Investor News

12.22.11 Concho Resources Inc. Acquires Permian Basin Properties

MIDLAND, Texas--(BUSINESS WIRE)--Dec. 22, 2011-- Concho Resources Inc. (NYSE: CXO) ("Concho" or the "Company") today announced that it has entered into a definitive agreement to acquire operated interests in certain producing and non-producing assets in the Wolfberry trend in the Permian Basin (the “Acquisition”) from Petroleum Development Corporation (NASDAQ: PETD) for approximately $175 million, subject to customary purchase price adjustments. The Acquisition adds approximately 10,800 gross (10,200 net) acres located in Andrews, Ector and Midland Counties, Texas.

Highlights of the Acquisition:

  • Adds over 170 identified Wolfberry drilling locations through 40-acre spacing
  • Estimated proved reserves of approximately 13 million barrels of oil equivalent (“MMBoe”) as of November 1, 2011
  • Current net production of approximately 1,100 barrels of oil equivalent per day (“Boepd”)
  • Increases the Company’s net acreage in the Wolfberry by 20% and raises the Company’s average working interest in the Wolfberry to 54% from 50%

In connection with the Acquisition, the Company will increase its 2012 capital budget from $1.30 billion to $1.37 billion to develop the newly acquired assets. In addition, the Company currently estimates that its 2012 production will total between 27.5 MMBoe and 28.5 MMBoe, an increase of approximately 0.5 MMBoe due to the Acquisition. The Company estimates that its updated 2012 capital budget can be substantially funded out of its after-tax cash flow assuming (i) a NYMEX crude oil price of $85 per barrel and a NYMEX natural gas price of $4 per thousand cubic feet of natural gas for the Company's unhedged production and (ii) that the Company achieves the mid-point of its 2012 production guidance.

The Acquisition, which is expected to close in the first quarter of 2012, will be funded with borrowings under the Company’s credit facility.

About Concho Resources Inc.

Concho Resources Inc. is an independent oil and natural gas company engaged in the acquisition, development and exploration of oil and natural gas properties. The Company's operations are focused in the Permian Basin of Southeast New Mexico and West Texas. For more information, visit Concho's website at www.concho.com.

Forward-Looking Statements and Cautionary Statements

The foregoing contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release specifically include statements, estimates and projections regarding the Acquisition, the Company's future production and 2012 capital budget, oil and natural gas reserves and number of identified drilling locations. These statements are based on certain assumptions made by the Company based on management's experience, expectations and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. Forward-looking statements are not guarantees of performance. Although the Company believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. Moreover, such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. These include the factors discussed or referenced in the "Risk Factors" section of the Company's most recent Form 10-K and 10-Q filings and risks relating to declines in the prices we receive for our oil and natural gas; uncertainties about the estimated quantities of reserves; risks related to the integration of the acquired assets; the effects of government regulation, permitting and other legal requirements, including new legislation or regulation of hydraulic fracturing; drilling and operating risks; the adequacy of our capital resources and liquidity; risks related to the concentration of our operations in the Permian Basin; the results of our hedging program; weather; litigation; shortages of oilfield equipment, services and qualified personnel and increases in costs for such equipment, services and personnel; uncertainties about our ability to replace reserves and economically develop our current reserves; competition in the oil and natural gas industry; our existing indebtedness; and other important factors that could cause actual results to differ materially from those projected.

Any forward-looking statement speaks only as of the date on which such statement is made, and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.

Source: Concho Resources Inc.

Concho Resources Inc.
Price Moncrief, 432-683-7443
Director, Corporate Development

12.16.11 Concho Resources Inc. Announces Participation in Upcoming Conference

MIDLAND, Texas--(BUSINESS WIRE)--Dec. 16, 2011-- Concho Resources Inc. (NYSE: CXO) (the "Company") today announced its participation at the Goldman Sachs Global Energy Conference 2012 on Tuesday, January 10th at 1:30 PM ET. The presentation will be available on Concho's website, www.concho.com.

About Concho Resources Inc.

Concho Resources Inc. is an independent oil and natural gas company engaged in the acquisition, development and exploration of oil and natural gas properties. The Company's operations are focused in the Permian Basin of Southeast New Mexico and West Texas. For more information, visit Concho’s website at www.concho.com.

Source: Concho Resources Inc.

Concho Resources Inc.
Toffee McAlister, 432-683-7443
Director, Investor Relations & Corporate Communications

11.02.11 Concho Resources Inc. Reports Third Quarter 2011 Financial and Operating Results and Provides 2012 Capital Budget Detail and Guidance

MIDLAND, Texas, Nov 02, 2011 (BUSINESS WIRE) --

Concho Resources Inc. (NYSE: CXO) ("Concho" or the "Company") today reported financial and operating results for the three and nine months ended September 30, 2011. Highlights for the three months ended September 30, 2011 include:

  • Production of 6.3 million barrels of oil equivalent ("MMBoe") for the third quarter of 2011, an increase of 73% over the third quarter of 2010 and a 13% increase over the second quarter of 2011
  • Net income of $356.2 million, or $3.44 per diluted share, for the third quarter of 2011, as compared to net income of $20.8 million, or $0.22 per diluted share, in the third quarter of 2010
  • Adjusted net income1 (non-GAAP) of $117.8 million, or $1.14 per diluted share, for the third quarter of 2011, as compared to $71.4 million, or $0.77 per diluted share, for the third quarter of 2010
  • EBITDAX2 (non-GAAP) of $349.6 million for the third quarter of 2011, an increase of 90% over the third quarter of 2010

1 Adjusted net income (non-GAAP) is comparable to securities analyst estimates. For an explanation of how we calculate adjusted net income (non-GAAP) and a reconciliation of net income (GAAP) to adjusted net income (non-GAAP), please see "Supplemental Non-GAAP Financial Measures" below.

2 For an explanation of how we calculate and use EBITDAX (non-GAAP) and a reconciliation of net income (GAAP) to EBITDAX (non-GAAP), please see "Supplemental Non-GAAP Financial Measures" below.

Third Quarter 2011 Financial Results

Production for the third quarter of 2011 totaled 6.3 MMBoe (3.9 million barrels of oil ("MMBbls") and 14.7 billion cubic feet of natural gas ("Bcf")), an increase of 73% as compared to 3.6 MMBoe (2.5 MMBbls and 7.1 Bcf) produced in the third quarter of 2010 from continuing operations. The increase in production is due in part to the Marbob acquisition in the fourth quarter of 2010 and the Company's successful 2010 and 2011 drilling program.

Timothy A. Leach, Concho's Chairman, CEO and President, commented, "Our third quarter results reflect outstanding execution by the entire Concho organization. Our team achieved record levels of production and cash flows while finishing the quarter in excellent financial position with a healthy balance sheet and significant liquidity. Looking forward to 2012, we expect to continue our trend of delivering substantial organic production growth while spending within cash flow and focusing on rate-of-return. We will allocate a greater proportion of our 2012 drilling budget to our Delaware Basin Bone Spring play, where we are expanding and testing the multiple horizons across our acreage. With our recent expansion efforts in the Delaware Basin Bone Spring play, I believe that we have assembled a premier acreage position that will enhance our future growth. Looking to the fourth quarter, we remain on track to meet our goals for 2011 and expect the momentum from our operational success to carry into 2012."

For the third quarter of 2011, the Company reported net income of $356.2 million, or $3.44 per diluted share, as compared to net income of $20.8 million, or $0.22 per diluted share, for the third quarter of 2010. The Company's third quarter 2011 results were impacted by several non-cash items, including a $387.0 million unrealized mark-to-market gain on commodity derivatives and $0.6 million of leasehold abandonments. Excluding these items and their tax effects, the third quarter 2011 adjusted net income (non-GAAP) was $117.8 million, or $1.14 per diluted share. Excluding these similar items and an impairment of long-lived assets recorded in the third quarter of 2010, our adjusted net income (non-GAAP) for the third quarter of 2010 was $71.4 million, or $0.77 per diluted share. For a reconciliation of net income (GAAP) to adjusted net income (non-GAAP), please see "Supplemental Non-GAAP Financial Measures" below.

EBITDAX (defined as net income, plus (1) exploration and abandonments expense, (2) depreciation, depletion and amortization expense, (3) accretion expense, (4) impairments of long-lived assets, (5) non-cash stock-based compensation expense, (6) bad debt expense, (7) unrealized (gain) loss on derivatives not designated as hedges, (8) (gain) loss on sale of assets, net, (9) interest expense, (10) federal and state income taxes, and (11) similar items listed above that are presented in discontinued operations) increased to $349.6 million in the third quarter of 2011, as compared to $184.3 million in the third quarter of 2010. For a reconciliation of net income (GAAP) to EBITDAX (non-GAAP), please see "Supplemental Non-GAAP Financial Measures" below.

Operating revenues for the third quarter of 2011 increased 101% when compared to the third quarter of 2010. This increase is attributable to the 73% increase in production, the 19% increase in the Company's unhedged realized oil price and the 22% increase in the Company's unhedged realized natural gas price in the third quarter of 2011 compared to the same period in 2010.

Oil and natural gas production expense for the third quarter of 2011, including taxes, totaled $84.1 million, or $13.32 per Boe, a 16% increase per Boe over the third quarter of 2010. This increase was primarily due to higher lease operating expenses and workover costs, in part due to higher third-party labor costs and a prior period underestimate of costs.

Depreciation, depletion and amortization for the third quarter of 2011 totaled $115.7 million, or $18.34 per Boe, a 16% increase per Boe from $57.6 million, or $15.82 per Boe, in the third quarter of 2010. The increase in depletion expense was primarily due to capitalized costs associated with new wells that were successfully drilled and completed in 2010 and 2011 and the Marbob acquisition.

General and administrative expense ("G&A") for the third quarter of 2011 totaled $22.9 million, or $3.62 per Boe, compared to $15.3 million, or $4.20 per Boe, in the third quarter of 2010. The decrease in per Boe expense in the third quarter of 2011 over the third quarter of 2010 was primarily due to increased production, offset by a 50% increase in absolute G&A costs due in part to increased staffing across the Company and the addition of employees from the Marbob acquisition.

The Company's cash flows from operating activities (GAAP) for the nine months ended September 30, 2011 was $779.0 million, as compared to $402.8 million for the nine months ended September 30, 2010, an increase of 93%. Adjusted cash flows (non-GAAP), which are cash flows from operating activities adjusted for settlements paid on derivatives not designated as hedges, was $701.2 million for the nine months ended September 30, 2011, as compared to $397.5 million for the nine months ended September 30, 2010, an increase of 76%. For a description of the use of adjusted cash flows (non-GAAP) and for a reconciliation of cash flows from operating activities (GAAP) to adjusted cash flows (non-GAAP), please see "Supplemental Non-GAAP Financial Measures" below.

In the third quarter of 2011, the Company made net cash payments for settlements on derivatives contracts not designated as hedges of $1.8 million and the non-cash unrealized mark-to-market gain for the derivatives contracts not designated as hedges was $387.0 million. This is compared to net cash receipts of $4.1 million on derivatives contracts not designated as hedges and a $70.2 million non-cash unrealized mark-to-market loss on contracts not designated as hedges in the third quarter of 2010. To better understand the impact of the Company's derivatives positions and their impact on the statement of operations, please see the "Summary Production and Operating Data" and "Derivatives Information" tables at the end of this press release.

Operations

For the quarter ended September 30, 2011, the Company commenced the drilling of or participated in a total of 223 gross wells (194 operated), 69 of which had been completed as producers and 154 of which were in progress at September 30, 2011. In addition, during the third quarter of 2011, the Company completed 170 wells that were drilled prior to the third quarter of 2011. Currently, the Company is operating 30 drilling rigs in the Permian Basin; 10 of these rigs are drilling Yeso wells in the New Mexico Shelf, 13 are drilling Wolfberry wells in the Texas Permian, 6 are drilling in the Delaware Basin Bone Spring play and 1 rig is drilling Lower Abo wells in the New Mexico Shelf.

New Mexico Shelf

During the third quarter of 2011, the Company drilled 122 wells (105 operated) on its New Mexico Shelf assets, which included both Yeso and Lower Abo wells, with a 100% success rate on the 55 wells that had been completed by September 30, 2011. In addition, during the third quarter of 2011, the Company completed 71 wells that were drilled prior to the third quarter of 2011.

Texas Permian

During the third quarter of 2011, the Company drilled 77 wells (74 operated) on its Texas Permian assets with a 100% success rate on the 12 wells that had been completed by September 30, 2011. In addition, during the third quarter of 2011, the Company completed 77 wells that were drilled prior to the third quarter of 2011.

Delaware Basin

During the third quarter of 2011, the Company drilled 24 wells (15 operated) on its Delaware Basin assets with a 100% success rate on the 2 wells that had been completed by September 30, 2011. In addition, during the third quarter of 2011, the Company completed 22 wells that were drilled prior to the third quarter of 2011. The Company's net production in the third quarter of 2011 from the Bone Spring play, which includes the Avalon shale, the Bone Spring sands and the Wolfcamp shale, averaged approximately 8,900 Boepd, an increase of 59% over the second quarter of 2011.

2012 Capital Budget

Concho's capital budget for 2012 is approximately $1.3 billion, which the Company believes will yield production in the range of 27.0 - 28.0 MMBoe. This budget contemplates operating an average of 35 drilling rigs for 2012. The Company estimates that its 2012 capital budget can be funded entirely out of its after-tax cash flow assuming (i) a NYMEX crude oil price of $85 per barrel and a NYMEX natural gas price of $4 per thousand cubic feet of natural gas ("Mcf") for the Company's unhedged production and (ii) that the Company achieves the mid-point of its 2012 production guidance. The Company intends to monitor both the direction of commodity prices and the costs of goods and services and may adjust its capital budget, and resultant estimated production and cash flows, as conditions warrant.

Of the approximately $1.1 billion dedicated to the Company's core areas, approximately $500 million will be dedicated to drilling and recompletion projects on its New Mexico Shelf assets (primarily in the Yeso and Lower Abo plays), approximately $375 million will be dedicated to drilling projects on its Delaware Basin assets (primarily in the Bone Spring play) and approximately $260 million will be dedicated to drilling and recompletion projects on its Texas Permian assets (primarily in the Wolfberry play). The Company expects to drill or participate in a total of 850 gross wells (700 operated), which includes 359 Yeso wells, 13 Lower Abo wells, 113 Bone Spring play wells and 309 Wolfberry wells. The remaining $160 million of capital will be allocated between leasehold acquisition, geological and geophysical ("G&G"), exploratory costs and other ($110 million) and facilities ($50 million).

2012 Guidance




Production:

Oil equivalent (MMBoe)
27.0 - 28.0
Oil (MMBbls)
17.3 - 17.9
Natural gas (Bcf)
58.3 - 60.5



Price differentials to NYMEX:

(excluding the effects of hedging)

Oil (Bbl)
93% - 95%
Natural gas (Mcf)
140% - 160%



Operating costs and expenses:

Lease operating expense:

Direct lease operating expense ($/Boe)
$6.40 - $6.80
Oil & natural gas taxes (% of oil and natural gas revenue)
8.25%



G&A expense:

Cash G&A expense ($/Boe)
$3.25 - $3.50
Non-cash stock based compensation ($/Boe)
$0.80 - $0.90



DD&A expense ($/Boe)
$18.00 - $19.00



Exploration, abandonments and G&G ($/Boe)
$0.50 - $1.50



Cash interest rates:

$300 million senior notes due 2017
8.625%
$600 million senior notes due 2021
7.000%
$600 million senior notes due 2022
6.500%
Remainder of debt
LIBOR + (150 - 250 bps)



Income taxes:
38%
Percent deferred of total taxes
80% - 90%



Capital expenditures ($ in billions)
$1.3



Liquidity Update

Lenders under Concho's revolving credit facility recently completed their semi-annual redetermination of the borrowing base, voting unanimously to reaffirm the $2.5 billion borrowing base and aggregate commitment of $2.0 billion. At September 30, 2011, Concho had $293.0 million outstanding on the credit facility.

Derivative Update

The Company maintains an active hedging program and continued to add to its derivative positions through October 2011. Please see the "Derivatives Information" tables at the end of this press release for more detailed information about the Company's current derivative positions.

Conference Call Information

The Company will host a conference call on Thursday, November 3, 2011 at 9:00 a.m. Central Time to discuss the third quarter 2011 financial and operating results and the 2012 capital budget and guidance. Interested parties may listen to the conference call via the Company's website at http://www.concho.com or by dialing (800) 659-2032 (passcode: 39505486). A replay of the conference call will be available on the Company's website or by dialing (888) 286-8010 (passcode: 60178210).

About Concho Resources Inc.

Concho Resources Inc. is an independent oil and natural gas company engaged in the acquisition, development and exploration of oil and natural gas properties. The Company's operations are focused in the Permian Basin of Southeast New Mexico and West Texas. For more information, visit Concho's website at www.concho.com.

Forward-Looking Statements and Cautionary Statements

The foregoing contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release specifically include statements, estimates and projections regarding the Company's future financial position, liquidity and capital resources, operations, performance, production growth, acquisitions, returns, capital expenditure budgets, oil and natural gas reserves, number of identified drilling locations, drilling program, derivative activities, costs and other guidance included in this press release. These statements are based on certain assumptions made by the Company based on management's experience, expectations and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. Forward-looking statements are not guarantees of performance. Although the Company believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. Moreover, such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. These include the factors discussed or referenced in the "Risk Factors" section of the Company's most recent Form 10-K and 10-Q filings and risks relating to declines in the prices we receive for our oil and natural gas; uncertainties about the estimated quantities of reserves; risks related to the integration of acquired assets; the effects of government regulation, permitting and other legal requirements, including new legislation or regulation of hydraulic fracturing; drilling and operating risks; the adequacy of our capital resources and liquidity; risks related to the concentration of our operations in the Permian Basin; the results of our hedging program; weather; litigation; shortages of oilfield equipment, services and qualified personnel and increases in costs for such equipment, services and personnel; uncertainties about our ability to replace reserves and economically develop our current reserves; competition in the oil and natural gas industry; our existing indebtedness; and other important factors that could cause actual results to differ materially from those projected.

Any forward-looking statement speaks only as of the date on which such statement is made, and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.



Concho Resources Inc.
Consolidated Balance Sheets
Unaudited







September 30,
December 31,
(in thousands, except share and per share data)

2011


2010
Assets
Current assets:



Cash and cash equivalents
$ 174

$ 384
Accounts receivable, net of allowance for doubtful accounts:



Oil and natural gas

216,832


136,471
Joint operations and other

168,935


131,912
Related parties

103


169
Derivative instruments

145,671


6,855
Deferred income taxes

-


42,716
Prepaid costs and other

15,381


12,126
Total current assets

547,096


330,633
Property and equipment:



Oil and natural gas properties, successful efforts method

6,687,087


5,616,249
Accumulated depletion and depreciation

(995,261 )

(730,509 )
Total oil and natural gas properties, net

5,691,826


4,885,740
Other property and equipment, net

53,791


28,047
Total property and equipment, net

5,745,617


4,913,787
Deferred loan costs, net

68,297


52,828
Intangible asset - operating rights, net

33,811


34,973
Inventory

26,349


28,342
Noncurrent derivative instruments

90,752


2,233
Other assets

10,864


5,698
Total assets
$ 6,522,786

$ 5,368,494
Liabilities and Stockholders' Equity
Current liabilities:



Accounts payable:



Trade
$ 6,781

$ 39,943
Related parties

25


1,197
Other current liabilities:



Bank overdrafts

56,892


12,314
Revenue payable

143,605


57,406
Accrued and prepaid drilling costs

291,151


215,079
Derivative instruments

1,960


97,775
Deferred income taxes

52,521


-
Other current liabilities

108,751


83,275
Total current liabilities

661,686


506,989
Long-term debt

1,789,532


1,668,521
Deferred income taxes

972,346


720,889
Noncurrent derivative instruments

-


51,647
Asset retirement obligations and other long-term liabilities

41,583


36,574
Commitments and contingencies



Stockholders' equity:



Common stock, $0.001 par value; 300,000,000 authorized; 103,724,471 and 102,842,082



shares issued at September 30, 2011 and December 31, 2010, respectively

104


103
Additional paid-in capital

1,919,397


1,874,649
Retained earnings

1,141,699


510,737
Treasury stock, at cost; 51,499 and 31,963 shares at September 30, 2011 and December 31, 2010,



respectively

(3,561 )

(1,615 )
Total stockholders' equity

3,057,639


2,383,874
Total liabilities and stockholders' equity
$ 6,522,786

$ 5,368,494











Concho Resources Inc.
Consolidated Statements of Operations
Unaudited

























Three Months Ended

Nine Months Ended



September 30,

September 30,

(in thousands, except per share data)




2011


2010(a)





2011


2010(a)


Operating revenues:









Oil sales

$ 332,659

$ 177,601


$ 957,833

$ 489,681
Natural gas sales


121,809


48,190



303,707


134,598
Total operating revenues


454,468


225,791



1,261,540


624,279
Operating costs and expenses:









Oil and natural gas production


84,050


41,762



217,285


111,534
Exploration and abandonments


3,498


3,617



4,624


5,648
Depreciation, depletion and amortization


115,730


57,624



304,899


157,394
Accretion of discount on asset retirement obligations


751


349



2,170


1,006
Impairments of long-lived assets


-


1,922



76


5,667
General and administrative (including non-cash stock-based compensation of $4,673 and $3,152









for the three months ended September 30, 2011 and 2010, respectively, and $13,866 and $8,854









for the nine months ended September 30, 2011 and 2010, respectively)


22,873


15,285



66,883


46,824
Bad debt expense


-


6



-


578
(Gain) loss on derivatives not designated as hedges


(385,222 )

66,107



(296,962 )

(62,229 )
Total operating costs and expenses


(158,320 )

186,672



298,975


266,422
Income from operations


612,788


39,119



962,565


357,857
Other income (expense):









Interest expense


(32,881 )

(12,036 )


(84,201 )

(34,293 )
Other, net


(2,503 )

(3,521 )


(4,590 )

(3,898 )
Total other expense


(35,384 )

(15,557 )


(88,791 )

(38,191 )
Income from continuing operations before income taxes


577,404


23,562



873,774


319,666
Income tax expense


(221,199 )

(7,392 )


(334,000 )

(118,375 )
Income from continuing operations


356,205


16,170



539,774


201,291
Income from discontinued operations, net of tax


-


4,605



91,188


11,195
Net income

$ 356,205

$ 20,775


$ 630,962

$ 212,486
Basic earnings per share:









Income from continuing operations

$ 3.47

$ 0.18


$ 5.27

$ 2.23
Income from discontinued operations, net of tax


-


0.05



0.88


0.12
Net income per share

$ 3.47

$ 0.23


$ 6.15

$ 2.35
Weighted average shares used in basic earnings per share


102,733


91,182



102,517


90,361
Diluted earnings per share:









Income from continuing operations

$ 3.44

$ 0.18


$ 5.21

$ 2.20
Income from discontinued operations, net of tax


-


0.04



0.88


0.12
Net income per share

$ 3.44

$ 0.22


$ 6.09

$ 2.32
Weighted average shares used in diluted earnings per share


103,696


92,440



103,613


91,631











(a) Retrospectively adjusted for presentation of discontinued operations.



Concho Resources Inc.
Consolidated Statements of Cash Flows
Unaudited












Nine Months Ended


September 30,
(in thousands)

2011


2010(a)


CASH FLOWS FROM OPERATING ACTIVITIES:



Net income
$ 630,962

$ 212,486
Adjustments to reconcile net income to net cash provided by operating activities:



Depreciation, depletion and amortization

304,899


157,394
Impairments of long-lived assets

76


5,667
Accretion of discount on asset retirement obligations

2,170


1,006
Exploration and abandonments, including dry holes

807


3,995
Non-cash compensation expense

13,866


8,854
Bad debt expense

-


578
Deferred income taxes

312,199


107,261
Loss on sale of assets

3,129


24
Gain on derivatives not designated as hedges

(296,962 )

(62,229 )
Discontinued operations

(82,118 )

19,041
Other non-cash items

309


3,760
Changes in operating assets and liabilities:



Accounts receivable

(125,091 )

(35,505 )
Prepaid costs and other

(8,420 )

(700 )
Inventory

1,204


(4,673 )
Accounts payable

(34,334 )

(8,127 )
Revenue payable

86,199


9,716
Other current liabilities

(29,909 )

(15,792 )
Net cash provided by operating activities

778,986


402,756
CASH FLOWS FROM INVESTING ACTIVITIES:



Capital expenditures on oil and natural gas properties

(932,770 )

(486,903 )
Acquisition of oil and natural gas properties

(113,438 )

(17,730 )
Additions to other property and equipment

(29,954 )

(3,750 )
Proceeds from the sale of assets

196,252


790
Settlements paid on derivatives not designated as hedges

(77,835 )

(5,231 )
Net cash used in investing activities

(957,745 )

(512,824 )
CASH FLOWS FROM FINANCING ACTIVITIES:



Proceeds from issuance of long-term debt

2,079,000


840,500
Payments of long-term debt

(1,949,500 )

(998,000 )
Net proceeds from issuance of common stock

-


219,308
Exercise of stock options

7,661


4,371
Excess tax benefit related to stock-based compensation

23,222


8,968
Payments for loan origination costs

(24,466 )

(2,299 )
Purchase of treasury stock

(1,946 )

(793 )
Bank overdrafts

44,578


35,136
Net cash provided by financing activities

178,549


107,191
Net decrease in cash and cash equivalents

(210 )

(2,877 )
Cash and cash equivalents at beginning of period

384


3,234
Cash and cash equivalents at end of period
$ 174

$ 357
SUPPLEMENTAL CASH FLOWS:



Cash paid for interest and fees, net of $73 and $119 capitalized interest
$ 60,752

$ 27,627
Cash paid for income taxes
$ 15,610

$ 17,771





(a) Retrospectively adjusted for presentation of discontinued operations.



Concho Resources Inc.
Summary Production and Operating Data
Unaudited

The following table sets forth summary information from our continuing operations concerning production and operating data for the periods indicated:


















Three Months Ended

Nine Months Ended




September 30,

September 30,





2011


2010



2011


2010












Production and operating data:








Net production volumes:








Oil (MBbl)

3,869


2,460



10,501


6,613
Natural gas (MMcf)

14,652


7,098



38,929


19,081
Total (MBoe)

6,311


3,643



16,989


9,793












Average daily production volumes:








Oil (Bbl)

42,054


26,739



38,465


24,223
Natural gas (Mcf)

159,258


77,152



142,596


69,894
Total (Boe)

68,597


39,598



62,231


35,872












Average prices:








Oil, without derivatives (Bbl)
$ 85.98

$ 72.20


$ 91.21

$ 74.05
Oil, with derivatives (Bbl) (a)
$ 83.90

$ 72.62


$ 82.77

$ 72.24
Natural gas, without derivatives (Mcf)
$ 8.31

$ 6.79


$ 7.80

$ 7.05
Natural gas, with derivatives (Mcf) (a)
$ 8.74

$ 7.39


$ 8.25

$ 7.60
Total, without derivatives (Boe)
$ 72.01

$ 61.98


$ 74.26

$ 63.75
Total, with derivatives (Boe) (a)
$ 71.73

$ 63.43


$ 70.06

$ 63.59












Operating costs and expenses per Boe:








Lease operating expenses and workover costs
$ 7.42

$ 5.57


$ 6.72

$ 5.88
Oil and natural gas taxes
$ 5.90

$ 5.89


$ 6.07

$ 5.51
Depreciation, depletion and amortization
$ 18.34

$ 15.82


$ 17.95

$ 16.07
General and administrative
$ 3.62

$ 4.20


$ 3.94

$ 4.78

























(a)

Includes the effect of the 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 consolidated statements of operations:




























Three Months Ended

Nine Months Ended




September 30,

September 30,


(in thousands)

2011


2010



2011


2010














Gain (loss) on derivatives not designated as hedges:










Cash receipts from (payments on) oil derivatives
$ (8,051 )
$ 1,034


$ (88,679 )
$ (11,951 )


Cash receipts from natural gas derivatives

6,263


4,258



17,468


10,378


Cash payments on interest rate derivatives

-


(1,224 )


(6,624 )

(3,658 )


Unrealized mark-to-market gain (loss) on commodity and interest rate derivatives



387,010


(70,175 )


374,797


67,460


Gain (loss) on derivatives not designated as hedges
$ 385,222

$ (66,107 )

$ 296,962

$ 62,229


























The presentation of average prices with derivatives is a non-GAAP measure as a result of including the cash payments on/receipts from 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.






Concho Resources Inc.
Supplemental Non-GAAP Financial Measures
Unaudited

EBITDAX

EBITDAX (as defined below) is presented herein, and reconciled from the generally accepted accounting principles ("GAAP") measure of net income because of its wide acceptance by the investment community as a financial indicator of a company's ability to internally fund exploration and development activities.

We define EBITDAX as net income, plus (1) exploration and abandonments expense, (2) depreciation, depletion and amortization expense, (3) accretion expense, (4) impairments of long-lived assets, (5) non-cash stock-based compensation expense, (6) bad debt expense, (7) unrealized (gain) loss on derivatives not designated as hedges, (8) (gain) loss on sale of assets, net, (9) interest expense, (10) federal and state income taxes, and (11) similar items listed above that are presented in discontinued operations. EBITDAX is not a measure of net income or cash flows as determined by GAAP.

Our EBITDAX measure (which includes continuing and discontinued operations) provides additional information which may be used to better understand our operations. EBITDAX is one of several metrics that we use as a supplemental financial measurement in the evaluation of our business and should not be considered as an alternative to, or more meaningful than, net income, as an indicator of our operating performance. Certain items excluded from EBITDAX are significant components in understanding and assessing a company's financial performance, such as a company's cost of capital and tax structure, as well as the historic cost of depreciable assets, none of which are components of EBITDAX. EBITDAX, as used by us, may not be comparable to similarly titled measures reported by other companies. We believe that EBITDAX is a widely followed measure of operating performance and is one of many metrics used by our management team, and by other users, of our consolidated financial statements. For example, EBITDAX can be used to assess our operating performance and return on capital in comparison to other independent exploration and production companies without regard to financial or capital structure, and to assess the financial performance of our assets and our company without regard to capital structure or historical cost basis.

The following table provides a reconciliation of net income to EBITDAX:


























Three Months Ended

Nine Months Ended



September 30,

September 30,
(in thousands)


2011


2010


2011


2010











Net income

$ 356,205

$ 20,775

$ 630,962

$ 212,486
Exploration and abandonments


3,498


3,617


4,624


5,648
Depreciation, depletion and amortization


115,730


57,624


304,899


157,394
Accretion of discount on asset retirement obligations


751


349


2,170


1,006
Impairments of long-lived assets


-


1,922


76


5,667
Non-cash stock-based compensation


4,673


3,152


13,866


8,854
Bad debt expense


-


6


-


578
Unrealized (gain) loss on derivatives not designated as hedges


(387,010 )

70,175


(374,797 )

(67,460 )
Loss on sale of assets, net


1,674


193


3,129


24
Interest expense


32,881


12,036


84,201


34,293
Income tax expense


221,199


7,392


334,000


118,375
Discontinued operations


-


7,030


(83,306 )

22,729
EBITDAX

$ 349,601

$ 184,271

$ 919,824

$ 499,594






















































Adjusted Net Income

The following tables provide information that the Company believes may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings and cash flows from operating activities to match realizations to production settlement months and make other adjustments to exclude certain non-cash items. The following table provides a reconciliation of net income (GAAP) to adjusted net income (non-GAAP).


























Three Months Ended



Nine Months Ended



September 30,

September 30,

(in thousands, except per share data)




2011


2010



2011


2010











Net income - as reported

$ 356,205

$ 20,775


$ 630,962

$ 212,486











Adjustments for certain non-cash items:









Unrealized mark-to-market (gain) loss on commodity and interest rate derivatives


(387,010 )

70,175



(374,797 )

(67,460 )
Impairments of long-lived assets


-


1,922



76


5,667
Leasehold abandonments


639


3,176



795


3,903
Discontinued operations:









Impairments of long-lived assets


-


-



-


3,567
Gain on sale of assets


-


-



(141,950 )

-
Tax impact (a)


147,980


(24,614 )


197,065


20,100
Adjusted net income

$ 117,814

$ 71,434


$ 312,151

$ 178,263











Adjusted basic earnings per share:









Adjusted net income per share

$ 1.15

$ 0.78


$ 3.04

$ 1.97
Weighted average shares used in adjusted basic earnings per share


102,733


91,182



102,517


90,361











Adjusted diluted earnings per share:









Adjusted net income per share

$ 1.14

$ 0.77


$ 3.01

$ 1.95
Weighted average shares used in adjusted diluted earnings per share


103,696


92,440



103,613


91,631






















(a) The tax impact is computed utilizing the Company's statutory effective federal and state income tax rates. The income tax rates for the three months ended September 30, 2011 and 2010, were 38.3% and 32.7%, respectively, and 38.2% and 37.0% for the nine months ended September 30, 2011 and 2010, respectively.



Adjusted Cash Flows

The following table provides a reconciliation of cash flows from operating activities (GAAP) to adjusted cash flows (non-GAAP).










Nine Months Ended



September 30,
(in thousands)

2011


2010






Cash flows from operating activities (a)
$ 778,986

$ 402,756
Settlements paid on derivatives not designated as hedges (b)

(77,835 )

(5,231 )
Adjusted cash flows
$ 701,151

$ 397,525













(a) Cash flows from operating activities includes net reductions of $110.4 million and $55.1 million for the nine months ended September 30, 2011 and 2010, respectively, associated with changes in working capital items. Changes in working capital items adjust for the timing of receipts and payments of actual cash.








(b) Amounts are presented in cash flows from investing activities for GAAP purposes.








Concho Resources Inc.
Costs Incurred
Unaudited

The table below provides the costs incurred for the three and nine months ended September 30, 2011 and 2010.


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



















Three Months Ended

Nine Months Ended





September 30,

September 30,
(in thousands)


2011

2010


2011

2010













Property acquisition costs:









Proved

$ -
$ 3,762

$ 69,148
$ 17,501
Unproved


42,432

10,874


117,772

31,903
Exploration


138,170

74,740


410,089

136,673
Development


233,062

88,310


567,547

334,222
Total costs incurred for oil and natural gas properties

$ 413,664
$ 177,686

$ 1,164,556
$ 520,299







































(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)


2011

2010


2011

2010















Proved property acquisition costs

$ -
$ -

$ 148
$ -


Exploration costs


198

321


838

573


Development costs


1,342

197


2,094

(1,227 )


Total

$ 1,540
$ 518

$ 3,080
$ (654 )




















Concho Resources Inc.
Derivatives Information at November 2, 2011
Unaudited

The table below provides data associated with our derivatives at November 2, 2011.


























Fourth Quarter









2011
2012
2013
2014
2015






















Oil Swaps:









Volume (Bbl)

3,133,436

11,308,000

7,434,000

1,248,000

600,000
NYMEX price (Bbl) (a)
$ 89.00
$ 93.85
$ 94.29
$ 83.94
$ 84.50











Natural Gas Swaps:









Volume (MMBtu)

3,069,000

300,000

-

-

-
NYMEX price (MMBtu) (b)
$ 6.62
$ 6.54

-

-

-











Natural Gas Basis Swaps:









Volume (MMBtu)

1,800,000

-

-

-

-
Price differential ($/MMBtu) (c)
$ 0.76

-

-

-

-























(a)

The index prices for the oil contracts are based on the NYMEX-West Texas Intermediate monthly average futures price.

(b)

The index prices for the natural gas contracts are based on the NYMEX-Henry Hub last trading day of the month futures price.

(c)

The basis differential between the El Paso Permian delivery point and NYMEX-Henry Hub delivery point.

SOURCE: Concho Resources Inc.

Concho Resources Inc.
Toffee McAlister, 432-683-7443
Director, Investor Relations & Corporate Communications
11.02.11 Concho Resources Inc. Expands Its Acreage Position in the Delaware Basin

MIDLAND, Texas, Nov 02, 2011 (BUSINESS WIRE) --

Concho Resources Inc. (NYSE: CXO) ("Concho" or the "Company") today announced that it has entered into definitive agreements to acquire acreage in the Delaware Basin (the "Acquisitions") from multiple parties during the third and fourth quarters of 2011 for aggregate consideration of approximately $330 million. The Acquisitions add approximately 137,000 gross (114,000 net) acres that are strategically positioned in both the northern and southern portions of the Company's Delaware Basin Bone Spring play. The Acquisitions consist primarily of leasehold but include an estimated 6 million barrels of oil equivalent ("MMBoe") proven reserves at closing and net daily production of approximately 1,500 barrels of oil equivalent per day ("Boepd").

Highlights of the Acquisitions:

  • Expands the Company's acreage position in the Delaware Basin to approximately 420,000 gross (270,000 net) acres from approximately 280,000 gross (160,000 net) acres as of June 30, 2011
  • Increases the Company's average working interest in the Delaware Basin to 64% from 56% as of June 30, 2011
  • Adds over 350 identified horizontal drilling locations with the potential to identify an additional 500 locations assuming 160-acre spacing

Additionally, during the third quarter of 2011 Concho achieved record levels of production from its Delaware Basin Bone Spring play, which includes the Avalon shale, the Bone Spring sands and the Wolfcamp shale. The Company's average net daily production in the third quarter of 2011 from its Delaware Basin Bone Spring play was approximately 8,900 Boepd, a 59% increase over the second quarter of 2011.

Timothy A. Leach, Concho's Chairman, CEO and President, commented, "We are pleased to announce a significant expansion of our acreage position in the Delaware Basin Bone Spring play at a very attractive acquisition price. Together with the Marbob acquisition and our leasing efforts, Concho has assembled a premier acreage position in the Delaware Basin targeting multiple horizons. As our operations team continues to deliver outstanding results in the Delaware Basin, we remain encouraged that this asset will be a significant driver of future growth."

The Acquisitions, which are all expected to close by December 2011, will be funded with borrowings under the Company's credit facility and are subject to customary purchase price adjustments and other customary closing conditions.

About Concho Resources Inc.

Concho Resources Inc. is an independent oil and natural gas company engaged in the acquisition, development and exploration of oil and natural gas properties. The Company's operations are focused in the Permian Basin of Southeast New Mexico and West Texas. For more information, visit Concho's website at www.concho.com.

Forward-Looking Statements and Cautionary Statements

The foregoing contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release specifically include statements, estimates and projections regarding the Company's future production growth, acquisitions, oil and natural gas reserves and number of identified drilling locations. These statements are based on certain assumptions made by the Company based on management's experience, expectations and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. Forward-looking statements are not guarantees of performance. Although the Company believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. Moreover, such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. These include the factors discussed or referenced in the "Risk Factors" section of the Company's most recent Form 10-K and 10-Q filings and risks relating to declines in the prices we receive for our oil and natural gas; uncertainties about the estimated quantities of reserves; risks related to the integration of the acquired assets; the effects of government regulation, permitting and other legal requirements, including new legislation or regulation of hydraulic fracturing; drilling and operating risks; the adequacy of our capital resources and liquidity; risks related to the concentration of our operations in the Permian Basin; the results of our hedging program; weather; litigation; shortages of oilfield equipment, services and qualified personnel and increases in costs for such equipment, services and personnel; uncertainties about our ability to replace reserves and economically develop our current reserves; competition in the oil and natural gas industry; our existing indebtedness; and other important factors that could cause actual results to differ materially from those projected.

Any forward-looking statement speaks only as of the date on which such statement is made, and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.

SOURCE: Concho Resources Inc.

Concho Resources Inc.
Toffee McAlister, 432-683-7443
Director, Investor Relations & Corporate Communications
10.17.11 Concho Resources Inc. Announces Participation in Upcoming Conferences

MIDLAND, Texas, Oct 17, 2011 (BUSINESS WIRE) --

Concho Resources Inc. (NYSE: CXO) (the "Company") today announced its participation at the Barclays Capital Second Annual Energy, Engineering and Construction One Day Forum on Thursday, November 10th, the Bank of America Merrill Lynch 2011 Global Energy Conference on Wednesday, November 16th at 8:10 AM ET, the Bank of America Merrill Lynch Leveraged Finance Conference on Thursday, December 1st at 3:30 PM ET, and the Capital One Southcoast 6th Annual Energy Conference on Tuesday, December 6th at 8:40 AM CT. The presentations will be available on Concho's website, www.concho.com. Additionally, all presentations will be webcast and can be accessed through the Company website.

About Concho Resources Inc.

Concho Resources Inc. is an independent oil and natural gas company engaged in the acquisition, development and exploration of oil and natural gas properties. The Company's operations are focused in the Permian Basin of Southeast New Mexico and West Texas. For more information, visit Concho's website at www.concho.com.

SOURCE: Concho Resources Inc.

Concho Resources Inc.
Toffee McAlister, 432-683-7443
Director, Investor Relations & Corporate Communication
09.15.11 Concho Resources Inc. Schedules Third Quarter 2011 Conference Call for November 3, 2011

Concho Resources Inc. (NYSE: CXO) ("Concho" or the "Company") will host a conference call on Thursday, November 3, 2011, at 9:00 a.m. CT to discuss its third quarter financial and operating results. Earnings are expected to be released after the market closes on Wednesday, November 2, 2011.

Individuals who would like to participate should call (800) 659-2032 (passcode: 39505486) approximately 15 minutes before the scheduled conference call time. To access the live audio webcast, please visit the investor relations section of the Company's website, www.concho.com. A replay of the call will also be available, by dialing (888) 286-8010 (passcode: 60178210) or via the Company's website, for approximately 30 days following the conference call.

About Concho Resources Inc.

Concho Resources Inc. is an independent oil and natural gas company engaged in the acquisition, development and exploration of oil and natural gas properties. The Company's operations are primarily focused in the Permian Basin of Southeast New Mexico and West Texas. For more information, visit Concho's website at www.concho.com.

SOURCE: Concho Resources Inc.

Concho Resources Inc.
Toffee McAlister, 432-683-7443
Director of Investor Relations & Corporate Communication
08.03.11 Concho Resources Inc. Reports Second Quarter 2011 Financial and Operating Results

MIDLAND, Texas, Aug 03, 2011 (BUSINESS WIRE) --

Concho Resources Inc. (NYSE: CXO) ("Concho" or the "Company") today reported financial and operating results for the three and six months ended June 30, 2011. Highlights for the three and six months ended June 30, 2011 include:

  • Production of 5.6 million barrels of oil equivalents ("MMBoe") for the second quarter of 2011, a 61% increase over the second quarter of 2010 and a 7% increase over the first quarter of 2011
  • Mid-year proved reserves increased to 342.6 MMBoe, up 6% from year-end 2010
  • Reserve replacement ratio1 of 354% for the first six months of 2011
  • Net income of $232.2 million, or $2.24 per diluted share, for the second quarter of 2011, as compared to net income of $124.2 million, or $1.35 per diluted share, in the second quarter of 2010
  • Adjusted net income2 (non-GAAP) of $113.2 million, or $1.09 per diluted share, for the second quarter of 2011, as compared to $57.9 million, or $0.63 per diluted share, for the second quarter of 2010
  • EBITDAX3 of $310.7 million for the second quarter of 2011, an increase of 92% over the second quarter of 2010

1 The Company uses the reserve replacement ratio as an indicator of the Company's ability to replenish annual production volumes and grow its reserves, thereby providing some information on the sources of future production. It should be noted that the reserve replacement ratio is a statistical indicator that has limitations. The ratio is limited because it typically varies widely based on the extent and timing of discoveries and property acquisitions. Its predictive and comparative value is also limited for the same reasons. In addition, since the ratio does not imbed the cost or timing of future production of new reserves, it cannot be used as a measure of value creation. The reserve replacement ratio of 354% was calculated by dividing net proved reserve additions of 38.2 MMBoe (the sum of extensions, discoveries, revisions and purchases) by production of 10.8 MMBoe.

2 Adjusted net income (non-GAAP) is comparable to securities analyst estimates. For an explanation of how the Company calculates adjusted net income (non-GAAP) and a reconciliation of net income (GAAP) to adjusted net income (non-GAAP), please see "Supplemental Non-GAAP Financial Measures" below.

3 For an explanation of how the Company calculates and uses EBITDAX (non-GAAP) and a reconciliation of net income (GAAP) to EBITDAX (non-GAAP), please see "Supplemental Non-GAAP Financial Measures" below.

Second Quarter 2011 Financial Results

Production for the second quarter of 2011 totaled 5.6 MMBoe (3.5 million barrels of oil ("MMBbls") and 12.3 billion cubic feet of natural gas ("Bcf")), an increase of 61% as compared to 3.5 MMBoe (2.3 MMBbls and 6.7 Bcf) produced in the second quarter of 2010.

As of July 1, 2011, the Company estimated that its total proved reserves were 342.6 MMBoe (62% proved developed) utilizing SEC reserve recognition standards and pricing assumptions based on the trailing 12-month average first-day-of-the-month prices as of June 2011 of $86.60 per barrel ("Bbl") of oil and $4.21 per million British thermal unit ("MMBtu") of natural gas. The Company's estimate of its total proved reserves as of July 1, 2011 is based on the Company's internal reserve analysis and has not been prepared by, reviewed or audited by the Company's independent petroleum engineers. This total represents a 6% increase from year-end 2010 total proved reserves of 323.5 MMBoe (57% proved developed). The total proved reserves estimate as of July 1, 2011 would have been reduced by approximately 2.2 MMBoe had the Company utilized the average twelve month 2010 SEC pricing of $75.96 per Bbl of oil and $4.38 per MMBtu of gas.

Timothy A. Leach, Concho's Chairman, CEO and President commented, "Our business delivered outstanding results in the first half of 2011. Despite the many factors that have challenged our operations, we remain on track to accomplish the goals we established for 2011. I am pleased with our reserve and production growth in the first six months of 2011 and the significant additions to our drilling inventory, particularly in our core Wolfberry and Delaware Basin assets. Finally, our results in the Delaware Basin are encouraging, and the significant quarter over quarter production growth from the Delaware Basin is indicative of the momentum we expect this area to carry into 2012."

For the second quarter of 2011, the Company reported net income of $232.2 million, or $2.24 per diluted share, as compared to net income of $124.2 million, or $1.35 per diluted share, for the second quarter of 2010. The Company's second quarter 2011 results were impacted by several non-cash items including: (1) a $192.6 million unrealized mark-to-market gain on commodity and interest rate derivatives and (2) $0.1 million of impairments of long-lived assets and leasehold abandonments, combined. Excluding these items and their tax effects, the second quarter 2011 adjusted net income (non-GAAP) was $113.2 million, or $1.09 per diluted share. Excluding these similar items and an impairment of long-lived assets included in discontinued operations recorded in the second quarter of 2010, our adjusted net income (non-GAAP) for the second quarter of 2010 was $57.9 million, or $0.63 per diluted share. For a reconciliation of net income (GAAP) to adjusted net income (non-GAAP), please see "Supplemental Non-GAAP Financial Measures" below.

EBITDAX (defined as net income, plus (1) exploration and abandonments expense, (2) depreciation, depletion and amortization expense, (3) accretion expense, (4) impairments of long-lived assets, (5) non-cash stock-based compensation expense, (6) bad debt expense, (7) unrealized (gain) loss on derivatives not designated as hedges, (8) (gain) loss on sale of assets, net, (9) interest expense, (10) federal and state income taxes, and (11) similar items listed above that are presented in discontinued operations) increased to $310.7 million in the second quarter of 2011, as compared to $161.7 million in the second quarter of 2010. For a reconciliation of net income (GAAP) to EBITDAX (non-GAAP), please "Supplemental Non-GAAP Financial Measures" below.

Operating revenues for the second quarter of 2011 increased 124% when compared to the second quarter of 2010. This increase is attributable to the 76% increase in production and the 30% increase in the Company's unhedged realized oil price and the 32% increase in the Company's unhedged realized natural gas price in the second quarter of 2011 compared to the same period in 2010.

Oil and natural gas production expense for the second quarter of 2011, including taxes, totaled $69.6 million, or $12.48 per Boe, an 8% increase per Boe over the second quarter of 2010. This increase was primarily due to higher commodity prices, which resulted in more oil and natural gas taxes (which averaged $6.51 per Boe in the second quarter of 2011 as compared to $4.99 per Boe in the second quarter of 2010).

Depreciation, depletion and amortization for the second quarter of 2011 totaled $98.9 million, or $17.74 per Boe, a 13% increase per Boe from $49.6 million, or $15.66 per Boe, in the second quarter of 2010.

General and administrative expense ("G&A") for the second quarter of 2011 totaled $22.6 million, or $4.06 per Boe, compared to $17.8 million, or $5.61 per Boe, in the second quarter of 2010. The decrease in per Boe expense in the second quarter of 2011 over the second quarter of 2010 was primarily due to increased production, offset by a 27% increase in absolute G&A costs due to increased staffing across the Company and the addition of employees from the Marbob acquisition.

The Company's cash flows from operating activities (GAAP) for the six months ended June 30, 2011 was $485.8 million, as compared to $239.5 million for the six months ended June 30, 2010, an increase of 103%. Adjusted cash flows (non-GAAP), which are cash flows from operating activities adjusted for settlements paid on derivatives not designated as hedges, was $409.8 million for the six months ended June 30, 2011, as compared to $230.2 million for the six months ended June 30, 2010, an increase of 78%. For a description of the use of adjusted cash flows (non-GAAP) and for a reconciliation of cash flows from operating activities (GAAP) to adjusted cash flows (non-GAAP), please "Supplemental Non-GAAP Financial Measures" below.

In the second quarter of 2011, the Company made cash payments for settlements on derivatives contracts not designated as hedges of $47.8 million and the non-cash unrealized mark-to-market gain for the derivatives contracts not designated as hedges was $192.6 million. This is compared to cash receipts of $1.5 million on derivatives contracts not designated as hedges and a $111.2 million non-cash unrealized mark-to-market gain on contracts not designated as hedges in the second quarter of 2010. To better understand the impact of the Company's derivatives positions and their impact on the statement of operations, please see the "Summary Production and Price Data" and "Derivatives Information" tables at the end of this press release.

Operations

For the quarter ended June 30, 2011, the Company commenced the drilling of or participated in a total of 229 gross wells (196 operated), 72 of which had been completed as producers and 157 of which were in progress at June 30, 2011. In addition, during the second quarter of 2011, the Company completed 127 wells that were drilled prior to the second quarter of 2011. Currently, the Company is operating 36 drilling rigs, all in the Permian Basin; 12 of these rigs are drilling Yeso wells on the New Mexico Shelf, 16 are drilling Wolfberry wells in the Texas Permian, 6 are drilling Bone Spring wells in the Delaware Basin and 2 rigs are drilling Lower Abo wells on the New Mexico Shelf.

New Mexico Shelf

During the second quarter of 2011, the Company drilled 131 wells (106 operated) on its New Mexico Shelf assets, which included both the Yeso and the Lower Abo, with a 100% success rate on the 60 wells that had been completed by June 30, 2011. In addition, during the second quarter of 2011, the Company completed 52 wells that were drilled prior to the second quarter of 2011. At June 30, 2011, on its New Mexico Shelf assets, the Company had identified 2,846 drilling locations, with proved undeveloped reserves attributable to 637 of such locations. Of these 2,846 drilling locations, 2,113 target the Yeso formation and 327 target the Lower Abo formation.

Texas Permian

During the second quarter of 2011, the Company drilled 73 wells (100% operated) on its Texas Permian assets with a 100% success rate on the 10 wells that had been completed by June 30, 2011. In addition, during the second quarter of 2011, the Company completed 58 wells that were drilled prior to the second quarter of 2011. At June 30, 2011, on its Texas Permian assets, the Company had identified 4,449 drilling locations, with proved undeveloped reserves attributable to 1,240 of such locations. Of these 4,449 drilling locations, 1,893 target the Wolfberry play through 40-acre spacing and 2,444 target the Wolfberry play on 20-acre spacing.

Delaware Basin

During the second quarter of 2011, the Company drilled or participated in 25 wells (17 operated) with a 100% success rate on the 2 wells that had been completed by June 30, 2011. In addition, during the second quarter of 2011, the Company completed 17 wells that were drilled prior to the second quarter of 2011. The Company's net production from the Bone Spring in the second quarter of 2011 averaged approximately 5,600 Boepd, an increase of 40% over the first quarter of 2011. At June 30, 2011, on its Delaware Basin assets, the Company had identified 1,464 drilling locations, with proved undeveloped reserves attributable to 106 of such locations. Of these drilling locations, 1,039 target horizontal objectives and 332 target the vertical Wolfbone play.

Derivative Update

The Company maintains an active hedging program and continued to add to its derivative positions through July 2011. Please see the "Derivatives Information" tables at the end of this press release for more detailed information about the Company's current derivative positions.

Conference Call Information

The Company will host a conference call on Thursday, August 4, 2011 at 9:00 a.m. Central Time to discuss the second quarter 2011 financial and operating results. Interested parties may listen to the conference call via the Company's website at http://www.concho.com or by dialing (866) 271-5140 (passcode: 82868431). A replay of the conference call will be available on the Company's website or by dialing (888) 286-8010 (passcode: 88954595).

About Concho Resources Inc.

Concho Resources Inc. is an independent oil and natural gas company engaged in the acquisition, development and exploration of oil and natural gas properties. The Company's operations are focused in the Permian Basin of Southeast New Mexico and West Texas. For more information, visit Concho's website at www.concho.com.

Forward-Looking Statements and Cautionary Statements

The foregoing contains forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that the Company expects, believes or anticipates will or may occur in the future are forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release specifically include statements, estimates and projections regarding the Company's future financial position, liquidity and capital resources, operations, performance, production growth, acquisitions, returns, capital expenditure budgets, oil and natural gas reserves, number of identified drilling locations, drilling program, derivative activities, costs and other guidance included in this press release. These statements are based on certain assumptions made by the Company based on management's experience, expectations and perception of historical trends, current conditions, anticipated future developments and other factors believed to be appropriate. Forward-looking statements are not guarantees of performance. Although the Company believes the expectations reflected in its forward-looking statements are reasonable and are based on reasonable assumptions, no assurance can be given that these assumptions are accurate or that any of these expectations will be achieved (in full or at all) or will prove to have been correct. Moreover, such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or expressed by the forward-looking statements. These include the factors discussed or referenced in the "Risk Factors" section of the Company's most recent Form 10-K filing and risks relating to declines in the prices we receive for our oil and natural gas; uncertainties about the estimated quantities of reserves; the effects of government regulation, permitting and other legal requirements, including new legislation or regulation of hydraulic fracturing; drilling and operating risks; the adequacy of our capital resources and liquidity; risks related to the concentration of our operations in the Permian Basin; the results of our hedging program; weather; litigation; shortages of oilfield equipment, services and qualified personnel and increases in costs for such equipment, services and personnel; uncertainties about our ability to replace reserves and economically develop our current reserves; competition in the oil and natural gas industry; our existing indebtedness; and other important factors that could cause actual results to differ materially from those projected.

Any forward-looking statement speaks only as of the date on which such statement is made, and the Company undertakes no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise, except as required by applicable law.








Concho Resources Inc.
Consolidated Balance Sheets
Unaudited











June 30,

December 31,
(in thousands, except share and per share data)

2011

2010
Assets
Current assets:





Cash and cash equivalents

$ 397


$ 384
Accounts receivable, net of allowance for doubtful accounts:





Oil and natural gas


216,128



136,471
Joint operations and other


170,969



131,912
Related parties


156



169
Derivative instruments


4,958



6,855
Deferred income taxes


28,962



42,716
Prepaid costs and other


16,982



12,126
Total current assets


438,552



330,633
Property and equipment, at cost:





Oil and natural gas properties, successful efforts method


6,280,554



5,616,249
Accumulated depletion and depreciation


(881,607 )


(730,509 )
Total oil and natural gas properties, net


5,398,947



4,885,740
Other property and equipment, net


50,340



28,047
Total property and equipment, net


5,449,287



4,913,787
Deferred loan costs, net


70,941



52,828
Intangible asset - operating rights, net


34,199



34,973
Inventory


38,076



28,342
Noncurrent derivative instruments


512



2,233
Other assets


4,576



5,698
Total assets

$ 6,036,143


$ 5,368,494
Liabilities and Stockholders' Equity
Current liabilities:





Accounts payable:





Trade

$ 11,118


$ 39,943
Related parties


534



1,197
Other current liabilities:





Bank overdrafts


30,357



12,314
Revenue payable


123,570



57,406
Accrued and prepaid drilling costs


296,681



215,079
Derivative instruments


74,399



97,775
Other current liabilities


100,450



83,275
Total current liabilities


637,109



506,989
Long-term debt


1,735,926



1,668,521
Deferred income taxes


845,702



720,889
Noncurrent derivative instruments


83,618



51,647
Asset retirement obligations and other long-term liabilities


39,427



36,574
Commitments and contingencies





Stockholders' equity:





Common stock, $0.001 par value; 300,000,000 authorized; 103,529,637 and 102,842,082 shares issued at June 30, 2011 and December 31, 2010, respectively




104



103
Additional paid-in capital


1,912,098



1,874,649
Retained earnings


785,494



510,737

Treasury stock, at cost; 48,849 and 31,963 shares at June 30, 2011 and December 31, 2010, respectively




(3,335 )


(1,615 )
Total stockholders' equity


2,694,361



2,383,874
Total liabilities and stockholders' equity

$ 6,036,143


$ 5,368,494


















Concho Resources Inc.
Consolidated Statements of Operations
Unaudited











Three Months Ended

Six Months Ended



June 30,

June 30,
(in thousands, except per share amounts)

2011

2010 (a)



2011

2010 (a)

Operating revenues:











Oil sales

$ 342,747


$ 159,292


$ 625,174


$ 312,080
Natural gas sales


103,485



40,023



181,898



86,408
Total operating revenues


446,232



199,315



807,072



398,488
Operating costs and expenses:











Oil and natural gas production


69,577



36,442



133,235



69,772
Exploration and abandonments


400



922



1,126



2,031
Depreciation, depletion and amortization


98,881



49,611



189,169



99,770
Accretion of discount on asset retirement obligations


715



316



1,419



657
Impairments of long-lived assets


76



3,489



76



3,745

General and administrative (including non-cash stock-based compensation of $4,725 and $2,871 for the three months ended June 30, 2011 and 2010, respectively, and $9,193 and $5,702 for the six months ended June 30, 2011 and 2010, respectively)




22,618



17,761



44,010



31,539
Bad debt expense


-



33



-



572
(Gain) loss on derivatives not designated as hedges


(144,882 )


(112,763 )


88,260



(128,336 )
Total operating costs and expenses


47,385



(4,189 )


457,295



79,750
Income from operations


398,847



203,504



349,777



318,738
Other income (expense):











Interest expense


(21,660 )


(11,192 )


(51,320 )


(22,257 )
Other, net


(1,735 )


(304 )


(2,087 )


(377 )
Total other expense


(23,395 )


(11,496 )


(53,407 )


(22,634 )
Income from continuing operations before income taxes


375,452



192,008



296,370



296,104
Income tax expense


(143,270 )


(72,220 )


(112,801 )


(110,983 )
Income from continuing operations


232,182



119,788



183,569



185,121
Income from discontinued operations, net of tax


-



4,383



91,188



6,590
Net income

$ 232,182


$ 124,171


$ 274,757


$ 191,711
Basic earnings per share:











Income from continuing operations

$ 2.26


$ 1.32


$ 1.79


$ 2.06
Income from discontinued operations, net of tax


-



0.04



0.89



0.07
Net income per share

$ 2.26


$ 1.36


$ 2.68


$ 2.13
Weighted average shares used in basic earnings per share


102,569



91,044



102,407



89,944
Diluted earnings per share:











Income from continuing operations

$ 2.24


$ 1.31


$ 1.77


$ 2.03
Income from discontinued operations, net of tax


-



0.04



0.88



0.07
Net income per share

$ 2.24


$ 1.35


$ 2.65


$ 2.10
Weighted average shares used in diluted earnings per share


103,638



92,297



103,570



91,220


























(a) Retrospectively adjusted for presentation of discontinued operations.































Concho Resources Inc.
Consolidated Statements of Cash Flows
Unaudited











Six Months Ended



June 30,
(in thousands)

2011

2010 (a)

CASH FLOWS FROM OPERATING ACTIVITIES:





Net income

$ 274,757


$ 191,711
Adjustments to reconcile net income to net cash provided by operating activities:





Depreciation, depletion and amortization


189,169



99,770
Impairments of long-lived assets


76



3,745
Accretion of discount on asset retirement obligations


1,419



657
Exploration and abandonments, including dry holes


168



819
Non-cash compensation expense


9,193



5,702
Bad debt expense


-



572
Deferred income taxes


101,967



99,516
(Gain) loss on sale of assets


1,455



(169 )
(Gain) loss on derivatives not designated as hedges


88,260



(128,336 )
Discontinued operations


(82,118 )


12,919
Other non-cash items


(2,321 )


2,420
Changes in operating assets and liabilities:





Accounts receivable


(105,761 )


(27,831 )
Prepaid costs and other


(3,734 )


105
Inventory


(10,868 )


(3,834 )
Accounts payable


(29,488 )


(8,900 )
Revenue payable


66,164



(897 )
Other current liabilities


(12,491 )


(8,439 )
Net cash provided by operating activities


485,847



239,530
CASH FLOWS FROM INVESTING ACTIVITIES:





Capital expenditures on oil and natural gas properties


(578,767 )


(278,002 )
Acquisition of oil and natural gas properties


(98,405 )


(13,362 )
Additions to other property and equipment


(24,981 )


(2,292 )
Proceeds from the sale of assets


196,252



790
Settlements paid on derivatives not designated as hedges


(76,047 )


(9,299 )
Net cash used in investing activities


(581,948 )


(302,165 )
CASH FLOWS FROM FINANCING ACTIVITIES:





Proceeds from issuance of long-term debt


1,645,000



360,000
Payments of long-term debt


(1,569,000 )


(562,000 )
Net proceeds from issuance of common stock


-



219,308
Exercise of stock options


7,140



4,080
Excess tax benefit related to stock-based compensation


21,117



6,703
Payments for loan origination costs


(24,466 )


(2,299 )
Purchase of treasury stock


(1,720 )


(585 )
Bank overdrafts


18,043



34,577
Net cash provided by financing activities


96,114



59,784
Net increase (decrease) in cash and cash equivalents


13



(2,851 )
Cash and cash equivalents at beginning of period


384



3,234
Cash and cash equivalents at end of period

$ 397


$ 383
SUPPLEMENTAL CASH FLOWS:





Cash paid for interest and fees, net of $73 and $56 capitalized interest

$ 32,069


$ 21,707
Cash paid for income taxes

$ 14,322


$ 16,715














(a) Retrospectively adjusted for presentation of discontinued operations.
























Concho Resources Inc.
Summary Production and Price Data
Unaudited













The following table sets forth summary information from our continuing and discontinued operations concerning our production and operating data for the periods indicated:









Three Months Ended
Six Months Ended





June 30,
June 30,





2011
2010
2011
2010












Production and operating data:








Net production volumes:








Oil (MBbl)


3,522


2,337


6,749


4,507
Natural gas (MMcf)


12,307


6,692


24,314


12,933
Total (MBoe)


5,573


3,452


10,801


6,663












Average daily production volumes:








Oil (Bbl)


38,703


25,681


37,287


24,901
Natural gas (Mcf)


135,242


73,538


134,331


71,453
Total (Boe)


61,244


37,938


59,676


36,809












Average prices:








Oil, without derivatives (Bbl)

$ 97.32

$ 74.64

$ 94.03

$ 74.81
Oil, with derivatives (Bbl) (a)

$ 83.57

$ 73.42

$ 82.09

$ 71.93
Natural gas, without derivatives (Mcf)

$ 8.41

$ 6.17

$ 7.48

$ 7.00
Natural gas, with derivatives (Mcf) (a)

$ 8.90

$ 7.01

$ 7.94

$ 7.48
Total, without derivatives (Boe)

$ 80.07

$ 62.49

$ 75.60

$ 64.19
Total, with derivatives (Boe) (a)

$ 72.48

$ 63.29

$ 69.18

$ 63.16












Operating costs and expenses per Boe:








Lease operating expenses and workover costs

$ 5.97

$ 6.71

$ 6.28

$ 6.29
Oil and natural gas taxes

$ 6.51

$ 5.01

$ 6.21

$ 5.29
Depreciation, depletion and amortization

$ 17.74

$ 15.67

$ 17.71

$ 16.20
General and administrative

$ 4.06

$ 5.08

$ 4.07

$ 4.67

























(a) Includes the cash payments/receipts from commodity derivatives not designated as hedges and reported in operating costs and expenses. The following table reflects the amounts of cash payments/receipts from 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
Six Months Ended





June 30,
June 30,


(in thousands)

2011
2010
2011
2010














Gain (loss) on derivatives not designated as hedges:










Cash payments on oil derivatives

$ (48,398 )
$ (2,852 )
$ (80,628 )
$ (12,985 )


Cash receipts from natural gas derivatives


6,076


5,614


11,205


6,120


Cash payments on interest rate derivatives


(5,429 )

(1,221 )

(6,624 )

(2,434 )


Unrealized mark-to-market gain (loss) on commodity and interest rate









derivatives


192,633


111,222


(12,213 )

137,635


Gain (loss) on derivatives not designated as hedges

$ 144,882

$ 112,763

$ (88,260 )
$ 128,336


























The presentation of average prices with derivatives is a non-GAAP measure as a result of including the cash payments on/receipts from 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.







The following table sets forth summary information from our continuing operations concerning production and operating data for the periods indicated:












Three Months Ended
Six Months Ended


June 30,
June 30,




2011
2010
2011
2010











Production and operating data:







Net production volumes:







Oil (MBbl)

3,522


2,123


6,632


4,153
Natural gas (MMcf)

12,307


6,266


24,277


11,983
Total (MBoe)

5,573


3,167


10,678


6,150











Average daily production volumes:







Oil (Bbl)

38,703


23,330


36,641


22,945
Natural gas (Mcf)

135,242


68,857


134,127


66,204
Total (Boe)

61,244


34,806


58,995


33,979











Average prices:







Oil, without derivatives (Bbl)
$ 97.32

$ 75.03

$ 94.27

$ 75.15

Oil, with derivatives (Bbl) (a)


$ 83.57

$ 73.69

$ 82.11

$ 72.02
Natural gas, without derivatives (Mcf)
$ 8.41

$ 6.39

$ 7.49

$ 7.21
Natural gas, with derivatives (Mcf) (a)
$ 8.90

$ 7.28

$ 7.95

$ 7.72
Total, without derivatives (Boe)
$ 80.07

$ 62.93

$ 75.58

$ 64.79
Total, with derivatives (Boe) (a)
$ 72.48

$ 63.81

$ 69.08

$ 63.68











Operating costs and expenses per Boe:







Lease operating expenses and workover costs
$ 5.97

$ 6.52

$ 6.31

$ 6.06
Oil and natural gas taxes
$ 6.51

$ 4.99

$ 6.17

$ 5.29
Depreciation, depletion and amortization
$ 17.74

$ 15.66

$ 17.72

$ 16.22
General and administrative
$ 4.06

$ 5.61

$ 4.12

$ 5.13























(a)

Includes the cash payments/receipts from commodity derivatives not designated as hedges and reported in operating costs and expenses. The following table reflects the amounts of cash payments/receipts from 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
Six Months Ended




June 30,
June 30,


(in thousands)
2011
2010
2011
2010













Gain (loss) on derivatives not designated as hedges:









Cash payments on oil derivatives
$ (48,398 )
$ (2,852 )
$ (80,628 )
$ (12,985 )


Cash receipts from natural gas derivatives

6,076


5,614


11,205


6,120


Cash payments on interest rate derivatives

(5,429 )

(1,221 )

(6,624 )

(2,434 )


Unrealized mark-to-market gain (loss) on commodity and interest rate derivatives



192,633


111,222


(12,213 )

137,635


Gain (loss) on derivatives not designated as hedges
$ 144,882

$ 112,763

$ (88,260 )
$ 128,336
























The presentation of average prices with derivatives is a non-GAAP measure as a result of including the cash payments on/receipts from 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.









Concho Resources Inc.

Supplemental Non-GAAP Financial Measures

Unaudited

EBITDAX

EBITDAX (as defined below) is presented herein, and reconciled from the generally accepted accounting principles ("GAAP") measure of net income because of its wide acceptance by the investment community as a financial indicator of a company's ability to internally fund exploration and development activities.

We define EBITDAX as net income, plus (1) exploration and abandonments expense, (2) depreciation, depletion and amortization expense, (3) accretion expense, (4) impairments of long-lived assets, (5) non-cash stock-based compensation expense, (6) bad debt expense, (7) unrealized (gain) loss on derivatives not designated as hedges, (8) (gain) loss on sale of assets, net, (9) interest expense, (10) federal and state income taxes, and (11) similar items listed above that are presented in discontinued operations. EBITDAX is not a measure of net income or cash flows as determined by GAAP.

Our EBITDAX measure (which includes continuing and discontinued operations) provides additional information which may be used to better understand our operations. EBITDAX is one of several metrics that we use as a supplemental financial measurement in the evaluation of our business and should not be considered as an alternative to, or more meaningful than, net income, as an indicator of our operating performance. Certain items excluded from EBITDAX are significant components in understanding and assessing a company's financial performance, such as a company's cost of capital and tax structure, as well as the historic cost of depreciable assets, none of which are components of EBITDAX. EBITDAX, as used by us, may not be comparable to similarly titled measures reported by other companies. We believe that EBITDAX is a widely followed measure of operating performance and is one of many metrics used by our management team, and by other users, of our consolidated financial statements. For example, EBITDAX can be used to assess our operating performance and return on capital in comparison to other independent exploration and production companies without regard to financial or capital structure, and to assess the financial performance of our assets and our company without regard to capital structure or historical cost basis.

The following table provides a reconciliation of net income to EBITDAX:














Three Months Ended
Six Months Ended



June 30,
June 30,
(in thousands)

2011
2010
2011
2010










Net income

$ 232,182

$ 124,171

$ 274,757

$ 191,711
Exploration and abandonments


400


922


1,126


2,031
Depreciation, depletion and amortization


98,881


49,611


189,169


99,770
Accretion of discount on asset retirement obligations


715


316


1,419


657
Impairments of long-lived assets


76


3,489


76


3,745
Non-cash stock-based compensation


4,725


2,871


9,193


5,702
Bad debt expense


-


33


-


572
Unrealized (gain) loss on derivatives not designated as hedges


(192,633 )

(111,222 )

12,213


(137,635 )
(Gain) loss on sale of assets, net


1,431


(152 )

1,455


(169 )
Interest expense


21,660


11,192


51,320


22,257
Income tax expense


143,270


72,220


112,801


110,983
Discontinued operations


-


8,229


(83,306 )

15,699
EBITDAX

$ 310,707

$ 161,680

$ 570,223

$ 315,323


















Adjusted Net Income

The following tables provide information that the Company believes may be useful to investors who follow the practice of some industry analysts who adjust reported company earnings and cash flows from operating activities to match realizations to production settlement months and make other adjustments to exclude certain non-cash items. The following table provides a reconciliation of net income (GAAP) to adjusted net income (non-GAAP).










Three Months Ended
Six Months Ended



June 30,
June 30,
(in thousands, except per share amounts)

2011
2010
2011

2010












Net income - as reported

$ 232,182

$ 124,171

$ 274,757

$

191,711














Adjustments for certain non-cash items:










Unrealized mark-to-market (gain) loss on commodity and interest rate derivatives


(192,633 )

(111,222 )

12,213


(137,635

)

Impairments of long-lived assets


76


3,489


76


3,745
Leasehold abandonments


30


318


156


727
Discontinued operations:










Impairments of long-lived assets


-


1,203


-


3,567
Gain on sale of assets


-


-


(141,950 )

-
Tax impact (a)


73,545


39,910


49,341


48,508
Adjusted net income

$ 113,200

$ 57,869

$ 194,593

$

110,623














Adjusted basic earnings per share:










Adjusted net income per share

$ 1.10

$ 0.64

$ 1.90

$

1.23


Weighted average shares used in adjusted basic earnings per share


102,569


91,044


102,407


89,944












Adjusted diluted earnings per share:










Adjusted net income per share

$ 1.09

$ 0.63

$ 1.88

$

1.21


Weighted average shares used in adjusted diluted earnings per share


103,638


92,297


103,570


91,220
























(a) The tax impact is computed utilizing the Company's statutory effective federal and state income tax rates. The income tax rates for the three months ended June 30, 2011 and 2010, were 38.2% and 37.6%, respectively, and 38.1% and 37.4% for the six months ended June 30, 2011 and 2010, respectively.

Adjusted Cash Flows

The following table provides a reconciliation of cash flows from operating activities (GAAP) to adjusted cash flows (non-GAAP).








Six Months Ended


June 30,
(in thousands)
2011
2010





Cash flows from operating activities (a)


$ 485,847

$ 239,530

Settlements paid on derivatives not designated as hedges (b)



(76,047 )

(9,299 )
Adjusted cash flows
$ 409,800

$ 230,231










(a) Cash flows from operating activities includes net reductions of $96.2 million and $49.8 million for the six months ended June 30, 2011 and 2010, respectively, associated with changes in working capital items. Changes in working capital items adjust for the timing of receipts and payments of actual cash.






(b)Amounts are presented in cash flows from investing activities for GAAP purposes.




Concho Resources Inc.
Costs Incurred
Unaudited


The table below provides the costs incurred for the three and six months ended June 30, 2011 and 2010.




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































Three Months Ended
Six Months Ended



June 30,
June 30,
(in thousands)

2011
2010
2011
2010










Property acquisition costs:








Proved

$ 3,230
$ 3,897
$ 69,148
$ 13,739
Unproved


18,132

15,673

75,340

21,029
Exploration


181,353

36,434

271,919

61,933
Development


140,768

134,206

334,485

245,912
Total costs incurred for oil and natural gas properties

$ 343,483
$ 190,210
$ 750,892
$ 342,613






























(a) The costs incurred for oil and natural gas producing activities includes the following amounts of asset retirement obligations:
























Three Months Ended
Six Months Ended



June 30,
June 30,
(in thousands)

2011
2010
2011
2010










Proved property acquisition costs

$ -
$ -
$ 148
$ -
Exploration costs


320

184

640

252
Development costs


757

776

752

(1,424 )
Total

$ 1,077
$ 960
$ 1,540
$ (1,172 )
















Concho Resources Inc.
Derivatives Information at August 3, 2011
Unaudited


The table below provides data associated with our derivatives at August 3, 2011.