20.18	$	17.95
		General and administrative .......................................................................................................................................................................................................			$	4.47	$	3.62	$	4.37	$	3.94
	(a)	Includes the effect of cash settlements received from (paid on) commodity derivatives not designated as hedges and reported in operating costs and expenses. The following table reflects the amounts of cash settlements received from (paid on) commodity derivatives not designated as hedges that were included in computing average prices with derivatives and reconciles to the amount in (gain) loss on derivatives not designated as hedges as reported in the statements of operations:
					Three Months Ended				Nine Months Ended
					September 30,				September 30,
		(in thousands)			2012		2011		2012		2011
		Gain (loss) on derivatives not designated as hedges:
			Cash receipts from (payments on) oil derivatives ...........................................................................................................................................................		$	15,859	$	(8,051)	$	(8,374)	$	(88,679)
			Cash receipts from natural gas derivatives .......................................................................................................................................................................			280		6,263		889		17,468
			Cash payments on interest rate derivatives ......................................................................................................................................................................			-		-		-		(6,624)
			Unrealized mark-to-market gain (loss) on commodity and
				interest rate derivatives ...................................................................................................................................................................................................		(151,554)		387,010		117,027		374,797
			Gain (loss) on derivatives not designated as hedges .......................................................................................................................................................		$	(135,415)	$	385,222	$	109,542	$	296,962
		The presentation of average prices with derivatives is a non-GAAP measure as a result of including the cash receipts from (payments on) commodity derivatives that are presented in gain (loss) on derivatives not designated as hedges in the statements of operations. This presentation of average prices with derivatives is a means by which to reflect the actual cash performance of our commodity derivatives for the respective periods and presents oil and natural gas prices with derivatives in a manner consistent with the presentation generally used by the investment community.

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The following table sets forth summary information from our discontinued operations concerning our production and operating data for the nine months ended September 30, 2011. The discontinued operations presentation is the result of reclassifying the results of operations from our March 2011 Bakken divestiture, which is more fully described in Note M of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited).”

			Nine Months Ended
			September 30, 2011
Production and operating data:
	Net production volumes:
		Oil (MBbl) .................................................................................................................................................................................................................................			117
		Natural gas (MMcf) ................................................................................................................................................................................................................			37
		Total (MBoe) ............................................................................................................................................................................................................................			123
	Average daily production volumes:
		Oil (MBbl) .................................................................................................................................................................................................................................			429
		Natural gas (MMcf) ................................................................................................................................................................................................................			136
		Total (MBoe) ............................................................................................................................................................................................................................			451
	Average prices:
		Oil, without derivatives (Bbl) .................................................................................................................................................................................................		$	80.82
		Oil, with derivatives (Bbl) .......................................................................................................................................................................................................		$	80.82
		Natural gas, without derivatives (Mcf) ................................................................................................................................................................................		$	1.84
		Natural gas, with derivatives (Mcf) ......................................................................................................................................................................................		$	1.84
		Total, without derivatives (Boe) ...........................................................................................................................................................................................		$	77.43
		Total, with derivatives (Boe) .................................................................................................................................................................................................		$	77.43
	Operating costs and expenses per Boe:
		Lease operating expenses and workover costs ..................................................................................................................................................................		$	3.85
		Oil and natural gas taxes ........................................................................................................................................................................................................		$	9.50
		Depreciation, depletion and amortization ..........................................................................................................................................................................		$	17.13

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Three Months Ended September 30, 2012 Compared to Three Months Ended September 30, 2011

Oil and natural gas revenues.  Revenue from oil and natural gas operations was$497.5 million for the three months ended September 30, 2012, an increase of$43.0 million (9 percent) from $454.5 million for the three months ended September 30, 2011. This increase was primarily due to an increase in the realized oil price and increased production due to (i) successful drilling efforts during 2011 and 2012, (ii) production from the OGX Acquisition which closed in November 2011, (iii) production from the PDC Acquisition which closed in February 2012 and (iv) production from the Three Rivers Acquisition which closed in July 2012. Specific factors affecting oil and natural gas revenues include the following:

·total oil production was 4,619 MBbl for the three months ended September 30, 2012, an increase of 750 MBbl (19 percent) from 3,869 MBbl for the three months ended September 30, 2011; 

·average realized oil price (excluding the effects of derivative activities) was $88.13 per Bbl during the three months ended September 30, 2012, an increase of 3 percent from $85.98 per Bbl during the three months ended September 30, 2011; 

·total natural gas production was 19,122 MMcf for the three months ended September 30, 2012, an increase of 4,470 MMcf (31 percent) from 14,652 MMcf for the three months ended September 30, 2011; and

·average realized natural gas price (excluding the effects of derivative activities) was $4.73 per Mcf during the three months ended September 30, 2012, a decrease of 43 percent from $8.31 per Mcf during the three months ended September 30, 2011. Our natural gas prices have been significantly higher than the related NYMEX prices primarily due to the value of the natural gas liquids in our liquids-rich natural gas stream.

Production expenses.  The following table provides the components of our total oil and natural gas production costs for the three months ended September 30, 2012 and 2011:

				Three Months Ended September 30,
				2012				2011
					Per				Per
(in thousands, except per unit amounts)			Amount		Boe		Amount		Boe
Lease operating expenses ..........................................................................................................................................................................................................			$	53,448	$	6.85	$	46,587	$	7.39
Taxes:
	Ad valorem ..............................................................................................................................................................................................................................			4,537		0.58		2,671		0.42
	Production ................................................................................................................................................................................................................................			36,343		4.66		34,593		5.48
Workover costs ............................................................................................................................................................................................................................				2,338		0.30		199		0.03
		Total oil and natural gas production expenses ...........................................................................................................................................................	$	96,666	$	12.39	$	84,050	$	13.32

Among the cost components of production expenses, we have some control over lease operating expenses and workover costs on properties we operate, but production and ad valorem taxes are directly related to commodity price changes.

Lease operating expenses for the three months ended September 30, 2011 included a $9.5 million ($1.50 per Boe) underestimate of costs related to the first and second quarters of 2011.

Lease operating expenses were $53.4 million ($6.85 per Boe) for the three months ended September 30, 2012, which was an increase of $6.8 million (15 percent) from $46.6 million ($7.39 per Boe) for the three months ended September 30, 2011. The increase in lease operating expenses was primarily due to (i) our wells successfully drilled and completed in 2011 and 2012, (ii) the acquisitions in 2011 and 2012 and (iii) an increase in cost of services, primarily labor related, due to the increased demand for services and related labor in the Permian Basin offset by an underestimate of costs in periods prior to the third quarter of 2011 as mentioned above. The decrease in lease operating expenses per Boe was primarily due to (i) the $1.50 per Boe included in the three months ended September 30, 2011 related to the underestimate of costs in periods prior to the third quarter of 2011 mentioned above and (ii)

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additional production from our wells successfully drilled which were completed in 2011 and 2012 where we are receiving benefits from economies of scale, offset in part by cost increases in services, primarily labor related.

Ad valorem taxes have increased primarily as a result of increased valuations of our Texas properties and the increase in the number of wells primarily associated with our 2011 and 2012 drilling activity in our Texas Permian area and the Texas properties acquired in the PDC Acquisition and the Three Rivers Acquisition.

Production taxes per unit of production were $4.66 per Boe during the three months ended September 30, 2012, a decrease of 15 percent from $5.48 per Boe during the three months ended September 30, 2011. The decrease was directly related to the decrease in commodity prices offset by our increase in oil and natural gas revenues related to increased volumes. Over the same period, our per Boe prices (excluding the effects of derivatives) decreased 11 percent.

Workover expenses were approximately $2.3 million and $0.2 million for the three months ended September 30, 2012 and 2011, respectively. The 2012 amounts related primarily to workovers in all areas, while the 2011 amounts related primarily to activity in the Texas Permian area performed to increase or restore production. 

Exploration and abandonments expense. The following table provides a breakdown of our exploration and abandonments expense for the three months ended September 30, 2012 and 2011:

		Three Months Ended
		September 30,
(in thousands)		2012		2011
Geological and geophysical .......................................................................................................................................................................		$	3,273	$	2,859
Exploratory dry hole costs .........................................................................................................................................................................			3,008		-
Leasehold abandonments and other .......................................................................................................................................................			677		639
	Total exploration and abandonments .............................................................................................................................................	$	6,958	$	3,498

Our geological and geophysical expense, which primarily consists of the costs of acquiring and processing seismic data, geophysical data and core analysis, primarily relating to our Delaware Basin and Texas Permian areas, was approximately $3.3 million and $2.9 million for the three months ended September 30, 2012 and 2011, respectively.

Our exploratory dry hole costs during the three months ended September 30, 2012 was primarily related to (i) expensing a dry hole that logged no pay in the Lower Abo formation in the New Mexico Shelf area and (ii) expensing the costs of drilling a well that experienced mechanical issues in the Texas Permian area.

For the three months ended September 30, 2012, we recorded approximately $0.7 million of leasehold abandonments, which related to non-core prospects in our New Mexico Shelf area.

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Depreciation, depletion and amortization expense.  The following table provides components of our depreciation, depletion and amortization expense for the three months ended September 30, 2012 and 2011:

		Three Months Ended September 30,
		2012				2011
(in thousands, except per unit amounts)			Amount	Per Boe			Amount	Per Boe
.........................................................................................................................................................................................................................................................................
Depletion of proved oil and natural gas properties ..........................................................................................................................................................................................		$	153,877	$	19.71	$	113,865	$	18.04
Depreciation of other property and equipment .................................................................................................................................................................................................			3,356		0.43		1,477		0.23
Amortization of intangible asset - operating rights ..........................................................................................................................................................................................			388		0.05		388		0.07
	Total depletion, depreciation and amortization ..........................................................................................................................................................................................	$	157,621	$	20.19	$	115,730	$	18.34
Oil price used to estimate proved oil reserves at period end ............................................................................................................................................................................		$	91.48			$	91.00
Natural gas price used to estimate proved natural gas reserves at period end ..................................................................................................................................................		$	2.82			$	4.16

Depletion of proved oil and natural gas properties was $153.9 million ($19.71 per Boe) for the three months ended September 30, 2012, an increase of $40.0 million (35 percent) from $113.9 million ($18.04 per Boe) for the three months ended September 30, 2011. The increase in depletion expense was primarily due to (i) capitalized costs associated with new wells that were successfully drilled and completed in 2011 and 2012 and (ii) costs associated with our acquisitions in 2011 and 2012. The increase in depletion expense per Boe was primarily due to (i) the properties acquired in the Three Rivers Acquisition having a higher rate per Boe than our legacy wells, (ii) drilling deeper, higher cost wells and (iii) the decrease in the natural gas price between periods utilized to determine proved reserves.

The amortization of the intangible asset is a result of the value assigned to the operating rights that we acquired in an acquisition. The intangible asset is currently being amortized over an estimated life of 25 years.

General and administrative expenses.The following table provides components of our general and administrative expenses for the three months ended September 30, 2012 and 2011:

		Three Months Ended September 30,
		2012				2011
				Per				Per
(in thousands, except per unit amounts)		Amount		Boe		Amount		Boe
General and administrative expenses ...................................................................................................................................		$	31,342	$	4.02	$	21,779	$	3.45
Non-cash stock-based compensation ..................................................................................................................................			7,959		1.02		4,673		0.74
Less: Third-party operating fee reimbursements ................................................................................................................			(4,428)		(0.57)		(3,579)		(0.57)
	Total general and administrative expenses ......................................................................................................................	$	34,873	$	4.47	$	22,873	$	3.62

General and administrative expenses were approximately $34.9 million ($4.47 per Boe) for the three months ended September 30, 2012, an increase of $12.0 million (52 percent) from $22.9 million ($3.62 per Boe) for the three months ended September 30, 2011. The increase in general and administrative expenses and non-cash stock-based compensation was primarily due to an increase in the number of employees and related personnel expenses to handle our increased activities, both from (i) increased drilling and exploration activities and (ii) our acquisitions in 2011 and 2012. The increase in general and administrative expenses per Boe was primarily due to (i) an increase in the number of employees and related personnel expenses to handle our increased activities and (ii) an increase in non-cash stock-based compensation expense, offset in part by (i) increased production from our wells successfully drilled and completed in 2011 and 2012, (ii) additional production associated with our acquisitions in 2011 and 2012 and (iii) increased third-party operating fee reimbursements.

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As the operator of certain oil and natural gas properties in which we own an interest, we earn overhead reimbursements during the drilling and production phases of the property. We earned reimbursements of $4.4 million and $3.6 million during the three months ended September 30, 2012 and 2011, respectively. This reimbursement is reflected as a reduction of general and administrative expenses in the consolidated statements of operations. The increase in third-party operating fee reimbursements is primarily due to drilling and completing wells in which we own a lower working interest resulting in increased third-party income.

(Gain) loss on derivatives not designated as hedges.The following table sets forth the cash settlements and the non-cash mark-to-market adjustments for the derivative contracts not designated as hedges for the three months ended September 30, 2012 and 2011:

			Three Months Ended
			September 30,
(in thousands)			2012		2011
Cash payments (receipts):
	Commodity derivatives - oil ...................................................................................................................................................................		$	(15,859)	$	8,051
	Commodity derivatives - natural gas ...................................................................................................................................................			(280)		(6,263)
Mark-to-market (gain) loss:
	Commodity derivatives - oil ...................................................................................................................................................................			151,260		(390,327)
	Commodity derivatives - natural gas ...................................................................................................................................................			294		3,317
		(Gain) loss on derivatives not designated as hedges ......................................................................................................................	$	135,415	$	(385,222)

Our earnings are affected by the changes in value of our derivatives portfolio between periods and the related cash settlements of those derivatives, which can be volatile to our earnings. To the extent the future commodity price outlook declines between measurement periods, we will have mark-to-market gains, while to the extent future commodity price outlook increases between measurement periods, we will have mark-to-market losses.

Interest expense.The following table sets forth interest expense, weighted average interest rates and weighted average debt balances for the three months ended September 30, 2012 and 2011:

		Three Months Ended
		September 30,
(dollars in thousands)		2012		2011
Interest expense ...........................................................................................................................................................................................................................................		$	51,337	$	32,881
.........................................................................................................................................................................................................................................................................
Weighted average interest rate - credit facility........................................................................................................................................................................................			2.4%		2.3%
Weighted average interest rate - senior notes..........................................................................................................................................................................................			6.5%		7.1%
	Total weighted average interest rate ..................................................................................................................................................................................................		5.2%		6.3%
Weighted average credit facility balance ................................................................................................................................................................................................		$	1,125,549	$	306,201
Weighted average senior notes balance ..................................................................................................................................................................................................			2,434,444		1,500,000
	Total weighted average debt balance ...............................................................................................................................................................................................	$	3,559,993	$	1,806,201

The increase in weighted average debt balance for the three months ended September 30, 2012 as compared to the corresponding period in 2011 was due primarily to (i) borrowings associated with our acquisitions in 2011 and 2012 and (ii) timing of our capital expenditures. The increase in interest expense was due to an overall increase in the weighted average debt balance, offset in part by a lower weighted average interest rate due to (i) the weighted average debt balance of credit facility borrowings bearing a lower interest rate than our senior notes and (ii) our recent senior note issuances having lower interest rates than historical issuances.

Income tax provisions.  We recorded an income tax expense of $4.2 million and $221.2 million for the three months ended September 30, 2012 and 2011, respectively. The effective income tax rate for the three months ended September 30, 2012 and 2011 was 41.0 percent and 38.3 percent, respectively.

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Nine Months Ended September 30, 2012 Compared to Nine Months Ended September 30, 2011

Oil and natural gas revenues.  Revenue from oil and natural gas operations was$1.44 billion for the nine months ended September 30, 2012, an increase of$0.2 billion (14 percent) from $1.26 billion for the nine months ended September 30, 2011. This increase was primarily due to increased production due to (i) successful drilling efforts during 2011 and 2012, (ii) production from the OGX Acquisition which closed in November 2011, (iii) production from the PDC Acquisition which closed in February 2012, and (iv) production from the Three Rivers Acquisition which closed in July 2012, partially offset by decreases in realized oil and natural gas prices. Specific factors affecting oil and natural gas revenues include the following:

·total oil production was 13,053 MBbl for the nine months ended September 30, 2012, an increase of 2,552 MBbl (24 percent) from 10,501 MBbl for the nine months ended September 30, 2011; 

·average realized oil price (excluding the effects of derivative activities) was $90.56 per Bbl during the nine months ended September 30, 2012, a decrease of 1 percent from $91.21 per Bbl during the nine months ended September 30, 2011; 

·total natural gas production was 50,970 MMcf for the nine months ended September 30, 2012, an increase of 12,041 MMcf (31 percent) from 38,929 MMcf for the nine months ended September 30, 2011; and

·average realized natural gas price (excluding the effects of derivative activities) was $5.03 per Mcf during the nine months ended September 30, 2012, a decrease of 36 percent from $7.80 per Mcf during the nine months ended September 30, 2011. Our natural gas prices have been significantly higher than the related NYMEX prices primarily due to the value of the natural gas liquids in our liquids-rich natural gas stream.

Production expenses.  The following table provides the components of our total oil and natural gas production costs for the nine months ended September 30, 2012 and 2011:

			Nine Months Ended September 30,
			2012				2011
						Per				Per
(in thousands, except per unit amounts)				Amount		Boe		Amount		Boe
Lease operating expenses ..........................................................................................................................................................................................................			$	148,771	$	6.90	$	113,049	$	6.66
Taxes:
	Ad valorem ..............................................................................................................................................................................................................................			11,573		0.54		8,013		0.47
	Production ................................................................................................................................................................................................................................			107,444		4.99		95,156		5.60
Workover costs ............................................................................................................................................................................................................................				8,717		0.40		1,067		0.06
		Total oil and natural gas production expenses ...........................................................................................................................................................	$	276,505	$	12.83	$	217,285	$	12.79

Among the cost components of production expenses, we have some control over lease operating expenses and workover costs on properties we operate, but production and ad valorem taxes are directly related to commodity price changes.

Lease operating expense for the nine months ended September 30, 2011 included a $4.0 million ($0.24 per Boe) underestimate of costs in periods prior to 2011.

Lease operating expenses were $148.8 million ($6.90 per Boe) for the nine months ended September 30, 2012, which was an increase of $35.8 million (32 percent) from $113.0 million ($6.66 per Boe) for the nine months ended September 30, 2011. The increase in lease operating expenses was primarily due to (i) our wells successfully drilled and completed in 2011 and 2012, (ii) the acquisitions in 2011 and 2012 and (iii) an increase in cost of services, primarily labor related, due to the increased demand for services and related labor in the Permian Basin, offset by an underestimate of costs in periods prior to 2011 mentioned above. The increase in lease operating expenses per Boe was primarily due to an increase in cost of services, primarily labor related, due to the increased demand for services and related labor in the Permian Basin, offset in part by (i) additional production from our wells successfully drilled and completed in 2011 and 2012 where we are receiving benefits from economies of scale and (ii) the $0.24 per Boe included in the nine months ended September 30, 2011 related to the underestimate of costs in periods prior to 2011 mentioned above.

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Ad valorem taxes have increased primarily as a result of increased valuations of our Texas properties and the increase in the number of wells primarily associated with our 2011 and 2012 drilling activity in our Texas Permian area and the Texas properties acquired in the PDC Acquisition and the Three Rivers Acquisition.

Production taxes per unit of production were $4.99 per Boe during the nine months ended September 30, 2012, a decrease of 11 percent from $5.60 per Boe during the nine months ended September 30, 2011. The decrease was directly related to the decrease in commodity prices offset by our increase in oil and natural gas revenues related to increased volumes. Over the same period, our per Boe prices (excluding the effects of derivatives) decreased 9 percent.

Workover expenses were approximately $8.7 million and $1.1 million for the nine months ended September 30, 2012 and 2011, respectively. The 2012 amounts related primarily to workovers in the New Mexico Shelf and Texas Permian areas, while the 2011 amounts related primarily to activity in the Texas Permian area performed to increase or restore production. 

Exploration and abandonments expense. The following table provides a breakdown of our exploration and abandonments expense for the nine months ended September 30, 2012 and 2011:

		Nine Months Ended September 30,
(in thousands)		2012		2011
Geological and geophysical .......................................................................................................................................................................		$	12,111	$	3,817
Exploratory dry hole costs .........................................................................................................................................................................			5,990		12
Leasehold abandonments and other .......................................................................................................................................................			9,234		795
	Total exploration and abandonments ...............................................................................................................................................	$	27,335	$	4,624

Our geological and geophysical expense, which primarily consists of the costs of acquiring and processing seismic data, geophysical data and core analysis, was approximately $12.1 million and $3.8 million, primarily relating to our Delaware Basin and Texas Permian areas, for the nine months ended September 30, 2012 and 2011, respectively.

Our exploratory dry hole costs during the nine months ended September 30, 2012 was primarily related to (i) expensing an unsuccessful lateral on a horizontal well due to mechanical issues in the Delaware Basin area, (ii) expensing a dry hole that logged no pay in the Lower Abo formation in the New Mexico Shelf area and (iii) expensing the costs of drilling a well that experienced mechanical issues in the Texas Permian area.

For the nine months ended September 30, 2012, we recorded approximately $9.2 million of leasehold abandonments, which related to non-core prospects in our New Mexico Shelf area.

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Depreciation, depletion and amortization expense.  The following table provides components of our depreciation, depletion and amortization expense for the nine months ended September 30, 2012 and 2011:

		Nine Months Ended September 30,
		2012				2011
					Per				Per
(in thousands, except per unit amounts)			Amount		Boe		Amount		Boe
Depletion of proved oil and natural gas properties ..........................................................................................		$	425,243	$	19.73	$	300,106	$	17.66
Depreciation of  other property and equipment ...............................................................................................			8,535		0.40		3,631		0.21
Amortization of intangible asset - operating rights ...........................................................................................			1,162		0.05		1,162		0.08
	Total depletion, depreciation and amortization ...............................................................................................	$	434,940	$	20.18	$	304,899	$	17.95
Oil price used to estimate proved oil reserves at period end ...........................................................................		$	91.48			$	91.00
Natural gas price used to estimate proved natural gas reserves at period end ............................................		$	2.82			$	4.16

Depletion of proved oil and natural gas properties was $425.2 million ($19.73 per Boe) for the nine months ended September 30, 2012, an increase of $125.1 million (42 percent) from $300.1 million ($17.66 per Boe) for the nine months ended September 30, 2011. The increase in depletion expense was primarily due to (i) capitalized costs associated with new wells that were successfully drilled and completed in 2011 and 2012 and (ii) costs associated with our acquisitions in 2012 and 2011. The increase in depletion expense per Boe was primarily due to (i) the properties acquired in the Three Rivers Acquisition having a higher rate per Boe than our legacy wells, (ii) drilling deeper, higher cost wells and (iii) the decrease in natural gas prices between periods utilized to determine proved reserves.

The amortization of the intangible asset is a result of the value assigned to the operating rights that we acquired in an acquisition. The intangible asset is currently being amortized over an estimated life of 25 years.

General and administrative expenses.The following table provides components of our general and administrative expenses for the nine months ended September 30, 2012 and 2011:

		Nine Months Ended September 30,
		2012				2011
				Per				Per
(in thousands, except per unit amounts)		Amount		Boe		Amount		Boe
General and administrative expenses.....................................................................................................................................		$	85,285	$	3.96	$	62,311	$	3.67
Non-cash stock-based compensation....................................................................................................................................			21,434		0.99		13,866		0.82
Less: Third-party operating fee reimbursements .................................................................................................................			(12,491)		(0.58)		(9,294)		(0.55)
	Total general and administrative expenses ......................................................................................................................	$	94,228	$	4.37	$	66,883	$	3.94

General and administrative expenses were $94.2 million ($4.37 per Boe) for the nine months ended September 30, 2012, an increase of $27.3 million (41 percent) from $66.9 million ($3.94 per Boe) for the nine months ended September 30, 2011. The increase in general and administrative expenses and non-cash stock-based compensation was primarily due to an increase in the number of employees and related personnel expenses to handle our increased activities, both from (i) increased drilling and exploration activities and (ii) our acquisitions in 2012 and 2011. The increase in total general and administrative expenses per Boe was primarily due to (i) an increase in the number of employees and related personnel expenses to handle our increased activities and (ii) an increase in non-cash stock-based compensation expense, offset in part by (i) increased production from our wells successfully drilled and completed in 2011 and 2012, (ii) additional production from our acquisitions in 2011 and 2012 and (iii) increased third-party operating fee reimbursements.

As the operator of certain oil and natural gas properties in which we own an interest, we earn overhead reimbursements during the drilling and production phases of the property. We earned reimbursements of $12.5 million and $9.3 million during the nine months

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ended September 30, 2012 and 2011, respectively. This reimbursement is reflected as a reduction of general and administrative expenses in the consolidated statements of operations. The increase in third-party operating fee reimbursements is primarily due to drilling wells during the nine months ended September 30, 2012 in which we own a lower working interest resulting in increased third-party income.

Gain on derivatives not designated as hedges.The following table sets forth the cash settlements and the non-cash mark-to-market adjustments for the derivative contracts not designated as hedges for the nine months ended September 30, 2012 and 2011:

		Nine Months Ended September 30,
(in thousands)			2012	2011
Cash payments (receipts):
	Commodity derivatives - oil ...................................................................................................................................................................	$	8,374	$	88,679
	Commodity derivatives - natural gas ...................................................................................................................................................		(889)		(17,468)
	Financial derivatives - interest ...............................................................................................................................................................		-		6,624
Mark-to-market (gain) loss:
	Commodity derivatives - oil ...................................................................................................................................................................		(117,760)		(381,385)
	Commodity derivatives - natural gas ...................................................................................................................................................		733		12,342
	Financial derivatives - interest ...............................................................................................................................................................		-		(5,754)
Gain on derivatives not designated as hedges ......................................................................................................................................		$	(109,542)	$	(296,962)

Our earnings are affected by the changes in value of our derivatives portfolio between periods and the related cash settlements of those derivatives, which can be volatile to our earnings. To the extent the future commodity price outlook declines between measurement periods, we will have mark-to-market gains, while to the extent future commodity price outlook increases between measurement periods, we will have mark-to-market losses.

Interest expense.The following table sets forth interest expense, weighted average interest rates and weighted average debt balances for the nine months ended September 30, 2012 and 2011:

			Nine Months Ended
			September 30,
(dollars in thousands)			2012		2011
Interest expense .............................................................................................................................................................................................................			$	129,073	$	84,201
Weighted average interest rate - credit facility .........................................................................................................................................................				2.4%		2.7%
Weighted average interest rate - senior notes ...........................................................................................................................................................				6.7%		7.3%
	Total weighted average interest rate ......................................................................................................................................................................			5.6%		6.0%
Weighted average credit facility balance ..................................................................................................................................................................				667,867		498,722
Weighted average senior notes balance ....................................................................................................................................................................				2,051,481		1,252,222
	Total weighted average debt balance ...................................................................................................................................................................	.........................................................................................................................................................................................................................................................................	$	2,719,348	$	1,750,944

The increase in weighted average debt balance for the nine months ended September 30, 2012 as compared to the corresponding 2011 period was due primarily to (i) borrowings associated with our acquisitions in 2012 and 2011 and (ii) timing of our capital expenditures. The increase in interest expense was due to an overall increase in the weighted average debt balance offset in part by a slightly lower weighted average interest rate due to (i) the weighted average debt balance of credit facility borrowings bearing a lower interest rate than our senior notes and (ii) our recent senior note issuances having lower interest rates than historical issuances.

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Income tax provisions.  We recorded an income tax expense of $220.8 million and $334.0 million for the nine months ended September 30, 2012 and 2011, respectively. The effective income tax rate for the nine months ended September 30, 2012 and 2011 was 38.3 percent and 38.2 percent, respectively.

Income from discontinued operations, net of tax. In March 2011, we sold our Bakken assets for cash consideration of approximately $195.9 million and recognized a pre-tax gain on the sale of assets of approximately $142.0 million. We have reflected the results of operations of these divested assets as discontinued operations, rather than as a component of continuing operations. See Note M of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited)” for additional information regarding these divestitures and their discontinued operations.

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Capital Commitments, Capital Resources and Liquidity

Capital commitments.  Our primary needs for cash are development, exploration and acquisition of oil and natural gas assets, payment of contractual obligations and working capital obligations. Funding for these cash needs may be provided by any combination of internally-generated cash flow, financing under our credit facility or proceeds from the disposition of assets or alternative financing sources, as discussed in “— Capital resources” below.

Oil and natural gas properties. Our costs incurred on oil and natural gas properties, excluding acquisitions and asset retirement obligations, during the nine months ended September 30, 2012 and 2011 totaled $1.1billion and $974.7 million, respectively. The primary reason for the differences in the costs incurred and cash flow expenditures is the timing of payments. The 2012 expenditures were funded in part from borrowings under our credit facility.

For 2012, we expect capital expenditures to total approximately $1.5 billion, excluding the costs of acquisitions other than customary leasehold purchases of acreage. Based on current commodity prices and capital costs, we believe our 2012 planned capital expenditures, excluding the effects of acquisitions, will exceed our 2012 cash flow, and we expect to fund any such shortfall with borrowings under our credit facility.

In November 2012, we announced our 2013 capital budget of approximately $1.6 billion, which we expect can be substantially funded within our cash flow, based on current commodity prices and capital costs. As our size and financial flexibility have grown, we take a longer-term view on spending within our cash flow, and our spending during any specific period may exceed our cash flow for that period. However, our capital budget is largely discretionary, and if we experience sustained oil and natural gas prices significantly below the current levels or substantial increases in our costs, we may reduce our capital spending program to be substantially within our cash flow.

Although we cannot provide any assurance, we generally attempt to fund our non-acquisition expenditures with our available cash and cash flow as adjusted from time to time; however, we may also use our credit facility, or other alternative financing sources, to fund such expenditures. The actual amount and timing of our expenditures may differ materially from our estimates as a result of, among other things, actual drilling results, the timing of expenditures by third parties on projects that we do not operate, the availability of drilling rigs and other services and equipment, regulatory, technological and competitive developments and market conditions. In addition, under certain circumstances we would consider increasing or reallocating our capital spending plans. 

Other than the customary purchase of leasehold acreage, our capital budgets are exclusive of acquisitions. We do not have a specific acquisition budget, since the timing and size of acquisitions are difficult to forecast. We evaluate opportunities to purchase or sell oil and natural gas properties in the marketplace and could participate as a buyer or seller of properties at various times. We seek to acquire oil and natural gas properties that provide opportunities for the addition of reserves and production through a combination of development, high-potential exploration and control of operations that will allow us to apply our operating expertise.

Acquisitions. Our expenditures for acquisitions of proved and unproved properties during the three months ended September 30, 2012 and 2011 totaled approximately $1.0billion and $42.4million, respectively, and approximately $1.3 billion and $186.9 million during the nine months ended September 30, 2012 and 2011, respectively. The significant acquisitions of proved properties during the nine months ended September 30, 2012 primarily related to the PDC Acquisition and the Three Rivers Acquisition. Expenditures for leasehold acreage acquisitions (which are expenditures we generally provide for in our planned capital expenditures) included in the total above were approximately $31.3million and $73.3million for the nine months ended September 30, 2012 and 2011, respectively.

Divestitures.In March 2011, we sold our Bakken assets for cash consideration of approximately $195.9 million and recognized a pre-tax gain on the sale of assets of approximately $142.0 million. For the nine months ended September 30, 2011, these assets produced an average of approximately 451 Boe per day, of which approximately 95 percent was oil. We used the net proceeds from this divestiture to initially repay a portion of the outstanding borrowings under our credit facility.

In November 2012, we entered into a definitive agreement to sell certain of our non-core assets, a portion of which were acquired in the Three Rivers Acquisition, for approximately $520 million, subject to customary closing adjustments. No assurances can be given that this divestment will close, which is dependent on numerous factors including, but not limited to, market conditions.

Contractual obligations.  Our contractual obligations include long-term debt, cash interest expense on debt, operating lease obligations, drilling commitments, employment agreements with officers, derivative liabilities and other obligations. Since December 31, 2011, the material changes in our contractual obligations included a $1.5 billion increase in outstanding long-term debt, a $665.1 million increase in cash interest expense on debt and a $117.0 million decrease in our net commodity derivative liability, which

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resulted in a net asset position. See Note I of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited)” for additional information regarding our long-term debt and “Item 3. Quantitative and Qualitative Disclosures About Market Risk” for information regarding the interest on our long-term debt and information on changes in the fair value of our open derivative obligations during the nine months ended September 30, 2012. 

Off-balance sheet arrangements.  Currently, we do not have any material off-balance sheet arrangements.

Capital resources.  Our primary sources of liquidity have been cash flows generated from operating activities (including the cash settlements received from (paid on) derivatives not designated as hedges presented in our investing activities) and financing provided by our credit facility. Based on current commodity prices and capital costs, we believe our 2012 planned capital expenditures, excluding the effects of acquisitions, will exceed our 2012 cash flow, and we expect to fund any such shortfall with borrowings under our credit facility. We believe that we have adequate availability under our credit facility to fund any cash flow deficits, though we could reduce our capital spending program to remain substantially within our cash flow.

The following table summarizes our net increase in cash and cash equivalents for the nine months ended September 30, 2012 and 2011:

		Nine Months Ended
		September 30,
(in thousands)		2012		2011
Net cash provided by operating activities ...............................................................................................................................		$	845,636	$	778,986
Net cash used in investing activities .........................................................................................................................................			(2,367,407)		(957,745)
Net cash provided by financing activities ...............................................................................................................................			1,521,720		178,549
	Net decrease in cash and cash equivalents ...................................................................................................................	$	(51)	$	(210)

Cash flow from operating activities. The increase in operating cash flows during the nine months ended September 30, 2012 over 2011 was principally due to increases in our oil and natural gas production as a result of (i) our exploration and development program and (ii) the acquisitions in 2011 and 2012; offset in part by the Bakken divestiture in 2011, decreases in average realized oil and natural gas prices and increases in oil and natural gas production costs and other operating costs.

Our net cash provided by operating activities also includes a reduction of $90.4million and $110.4million for the nine months ended September 30, 2012 and 2011, respectively, associated with changes in working capital items. Changes in working capital items adjust for the timing of receipts and payments of actual cash.

Cash flow used in investing activities. During the nine months ended September 30, 2012 and 2011, we invested $2.3 billion and $1.0 billion, respectively, for capital expenditures on oil and natural gas properties. Cash flows used in investing activities were higher during the nine months ended September 30, 2012 as compared to 2011, due to (i) an increase in our exploration and development expenditures and (ii) our PDC Acquisition and Three Rivers Acquisition in 2012.

Cash flow from financing activities.During the nine months ended September 30, 2012 and 2011 we completed the following significant activities:

·In August 2012, we issued $700 million in aggregate principal amount of 5.5% senior notes due 2023 at par, for which we received net proceeds of approximately $688.6 million. We used the net proceeds to repay a portion of the borrowings under our credit facility, which increased our liquidity for future activities.

·In May 2012, we amended our credit facility, increasing the aggregate lender commitments from $2.0 billion to $2.5 billion, equal to our then $2.5 billion borrowing base. We paid our bank group $2.2 million associated with the amendment to increase the commitments.

·In March 2012, we issued $600 million in aggregate principal amount of 5.5% senior notes due 2022 at par, for which we received net proceeds of approximately $590.0 million. We used the net proceeds to repay a portion of the borrowings under our credit facility, which increased our liquidity for future activities.

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·In May 2011, we issued $600 million in aggregate principal amount of 6.5% senior notes due 2022 at par, for which we received net proceeds of approximately $587.1 million. We used the net proceeds to repay a portion of the borrowings under our credit facility.

Our credit facility has a maturity date of April 25, 2016. Our borrowing base is $3.0 billion until the next scheduled borrowing base redetermination in April 2013, and commitments from our bank group total $2.5 billion. Between scheduled borrowing base redeterminations, the Company and the lenders (requiring a 66 2/3 percent vote), may each request one special redetermination. At September 30, 2012 our availability to borrow additional funds was approximately $1.7 billion based on bank commitments of $2.5 billion. 

Advances on our credit facility bear interest, at our option, based on (i) the prime rate of JPMorgan Chase Bank (“JPM Prime Rate”) (3.25 percent at September 30, 2012) or (ii) a Eurodollar rate (substantially equal to the London Interbank Offered Rate).  The credit facility’s interest rates of Eurodollar rate advances and JPM Prime Rate advances varied, with interest margins ranging from 150 to 250 basis points and 50 to 150 basis points, respectively, per annum depending on the debt balance outstanding. We pay commitment fees on the unused portion of the available commitment ranging from 37.5 to 50 basis points per annum, depending on utilization of the commitments.

In conducting our business, we may utilize various financing sources, including the issuance of (i) fixed and floating rate debt, (ii) convertible securities, (iii) preferred stock, (iv) common stock and (v) other securities. Over the last three years, we have demonstrated our use of the capital markets by issuing common stock in public offerings and private placements and issuing senior unsecured debt. However, there are no assurances that we can access the capital markets to obtain additional funding, if needed, and at what cost and terms. We may also sell assets and issue securities in exchange for oil and natural gas assets or interests in oil and natural gas companies.  Additional securities may be of a class senior to common stock with respect to such matters as dividends and liquidation rights and may also have other rights and preferences as determined from time to time by our board of directors. Utilization of some of these financing sources may require approval from the lenders under our credit facility.

Liquidity. Our principal sources of short-term liquidity are cash on hand and available borrowing capacity under our credit facility.  At September 30, 2012, we had $0.3million of cash on hand.

At September 30, 2012, the commitments under our credit facility were $2.5 billion, which provided us with approximately $1.7billion of available borrowing capacity. Upon a redetermination, our $3.0 billion borrowing base could be substantially reduced. There is no assurance that our borrowing base will not be reduced, which could affect our liquidity.

In November 2012, we entered into a definitive agreement to sell certain of our non-core assets, a portion of which were acquired in the Three Rivers Acquisition, for approximately $520 million, subject to customary closing adjustments.  No assurances can be given that we will complete this divestment, which is dependent on numerous factors including, but not limited to, market conditions. Proceeds from the divestment will be used to reduce borrowings under our credit facility, which would increase our availability under the credit facility. If complete, this divestment would have no effect on our current commitments or borrowing base under our credit facility.

Debt ratings. We receive debt credit ratings from Standard & Poor’s Ratings Group, Inc. (“S&P”) and Moody’s Investors Service, Inc. (“Moody’s”), which are subject to regular reviews. S&P’s corporate rating for us is “BB+” with a stable outlook. Moody’s corporate rating for us is “Ba3” with a stable outlook. S&P and Moody’s consider many factors in determining our ratings including: production growth opportunities, liquidity, debt levels and asset and reserve mix. A reduction in our debt ratings could negatively affect our ability to obtain additional financing or the interest rate, fees and other terms associated with such additional financing.

Book capitalization and current ratio.  Our book capitalization at September 30, 2012 was $7.0billion, consisting of debt of $3.6 billion and stockholders’ equity of $3.4 billion. Our debt to book capitalization was 52percent and 41percent at September 30, 2012 and December 31, 2011, respectively. Our ratio of current assets to current liabilities was 0.71to 1.0 at September 30, 2012 as compared to 0.59 to 1.0 at December 31, 2011.

Inflation and changes in prices.  Our revenues, the value of our assets, and our ability to obtain bank financing or additional capital on attractive terms have been and will continue to be affected by changes in commodity prices and the costs to produce our reserves. Commodity prices are subject to significant fluctuations that are beyond our ability to control or predict. During the nine months ended September 30, 2012, we received an average of $90.56per barrel of oil and $5.03per Mcf of natural gas before consideration of commodity derivative contracts compared to $91.21per barrel of oil and $7.80per Mcf of natural gas in the nine months ended September 30, 2011. Although certain of our costs are affected by general inflation, inflation does not normally have a significant effect on our business. In a trend that began in 2004, and that has continued until recently, oil prices have increased

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significantly. The higher oil price led to increased activity in the industry and, consequently, rising costs. These cost trends have put pressure not only on our operating costs, but also on capital costs. Although we have seen a decrease in commodity prices, the cost trends have not followed proportionally.

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Critical Accounting Policies, Practices and Estimates

Our historical consolidated financial statements and related notes to consolidated financial statements contain information that is pertinent to our management’s discussion and analysis of financial condition and results of operations. Preparation of financial statements in conformity with accounting principles generally accepted in the United States requires that our management make estimates, judgments and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. However, the accounting principles used by us generally do not change our reported cash flows or liquidity. Interpretation of the existing rules must be done and judgments made on how the specifics of a given rule apply to us. 

In management’s opinion, the more significant reporting areas impacted by management’s judgments and estimates are revenue recognition, the choice of accounting method for oil and natural gas activities, oil and natural gas reserve estimation, asset retirement obligations, impairment of long-lived assets, valuation of stock-based compensation, valuation of business combinations and valuation of financial derivative instruments. Management’s judgments and estimates in these areas are based on information available from both internal and external sources, including engineers, geologists and historical experience in similar matters. Actual results could differ from the estimates, as additional information becomes known.

There have been no material changes in our critical accounting policies and procedures during the nine months ended September 30, 2012. See our disclosure of critical accounting policies in “Item 8. Financial Statements and Supplementary Data” of our Annual Report on Form 10-K for the year ended December 31, 2011, filed with the United States Securities and Exchange Commission (the “SEC”) on February 24, 2012.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

The following market risk disclosures should be read in conjunction with the quantitative and qualitative disclosures about market risk contained in our Annual Report on Form 10-K for the year ended December 31, 2011.

We are exposed to a variety of market risks including credit risk, commodity price risk and interest rate risk. We address these risks through a program of risk management which includes the use of derivative instruments. The following quantitative and qualitative information is provided about financial instruments to which we are a party at September 30, 2012, and from which we may incur future gains or losses from changes in market interest rates or commodity prices and losses from extension of credit.  We do not enter into derivative or other financial instruments for speculative or trading purposes.

Hypothetical changes in interest rates and commodity prices chosen for the following estimated sensitivity analysis are considered to be reasonably possible near-term changes generally based on consideration of past fluctuations for each risk category. However, since it is not possible to accurately predict future changes in interest rates and commodity prices, these hypothetical changes may not necessarily be an indicator of probable future fluctuations.

Credit risk.We monitor our risk of loss due to non-performance by counterparties of their contractual obligations. Our principal exposure to credit risk is through the sale of our oil and natural gas production, which we market to energy marketing companies and refineries and to a lesser extent our derivative counterparties. We monitor our exposure to these counterparties primarily by reviewing credit ratings, financial statements and payment history. We extend credit terms based on our evaluation of each counterparty’s creditworthiness. Although we have not generally required our counterparties to provide collateral to support their obligation to us, we may, if circumstances dictate, require collateral in the future. In this manner, we reduce credit risk.

We have entered into International Swap Dealers Association Master Agreements (“ISDA Agreements”) with each of our derivative counterparties. The terms of the ISDA Agreements provide us and the counterparties with rights of set off upon the occurrence of defined acts of default by either us or a counterparty to a derivative, whereby the party not in default may set off all derivative liabilities owed to the defaulting party against all derivative asset receivables from the defaulting party. See Note H of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited)” for additional information regarding our derivative activities.

We are closely monitoring the European debt crisis, which could negatively impact the U.S. debt markets. If further deterioration occurs, it could impair our ability to raise debt, access our credit facility and collect hedging proceeds from our derivative counterparties.

Commodity price risk. We are exposed to market risk as the prices of oil and natural gas are subject to fluctuations resulting from changes in supply and demand. To reduce our exposure to changes in the prices of oil and natural gas we have entered into, and may in the future enter into additional, commodity price risk management arrangements for a portion of our oil and natural gas production. The agreements that we have entered into generally have the effect of providing us with a fixed price for a portion of our expected future oil and natural gas production over a fixed period of time. Our commodity price risk management activities could have the effect of reducing net income and the value of our securities. An average increase in the commodity price of $10.00 per barrel of oil and $1.00 per MMBtu for natural gas from the commodity prices at September 30, 2012, would have resulted in a net unrealized loss on our commodity price risk management contracts of approximately $235.2 million. 

At September 30, 2012, we had (i) oil price swaps that settle on a monthly basis covering future oil production from October 1, 2012 through June 30, 2017 and (ii) natural gas price swaps, natural gas price collars and natural gas basis swaps covering future natural gas production from October 1, 2012 to December 31, 2012. See Note H of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited)” for additional information on our commodity derivative instruments. The average NYMEX oil price and average NYMEX natural gas prices for the nine months ended September 30, 2012, was $96.21 per Bbl and $2.59 per MMBtu, respectively. At November 5, 2012, the NYMEX oil price and NYMEX natural gas price were $85.65 per Bbl and $3.55 per MMBtu, respectively. A decrease in the average NYMEX oil and natural gas prices below those at September 30, 2012, would increase the fair value asset of our commodity derivative contracts from their recorded

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balance at September 30, 2012. Changes in the recorded fair value of the undesignated commodity derivative contracts are marked to market through earnings as unrealized gains or losses. The potential increase in our fair value asset would be recorded in earnings as an unrealized gain. However, an increase in the average NYMEX oil and natural gas prices above those at September 30, 2012, would decrease the fair value asset of our commodity derivative contracts from their recorded balance at September 30, 2012. The potential decrease in our fair value asset would be recorded in earnings as an unrealized loss. We are currently unable to estimate the effects on the earnings of future periods resulting from changes in the market value of our commodity derivative contracts.

Interest rate risk. Our exposure to changes in interest rates relates primarily to debt obligations. We manage our interest rate exposure by limiting our variable-rate debt to a certain percentage of total capitalization and by monitoring the effects of market changes in interest rates. To reduce our exposure to changes in interest rates we have in the past entered into, and may in the future enter into additional, interest rate risk management arrangements for a portion of our outstanding debt. The agreements that we have entered into generally have the effect of providing us with a fixed interest rate for a portion of our variable rate debt. We may utilize interest rate derivatives to alter interest rate exposure in an attempt to reduce interest rate expense related to existing debt issues. Interest rate derivatives are used solely to modify interest rate exposure and not to modify the overall leverage of the debt portfolio. We are exposed to changes in interest rates as a result of our credit facility, and the terms of our credit facility require us to pay higher interest rate margins as we utilize a larger percentage of our available commitments.

We had total indebtedness of $804.0 million outstanding under our credit facility at September 30, 2012. The impact of a 1 percent increase in interest rates on this amount of debt would result in increased annual interest expense of approximately $8.0 million.

The fair value of our derivative instruments is determined based on our valuation models. We did not change our valuation method during the nine months ended September 30, 2012. During the nine months ended September 30, 2012, we were party to commodity derivative instruments. See Note H of the Condensed Notes to Consolidated Financial Statements included in “Item 1. Consolidated Financial Statements (Unaudited)” for additional information regarding our derivative instruments.  The following table reconciles the changes that occurred in the fair values of our derivative instruments during the nine months ended September 30, 2012:

		Commodity Derivative
		Instruments
(in thousands)		Net Assets (Liabilities) (a)
Fair value of contracts outstanding at December 31, 2011 ....................................................................................................................................			$	(78,830)
	Changes in fair values (b) ......................................................................................................................................................................................			109,542
	Contract maturities .................................................................................................................................................................................................			7,485
Fair value of contracts outstanding at September 30, 2012 ...................................................................................................................................			$	38,197
(a)	Represents the fair values of open derivative contracts subject to market risk.
(b)	At inception, new derivative contracts entered into by us have no intrinsic value.

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Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures. As required by Rule 13a-15(b) of the Exchange Act, we have evaluated, under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon the evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective at September 30, 2012 at the reasonable assurance level.

Changes in Internal Control over Financial Reporting. There have been no changes in our internal controls over financial reporting (as defined in Rule 13a-15(f) under the Exchange Act) that occurred during our last fiscal quarter that have materially affected or are reasonably likely to materially affect our internal controls over financial reporting.

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PART II – OTHER INFORMATION

Item 1.  Legal Proceedings

We are a party to proceedings and claims incidental to our business. While many of these other matters involve inherent uncertainty, we believe that the liability, if any, ultimately incurred with respect to such other proceedings and claims will not have a material adverse effect on our consolidated financial position as a whole or on our liquidity, capital resources or future results of operations. We will continue to evaluate proceedings and claims involving us on a regular basis and will establish and adjust any reserves as appropriate to reflect our assessment of the then current status of the matters.

Item 1A.  Risk Factors

In addition to the other information set forth in this Quarterly Report on Form 10-Q, you should carefully consider the risks discussed in our Annual Report on Form 10-K for the year ended December 31, 2011, under the headings “Item 1. Business – Competition,” “— Marketing Arrangements” and “— Applicable Laws and Regulations,” “Item 1A. Risk Factors,” “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” and “Item 7A. Quantitative and Qualitative Disclosures About Market Risk,” which risks could materially affect our business, financial condition or future results. There have been no material changes in our risk factors from those described in our Annual Report on Form 10-K for the year ended December 31, 2011.  The risks described in this Quarterly Report on Form 10-Q and in our Annual Report on Form 10-K are not the only risks facing our company. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Period		Total number of shares withheld (a)	Average price per share		Total number of shares purchased as part of publicly announced plans	Maximum number of shares that may yet be purchased under the plan
July 1, 2012 - July 31, 2012 ....................................................................................................................................................................		529	$	85.09	-
August 1, 2012 - August 31, 2012 .........................................................................................................................................................		621	$	86.78	-
September 1, 2012 - September 30, 2012 ............................................................................................................................................		600	$	94.33	-
(a)	Represents shares that were withheld by us to satisfy tax withholding obligations of certain of our officers and key employees
	that arose upon the lapse of restrictions on restricted stock.

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Item 6.  Exhibits

Exhibit  Number	Exhibit
3.1	Restated Certificate of Incorporation (filed as Exhibit 3.1 to the Company’s Current Report on Form 8-K on August 8, 2007, and incorporated herein by reference).
3.2	Amended and Restated Bylaws of Concho Resources Inc., as amended November 7, 2012 (filed as Exhibit 3.1 to the Company’s Current Report on Form 8-K on November 8, 2012, and incorporated herein by reference).
4.1	Specimen Common Stock Certificate (filed as Exhibit 4.1 to the Company’s Registration Statement on Form S-1/A on July 5, 2007, and incorporated herein by reference).
4.2	Seventh Supplemental Indenture, dated August 17, 2012, between Concho Resources Inc., the subsidiary guarantors named therein, and Wells Fargo Bank, National Association, as trustee (filed as Exhibit 4.1 to the Company’s Current Report on Form 8-K on August 17, 2012, and incorporated herein by reference).
4.3	Form of 5.5% Senior Notes due 2023 (included in Exhibit 4.1 to the Company’s Current Report on Form 8-K on August 17, 2012, and incorporated herein by reference).
10.1	Tenth Amendment to Amended and Restated Credit Agreement, dated as of October 26, 2012, among Concho Resources Inc., the lenders party thereto and JPMorgan Chase Bank, N.A., as administrative agent (filed as Exhibit 10.1 to the Company’s Current Report on Form 8-K on October 29, 2012, and incorporated herein by reference).
31.1 (a)	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2 (a)	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1 (b)	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2 (b)	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS (a)	XBRL Instance Document.
101.SCH (a)	XBRL Schema Document.
101.CAL (a)	XBRL Calculation Linkbase Document.
101.DEF (a)	XBRL Definition Linkbase Document.
101.LAB (a)	XBRL Labels Linkbase Document.
101.PRE (a)	XBRL Presentation Linkbase Document.

(a)  Filed herewith.

(b)  Furnished herewith.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

CONCHO RESOURCES INC.
Date:	November 8, 2012	By	/s/  Timothy A. Leach
			Timothy A. Leach
			Director, Chairman of the Board of Directors, Chief Executive
			Officer and President (Principal Executive Officer)
		By	/s/  Darin G. Holderness
			Darin G. Holderness
			Senior Vice President and Chief Financial Officer
			(Principal Financial and Accounting Officer)

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EXHIBIT INDEX

Exhibit  Number	Exhibit
3.1	Restated Certificate of Incorporation (filed as Exhibit 3.1 to the Company’s Current Report on Form 8-K on August 8, 2007, and incorporated herein by reference).
3.2	Amended and Restated Bylaws of Concho Resources Inc., as amended November 7, 2012 (filed as Exhibit 3.1 to the Company’s Current Report on Form 8-K on November 8, 2012, and incorporated herein by reference).
4.1	Specimen Common Stock Certificate (filed as Exhibit 4.1 to the Company’s Registration Statement on Form S-1/A on July 5, 2007, and incorporated herein by reference).
4.2	Seventh Supplemental Indenture, dated August 17, 2012, between Concho Resources Inc., the subsidiary guarantors named therein, and Wells Fargo Bank, National Association, as trustee (filed as Exhibit 4.1 to the Company’s Current Report on Form 8-K on August 17, 2012, and incorporated herein by reference).
4.3	Form of 5.5% Senior Notes due 2023 (included in Exhibit 4.1 to the Company’s Current Report on Form 8-K on August 17, 2012, and incorporated herein by reference).
10.1	Tenth Amendment to Amended and Restated Credit Agreement, dated as of October 26, 2012, among Concho Resources Inc., the lenders party thereto and JPMorgan Chase Bank, N.A., as administrative agent (filed as Exhibit 10.1 to the Company’s Current Report on Form 8-K on October 29, 2012, and incorporated herein by reference).
31.1 (a)	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2 (a)	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1 (b)	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2 (b)	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS (a)	XBRL Instance Document.
101.SCH (a)	XBRL Schema Document.
101.CAL (a)	XBRL Calculation Linkbase Document.
101.DEF (a)	XBRL Definition Linkbase Document.
101.LAB (a)	XBRL Labels Linkbase Document.
101.PRE (a)	XBRL Presentation Linkbase Document.

(a)  Filed herewith.

(b)  Furnished herewith.

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EXHIBIT 31.1

CERTIFICATIONS

I, Timothy A. Leach, certify that:

1.I have reviewed this quarterly report of Concho Resources Inc. (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 8, 2012	/s/  Timothy A. Leach
		Timothy A. Leach
		Director, Chairman of the Board of Directors, Chief Executive Officer
		and President (Principal Executive Officer)

EXHIBIT 31.2

CERTIFICATIONS

I, Darin G. Holderness, certify that:

1.I have reviewed this quarterly report of Concho Resources Inc. (the “registrant”);

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting.

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:	November 8, 2012	/s/  Darin G. Holderness
		Darin G. Holderness
		Senior Vice President and Chief Financial Officer
		(Principal Financial and Accounting Officer)

                        EXHIBIT 32.1

Certification of Chief Executive Officer of Concho Resources Inc.

(Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002)

In connection with the quarterly report of Concho Resources Inc. (the “Company”), as filed with the Securities and Exchange Commission on the date hereof (the “Report”), Timothy A. Leach, Chief Executive Officer of the Company, hereby certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to his knowledge:

(1)the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	November 8, 2012	/s/  Timothy A. Leach
		Timothy A. Leach
		Director, Chairman of the Board of Directors, Chief Executive Officer
		and President (Principal Executive Officer)

EXHIBIT 32.2

Certification of Chief Financial Officer of Concho Resources Inc.

(Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002)

In connection with the quarterly report of Concho Resources Inc. (the “Company”), as filed with the Securities and Exchange Commission on the date hereof (the “Report”), Darin G. Holderness, Chief Financial Officer of the Company, hereby certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to his knowledge:

(1)the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2)the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	November 8, 2012	/s/  Darin G. Holderness
		Darin G. Holderness
		Senior Vice President and Chief Financial Officer
		(Principal Financial and Accounting Officer)