Vital Energy (VTLE) 10-Q 7 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 04, 2014
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'Laredo Petroleum, Inc.	'
Entity Central Index Key	'0001528129	'
Document Type	'10-Q	'
Document Period End Date	30-Jun-14	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Current Reporting Status	'Yes	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	143,762,444
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'
Entity Voluntary Filers	'No	'
Entity Well-known Seasoned Issuer	'Yes	'

Consolidated_balance_sheets

Consolidated balance sheets (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$399,506	$198,153
Accounts receivable, net	95,720	77,318
Derivatives	1,360	15,806
Deferred income taxes	13,588	3,634
Other current assets	20,447	12,698
Total current assets	530,621	307,609
Oil and natural gas properties, full cost method:	'	'
Proved properties	3,698,051	3,276,578
Unproved properties not being amortized	225,056	208,085
Midstream service assets	80,265	51,704
Other fixed assets	42,016	32,832
Total property and equipment	4,045,388	3,569,199
Less accumulated depletion, depreciation, amortization and impairment	-1,467,172	-1,364,875
Net property and equipment	2,578,216	2,204,324
Derivatives	0	79,726
Deferred loan costs, net	31,088	25,933
Investment in equity method investee	40,871	5,913
Other assets, net	242	255
Total assets	3,181,038	2,623,760
Current liabilities:	'	'
Accounts payable	18,387	16,002
Accrued payable - affiliates	20,104	3,489
Undistributed revenue and royalties	44,122	35,124
Accrued capital expenditures	129,674	116,328
Derivatives	44,374	10,795
Other current liabilities	78,007	72,231
Total current liabilities	334,668	253,969
Long-term debt	1,501,419	1,051,538
Derivatives	36,317	2,680
Deferred income taxes	15,980	16,293
Asset retirement obligations	22,975	21,478
Other noncurrent liabilities	5,370	5,546
Total liabilities	1,916,729	1,351,504
Commitments and contingencies	'	'
Stockholders' equity:	'	'
Preferred stock, $0.01 par value, 50,000,000 shares authorized and zero issued at June 30, 2014 and December 31, 2013	0	0
Common stock, $0.01 par value, 450,000,000 shares authorized, and 143,737,390 and 142,671,436 issued, at June 30, 2014 and December 31, 2013, respectively	1,437	1,427
Additional paid-in capital	1,294,964	1,283,809
Accumulated deficit	-32,092	-12,980
Total stockholders’ equity	1,264,309	1,272,256
Total liabilities and stockholders’ equity	$3,181,038	$2,623,760

Consolidated_balance_sheets_Pa

Consolidated balance sheets (Parenthetical) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Statement of Financial Position [Abstract]	'	'
Preferred stock, par value (in dollars per share)	$0.01	$0.01
Preferred stock, shares authorized	50,000,000	50,000,000
Preferred stock, shares issued	0	0
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized	450,000,000	450,000,000
Common stock issued	143,737,390	142,671,436

Consolidated_statements_of_ope

Consolidated statements of operations (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Revenues:	'	'	'	'
Oil and natural gas sales	$182,872	$177,048	$356,086	$340,673
Midstream service revenue	172	248	268	328
Total revenues	183,044	177,296	356,354	341,001
Costs and expenses:	'	'	'	'
Lease operating expenses	20,179	22,185	41,964	44,627
Production and ad valorem taxes	13,160	9,722	25,610	21,167
Midstream service expense	1,526	697	2,371	1,479
Natural gas volume commitment - affiliates	588	139	1,104	139
General and administrative	29,552	20,495	57,206	40,129
Accretion of asset retirement obligations	422	410	837	804
Depletion, depreciation and amortization	53,056	66,234	102,663	130,737
Total costs and expenses	118,483	119,882	231,755	239,082
Operating income	64,561	57,414	124,599	101,919
Non-operating income (expense):	'	'	'	'
Commodity derivatives, net	-63,125	23,975	-94,237	7,121
Interest rate derivatives, net	0	-9	0	-15
Loss from equity method investee	-41	-49	-25	-113
Interest expense	-30,657	-25,943	-59,643	-51,292
Interest and other income	194	12	277	27
Write-off of deferred loan costs	0	0	-124	0
Loss on disposal of assets, net	-205	-59	-226	-59
Non-operating expense, net	-93,834	-2,073	-153,978	-44,331
Income (loss) from continuing operations before income taxes	-29,273	55,341	-29,379	57,588
Income tax benefit (expense):	'	'	'	'
Deferred	10,374	-20,047	10,267	-21,157
Total income tax benefit (expense)	10,374	-20,047	10,267	-21,157
Income (loss) from continuing operations	-18,899	35,294	-19,112	36,431
Income from discontinued operations, net of tax	0	518	0	790
Net income (loss)	($18,899)	$35,812	($19,112)	$37,221
Basic net income per share:	'	'	'	'
Income (loss) from continuing operations, per basic share	($0.13)	$0.28	($0.14)	$0.29
Income from discontinued operations, net of tax, per basic share	$0	$0	$0	$0.01
Net income (loss), basic (in dollars per share)	($0.13)	$0.28	($0.14)	$0.30
Diluted net income per share	'	'	'	'
Income (loss) from continuing operations, per diluted share	($0.13)	$0.27	($0.14)	$0.28
Income from discontinued operations, net of tax, per diluted share	$0	$0	$0	$0.01
Net income (loss), diluted (in dollars per share)	($0.13)	$0.27	($0.14)	$0.29
Weighted average common shares outstanding:	'	'	'	'
Basic (in shares)	141,298	127,362	141,183	127,281
Diluted (in shares)	141,298	129,384	141,183	129,119

Consolidated_statement_of_stoc

Consolidated statement of stockholders' equity (USD $)	Total	Common Stock	Additional paid-in capital	Treasury Stock (at cost)	Accumulated deficit
In Thousands, except Share data, unless otherwise specified
Balance, beginning of period at Dec. 31, 2013	$1,272,256	$1,427	$1,283,809	$0	($12,980)
Balance, beginning of period (in shares) at Dec. 31, 2013	'	142,671,000	'	0	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'
Restricted stock awards	'	12	-12	'	'
Restricted stock awards (in shares)	'	1,161,000	'	'	'
Restricted stock forfeitures	'	-1	1	'	'
Restricted stock forfeitures (in shares)	'	-50,000	'	'	'
Vested restricted stock exchanged for tax withholding	-3,556	'	'	-3,556	'
Vested restricted stock exchanged for tax withholding (in shares)	'	'	'	136,000	'
Retirement of treasury stock	'	-2	-3,554	3,556	'
Retirement of treasury stock (in shares)	'	-136,000	'	-136,000	'
Exercise of employee stock options	1,829	1	1,828	'	'
Exercise of employee stock options (in shares)	'	91,000	'	'	'
Stock-based compensation	12,892	'	12,892	'	'
Net loss	-19,112	'	'	'	-19,112
Balance, end of period (in shares)	'	143,737,000	'	0	'
Balance, end of period at Jun. 30, 2014	$1,264,309	$1,437	$1,294,964	$0	($32,092)

Consolidated_statements_of_cas

Consolidated statements of cash flows (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Cash flows from operating activities:	'	'
Net income (loss)	($19,112)	$37,221
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Deferred income tax (benefit) expense	-10,267	21,601
Depletion, depreciation and amortization	102,663	131,364
Non-cash stock-based compensation, net of amount capitalized	10,725	7,680
Accretion of asset retirement obligations	837	804
(Gain) loss on derivatives, net	94,237	-7,106
Cash settlements (paid) received for matured derivatives, net	-5,851	4,657
Cash settlements received for early terminations of derivatives, net	76,660	0
Change in net present value of deferred premiums paid for derivatives	120	282
Cash premiums paid for derivatives	-3,779	-5,249
Amortization of deferred loan costs	2,512	2,627
Write-off of deferred loan costs	124	0
Other	145	74
Increase in accounts receivable	-18,402	-6,591
Increase in other assets	-7,749	-894
Increase (decrease) in accounts payable	2,385	-16,568
Increase in undistributed revenues and royalties	8,998	4,327
Increase in other accrued liabilities	3,058	1,484
Increase in other noncurrent liabilities	1,644	422
Increase in fair value of performance unit awards	1,151	2,155
Net cash provided by operating activities	240,099	178,290
Capital expenditures:	'	'
Acquisition of oil and natural gas properties	-6,493	0
Acquisition of mineral interests	-7,305	0
Investment in equity method investee	-19,471	-3,287
Oil and natural gas properties	-412,211	-375,901
Midstream service assets	-25,909	-8,302
Other fixed assets	-8,436	-8,803
Proceeds from dispositions of capital assets, net of costs	597	0
Net cash used in investing activities	-479,228	-396,293
Cash flows from financing activities:	'	'
Borrowings on revolving credit facilities	0	230,000
Issuance of January 2022 Notes	450,000	0
Purchase of treasury stock	-3,556	-919
Proceeds from exercise of employee stock options	1,829	0
Payments for loan costs	-7,791	-714
Net cash provided by financing activities	440,482	228,367
Net increase in cash and cash equivalents	201,353	10,364
Cash and cash equivalents at beginning of period	198,153	33,224
Cash and cash equivalents at end of period	$399,506	$43,588

Organization

Organization	6 Months Ended
	Jun. 30, 2014
Organization, Consolidation and Presentation of Financial Statements [Abstract]	'
Organization	'
	Organization
	Laredo Petroleum, Inc. ("Laredo" and formerly known as Laredo Petroleum Holdings, Inc.), together with its subsidiary, Laredo Midstream Services, LLC ("Laredo Midstream"), is an independent energy company focused on the exploration, development and acquisition of oil and natural gas properties primarily in the Permian Basin in West Texas. In these notes, the "Company," (i) when used in the present tense, prospectively or as of December 31, 2013, refers to Laredo and Laredo Midstream collectively; (ii) when used for historical periods prior to December 31, 2013, refers to Laredo and its subsidiaries, collectively. All amounts, dollars and percentages presented in these unaudited consolidated financial statements and the related notes are rounded and therefore approximate.

Basis_of_presentation_and_sign

Basis of presentation and significant accounting policies	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Basis of presentation and significant accounting policies	'
	Basis of presentation and significant accounting policies
	1.    Basis of presentation
	The accompanying unaudited consolidated financial statements were derived from the historical accounting records of the Company and reflect the historical financial position, results of operations and cash flows for the periods described herein. The Company uses the equity method of accounting to record its net interests when the Company holds 20% to 50% of the voting rights and/or has the ability to exercise significant influence but does not control the entity. Under the equity method, the Company's proportionate share of the investee's net income (loss) is included in the unaudited consolidated statements of operations. See Note L for additional discussion of the Company's equity method investment. The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). All material intercompany transactions and account balances have been eliminated in the consolidation of accounts. The Company reports as one business segment, which explores for, develops and produces oil and natural gas. Unless otherwise indicated, the information in these notes relate to the Company’s continuing operations.
	The accompanying consolidated financial statements have not been audited by the Company’s independent registered public accounting firm, except that the consolidated balance sheet at December 31, 2013 is derived from audited consolidated financial statements. In the opinion of management, the accompanying unaudited consolidated financial statements reflect all necessary adjustments to present fairly the Company’s financial position as of June 30, 2014, results of operations for the three and six months ended June 30, 2014 and 2013 and cash flows for the six months ended June 30, 2014 and 2013.
	Certain disclosures have been condensed or omitted from these unaudited consolidated financial statements. Accordingly, these unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in Laredo’s Annual Report on Form 10-K for the year ended December 31, 2013 (the "2013 Annual Report").
	2.    Use of estimates in the preparation of interim unaudited consolidated financial statements
	The preparation of the accompanying unaudited consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Although management believes these estimates are reasonable, actual results could differ from these estimates. The interim results reflected in the unaudited consolidated financial statements are not necessarily indicative of the results that may be expected for other interim periods or for the full year.
	Significant estimates include, but are not limited to, (i) estimates of the Company’s reserves of oil and natural gas, (ii) future cash flows from oil and natural gas properties, (iii) depletion, depreciation and amortization, (iv) asset retirement obligations, (v) stock-based compensation, (vi) deferred income taxes, (vii) fair value of assets acquired and liabilities assumed in an acquisition and (viii) fair values of commodity derivatives, interest rate derivatives, commodity deferred premiums, performance share awards and performance unit awards. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment. Such estimates and assumptions are adjusted when facts and circumstances dictate. Illiquid credit markets and volatile equity and energy markets have combined to increase the uncertainty inherent in such estimates and assumptions. Management believes its estimates and assumptions to be reasonable under the circumstances. As future events and their effects cannot be determined with precision, actual values and results could differ from these estimates. Any changes in estimates resulting from future changes in the economic environment will be reflected in the financial statements in future periods.
	3.    Reclassifications
	Certain amounts in the accompanying unaudited consolidated financial statements have been reclassified to conform to the 2014 presentation. These reclassifications had no impact to previously reported net income (loss), total stockholders' equity or cash flows.
	4.    Treasury stock
	The Company acquires treasury stock, which is recorded at cost, to satisfy tax withholding obligations for Laredo's employees that arise upon the lapse of restrictions on restricted stock. Upon acquisition, this treasury stock is retired.
	5.    Accounts receivable
	The Company sells oil and natural gas to various customers and participates with other parties in the drilling, completion and operation of oil and natural gas wells. Joint interest and oil and natural gas sales receivables related to these operations are generally unsecured. Accounts receivable for joint interest billings are recorded as amounts billed to customers less an allowance for doubtful accounts.
	Amounts are considered past due after 30 days. The Company determines joint interest operations accounts receivable allowances based on management’s assessment of the creditworthiness of the joint interest owners. Additionally, as the operator of the majority of its wells, the Company has the ability to realize the receivables through netting of anticipated future production revenues. The Company maintains an allowance for doubtful accounts for estimated losses inherent in its accounts receivable portfolio. In establishing the required allowance, management considers historical losses, current receivables aging, and existing industry and economic data. The Company reviews its allowance for doubtful accounts quarterly. Past due balances greater than 90 days and over a specified amount are reviewed individually for collectability. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is remote.
	Accounts receivable consist of the following components for the periods presented:
	(in thousands)		30-Jun-14			31-Dec-13
	Oil and natural gas sales		$	68,476		$	57,647
	Joint operations, net(1)		23,274			16,629
	Other		3,970			3,042
	Total		$	95,720		$	77,318
	______________________________________________________________________________
	-1	Accounts receivable for joint operations are presented net of an allowance for doubtful accounts of $0.7 million as of June 30, 2014 and December 31, 2013.
	6.    Derivatives
	The Company uses derivatives to reduce its exposure to fluctuations in the prices of oil and natural gas. By removing a significant portion of the price volatility associated with future production, the Company expects to mitigate, but not eliminate, the potential effects of variability in cash flows from operations due to fluctuations in commodity prices. These transactions are primarily in the form of collars, swaps, puts and basis swaps. In addition, in prior periods the Company entered into derivative contracts in the form of interest rate derivatives to minimize the effects of fluctuations in interest rates.
	Derivatives are recorded at fair value and are included on the unaudited consolidated balance sheets as assets or liabilities. The Company nets the fair value of derivatives by counterparty in the accompanying unaudited consolidated balance sheets where the right of offset exists. The Company determines the fair value of its derivatives by utilizing pricing models for substantially similar instruments. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties.
	The Company’s derivatives were not designated as hedges for accounting purposes for any of the periods presented. Accordingly, the changes in fair value are recognized in the unaudited consolidated statements of operations in the period of change. Gains and losses on derivatives are included in cash flows from operating activities (see Note G).
	7.    Property and equipment
	The following table sets forth the Company’s property and equipment for the periods presented:
	(in thousands)		30-Jun-14			31-Dec-13
	Proved oil and natural gas properties		$	3,698,051		$	3,276,578
	Less accumulated depletion and impairment		(1,448,013		)	(1,349,315		)
	Proved oil and natural gas properties, net		2,250,038			1,927,263
	Unproved properties not being amortized		225,056			208,085
	Midstream service assets		80,265			51,704
	Less accumulated depreciation		(6,007		)	(4,404		)
	Midstream service assets, net		74,258			47,300
	Other fixed assets		42,016			32,832
	Less accumulated depreciation and amortization		(13,152		)	(11,156		)
	Other fixed assets, net		28,864			21,676
	Total property and equipment, net		$	2,578,216		$	2,204,324
	For the three months ended June 30, 2014 and 2013, depletion expense was $19.55 per barrel of oil equivalent ("BOE") and $20.08 per BOE, respectively. For the six months ended June 30, 2014 and 2013, depletion expense was $19.58 per BOE and $20.16 per BOE, respectively.
	8.    Deferred loan costs
	Loan origination fees, which are stated at cost, net of amortization, are amortized over the life of the respective debt agreements utilizing the effective interest and straight-line methods. The Company capitalized $7.8 million of deferred loan costs during the six months ended June 30, 2014 mainly as a result of the issuance of the January 2022 Notes (as defined below). The Company capitalized $0.7 million of deferred loan costs during the six months ended June 30, 2013. The Company had total deferred loan costs of $31.1 million and $25.9 million, net of accumulated amortization of $16.7 million and $14.2 million, as of June 30, 2014 and December 31, 2013, respectively.
	As a result of changes in the borrowing base of the Senior Secured Credit Facility (as defined below) due to the issuance of the January 2022 Notes, the Company wrote-off $0.1 million in deferred loan costs during the six months ended June 30, 2014. No deferred loan costs were written-off during the six months ended June 30, 2013.
	Future amortization expense of deferred loan costs as of June 30, 2014 is as follows:
	(in thousands)
	Remaining 2014		$	2,627
	2015		5,295
	2016		5,361
	2017		5,432
	2018		5,222
	Thereafter		7,151
	Total		$	31,088
	9.    Other current liabilities
	Other current liabilities consist of the following components for the periods presented:
	(in thousands)		30-Jun-14			31-Dec-13
	Accrued interest payable		$	37,065		$	25,885
	Accrued compensation and benefits		11,804			16,711
	Lease operating expense payable		11,056			10,637
	Performance unit awards		2,971			—
	Asset retirement obligations		886			265
	Prepaid drilling liability		851			1,393
Other accrued liabilities		13,374			17,340
Total other current liabilities		$	78,007		$	72,231
10.    Asset retirement obligations
Asset retirement obligations associated with the retirement of tangible long-lived assets are recognized as a liability in the period in which they are incurred and become determinable. The associated asset retirement costs are part of the carrying amount of the long-lived asset. Subsequently, the asset retirement cost included in the carrying amount of the related long-lived asset is charged to expense through the depletion of the asset. Changes in the liability due to the passage of time are recognized as an increase in the carrying amount of the liability and as corresponding accretion expense.
The fair value of additions to the asset retirement obligation liability is measured using valuation techniques consistent with the income approach, which converts future cash flows into a single discounted amount. Significant inputs to the valuation include: (i) estimated plug and abandonment cost per well based on Company experience; (ii) estimated remaining life per well based on the reserve life per well; (iii) future inflation factors; and (iv) the Company's average credit adjusted risk free rate. Inherent in the fair value calculation of asset retirement obligations are numerous assumptions and judgments including, in addition to those noted above, the ultimate settlement of these amounts, the ultimate timing of such settlement and changes in legal, regulatory, environmental and political environments. To the extent future revisions to these assumptions impact the fair value of the existing asset retirement obligation liability, a corresponding adjustment will be made to the asset balance.
The Company is obligated by contractual and regulatory requirements to remove certain pipeline and gas gathering assets and perform other remediation of the sites where such pipeline and gas gathering assets are located upon the retirement of those assets. However, the fair value of the asset retirement obligation cannot currently be reasonably estimated because the settlement dates are indeterminate. The Company will record an asset retirement obligation for pipeline and gas gathering assets in the periods in which settlement dates become reasonably determinable.
The following reconciles the Company’s asset retirement obligation liability for continuing and discontinued operations for the periods presented:
(in thousands)		Six months ended June 30, 2014			Year ended December 31, 2013
Liability at beginning of period		$	21,743		$	21,505
Liabilities added due to acquisitions, drilling and other		1,591			2,709
Accretion expense		837			1,475
Liabilities settled upon plugging and abandonment		(310		)	(226		)
Liabilities removed due to Anadarko Basin Sale(1)		—			(7,801		)
Revision of estimates		—			4,081
Liability at end of period		$	23,861		$	21,743
______________________________________________________________________________
-1	See Note C.3 for definition of and information regarding the Anadarko Basin Sale.
11.    Fair value measurements
The carrying amounts reported in the unaudited consolidated balance sheets for cash and cash equivalents, accounts receivable, prepaid expenses, accounts payable, undistributed revenue and royalties and other accrued liabilities approximate their fair values. See Note D for fair value disclosures related to the Company’s debt obligations. The Company carries its derivatives at fair value. See Note G and Note H for details regarding the fair value of the Company’s derivatives.
12.    Compensation awards
Stock-based compensation expense is recognized in "General and administrative" in the Company’s unaudited consolidated statements of operations over the awards’ vesting periods and is based on their grant date fair value. The Company utilizes the closing stock price on the date of grant, less an expected forfeiture rate, to determine the fair value of service vesting restricted stock awards and a Black-Scholes pricing model to determine the fair values of service vesting restricted stock option awards. The Company utilizes a Monte Carlo simulation prepared by an independent third party to determine the fair values of the performance share awards and performance unit awards. On January 1, 2014, the Company began capitalizing a portion of stock-based compensation for employees who are directly involved in the acquisition and exploration of its properties into the full-cost pool. Capitalized stock-based compensation is included as an addition to "Oil and natural gas properties" in the unaudited consolidated balance sheets. See Note E for further discussion regarding the restricted stock awards, restricted stock option awards, performance share awards and performance unit awards.
13.    Environmental
The Company is subject to extensive federal, state and local environmental laws and regulations. These laws, among other things, regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. All environmental expenditures, including expenditures that relate to an existing condition caused by past operations and that have no future economic benefits, are expensed in the period in which they occur. Liabilities for expenditures of a non-capital nature are recorded when environmental assessment or remediation is probable and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments is fixed and readily determinable. Management believes no materially significant liabilities of this nature existed as of June 30, 2014 or December 31, 2013.
14.    Supplemental cash flow disclosure information and non-cash investing and financing information
The following table summarizes the supplemental disclosure of cash flow information for the periods presented:
		Six months ended June 30,
(in thousands)		2014			2013
Cash paid for interest, net of $0 and $212 of capitalized interest, respectively		$	46,140		$	48,348
The following presents the supplemental disclosure of non-cash investing and financing information for the periods presented:
		Six months ended June 30,
(in thousands)		2014			2013
Change in accrued capital expenditures		$	13,346		$	(33,892	)
Capitalized asset retirement cost		$	1,591		$	1,262
Capitalized stock-based compensation		$	2,167		$	—
Restricted deposits on pending sale		$	—		$	44,000

Acquisition_and_divestiture_No

Acquisition and divestiture (Notes)	6 Months Ended
	Jun. 30, 2014
Acquisition and Divestitures [Abstract]	'
Acquisition and divestiture	'
	Acquisitions and divestiture
	1.    2014 acquisition of mineral interests
	On February 25, 2014, the Company completed the acquisition of the mineral interests underlying 278 net acres in Glasscock County, Texas in the Permian Basin for $7.3 million. These mineral interests entitle the Company to receive royalty interests on all production from these acreages with no additional future capital or operating expenses required. As such, the acquisition was accounted for as an acquisition of assets.
	2.    2014 acquisitions of proved and unproved oil and natural gas properties
	The Company accounts for acquisitions of proved and unproved oil and natural gas properties under the acquisition method of accounting. Accordingly, the Company conducts assessments of net assets acquired and recognizes amounts for identifiable assets acquired and liabilities assumed at the estimated acquisition date fair values, while transaction and integration costs associated with the acquisitions are expensed as incurred.
	The Company makes various assumptions in estimating the fair values of assets acquired and liabilities assumed. The most significant assumptions relate to the estimated fair values of proved and unproved oil and natural gas properties. The fair values of these properties are measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a market-based weighted average cost of capital rate. The market-based weighted average cost of capital rate is subject to additional project-specific risk factors. To compensate for the inherent risk of estimating the value of the unproved properties, the discounted future net revenues of probable and possible reserves are reduced by additional risk-weighting factors.
	On June 11, 2014, the Company completed the acquisition of proved and unproved oil and natural gas properties, totaling 460 net acres, located in Reagan County, Texas for $4.7 million, net of closing adjustments. On June 23, 2014, the Company completed the acquisition of proved and unproved oil and natural gas properties, totaling 24 net acres, located in Glasscock County, Texas for $1.8 million. The results of operations prior to June 2014 do not include results from these acquisitions.
	3.    2013 divestiture of Anadarko assets
	On August 1, 2013, the Company completed the sale of its oil and natural gas properties, associated pipeline assets and various other related property and equipment in the Anadarko Granite Wash, Central Texas Panhandle and the Eastern Anadarko Basin (the "Anadarko Basin Sale") to certain affiliates of EnerVest, Ltd. (collectively, "EnerVest") and certain other third parties in connection with the exercise of such third parties' preferential rights associated with the oil and natural gas assets. The purchase price consisted of $400.0 million from EnerVest and $38.0 million from the third parties. $388.0 million of the purchase price, excluding closing adjustments, was allocated to oil and natural gas properties pursuant to the rules governing full cost accounting. After transaction costs and adjustments at closing reflecting an economic effective date of April 1, 2013, the net proceeds were $428.3 million, net of working capital adjustments.
	Effective at closing, the operations and cash flows of these properties were eliminated from the ongoing operations of the Company and the Company does not have continuing involvement in the operations of these properties. The results of operations of the oil and natural gas properties that are a component of the Anadarko Basin Sale are not presented as discontinued operations pursuant to the rules governing full cost accounting for oil and natural gas properties.
	The following table presents revenues and operating expenses of the oil and natural gas properties that are a component of the Anadarko Basin Sale included in the accompanying unaudited consolidated statements of operations for the periods presented:
	(in thousands)		Three months ended June 30, 2013			Six months ended June 30, 2013
	Revenues		$	26,135		$	49,737
	Expenses(1)		19,918			40,837
	_________________________________________________________________________
	-1	Expenses include lease operating expense, production and ad valorem tax expense, accretion expense and depletion, depreciation and amortization expense.
	For the three and six months ended June 30, 2013, the results of operations of the associated pipeline assets and various other related property and equipment ("Pipeline Assets") are presented as results of discontinued operations, net of tax in these unaudited consolidated financial statements. As a result of the sale of the Pipeline Assets, a gain of $3.2 million was recognized in the consolidated statements of operations for the year ended December 31, 2013 in the line item "Loss on disposal of assets, net."
	The following represents operating results from discontinued operations for the periods presented:
	(in thousands)		Three months ended June 30, 2013			Six months ended June 30, 2013
	Revenues:
	Midstream service revenue		$	1,478		$	3,310
	Total revenues from discontinued operations		1,478			3,310
	Cost and expenses:
	Midstream service expense		669			1,449
	Depletion, depreciation and amortization		—			627
	Total costs and expenses from discontinued operations		669			2,076
	Income from discontinued operations before income tax		809			1,234
	Income tax expense		(291		)	(444		)
	Income from discontinued operations		$	518		$	790

Debt

Debt	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Debt
	1.    Interest expense
	The following amounts have been incurred and charged to interest expense for the periods presented:
			Three months ended June 30,					Six months ended June 30,
	(in thousands)		2014		2013			2014		2013
	Cash payments for interest		$	19,291	$	20,816		$	46,140	$	48,560
	Amortization of deferred loan costs and other adjustments		1,194		1,320			2,323		2,624
	Change in accrued interest		10,172		3,924			11,180		320
	Interest costs incurred		30,657		26,060			59,643		51,504
	Less capitalized interest		—		(117		)	—		(212		)
	Total interest expense		$	30,657	$	25,943		$	59,643	$	51,292
	2.   January 2022 Notes
	On January 23, 2014, the Company completed an offering of $450.0 million in aggregate principal amount of 5 5/8% senior unsecured notes due 2022 (the "January 2022 Notes"), and entered into an Indenture (the "Indenture") among Laredo, Laredo Midstream as guarantor and Wells Fargo Bank, National Association, as trustee. The January 2022 Notes will mature on January 15, 2022 with interest accruing at a rate of 5 5/8% per annum and payable semi-annually in cash in arrears on January 15 and July 15 of each year, commencing July 15, 2014. The January 2022 Notes are guaranteed on a senior unsecured basis by Laredo Midstream and certain of the Company’s future restricted subsidiaries.
	The January 2022 Notes were issued pursuant to the Indenture in a transaction exempt from the registration requirements of the Securities Act of 1933, as amended (the "Securities Act"). The January 2022 Notes were offered and sold only to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside the United States pursuant to Regulation S under the Securities Act. The Company received net proceeds of $442.2 million from the offering, after deducting the initial purchasers’ discount and the estimated outstanding offering expenses. The Company is using the net proceeds of the offering for general working capital purposes.
	The Company may redeem, at its option, all or part of the January 2022 Notes at any time on and after January 15, 2017, at the applicable redemption price plus accrued and unpaid interest to the date of redemption. In addition, the Company may redeem, at its option, all or part of the January 2022 Notes at any time prior to January 15, 2017 at a redemption price equal to 100% of the principal amount of the January 2022 Notes redeemed plus the applicable premium and accrued and unpaid interest and additional interest, if any, to the date of redemption. Further, before January 15, 2017, the Company may on one or more occasions redeem up to 35% of the aggregate principal amount of the January 2022 Notes in an amount not exceeding the net proceeds from one or more private or public equity offerings at a redemption price of 105.625% of the principal amount of the January 2022 Notes, plus accrued and unpaid interest to the date of redemption, if at least 65% of the aggregate principal amount of the January 2022 Notes remains outstanding immediately after such redemption and the redemption occurs within 180 days of the closing date of each such equity offering. If a change of control occurs prior to January 15, 2015, the Company may redeem all, but not less than all, of the January 2022 Notes at a redemption price equal to 110% of the principal amount of the January 2022 Notes plus any accrued and unpaid interest to the date of redemption.
	In connection with the closing of the offering of the January 2022 Notes, the Company entered into a registration rights agreement with the several initial purchasers named in the registration rights agreement, pursuant to which the Company filed a registration statement with the Securities and Exchange Commission ("SEC") that became effective with respect to an offer to exchange the January 2022 Notes for substantially identical notes (other than with respect to restrictions on transfer or any increase in annual interest rate) that are registered under the Securities Act. The offer to exchange the January 2022 Notes for substantially identical notes registered under the Securities Act was launched on April 22, 2014 with all notes exchanged on May 22, 2014.
	3.    May 2022 Notes
	On April 27, 2012, the Company completed an offering of $500.0 million in aggregate principal amount of 7 3/8% senior unsecured notes due 2022 (the "May 2022 Notes"). The May 2022 Notes will mature on May 1, 2022 and bear an interest rate of 7 3/8% per annum, payable semi-annually, in cash in arrears on May 1 and November 1 of each year, commencing November 1, 2012. The May 2022 Notes are fully and unconditionally guaranteed on a senior unsecured basis by Laredo Midstream and certain of the Company’s future restricted subsidiaries.
	4.    2019 Notes
	On January 20, 2011, the Company completed an offering of $350.0 million 9 1/2% senior unsecured notes due 2019 (the "January Notes") and on October 19, 2011, the Company completed an offering of an additional $200.0 million 9 1/2% senior unsecured notes due 2019 (the "October Notes" and together with the January Notes, the "2019 Notes"). The 2019 Notes will mature on February 15, 2019 and bear an interest rate of 9 1/2% per annum, payable semi-annually, in cash in arrears on February 15 and August 15 of each year. The 2019 Notes are fully and unconditionally guaranteed on a senior unsecured basis by Laredo Midstream and certain of the Company’s future restricted subsidiaries.
	5.    Senior Secured Credit Facility
	As of June 30, 2014, the Fourth Amended and Restated Credit Agreement (as amended, the "Senior Secured Credit Facility"), which matures on November 4, 2018, had a borrowing base of $1.0 billion and an aggregate elected commitment of $825.0 million with no amounts outstanding. It contains both financial and non-financial covenants, all of which the Company was in compliance with as of June 30, 2014. Laredo is required to pay an annual commitment fee on the unused portion of the financial institutions' commitment of 0.375% to 0.5%, based on the ratio of outstanding revolving credit to the total commitment under the Senior Secured Credit Facility. Additionally, the Senior Secured Credit Facility provides for the issuance of letters of credit, limited to the lesser of total capacity or $20.0 million. On August 5, 2014, there were no amounts outstanding on the Senior Secured Credit Facility.
	6.    Fair value of debt
	The Company has not elected to account for its debt instruments at fair value. The following table presents the carrying amount and fair values of the Company’s debt instruments for the periods presented:
			30-Jun-14					31-Dec-13
	(in thousands)		Carrying		Fair			Carrying		Fair
			value		value			value		value
	2019 Notes(1)		$	551,419	$	599,500		$	551,538	$	615,313
	January 2022 Notes		450,000		465,750			—		—
	May 2022 Notes		500,000		561,250			500,000		549,375
	Total value of debt		$	1,501,419	$	1,626,500		$	1,051,538	$	1,164,688
	______________________________________________________________________________
	-1	The carrying value of the 2019 Notes includes the October Notes unamortized bond premium of $1.4 million and $1.5 million as of June 30, 2014 and December 31, 2013, respectively.
	The fair values of the debt outstanding on the 2019 Notes, the January 2022 Notes and the May 2022 Notes were determined using the June 30, 2014 and December 31, 2013 quoted market price (Level 1) for each respective instrument. See Note H for information about fair value hierarchy levels.

Employee_compensation

Employee compensation	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
Employee Compensation	'
	Employee compensation
	The Company has a Long-Term Incentive Plan (the "LTIP"), which provides for the granting of incentive awards in the form of restricted stock awards, restricted stock options awards, performance share awards, performance unit awards and other awards. The LTIP provides for the issuance of 10.0 million shares.
	The Company recognizes the fair value of stock-based compensation granted to employees and directors over the requisite service period as a charge against earnings, net of amounts capitalized. The Company's stock-based compensation awards are accounted for as equity instruments. Stock-based compensation is included in "General and administrative" in the unaudited consolidated statements of operations. On January 1, 2014, the Company began capitalizing a portion of stock-based compensation for employees who are directly involved in the acquisition, exploration and development of oil and natural gas properties into the full-cost pool. Capitalized stock-based compensation is included as an addition to "Oil and natural gas properties" in the unaudited consolidated balance sheets.
	1.    Restricted stock awards
	All restricted stock awards are treated as issued and outstanding in the accompanying unaudited consolidated financial statements. If an employee terminates employment prior to the restriction lapse date, the awarded shares are forfeited and canceled and are no longer considered issued and outstanding. If the employee's termination of employment is by reason of death or disability, all of the holder's restricted stock will automatically vest. Restricted stock awards granted to officers and employees vest in a variety of vesting schedules including (i) 20% at the grant date and then vest 20% annually thereafter; (ii) 33%, 33% and 34% per year beginning on the first anniversary date of the grant; (iii) 50% in year two and 50% in year three; (iv) fully on the first anniversary date of the grant and (v) fully on the third anniversary date of the grant. Restricted stock awards granted to non-employee directors vest fully on the first anniversary date of the grant.
	The following table reflects the outstanding restricted stock awards for the six months ended June 30, 2014:
	(in thousands, except for weighted-average grant date fair values)		Restricted			Weighted-average
			stock			grant date
			awards			fair value (per award)
	Outstanding at December 31, 2013		1,799			$	19.17
	Granted		1,161			$	25.75
	Forfeited		(50	)		$	22.62
	Vested(1)		(527	)		$	17.7
	Outstanding at June 30, 2014		2,383			$	22.64
	______________________________________________________________________________
	-1	The vesting of certain restricted stock awards could result in federal and state income tax expense or benefits related to the difference between the market price of the common stock at the date of vesting and the date of grant. For the three and six months ended June 30, 2014, the Company's recognized income tax expense related to the vesting of restricted stock awards was immaterial. The Company recognized income tax expense of $0.1 million and $0.4 million during the three and six months ended June 30, 2013, respectively, related to restricted stock awards, which were recorded as adjustments to deferred income taxes.
	The Company utilizes the closing stock price on the date of grant to determine the fair value of service vesting restricted stock awards. As of June 30, 2014, unrecognized stock-based compensation related to the restricted stock awards was $39.5 million. Such cost is expected to be recognized over a weighted-average period of 1.91 years.
	2.    Restricted stock option awards
	Restricted stock option awards granted under the LTIP vest and are exercisable in four equal installments on each of the four anniversaries of the date of the grant. The following table reflects the stock option award activity for the six months ended June 30, 2014:
	(in thousands, except for weighted-average exercise price and contractual term)		Restricted			Weighted-average			Weighted-average
			stock option			exercise price			remaining contractual term
			awards			(per option)			(years)
	Outstanding at December 31, 2013		1,229			$	19.32		8.82
	Granted		336			$	25.6		9.66
	Exercised(1)		(91	)		$	20.02		8.22
	Expired or canceled		—			$	—		—
	Forfeited		(13	)		$	19.61		—
	Outstanding at June 30, 2014		1,461			$	20.72		8.64
	Vested and exercisable at end of period(2)		355			$	20.35		8.17
	Vested, exercisable, and expected to vest at end of period(3)		1,428			$	20.71		8.64
	_____________________________________________________________________________
	-1	The exercise of stock option awards could result in federal and state income tax expense or benefits related to the difference between the fair value of the stock option at the date of grant and the intrinsic value of the stock option when exercised. The Company recognized income tax expense of $0.1 million and $0.2 million during the three and six months ended June 30, 2014, respectively, related to stock options, which were recorded as adjustments to deferred income taxes. No stock options were exercised during the three and six months ended June 30, 2013.
	-2	The aggregate intrinsic value of vested and exercisable options at June 30, 2014 was $3.8 million.
	-3	The aggregate intrinsic value of vested, exercisable and expected to vest options at June 30, 2014 was $14.7 million.
	The Company utilizes the Black-Scholes option pricing model to determine the fair values of restricted stock option awards and is recognizing the associated expense on a straight-line basis over the four-year requisite service period of the awards. Determining the fair value of equity-based awards requires judgment, including estimating the expected term that stock option awards will be outstanding prior to exercise and the associated volatility. As of June 30, 2014 unrecognized stock-based compensation related to the restricted option awards was $10.7 million. Such cost is expected to be recognized over a weighted-average period of 2.79 years.
	The assumptions used to estimate the fair value of restricted stock options granted on February 27, 2014 are as follows:
	Risk-free interest rate(1)	1.88		%
	Expected option life(2)	6.25 years
	Expected volatility(3)	53.21		%
	Fair value per stock option	$	13.41
	______________________________________________________________________________
	-1	U.S. Treasury yields as of the grant date were utilized for the risk-free interest rate assumption, matching the treasury yield terms to the expected life of the option.
	-2	As the Company had limited exercise history at the time of valuation relating to terminations and modifications, expected option life assumptions were developed using the simplified method in accordance with GAAP.
	-3	The Company utilized a peer historical look-back, which was weighted with the Company’s own volatility, in order to develop the expected volatility.
	In accordance with the LTIP and stock option agreement, the options granted will become exercisable in accordance with the following schedule based upon the number of full years of the optionee's continuous employment or service with the Company, following the date of grant:
	Full years of continuous employment		Incremental percentage of			Cumulative percentage of
			option exercisable			option exercisable
	Less than one		—	%		—	%
	One		25	%		25	%
	Two		25	%		50	%
	Three		25	%		75	%
	Four		25	%		100	%
	No shares of common stock may be purchased unless the optionee has remained in continuous employment with the Company for one year from the grant date. Unless terminated sooner, the option will expire if and to the extent it is not exercised within 10 years from the grant date. The unvested portion of a stock option award shall expire upon termination of employment, and the vested portion of a stock option award shall remain exercisable for (i) one year following termination of employment by reason of the holder's death or disability, but not later than the expiration of the option period, or (ii) 90 days following termination of employment for any reason other than the holder's death or disability, and other than the holder's termination of employment for cause. Both the unvested and the vested but unexercised portion of a stock option award shall expire upon the termination of the option holder's employment or service by the Company for cause.
	3.    Performance share awards
	The Company performance share awards granted to management on February 27, 2014 ("Performance Share Awards") are subject to a combination of market and service vesting criteria. A Monte Carlo simulation prepared by an independent third party was utilized in order to determine the fair value of these awards at the date of grant. The Company has determined the performance share awards are equity awards and is recognizing the associated expense on a straight-line basis over the three-year requisite service period of the awards. These awards will be settled in stock at the end of the requisite service period based on the achievement of certain performance criteria.
	The Performance Share Awards have a performance period of January 1, 2014 to December 31, 2016 and any shares earned under such awards are expected to be issued in the first quarter of 2017 if the performance criteria is met. During the six months ended June 30, 2014, 271,667 performance shares were awarded and all remain outstanding at June 30, 2014. As of June 30, 2014, unrecognized stock-based compensation related to the Performance Share Awards was $6.7 million. Such cost is expected to be recognized over a weighted-average period of 2.66 years.
	The assumptions used to estimate the fair value of the Performance Share Awards are as follows:
	Risk-free rate(1)		0.63		%
	Dividend yield		—		%
	Expected volatility(2)		38.21		%
	Laredo stock closing price as of February 27, 2014		$	25.6
	Fair value per performance share		$	28.56
	______________________________________________________________________________
-1	The risk-free rate was derived using a zero-coupon yield derived from the Treasury Constant Maturities yield curve on the grant date.
-2	The Company utilized a peer historical look-back, weighted with the Company's own volatility, to develop the expected volatility.
4.    Stock-based compensation award expense
The following has been recorded to stock-based compensation expense for the periods presented:
		Three months ended June 30,							Six months ended June 30,
(in thousands)		2014				2013			2014			2013
Restricted stock award compensation		$	6,010			$	3,572		$	10,242		$	6,398
Restricted stock option award compensation		1,010				891			1,805			1,282
Restricted performance share unit award compensation		625				—			845			—
Total stock-based compensation		7,645				4,463			12,892			7,680
Less amounts capitalized in oil and natural gas properties		(1,249		)		—			(2,167		)	—
Net stock-based compensation expense		$	6,396			$	4,463		$	10,725		$	7,680
5.    Performance unit awards
The performance unit awards issued to management on February 15, 2013 ("2013 Performance Unit Awards") and on February 3, 2012 ("2012 Performance Unit Awards") are subject to a combination of market and service vesting criteria. A Monte Carlo simulation prepared by an independent third party is utilized in order to determine the fair value of these awards at the date of grant and to re-measure the fair value at the end of each reporting period until settlement in accordance with GAAP. The volatility criteria utilized in the Monte Carlo simulation is based on the volatility of the Company's stock price and the stock price volatilities of a group of peer companies that have been determined to be most representative of the Company’s expected volatility. These awards are accounted for as liability awards as they will be settled in cash at the end of the requisite service period based on the achievement of certain performance criteria. The liability and related compensation expense of these awards for each period is recognized by dividing the fair value of the total liability by the requisite service period and recording the pro rata share for the period for which service has already been provided. As there are inherent uncertainties related to these factors and the Company’s judgment in applying them to the fair value determinations, there is risk that the recorded performance unit compensation may not accurately reflect the amount ultimately earned by the members of management.
The 44,481 outstanding 2013 Performance Unit Awards have a performance period of January 1, 2013 to December 31, 2015 and are expected to be paid in the first quarter of 2016 if the performance criteria are met. The 27,381 outstanding 2012 performance units have a performance period of January 1, 2012 to December 31, 2014 and are expected to be paid in the first quarter of 2015 if the performance criteria are met.
Compensation expense for these awards amounted to $1.1 million and $2.1 million in the three months ended June 30, 2014 and 2013, respectively, and $1.2 million and $2.2 million in the six months ended June 30, 2014 and 2013, respectively, and is recognized in "General and administrative" in the Company’s unaudited consolidated statements of operations, and the corresponding liabilities are included in "Other current liabilities" and "Other noncurrent liabilities" in the unaudited consolidated balance sheets.

Income_taxes

Income taxes	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Income taxes	'
	Income taxes
	Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating losses and tax credit carry-forwards. Under this method, deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income (loss) in the period that includes the enactment date. A valuation allowance is established to reduce deferred tax assets if it is determined it is more likely than not that the related tax benefit will not be realized. On a quarterly basis, management evaluates the need for and adequacy of valuation allowances based on the expected realizability of the deferred tax assets and adjusts the amount of such allowances, if necessary.
	The Company evaluates uncertain tax positions for recognition and measurement in the consolidated financial statements. To recognize a tax position, the Company determines whether it is more likely than not that the tax position will be sustained upon examination, including resolution of any related appeals or litigation, based on the technical merits of the position. A tax position that meets the more-likely-than-not threshold is measured to determine the amount of benefit to be recognized in the consolidated financial statements. The amount of tax benefit recognized with respect to any tax position is measured as the largest amount of benefit that is greater than 50% likely of being realized upon settlement. The Company has no unrecognized tax benefits related to uncertain tax positions in the consolidated financial statements at June 30, 2014 or December 31, 2013.
	The Company is subject to corporate income taxes and the Texas franchise tax. Income tax (expense) benefit attributable to income (loss) from continuing operations for the periods presented consisted of the following:
		Three months ended June 30,						Six months ended June 30,
	(in thousands)	2014			2013			2014			2013
	Current taxes	$	—		$	—		$	—		$	—
	Deferred taxes	10,374			(20,047		)	10,267			(21,157		)
	Income tax benefit (expense)	$	10,374		$	(20,047	)	$	10,267		$	(21,157	)
	The following presents the comprehensive provision for income taxes for the periods presented:
		Three months ended June 30,						Six months ended June 30,
	(in thousands)	2014			2013			2014			2013
	Comprehensive provision for income taxes allocable to:
	Continuing operations	$	10,374		$	(20,047	)	$	10,267		$	(21,157	)
	Discontinued operations	—			(291		)	—			(444		)
	Comprehensive provision for income taxes	$	10,374		$	(20,338	)	$	10,267		$	(21,601	)
	Income tax benefit (expense) attributable to income (loss) from continuing operations before income taxes differed from amounts computed by applying the applicable federal income tax rate of 35% to pre-tax earnings as a result of the following:
		Three months ended June 30,						Six months ended June 30,
	(in thousands)	2014			2013			2014			2013
	Income tax benefit (expense) computed by applying the statutory rate	$	10,246		$	(18,816	)	$	10,283		$	(19,580	)
	State income tax, net of federal tax benefit and increase in valuation allowance	347			(551		)	1,634			(572		)
	Non-deductible stock-based compensation	(123		)	(164		)	(239		)	(339		)
	Stock-based compensation tax deficiency	(15		)	(120		)	(156		)	(411		)
	Change in deferred tax valuation allowance	(34		)	(20		)	(1,112		)	(29		)
	Other items	(47		)	(376		)	(143		)	(226		)
	Income tax benefit (expense)	$	10,374		$	(20,047	)	$	10,267		$	(21,157	)
	The effective rate on income (loss) from continuing operations before income taxes was 35% and 36% for the three months ended June 30, 2014 and 2013, respectively, and 35% and 37% for the six months ended June 30, 2014 and 2013, respectively. The Company's effective tax rate is affected by recurring permanent differences and by discrete items that may occur in any given year, but are not consistent from year to year.
	The impact of significant discrete items is separately recognized in the quarter in which they occur. During the three and six months ended June 30, 2014 and 2013, certain shares related to restricted stock awards vested at times when the Company's stock price was lower than the fair value of those shares at the time of grant. As a result, the income tax deduction related to such shares is less than the expense previously recognized for book purposes. During the three and six months ended June 30, 2014, certain restricted stock options were exercised. The income tax deduction related to the options intrinsic value was less than the expense previously recognized for book purposes. In accordance with GAAP, such shortfalls reduce additional paid-in capital to the extent windfall tax benefits have been previously recognized. However, the Company has not previously recognized any windfall tax benefits. Therefore, the tax impact of these shortfalls totaling $0.1 million and $0.2 million for the three and six months ended June 30, 2014, respectively, and $0.1 million and $0.4 million for the three and six months ended June 30, 2013, respectively, is included in income tax expense attributable to continuing operations for the period.
	Significant components of the Company’s deferred tax liabilities for the periods presented are as follows:
	(in thousands)	30-Jun-14			31-Dec-13
	Net operating loss carry-forward	$	310,579		$	284,890
	Oil and natural gas properties and equipment	(351,515		)	(278,735		)
	Derivatives	30,969			(30,859		)
	Stock-based compensation	7,807			6,578
	Accrued bonus	2,368			3,740
	Capitalized interest	2,411			2,099
	Other	(3,739		)	(240		)
	Gross deferred tax liability	(1,120		)	(12,527		)
	Valuation allowance	(1,272		)	(132		)
	Net deferred tax liability	$	(2,392	)	$	(12,659	)
	Net deferred tax assets and liabilities were classified in the unaudited consolidated balance sheets as follows for the periods presented:
	(in thousands)	30-Jun-14			31-Dec-13
	Deferred tax asset	$	13,588		$	3,634
	Deferred tax liability	(15,980		)	(16,293		)
	Net deferred tax liability	$	(2,392	)	$	(12,659	)
	The Company had federal net operating loss carry-forwards totaling $879.0 million and state of Oklahoma net operating loss carry-forwards totaling $112.8 million as of June 30, 2014. These carry-forwards begin expiring in 2026. As of June 30, 2014, the Company believes the federal and the state of Oklahoma net operating loss carry-forwards are fully realizable. The Company considered all available evidence, both positive and negative in determining whether, based on the weight of that evidence, a valuation allowance was needed on either the federal or the Oklahoma net operating loss carry-forwards. Such consideration included estimated future projected earnings based on existing reserves and projected future cash flows from its oil and natural gas reserves (including the timing of those cash flows), the reversal of deferred tax liabilities recorded as of June 30, 2014, the Company’s ability to capitalize intangible drilling costs, rather than expensing these costs in order to prevent an operating loss carry-forward from expiring unused, and future projections of Oklahoma sourced income.
	The Company's federal and state operating loss carry-forwards include windfall tax deductions from vestings of certain restricted stock awards and stock option exercises that were not recorded in the Company's income tax provision. The amount of windfall tax benefit recognized in additional paid-in capital is limited to the amount of benefit realized currently in income taxes payable. As of June 30, 2014, the Company had suspended additional paid-in capital credits of $4.2 million related to windfall tax deductions. Upon realization of the net operating loss carry-forwards from such windfall tax deductions, the Company would record a benefit of up to $4.2 million in additional paid-in capital.
	The Company maintains a valuation allowance to reduce certain deferred tax assets to amounts that are more likely than not to be realized. As of June 30, 2014, a full valuation allowance of $1.3 million was recorded against the deferred tax asset related to the Company’s charitable contribution carry-forward of $3.6 million.
	The Company's income tax returns for the years 2010 through 2013 remain open and subject to examination by federal tax authorities and/or the tax authorities in Oklahoma, Texas and Louisiana which are the jurisdictions where the Company has or had operations. Additionally, the statute of limitations for examination of federal net operating loss carry-forwards typically does not begin to run until the year the attribute is utilized in a tax return. The Company's 2011 federal income tax return is currently under examination.

Derivatives

Derivatives	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Derivatives	'
	Derivatives
	1.    Commodity derivatives
	The Company engages in derivative transactions such as collars, swaps, puts and basis swaps to hedge price risks due to unfavorable changes in oil and natural gas prices related to its oil and natural gas production. As of June 30, 2014, the Company had 48 open derivative contracts with financial institutions which extend from July 2014 to December 2016. None of these contracts were designated as hedges for accounting purposes. The contracts are recorded at fair value on the balance sheet and gains and losses are recognized in current period earnings. Gains and losses on derivatives are reported on the unaudited consolidated statements of operations in the respective "Gain (loss) on derivatives" amounts.
	Each collar transaction has an established price floor and ceiling. When the settlement price is below the price floor established by these collars, the Company receives an amount from its counterparty equal to the difference between the settlement price and the price floor multiplied by the hedged contract volume. When the settlement price is above the price ceiling established by these collars, the Company pays its counterparty an amount equal to the difference between the settlement price and the price ceiling multiplied by the hedged contract volume.
	Each swap transaction has an established fixed price. When the settlement price is below the fixed price, the counterparty pays the Company an amount equal to the difference between the settlement price and the fixed price multiplied by the hedged contract volume. When the settlement price is above the fixed price, the Company pays its counterparty an amount equal to the difference between the settlement price and the fixed price multiplied by the hedged contract volume.
	Each put transaction has an established floor price. The Company pays its counterparty a premium in order to enter into the put transaction. When the settlement price is below the floor price, the counterparty pays the Company an amount equal to the difference between the settlement price and the fixed price multiplied by the hedged contract volume. When the settlement price is above the floor price, the put option expires.
	The oil basis swap transaction has an established fixed basis differential. The Company's oil basis swap differential is between the West Texas Intermediate Midland Argus ("Midland Argus") index crude oil price and the West Texas Intermediate Argus Cushing ("WTI Argus") index crude oil price. When the WTI Argus price less the fixed basis differential is greater than the actual Midland Argus price, the difference multiplied by the hedged contract volume is paid to the Company by the counterparty. When the WTI Argus price less the fixed basis differential is less than the actual Midland Argus price, the difference multiplied by the hedged contract volume is paid by the Company to the counterparty.
	During the first quarter of 2014, the Company unwound a physical commodity contract and the associated oil basis swap financial derivative contract which hedged the differential between the Light Louisiana Sweet Argus and the Brent International Petroleum Exchange index oil prices. Prior to its unwind, the physical commodity contract qualified to be scoped out of mark-to-market accounting in accordance with the normal purchase and normal sale scope exemption. Once modified to settle financially in the unwind agreement, the contract ceased to qualify for the normal purchase and normal sale scope exemption, therefore requiring it to be marked-to-market. The Company received net proceeds of $76.7 million from the early termination of these contracts. The Company agreed to settle the contracts early due to the counterparty's decision to exit the physical commodity trading business.
	During the six months ended June 30, 2014, the Company entered into additional commodity contracts to hedge a portion of its estimated future production. The following table summarizes information about these additional commodity derivative contracts:
			Aggregate			Swap				Floor				Ceiling				Contract period
			volumes			price				price				price
	Oil (volumes in Bbl):
	Swap		288,000			$	103.56			$	—			$	—			July 2014 - December 2014
	Swap		672,000			$	96.56			$	—			$	—			January 2015 - December 2015
	Price collar		696,000			$	—			$	80			$	100.2			January 2016 - December 2016
	Swap		640,500			$	84.85			$	—			$	—			January 2016 - December 2016
	Swap		933,300			$	84.8			$	—			$	—			January 2016 - December 2016
	Natural gas (volumes in MMBtu):
	Swap(1)		5,508,000			$	4.32			$	—			$	—			March 2014 - December 2014
	Price collar(1)		3,797,500			$	—			$	4			$	5.5			May 2014 - December 2014
	Price collar(1)		20,440,000			$	—			$	3			$	5.95			January 2015 - December 2015
	Price collar(1)		18,666,000			$	—			$	3			$	5.6			January 2016 - December 2016
	______________________________________________________________________________
	(1)        These natural gas derivatives are settled based on the Inside FERC West Texas Waha index price for the calculation period.
	The following table summarizes open positions as of June 30, 2014, and represents, as of such date, derivatives in place through December 2016, on annual production volumes:
			Remaining Year				Year				Year
			2014				2015				2016
	Oil positions:
	Puts:
	Hedged volume (Bbl)		270,000				456,000				—
	Weighted-average price ($/Bbl)		$	75			$	75			$	—
	Swaps:
	Hedged volume (Bbl)		1,371,998				672,000				1,573,800
	Weighted-average price ($/Bbl)		$	96.35			$	96.56			$	84.82
	Collars:
	Hedged volume (Bbl)		1,473,000				6,557,020				2,556,000
	Weighted-average floor price ($/Bbl)		$	86.42			$	79.81			$	80
	Weighted-average ceiling price ($/Bbl)		$	104.89			$	95.4			$	93.77
	Basis swaps:
	Hedged volume(1) (Bbl)		1,104,000				—				—
	Weighted-average price(1) ($/Bbl)		$	(1.00	)		$	—			$	—
	Natural gas positions:
	Swaps:
	Hedged volume (MMBtu)		3,312,000				—				—
	Weighted-average price ($/MMBtu)		$	4.32			$	—			$	—
	Collars:
	Hedged volume (MMBtu)		7,652,000				28,600,000				18,666,000
	Weighted-average floor price ($/MMBtu)		$	3.37			$	3			$	3
	Weighted-average ceiling price ($/MMBtu)		$	5.5			$	5.96			$	5.6
	_______________________________________________________________________________
	-1	The associated oil basis swap derivative is settled based on the differential between the WTI Argus index oil price and the Midland Argus oil futures.
	The following represents cash settlements (paid) received for matured derivatives for the periods presented:
			Three months ended June 30,								Six months ended June 30,
	(in thousands)		2014				2013				2014				2013
	Commodity derivatives (paid) received		$	(4,420	)		$	1,086			$	(5,851	)		$	4,863
	Interest rate derivatives paid		—				(105		)		—				(206		)
	Cash settlements (paid) received for matured derivatives, net		$	(4,420	)		$	981			$	(5,851	)		$	4,657
	2.    Interest rate derivatives
	The Company is exposed to market risk for changes in interest rates related to any drawn amount on its Senior Secured Credit Facility. In prior periods, interest rate derivative agreements were used to manage a portion of the exposure related to changing interest rates by converting floating-rate debt to fixed-rate debt. If the London Interbank Offered Rate ("LIBOR") was lower than the fixed rate in the contract, the Company was required to pay the counterparties the difference, and conversely, the counterparties were required to pay the Company if LIBOR was higher than the fixed rate in the contract. The Company did not designate the interest rate derivatives as cash flow hedges; therefore, the changes in fair value of these instruments were recorded in current earnings. The Company had one interest rate swap and one interest rate cap outstanding for a notional amount of $100.0 million with fixed pay rates of 1.11% and 3.00%, respectively, until their expiration in September 2013. No interest rate derivatives were in place during the period ended June 30, 2014.
	3.    Balance sheet presentation
	The Company’s oil and natural gas commodity derivatives are presented on a net basis in "Derivatives" on the unaudited consolidated balance sheets.
	The following summarizes the fair value of derivatives outstanding on a gross basis as of June 30, 2014 and December 31, 2013, respectively:
	(in thousands)		30-Jun-14				31-Dec-13
Assets:
Commodity derivatives:
Oil derivatives		$	20,484			$	140,496
Natural gas derivatives		2,125				657
Total assets		$	22,609			$	141,153
Liabilities:
Commodity derivatives:
Oil derivatives(1)		$	96,749			$	56,818
Natural gas derivatives(2)		5,191				2,278
Total liabilities		$	101,940			$	59,096
Net derivative position		$	(79,331	)		$	82,057
______________________________________________________________________________
-1	The oil derivatives fair value includes a deferred premium liability of $7.9 million and $11.1 million as of June 30, 2014 and December 31, 2013, respectively.
-2	The natural gas derivatives fair value includes a deferred premium liability of $1.1 million and $1.6 million as of June 30, 2014 and December 31, 2013, respectively.
By using derivatives to hedge exposures to changes in commodity prices and interest rates, the Company exposes itself to credit risk and market risk. Market risk is the exposure to changes in the market price of oil and natural gas, which are subject to fluctuations from a variety of factors, including changes in supply and demand. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. When the fair value of a derivative contract is positive, the counterparty owes the Company, thereby creating credit risk. The Company’s counterparties are participants in the Senior Secured Credit Facility which is secured by the Company’s oil and natural gas reserves; therefore, the Company is not required to post any collateral. The Company does not require collateral from its counterparties. The Company minimizes the credit risk in derivatives by: (i) limiting its exposure to any single counterparty; (ii) entering into derivatives only with counterparties that are also lenders in the Senior Secured Credit Facility and meet the Company’s minimum credit quality standard, or have a guarantee from an affiliate that meets the Company’s minimum credit quality standard; and (iii) monitoring the creditworthiness of the Company’s counterparties on an ongoing basis. In accordance with the Company’s standard practice, its commodity and interest rate derivatives are subject to counterparty netting under agreements governing such derivatives and, therefore, the risk of such loss is somewhat mitigated as of June 30, 2014.

Fair_value_measurements

Fair value measurements	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Fair value measurements	'
	Fair value measurements
	The Company accounts for its oil and natural gas commodity derivatives and, in prior periods, its interest rate derivatives at fair value. The fair value of derivatives is determined utilizing pricing models for similar instruments. The models use a variety of techniques to arrive at fair value, including quotes and pricing analysis. Inputs to the pricing models include publicly available prices and forward curves generated from a compilation of data gathered from third parties.
	The Company has categorized its assets and liabilities measured at fair value, based on the priority of inputs to the valuation technique, into a three-level fair value hierarchy. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3).
	Assets and liabilities recorded at fair value on the unaudited consolidated balance sheets are categorized based on inputs to the valuation techniques as follows:
	Level 1—	Assets and liabilities recorded at fair value for which values are based on unadjusted quoted prices for identical assets or liabilities in an active market that management has the ability to access. Active markets are considered 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—	Assets and liabilities recorded at fair value for which values are based on quoted prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the assets or liabilities. Substantially all of these inputs are observable in the marketplace throughout the full term of the price risk management instrument and can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace.
	Level 3—	Assets and liabilities recorded at fair value for which values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. Unobservable inputs are not corroborated by market data. These inputs reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.
	When the inputs used to measure fair value fall within different levels of the hierarchy in a liquid environment, the level within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement in its entirety. The Company conducts a review of fair value hierarchy classifications on an annual basis. Changes in the observability of valuation inputs may result in a reclassification for certain financial assets or liabilities. Transfers between fair value hierarchy levels are recognized and reported in the period in which the transfer occurred. No transfers between fair value hierarchy levels occurred during the six months ended June 30, 2014 or 2013.
	1. Fair value measurement on a recurring basis
	The following presents the Company’s fair value hierarchy for assets and liabilities measured at fair value on a recurring basis for the periods presented:
	(in thousands)		Level 1			Level 2			Level 3			Total fair
												value
	As of June 30, 2014:
	Commodity derivatives		$	—		$	(70,306	)	$	—		$	(70,306	)
	Deferred premiums		—			—			(9,025		)	(9,025		)
	Total		$	—		$	(70,306	)	$	(9,025	)	$	(79,331	)
	(in thousands)		Level 1			Level 2			Level 3			Total fair
												value
	As of December 31, 2013:
	Commodity derivatives		$	—		$	94,741		$	—		$	94,741
	Deferred premiums		—			—			(12,684		)	(12,684		)
	Total		$	—		$	94,741		$	(12,684	)	$	82,057
	These items are included in "Derivatives" on the unaudited consolidated balance sheets. Significant Level 2 assumptions associated with the calculation of discounted cash flows used in the mark-to-market analysis of commodity derivatives include the NYMEX natural gas and oil prices, appropriate risk-adjusted discount rates and other relevant data. Significant Level 2 assumptions associated with the calculation of discounted cash flows used in the mark-to-market analysis of interest rate swaps included the interest rate curves, appropriate risk adjusted discount rates and other relevant data.
	The Company’s deferred premiums associated with its commodity derivative contracts are categorized as Level 3, as the Company utilizes a net present value calculation to determine the valuation. They are considered to be measured on a recurring basis as the derivative contracts they derive from are measured on a recurring basis. As commodity derivative contracts containing deferred premiums are entered into, the Company discounts the associated deferred premium to its net present value at the contract trade date, using the Senior Secured Credit Facility rate at the trade date (historical input rates range from 2.00% to 3.56%), and then records the change in net present value to interest expense over the period from trade until the final settlement date at the end of the contract. After this initial valuation, the net present value of each deferred premium is not adjusted; therefore, significant increases (decreases) in the Senior Secured Credit Facility rate would result in a significantly lower (higher) fair value measurement for each new contract entered into which contained a deferred premium; however, the valuation for the deferred premiums already recorded would remain unaffected. While the Company believes the sources utilized to arrive at the fair value estimates are reliable, different sources or methods could have yielded different fair value estimates; therefore, on a quarterly basis, the valuation is compared to counterparty valuations and a third-party valuation of the deferred premiums for reasonableness.
	The following table presents actual cash payments required for deferred premium contracts in place as of June 30, 2014, and for the calendar years following:
	(in thousands)
	Remaining 2014		$	3,640
	2015		5,166
	2016		358
	Total		$	9,164
	A summary of the changes in assets classified as Level 3 measurements for the periods presented are as follows:
			Three months ended June 30,						Six months ended June 30,
	(in thousands)		2014			2013			2014			2013
	Balance of Level 3 at beginning of period		$	(10,790	)	$	(22,438	)	$	(12,684	)	$	(24,709	)
	Change in net present value of deferred premiums for derivatives		(55		)	(131		)	(120		)	(282		)
	Settlements		1,820			2,827			3,779			5,249
	Balance of Level 3 at end of period		$	(9,025	)	$	(19,742	)	$	(9,025	)	$	(19,742	)
	2. Fair value measurement on a nonrecurring basis
	The Company accounts for the impairment of long-lived assets, if any, at fair value on a nonrecurring basis. For purposes of fair value measurement, it was determined that the impairment of long-lived assets is classified as Level 3, based on the use of internally developed cash-flow models. No impairments of long-lived assets were recorded in the six months ended June 30, 2014 or 2013.
	The accounting policies for impairment of oil and natural gas properties are discussed in the audited consolidated financial statements and notes thereto included in the 2013 Annual Report. Significant inputs included in the calculation of discounted cash flows used in the impairment analysis include the Company’s estimate of operating and development costs, anticipated production of proved reserves and other relevant data.

Credit_risk

Credit risk	6 Months Ended
	Jun. 30, 2014
Risks and Uncertainties [Abstract]	'
Credit risk	'
	Credit risk
	The Company’s oil and natural gas sales are to a variety of purchasers, including intrastate and interstate pipelines or their marketing affiliates and independent marketing companies. The Company’s joint operations accounts receivable are from a number of oil and natural gas companies, partnerships, individuals and others who own interests in the properties operated by the Company. Management believes that any credit risk imposed by a concentration in the oil and natural gas industry is offset by the creditworthiness of the Company’s customer base and industry partners. The Company routinely assesses the recoverability of all material trade and other receivables to determine collectability.
	The Company uses derivatives to hedge its exposure to oil and natural gas price volatility and, in the past, its exposure to interest rate risk associated with the Senior Secured Credit Facility. These transactions expose the Company to potential credit risk from its counterparties. In accordance with the Company’s standard practice, its derivatives are subject to counterparty netting under agreements governing such derivatives; therefore, the credit risk associated with its derivative counterparties is somewhat mitigated. See Note G for additional information regarding the Company’s derivatives.

Commitments_and_contingencies

Commitments and contingencies	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
Commitments and contingencies	'
	Commitments and contingencies
	1.    Litigation
	From time to time the Company is involved in legal proceedings and/or may be subject to industry rulings that could bring rise to claims in the ordinary course of business. The Company has concluded that the likelihood is remote that the ultimate resolution of any pending litigation or pending claims will be material or have a material adverse effect on the Company’s business, financial position, results of operations or liquidity.
	2.    Drilling contracts
	The Company has committed to several short-term drilling contracts with various third parties in order to complete its various drilling projects. The contracts contain an early termination clause that requires the Company to pay significant penalties to the third party should the Company cease drilling efforts. These penalties would negatively impact the Company’s financial statements upon contract termination. Future commitments of $34.8 million as of June 30, 2014 are not recorded in the accompanying unaudited consolidated balance sheets. Management does not anticipate canceling any drilling contracts or discontinuing drilling efforts in 2014.
	3.    Federal and state regulations
	Oil and natural gas exploration, production and related operations are subject to extensive federal and state laws, rules and regulations. Failure to comply with these laws, rules and regulations can result in substantial penalties. The regulatory burden on the oil and natural gas industry increases the cost of doing business and affects profitability. The Company believes that it is in compliance with currently applicable federal and state regulations related to oil and natural gas exploration and production, and that compliance with the current regulations will not have a material adverse impact on the financial position or results of operations of the Company. Because these rules and regulations are frequently amended or reinterpreted, the Company is unable to predict the future cost or impact of complying with these regulations.

Net_income_loss_per_share

Net income (loss) per share	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Net income (loss) per share	'
	Net income (loss) per share
	Basic net income (loss) per share is computed by dividing net income (loss) by the weighted-average number of shares outstanding for the period. Diluted net income (loss) per share reflects the potential dilution of non-vested restricted stock awards, Performance Share Awards and outstanding restricted stock options. For the three and six months ended June 30, 2014, all of these potentially dilutive items were anti-dilutive due to the Company's net loss and, therefore, were excluded from the calculation of diluted net loss per share.
	The effect of the Company's outstanding options that were granted in February 2012 to purchase 414,239 shares of common stock at $24.11 per share were excluded from the calculation of diluted net income per share for the three and six months ended June 30, 2013 because the exercise price of those options was greater than the average market price during the period, and, therefore, the inclusion of these outstanding options would have been anti-dilutive. The effect of the Company's outstanding options that were granted in February 2013 to purchase 968,938 shares of common stock at $17.34 per share were excluded from the calculation of diluted net income per share for the three and six months ended June 30, 2013, because, utilizing the treasury method, the sum of the assumed proceeds including the unrecognized compensation, exceeded the average stock price during the period and, therefore, the inclusion of these outstanding options would have been anti-dilutive.
	The following is the calculation of basic and diluted weighted-average shares outstanding and net income (loss) per share for the periods presented:
		Three months ended June 30,					Six months ended June 30,
	(in thousands, except for per share data)	2014			2013		2014			2013
	Net income (loss) (numerator):
	Income (loss) from continuing operations—basic and diluted	$	(18,899	)	$	35,294	$	(19,112	)	$	36,431
	Income from discontinued operations, net of tax—basic and diluted	—			518		—			790
	Net income (loss)—basic and diluted	$	(18,899	)	$	35,812	$	(19,112	)	$	37,221
	Weighted-average shares (denominator):
	Weighted-average shares—basic	141,298			127,362		141,183			127,281
	Non-vested restricted stock	—			2,022		—			1,838
	Weighted-average shares—diluted	141,298			129,384		141,183			129,119
	Net income (loss) per share:
	Basic:
	Income (loss) from continuing operations	$	(0.13	)	$	0.28	$	(0.14	)	$	0.29
	Income from discontinued operations, net of tax	—			—		—			0.01
	Net income (loss) per share	$	(0.13	)	$	0.28	$	(0.14	)	$	0.3
	Diluted:
	Income (loss) from continuing operations	$	(0.13	)	$	0.27	$	(0.14	)	$	0.28
	Income from discontinued operations, net of tax	—			—		—			0.01
	Net income (loss) per share	$	(0.13	)	$	0.27	$	(0.14	)	$	0.29

Variable_interest_entity

Variable interest entity	6 Months Ended
	Jun. 30, 2014
Variable Interest Entity [Abstract]	'
Variable Interest Entity	'
	Variable interest entity
	An entity is referred to as a variable interest entity ("VIE") pursuant to accounting guidance for consolidation if it possesses one of the following criteria: (i) it is thinly capitalized, (ii) the residual equity holders do not control the entity, (iii) the equity holders are shielded from the economic losses, (iv) the equity holders do not participate fully in the entity's residual economics, or (v) the entity was established with non-substantive voting interests. In order to determine if a VIE should be consolidated, an entity must determine if it is the primary beneficiary of the VIE. The primary beneficiary of a VIE is that variable interest holder possessing a controlling financial interest through: (i) its power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and (ii) its obligation to absorb losses or its right to receive benefits from the VIE that could potentially be significant to the VIE. In order to determine whether the Company owns a variable interest in a VIE, a qualitative analysis is performed of the entity’s design, organizational structure, primary decision makers and relevant agreements. The Company continually monitors its VIE exposure to determine if any events have occurred that could cause the primary beneficiary to change.
	Laredo Midstream contributed $8.2 million and $19.5 million during the three and six months ended June 30, 2014, respectively, and $2.3 million and $3.2 million during the three and six months ended June 30, 2013, respectively, to Medallion Gathering & Processing, LLC ("Medallion"), a Texas limited liability company. Laredo Midstream holds 49% of Medallion ownership units. Medallion, which was formed on October 31, 2012 and its wholly owned subsidiary, Medallion Pipeline Company, LLC ("MPC"), a Texas limited liability company formed on September 9, 2013, were established for the purpose of developing midstream solutions and providing midstream infrastructure to bring discovered oil and natural gas to market. Laredo Midstream and the other 51% interest-holder have agreed that the voting rights of Medallion, the profit and loss sharing, and the additional capital contribution requirements shall be equal to the ownership unit percentage held. Additionally, Medallion requires a super-majority vote of 75% for all key operating and business decisions. The Company has determined that Medallion is a VIE. However, Laredo Midstream is not considered to be the primary beneficiary of the VIE because Laredo Midstream does not have the power to direct the activities that most significantly affect Medallion's economic performance. As such, Medallion is accounted for under the equity method of accounting with the Company's proportionate share of Medallion's net income (loss) reflected in the unaudited consolidated statements of operations as "Loss from equity method investee" and the carrying amount reflected on the unaudited consolidated balance sheets as "Investment in equity method investee."
	As of June 30, 2014, Laredo Midstream has a remaining commitment to contribute an additional $21.6 million to Medallion in 2014 towards the construction of a pipeline by MPC. The Company has recorded a capital contribution payable of $18.1 million related to the capital call for the second and third quarter cash requirements of the project and a payable of $2.0 million related to its minimum volume commitment to Medallion, which is reported on the unaudited consolidated balance sheet as "Accrued payable - affiliates." The corresponding expense is reported on the unaudited consolidated statements of operations in the "Natural gas volume commitment - affiliates" line item.

Recently_issued_accounting_sta

Recently issued accounting standards	6 Months Ended
	Jun. 30, 2014
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
Recently issued accounting standards	'
	Recent accounting pronouncements
	In May 2014, the Financial Accounting Standards Board ("FASB") issued a comprehensive new revenue recognition standard that supersedes the revenue recognition requirements in Topic 605, Revenue Recognition, and industry-specific guidance in Subtopic 932-605, Extractive Activities—Oil and Gas—Revenue Recognition. The core principle of the new guidance is that a company should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for transferring those goods or services. The new standard also requires significantly expanded disclosure regarding the qualitative and quantitative information of an entity's nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers. The standard creates a five-step model that requires companies to exercise judgment when considering the terms of a contract and all relevant facts and circumstances. The standard allows for several transition methods: (a) a full retrospective adoption in which the standard is applied to all of the periods presented, or (b) a modified retrospective adoption in which the standard is applied only to the most current period presented in the financial statements, including additional disclosures of the standard’s application impact to individual financial statement line items. This standard is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. The Company is currently evaluating this standard and its existing revenue recognition policies to determine which contracts in the scope of the guidance will be affected by the new requirements and what impact they will have on its consolidated financial statements upon adoption of this standard.
	In April 2014, the FASB issued guidance on reporting discontinued operations and disclosures of disposals of components of an entity. The guidance changes the criteria for reporting discontinued operations, including raising the threshold for a disposal to qualify as discontinued operations. The guidance also requires entities to provide additional disclosure about discontinued operations as well as disposal transactions that do not meet the discontinued operations criteria. The pronouncement is effective for annual and interim periods beginning after December 15, 2014. Early adoption is permitted for disposals or for assets classified as held for sale that have not been reported in previously issued financial statements. The Company elected to early adopt this guidance in the second quarter of 2014 on a prospective basis, and the adoption did not have an effect on its consolidated financial statements.
	In July 2013, the FASB issued guidance on the presentation of an unrecognized tax benefit when a net operating loss carry-forward, a similar tax loss or a tax credit carry-forward exists. The guidance requires an unrecognized tax benefit, or a portion of an unrecognized tax benefit, to be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carry-forward, a similar tax loss or a tax credit carry-forward except when (i) a net operating loss carry-forward, a similar tax loss or a tax credit carry-forward is not available at the reporting date under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position, or (ii) the tax law of the applicable jurisdiction does not require the entity to use, and the entity does not intend to use, the deferred tax asset for such purpose. In those situations the unrecognized tax benefit should be presented in the financial statements as a liability and should not be combined with deferred tax assets. The Company adopted this guidance on January 1, 2014, and the adoption did not have an effect on its consolidated financial statements.

Subsidiary_guarantees

Subsidiary guarantees	6 Months Ended
	Jun. 30, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]	'
Subsidiary guarantees	'
	Subsidiary guarantees
	Laredo Midstream has fully and unconditionally guaranteed the 2019 Notes, the January 2022 Notes, the May 2022 Notes and the Senior Secured Credit Facility. In accordance with practices accepted by the SEC, Laredo has prepared condensed consolidating financial statements in order to quantify the assets, results of operations and cash flows of Laredo Midstream as a subsidiary guarantor. The following unaudited condensed consolidating balance sheets as of June 30, 2014 and December 31, 2013, unaudited condensed consolidating statements of operations for the three and six months ended June 30, 2014 and 2013 and unaudited condensed consolidating statements of cash flows for the six months ended June 30, 2014 and 2013, present financial information for Laredo on a stand-alone basis (carrying any investment in subsidiaries under the equity method), financial information for Laredo Midstream on a stand-alone basis (carrying any investment in subsidiaries under the equity method), and the consolidation and elimination entries necessary to arrive at the information for the Company on a condensed consolidated basis. Deferred income taxes for Laredo Midstream are recorded on Laredo's statements of financial position, statements of operations and statements of cash flows as it is a disregarded entity for income tax purposes. Laredo and Laredo Midstream are not restricted from making distributions to each other. During the three months ended June 30, 2014, certain midstream service assets were transferred from Laredo to Laredo Midstream at historical cost.
	Condensed consolidating balance sheet
	June 30, 2014
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Accounts receivable, net	$	95,604		$	116		$	—		$	95,720
	Other current assets	434,888			13			—			434,901
	Total oil and natural gas properties, net	2,475,094			—			—			2,475,094
	Total midstream service assets, net	—			74,258			—			74,258
	Total other fixed assets, net	28,574			290			—			28,864
	Investment in subsidiaries and equity method investee	88,330			40,871			(88,330		)	40,871
	Total other long-term assets	31,330			—			—			31,330
	Total assets	$	3,153,820		$	115,548		$	(88,330	)	$	3,181,038
	Accounts payable	$	18,017		$	370		$	—		$	18,387
	Other current liabilities	289,433			26,848			—			316,281
	Other long-term liabilities	80,642			—			—			80,642
	Long-term debt	1,501,419			—			—			1,501,419
	Stockholders’ equity	1,264,309			88,330			(88,330		)	1,264,309
	Total liabilities and stockholders’ equity	$	3,153,820		$	115,548		$	(88,330	)	$	3,181,038
	Condensed consolidating balance sheet
	December 31, 2013
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Accounts receivable, net	$	77,318		$	—		$	—		$	77,318
	Other current assets	230,291			—			—			230,291
	Total oil and natural gas properties, net	2,135,348			—			—			2,135,348
	Total midstream service assets, net	5,802			41,498			—			47,300
	Total other fixed assets, net	21,676			—			—			21,676
	Investment in subsidiaries and equity method investee	36,666			5,913			(36,666		)	5,913
	Total other long-term assets	105,914			—			—			105,914
	Total assets	$	2,613,015		$	47,411		$	(36,666	)	$	2,623,760
	Accounts payable	$	12,216		$	3,786		$	—		$	16,002
	Other current liabilities	231,008			6,959			—			237,967
	Other long-term liabilities	45,997			—			—			45,997
	Long-term debt	1,051,538			—			—			1,051,538
	Stockholders’ equity	1,272,256			36,666			(36,666		)	1,272,256
	Total liabilities and stockholders’ equity	$	2,613,015		$	47,411		$	(36,666	)	$	2,623,760
	Condensed consolidating statement of operations
	For the three months ended June 30, 2014
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Total operating revenues	$	182,872		$	1,542		$	(1,370	)	$	183,044
	Total operating costs and expenses	116,596			3,257			(1,370		)	118,483
	Income (loss) from operations	66,276			(1,715		)	—			64,561
	Interest expense, net	(30,463		)	—			—			(30,463		)
	Other, net	(65,086		)	(44		)	1,759			(63,371		)
	Loss from continuing operations before income tax	(29,273		)	(1,759		)	1,759			(29,273		)
	Deferred income tax benefit	10,374			—			—			10,374
	Loss from continuing operations	(18,899		)	(1,759		)	1,759			(18,899		)
	Net loss	$	(18,899	)	$	(1,759	)	$	1,759		$	(18,899	)
	Condensed consolidating statement of operations
	For the three months ended June 30, 2013
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Total operating revenues	$	177,296		$	2,718		$	(2,718	)	$	177,296
	Total operating costs and expenses	122,028			572			(2,718		)	119,882
	Income from operations	55,268			2,146			—			57,414
	Interest expense, net	(25,931		)	—			—			(25,931		)
Other, net	27,049			(49		)	(3,142		)	23,858
Income from continuing operations before income tax	56,386			2,097			(3,142		)	55,341
Deferred income tax expense	(20,047		)	—			—			(20,047		)
Income from continuing operations	36,339			2,097			(3,142		)	35,294
Income (loss) from discontinued operations, net of tax	(527		)	1,045			—			518
Net income	$	35,812		$	3,142		$	(3,142	)	$	35,812
Condensed consolidating statement of operations
For the six months ended June 30, 2014
(Unaudited)
(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
							eliminations			company
Total operating revenues	$	356,086		$	2,572		$	(2,304	)	$	356,354
Total operating costs and expenses	229,106			4,953			(2,304		)	231,755
Income (loss) from operations	126,980			(2,381		)	—			124,599
Interest expense, net	(59,366		)	—			—			(59,366		)
Other, net	(96,993		)	(77		)	2,458			(94,612		)
Loss from continuing operations before income tax	(29,379		)	(2,458		)	2,458			(29,379		)
Deferred income tax benefit	10,267			—			—			10,267
Loss from continuing operations	(19,112		)	(2,458		)	2,458			(19,112		)
Net loss	$	(19,112	)	$	(2,458	)	$	2,458		$	(19,112	)
Condensed consolidating statement of operations
For the six months ended June 30, 2013
(Unaudited)
(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
							eliminations			company
Total operating revenues	$	340,965		$	5,364		$	(5,328	)	$	341,001
Total operating costs and expenses	242,859			1,551			(5,328		)	239,082
Income from operations	98,106			3,813			—			101,919
Interest expense, net	(51,265		)	—			—			(51,265		)
Other, net	13,089			(113		)	(6,042		)	6,934
Income from continuing operations before income tax	59,930			3,700			(6,042		)	57,588
Deferred income tax expense	(21,157		)	—			—			(21,157		)
Income from continuing operations	38,773			3,700			(6,042		)	36,431
Income (loss) from discontinued operations, net of tax	(1,552		)	2,342			—			790
Net income	$	37,221		$	6,042		$	(6,042	)	$	37,221
Condensed consolidating statement of cash flows
For the six months ended June 30, 2014
(Unaudited)
(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
							eliminations			company
Net cash flows provided by (used in) operating activities	$	240,880		$	(3,239	)	$	2,458		$	240,099
Change in investments between affiliates	(44,202		)	46,660			(2,458		)	—
Capital expenditures and other	(435,807		)	(43,421		)	—			(479,228		)
Net cash flows provided by financing activities	440,482			—			—			440,482
Net increase in cash and cash equivalents	201,353			—			—			201,353
Cash and cash equivalents at beginning of period	198,153			—			—			198,153
Cash and cash equivalents at end of period	$	399,506		$	—		$	—		$	399,506
Condensed consolidating statement of cash flows
For the six months ended June 30, 2013
(Unaudited)
(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
							eliminations			company
Net cash flows provided by operating activities	$	177,967		$	6,365		$	(6,042	)	$	178,290
Change in investments between affiliates	(11,266		)	5,224			6,042			—
Capital expenditures and other	(384,704		)	(11,589		)	—			(396,293		)
Net cash flows provided by financing activities	228,367			—			—			228,367
Net increase in cash and cash equivalents	10,364			—			—			10,364
Cash and cash equivalents at beginning of period	33,224			—			—			33,224
Cash and cash equivalents at end of period	$	43,588		$	—		$	—		$	43,588

Subsequent_events

Subsequent events	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
Subsequent events	'
	Subsequent events
	1.    Leasehold acquisitions
	Subsequent to June 30, 2014, the Company acquired or entered into agreements to acquire 8,777 net acres of additional leasehold interests in Reagan, Irion and Glasscock counties, primarily within the Company's core development area, for an aggregate purchase price of $195.6 million.

Supplementary_information

Supplementary information	6 Months Ended
	Jun. 30, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'
Supplementary information	'
	Supplementary information
	Costs incurred in oil and natural gas property acquisition, exploration and development activities
	Costs incurred in the acquisition, exploration and development of oil and natural gas assets are presented below for the periods presented:
			Three months ended June 30,				Six months ended June 30,
	(in thousands)		2014		2013		2014		2013
	Property acquisition costs:								—
	Proved		$	3,848	$	—	$	3,873	$	—
	Unproved		2,645		—		9,925		—
	Exploration		8,143		12,167		16,642		20,928
	Development costs(1)		220,240		165,416		408,553		322,732
	Total costs incurred		$	234,876	$	177,583	$	438,993	$	343,660
	____________________________________________________________________________
	-1	The costs incurred for oil and natural gas development activities include $0.9 million and $0.7 million in asset retirement obligations for the three months ended June 30, 2014 and 2013, respectively, and $1.5 million and $1.3 million for the six months ended June 30, 2014 and 2013, respectively.

Basis_of_presentation_and_sign1

Basis of presentation and significant accounting policies (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Basis of presentation	'
	Basis of presentation
	The accompanying unaudited consolidated financial statements were derived from the historical accounting records of the Company and reflect the historical financial position, results of operations and cash flows for the periods described herein. The Company uses the equity method of accounting to record its net interests when the Company holds 20% to 50% of the voting rights and/or has the ability to exercise significant influence but does not control the entity. Under the equity method, the Company's proportionate share of the investee's net income (loss) is included in the unaudited consolidated statements of operations. See Note L for additional discussion of the Company's equity method investment. The accompanying unaudited consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). All material intercompany transactions and account balances have been eliminated in the consolidation of accounts. The Company reports as one business segment, which explores for, develops and produces oil and natural gas. Unless otherwise indicated, the information in these notes relate to the Company’s continuing operations.
	The accompanying consolidated financial statements have not been audited by the Company’s independent registered public accounting firm, except that the consolidated balance sheet at December 31, 2013 is derived from audited consolidated financial statements. In the opinion of management, the accompanying unaudited consolidated financial statements reflect all necessary adjustments to present fairly the Company’s financial position as of June 30, 2014, results of operations for the three and six months ended June 30, 2014 and 2013 and cash flows for the six months ended June 30, 2014 and 2013.
	Certain disclosures have been condensed or omitted from these unaudited consolidated financial statements. Accordingly, these unaudited consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in Laredo’s Annual Report on Form 10-K for the year ended December 31, 2013 (the "2013 Annual Report").
Use of estimates in the preparation of interim consolidated financial statements	'
	Use of estimates in the preparation of interim unaudited consolidated financial statements
	The preparation of the accompanying unaudited consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions about future events. These estimates and the underlying assumptions affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Although management believes these estimates are reasonable, actual results could differ from these estimates. The interim results reflected in the unaudited consolidated financial statements are not necessarily indicative of the results that may be expected for other interim periods or for the full year.
	Significant estimates include, but are not limited to, (i) estimates of the Company’s reserves of oil and natural gas, (ii) future cash flows from oil and natural gas properties, (iii) depletion, depreciation and amortization, (iv) asset retirement obligations, (v) stock-based compensation, (vi) deferred income taxes, (vii) fair value of assets acquired and liabilities assumed in an acquisition and (viii) fair values of commodity derivatives, interest rate derivatives, commodity deferred premiums, performance share awards and performance unit awards. As fair value is a market-based measurement, it is determined based on the assumptions that market participants would use. These estimates and assumptions are based on management’s best judgment. Management evaluates its estimates and assumptions on an ongoing basis using historical experience and other factors, including the current economic environment. Such estimates and assumptions are adjusted when facts and circumstances dictate. Illiquid credit markets and volatile equity and energy markets have combined to increase the uncertainty inherent in such estimates and assumptions. Management believes its estimates and assumptions to be reasonable under the circumstances. As future events and their effects cannot be determined with precision, actual values and results could differ from these estimates. Any changes in estimates resulting from future changes in the economic environment will be reflected in the financial statements in future periods.
Reclassifications	'
	Reclassifications
	Certain amounts in the accompanying unaudited consolidated financial statements have been reclassified to conform to the 2014 presentation. These reclassifications had no impact to previously reported net income (loss), total stockholders' equity or cash flows.
Treasury stock	'
	Treasury stock
	The Company acquires treasury stock, which is recorded at cost, to satisfy tax withholding obligations for Laredo's employees that arise upon the lapse of restrictions on restricted stock. Upon acquisition, this treasury stock is retired.
Accounts receivable	'
	Accounts receivable
	The Company sells oil and natural gas to various customers and participates with other parties in the drilling, completion and operation of oil and natural gas wells. Joint interest and oil and natural gas sales receivables related to these operations are generally unsecured. Accounts receivable for joint interest billings are recorded as amounts billed to customers less an allowance for doubtful accounts.
	Amounts are considered past due after 30 days. The Company determines joint interest operations accounts receivable allowances based on management’s assessment of the creditworthiness of the joint interest owners. Additionally, as the operator of the majority of its wells, the Company has the ability to realize the receivables through netting of anticipated future production revenues. The Company maintains an allowance for doubtful accounts for estimated losses inherent in its accounts receivable portfolio. In establishing the required allowance, management considers historical losses, current receivables aging, and existing industry and economic data. The Company reviews its allowance for doubtful accounts quarterly. Past due balances greater than 90 days and over a specified amount are reviewed individually for collectability. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is remote.
Derivatives	'
	Derivatives
	The Company uses derivatives to reduce its exposure to fluctuations in the prices of oil and natural gas. By removing a significant portion of the price volatility associated with future production, the Company expects to mitigate, but not eliminate, the potential effects of variability in cash flows from operations due to fluctuations in commodity prices. These transactions are primarily in the form of collars, swaps, puts and basis swaps. In addition, in prior periods the Company entered into derivative contracts in the form of interest rate derivatives to minimize the effects of fluctuations in interest rates.
	Derivatives are recorded at fair value and are included on the unaudited consolidated balance sheets as assets or liabilities. The Company nets the fair value of derivatives by counterparty in the accompanying unaudited consolidated balance sheets where the right of offset exists. The Company determines the fair value of its derivatives by utilizing pricing models for substantially similar instruments. Inputs to the pricing models include publicly available prices and forward price curves generated from a compilation of data gathered from third parties.
	The Company’s derivatives were not designated as hedges for accounting purposes for any of the periods presented. Accordingly, the changes in fair value are recognized in the unaudited consolidated statements of operations in the period of change. Gains and losses on derivatives are included in cash flows from operating activities (see Note G).
Deferred loan costs	'
	Deferred loan costs
	Loan origination fees, which are stated at cost, net of amortization, are amortized over the life of the respective debt agreements utilizing the effective interest and straight-line methods.
Asset retirement obligations	'
	Asset retirement obligations
	Asset retirement obligations associated with the retirement of tangible long-lived assets are recognized as a liability in the period in which they are incurred and become determinable. The associated asset retirement costs are part of the carrying amount of the long-lived asset. Subsequently, the asset retirement cost included in the carrying amount of the related long-lived asset is charged to expense through the depletion of the asset. Changes in the liability due to the passage of time are recognized as an increase in the carrying amount of the liability and as corresponding accretion expense.
	The fair value of additions to the asset retirement obligation liability is measured using valuation techniques consistent with the income approach, which converts future cash flows into a single discounted amount. Significant inputs to the valuation include: (i) estimated plug and abandonment cost per well based on Company experience; (ii) estimated remaining life per well based on the reserve life per well; (iii) future inflation factors; and (iv) the Company's average credit adjusted risk free rate. Inherent in the fair value calculation of asset retirement obligations are numerous assumptions and judgments including, in addition to those noted above, the ultimate settlement of these amounts, the ultimate timing of such settlement and changes in legal, regulatory, environmental and political environments. To the extent future revisions to these assumptions impact the fair value of the existing asset retirement obligation liability, a corresponding adjustment will be made to the asset balance.
	The Company is obligated by contractual and regulatory requirements to remove certain pipeline and gas gathering assets and perform other remediation of the sites where such pipeline and gas gathering assets are located upon the retirement of those assets. However, the fair value of the asset retirement obligation cannot currently be reasonably estimated because the settlement dates are indeterminate. The Company will record an asset retirement obligation for pipeline and gas gathering assets in the periods in which settlement dates become reasonably determinable.
Compensation awards	'
	Compensation awards
	Stock-based compensation expense is recognized in "General and administrative" in the Company’s unaudited consolidated statements of operations over the awards’ vesting periods and is based on their grant date fair value. The Company utilizes the closing stock price on the date of grant, less an expected forfeiture rate, to determine the fair value of service vesting restricted stock awards and a Black-Scholes pricing model to determine the fair values of service vesting restricted stock option awards. The Company utilizes a Monte Carlo simulation prepared by an independent third party to determine the fair values of the performance share awards and performance unit awards. On January 1, 2014, the Company began capitalizing a portion of stock-based compensation for employees who are directly involved in the acquisition and exploration of its properties into the full-cost pool. Capitalized stock-based compensation is included as an addition to "Oil and natural gas properties" in the unaudited consolidated balance sheets. See Note E for further discussion regarding the restricted stock awards, restricted stock option awards, performance share awards
Environmental	'
	Environmental
	The Company is subject to extensive federal, state and local environmental laws and regulations. These laws, among other things, regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. All environmental expenditures, including expenditures that relate to an existing condition caused by past operations and that have no future economic benefits, are expensed in the period in which they occur. Liabilities for expenditures of a non-capital nature are recorded when environmental assessment or remediation is probable and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments is fixed and readily determinable. Management believes no materially significant liabilities of this nature existed as of June 30, 2014 or December 31, 2013.
Employee compensation	'
	The Company recognizes the fair value of stock-based compensation granted to employees and directors over the requisite service period as a charge against earnings, net of amounts capitalized. The Company's stock-based compensation awards are accounted for as equity instruments. Stock-based compensation is included in "General and administrative" in the unaudited consolidated statements of operations. On January 1, 2014, the Company began capitalizing a portion of stock-based compensation for employees who are directly involved in the acquisition, exploration and development of oil and natural gas properties into the full-cost pool. Capitalized stock-based compensation is included as an addition to "Oil and natural gas properties" in the unaudited consolidated balance sheets.
Income Taxes	'
	Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating losses and tax credit carry-forwards. Under this method, deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income (loss) in the period that includes the enactment date. A valuation allowance is established to reduce deferred tax assets if it is determined it is more likely than not that the related tax benefit will not be realized. On a quarterly basis, management evaluates the need for and adequacy of valuation allowances based on the expected realizability of the deferred tax assets and adjusts the amount of such allowances, if necessary.
	The Company evaluates uncertain tax positions for recognition and measurement in the consolidated financial statements. To recognize a tax position, the Company determines whether it is more likely than not that the tax position will be sustained upon examination, including resolution of any related appeals or litigation, based on the technical merits of the position. A tax position that meets the more-likely-than-not threshold is measured to determine the amount of benefit to be recognized in the consolidated financial statements. The amount of tax benefit recognized with respect to any tax position is measured as the largest amount of benefit that is greater than 50% likely of being realized upon settlement.
Fair value measurements	'
	Fair value measurements
	The carrying amounts reported in the unaudited consolidated balance sheets for cash and cash equivalents, accounts receivable, prepaid expenses, accounts payable, undistributed revenue and royalties and other accrued liabilities approximate their fair values. See Note D for fair value disclosures related to the Company’s debt obligations. The Company carries its derivatives at fair value. See Note G and Note H for details regarding the fair value of the Company’s derivatives.
	The Company accounts for its oil and natural gas commodity derivatives and, in prior periods, its interest rate derivatives at fair value. The fair value of derivatives is determined utilizing pricing models for similar instruments. The models use a variety of techniques to arrive at fair value, including quotes and pricing analysis. Inputs to the pricing models include publicly available prices and forward curves generated from a compilation of data gathered from third parties.
	The Company has categorized its assets and liabilities measured at fair value, based on the priority of inputs to the valuation technique, into a three-level fair value hierarchy. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3).
	Assets and liabilities recorded at fair value on the unaudited consolidated balance sheets are categorized based on inputs to the valuation techniques as follows:
	Level 1—	Assets and liabilities recorded at fair value for which values are based on unadjusted quoted prices for identical assets or liabilities in an active market that management has the ability to access. Active markets are considered 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—	Assets and liabilities recorded at fair value for which values are based on quoted prices in markets that are not active or model inputs that are observable either directly or indirectly for substantially the full term of the assets or liabilities. Substantially all of these inputs are observable in the marketplace throughout the full term of the price risk management instrument and can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace.
	Level 3—	Assets and liabilities recorded at fair value for which values are based on prices or valuation techniques that require inputs that are both unobservable and significant to the overall fair value measurement. Unobservable inputs are not corroborated by market data. These inputs reflect management’s own assumptions about the assumptions a market participant would use in pricing the asset or liability.
	When the inputs used to measure fair value fall within different levels of the hierarchy in a liquid environment, the level within which the fair value measurement is categorized is based on the lowest level input that is significant to the fair value measurement in its entirety. The Company conducts a review of fair value hierarchy classifications on an annual basis. Changes in the observability of valuation inputs may result in a reclassification for certain financial assets or liabilities. Transfers between fair value hierarchy levels are recognized and reported in the period in which the transfer occurred.
	The Company accounts for the impairment of long-lived assets, if any, at fair value on a nonrecurring basis. For purposes of fair value measurement, it was determined that the impairment of long-lived assets is classified as Level 3, based on the use of internally developed cash-flow models.
Credit risk	'
	The Company routinely assesses the recoverability of all material trade and other receivables to determine collectability.
	The Company uses derivatives to hedge its exposure to oil and natural gas price volatility and, in the past, its exposure to interest rate risk associated with the Senior Secured Credit Facility. These transactions expose the Company to potential credit risk from its counterparties. In accordance with the Company’s standard practice, its derivatives are subject to counterparty netting under agreements governing such derivatives; therefore, the credit risk associated with its derivative counterparties is somewhat mitigated.
Earnings Per Share	'
	Basic net income (loss) per share is computed by dividing net income (loss) by the weighted-average number of shares outstanding for the period. Diluted net income (loss) per share reflects the potential dilution of non-vested restricted stock awards, Performance Share Awards and outstanding restricted stock options.
Variable Interest Entity	'
	An entity is referred to as a variable interest entity ("VIE") pursuant to accounting guidance for consolidation if it possesses one of the following criteria: (i) it is thinly capitalized, (ii) the residual equity holders do not control the entity, (iii) the equity holders are shielded from the economic losses, (iv) the equity holders do not participate fully in the entity's residual economics, or (v) the entity was established with non-substantive voting interests. In order to determine if a VIE should be consolidated, an entity must determine if it is the primary beneficiary of the VIE. The primary beneficiary of a VIE is that variable interest holder possessing a controlling financial interest through: (i) its power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and (ii) its obligation to absorb losses or its right to receive benefits from the VIE that could potentially be significant to the VIE. In order to determine whether the Company owns a variable interest in a VIE, a qualitative analysis is performed of the entity’s design, organizational structure, primary decision makers and relevant agreements. The Company continually monitors its VIE exposure to determine if any events have occurred that could cause the primary beneficiary to change.

Basis_of_presentation_and_sign2

Basis of presentation and significant accounting policies (Tables)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Schedule of components of accounts receivable	'
	Accounts receivable consist of the following components for the periods presented:
	(in thousands)		30-Jun-14			31-Dec-13
	Oil and natural gas sales		$	68,476		$	57,647
	Joint operations, net(1)		23,274			16,629
	Other		3,970			3,042
	Total		$	95,720		$	77,318
	______________________________________________________________________________
	-1	Accounts receivable for joint operations are presented net of an allowance for doubtful accounts of $0.7 million as of June 30, 2014 and December 31, 2013.
Schedule of property and equipment	'
	The following table sets forth the Company’s property and equipment for the periods presented:
	(in thousands)		30-Jun-14			31-Dec-13
	Proved oil and natural gas properties		$	3,698,051		$	3,276,578
	Less accumulated depletion and impairment		(1,448,013		)	(1,349,315		)
	Proved oil and natural gas properties, net		2,250,038			1,927,263
	Unproved properties not being amortized		225,056			208,085
	Midstream service assets		80,265			51,704
	Less accumulated depreciation		(6,007		)	(4,404		)
	Midstream service assets, net		74,258			47,300
	Other fixed assets		42,016			32,832
	Less accumulated depreciation and amortization		(13,152		)	(11,156		)
	Other fixed assets, net		28,864			21,676
	Total property and equipment, net		$	2,578,216		$	2,204,324
Schedule of future amortization expense of deferred loan costs	'
	Future amortization expense of deferred loan costs as of June 30, 2014 is as follows:
	(in thousands)
	Remaining 2014		$	2,627
	2015		5,295
	2016		5,361
	2017		5,432
	2018		5,222
	Thereafter		7,151
	Total		$	31,088
Schedule of components of other current liabilities	'
	Other current liabilities consist of the following components for the periods presented:
	(in thousands)		30-Jun-14			31-Dec-13
	Accrued interest payable		$	37,065		$	25,885
	Accrued compensation and benefits		11,804			16,711
	Lease operating expense payable		11,056			10,637
	Performance unit awards		2,971			—
	Asset retirement obligations		886			265
	Prepaid drilling liability		851			1,393
	Other accrued liabilities		13,374			17,340
	Total other current liabilities		$	78,007		$	72,231
Schedule of reconciliation of asset retirement obligations liability	'
	The following reconciles the Company’s asset retirement obligation liability for continuing and discontinued operations for the periods presented:
	(in thousands)		Six months ended June 30, 2014			Year ended December 31, 2013
	Liability at beginning of period		$	21,743		$	21,505
	Liabilities added due to acquisitions, drilling and other		1,591			2,709
	Accretion expense		837			1,475
	Liabilities settled upon plugging and abandonment		(310		)	(226		)
	Liabilities removed due to Anadarko Basin Sale(1)		—			(7,801		)
	Revision of estimates		—			4,081
	Liability at end of period		$	23,861		$	21,743
	______________________________________________________________________________
	-1	See Note C.3 for definition of and information regarding the Anadarko Basin Sale.
Supplemental cash flow disclosure information and non-cash investing and financing infromation	'
	The following table summarizes the supplemental disclosure of cash flow information for the periods presented:
			Six months ended June 30,
	(in thousands)		2014			2013
	Cash paid for interest, net of $0 and $212 of capitalized interest, respectively		$	46,140		$	48,348
	The following presents the supplemental disclosure of non-cash investing and financing information for the periods presented:
			Six months ended June 30,
	(in thousands)		2014			2013
	Change in accrued capital expenditures		$	13,346		$	(33,892	)
	Capitalized asset retirement cost		$	1,591		$	1,262
	Capitalized stock-based compensation		$	2,167		$	—
	Restricted deposits on pending sale		$	—		$	44,000

Acquisition_and_divestiture_Ta

Acquisition and divestiture (Tables)	6 Months Ended
	Jun. 30, 2014
Acquisition and Divestitures [Abstract]	'
Operating results from discontinued operations	'
	The following represents operating results from discontinued operations for the periods presented:
	(in thousands)		Three months ended June 30, 2013			Six months ended June 30, 2013
	Revenues:
	Midstream service revenue		$	1,478		$	3,310
	Total revenues from discontinued operations		1,478			3,310
	Cost and expenses:
	Midstream service expense		669			1,449
	Depletion, depreciation and amortization		—			627
	Total costs and expenses from discontinued operations		669			2,076
	Income from discontinued operations before income tax		809			1,234
	Income tax expense		(291		)	(444		)
	Income from discontinued operations		$	518		$	790
	The following table presents revenues and operating expenses of the oil and natural gas properties that are a component of the Anadarko Basin Sale included in the accompanying unaudited consolidated statements of operations for the periods presented:
	(in thousands)		Three months ended June 30, 2013			Six months ended June 30, 2013
	Revenues		$	26,135		$	49,737
	Expenses(1)		19,918			40,837
	_________________________________________________________________________
	-1	Expenses include lease operating expense, production and ad valorem tax expense, accretion expense and depletion, depreciation and amortization expense.

Debt_Tables

Debt (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of amounts incurred and charged to interest expenses	'
	The following amounts have been incurred and charged to interest expense for the periods presented:
			Three months ended June 30,					Six months ended June 30,
	(in thousands)		2014		2013			2014		2013
	Cash payments for interest		$	19,291	$	20,816		$	46,140	$	48,560
	Amortization of deferred loan costs and other adjustments		1,194		1,320			2,323		2,624
	Change in accrued interest		10,172		3,924			11,180		320
	Interest costs incurred		30,657		26,060			59,643		51,504
	Less capitalized interest		—		(117		)	—		(212		)
	Total interest expense		$	30,657	$	25,943		$	59,643	$	51,292
Schedule of carrying amount and fair value of debt instruments	'
	The following table presents the carrying amount and fair values of the Company’s debt instruments for the periods presented:
			30-Jun-14					31-Dec-13
	(in thousands)		Carrying		Fair			Carrying		Fair
			value		value			value		value
	2019 Notes(1)		$	551,419	$	599,500		$	551,538	$	615,313
	January 2022 Notes		450,000		465,750			—		—
	May 2022 Notes		500,000		561,250			500,000		549,375
	Total value of debt		$	1,501,419	$	1,626,500		$	1,051,538	$	1,164,688
	______________________________________________________________________________
	-1	The carrying value of the 2019 Notes includes the October Notes unamortized bond premium of $1.4 million and $1.5 million as of June 30, 2014 and December 31, 2013, respectively.

Employee_compensation_Tables

Employee compensation (Tables)	6 Months Ended
	Jun. 30, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Schedule of outstanding restricted stock awards	'
	The following table reflects the outstanding restricted stock awards for the six months ended June 30, 2014:
	(in thousands, except for weighted-average grant date fair values)		Restricted			Weighted-average
			stock			grant date
			awards			fair value (per award)
	Outstanding at December 31, 2013		1,799			$	19.17
	Granted		1,161			$	25.75
	Forfeited		(50	)		$	22.62
	Vested(1)		(527	)		$	17.7
	Outstanding at June 30, 2014		2,383			$	22.64
	______________________________________________________________________________
	-1	The vesting of certain restricted stock awards could result in federal and state income tax expense or benefits related to the difference between the market price of the common stock at the date of vesting and the date of grant. For the three and six months ended June 30, 2014, the Company's recognized income tax expense related to the vesting of restricted stock awards was immaterial. The Company recognized income tax expense of $0.1 million and $0.4 million during the three and six months ended June 30, 2013, respectively, related to restricted stock awards, which were recorded as adjustments to deferred income taxes.
Schedule of stock option award activity	'
	The following table reflects the stock option award activity for the six months ended June 30, 2014:
	(in thousands, except for weighted-average exercise price and contractual term)		Restricted			Weighted-average			Weighted-average
			stock option			exercise price			remaining contractual term
			awards			(per option)			(years)
	Outstanding at December 31, 2013		1,229			$	19.32		8.82
	Granted		336			$	25.6		9.66
	Exercised(1)		(91	)		$	20.02		8.22
	Expired or canceled		—			$	—		—
	Forfeited		(13	)		$	19.61		—
	Outstanding at June 30, 2014		1,461			$	20.72		8.64
	Vested and exercisable at end of period(2)		355			$	20.35		8.17
	Vested, exercisable, and expected to vest at end of period(3)		1,428			$	20.71		8.64
	_____________________________________________________________________________
	-1	The exercise of stock option awards could result in federal and state income tax expense or benefits related to the difference between the fair value of the stock option at the date of grant and the intrinsic value of the stock option when exercised. The Company recognized income tax expense of $0.1 million and $0.2 million during the three and six months ended June 30, 2014, respectively, related to stock options, which were recorded as adjustments to deferred income taxes. No stock options were exercised during the three and six months ended June 30, 2013.
	-2	The aggregate intrinsic value of vested and exercisable options at June 30, 2014 was $3.8 million.
	-3	The aggregate intrinsic value of vested, exercisable and expected to vest options at June 30, 2014 was $14.7 million.
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions [Table Text Block]	'
	The assumptions used to estimate the fair value of restricted stock options granted on February 27, 2014 are as follows:
	Risk-free interest rate(1)	1.88		%
	Expected option life(2)	6.25 years
	Expected volatility(3)	53.21		%
	Fair value per stock option	$	13.41
	______________________________________________________________________________
	-1	U.S. Treasury yields as of the grant date were utilized for the risk-free interest rate assumption, matching the treasury yield terms to the expected life of the option.
	-2	As the Company had limited exercise history at the time of valuation relating to terminations and modifications, expected option life assumptions were developed using the simplified method in accordance with GAAP.
	-3	The Company utilized a peer historical look-back, which was weighted with the Company’s own volatility, in order to develop the expected volatility.
Share Based Compensation Schedule Of Vesting Rights Options	'
	In accordance with the LTIP and stock option agreement, the options granted will become exercisable in accordance with the following schedule based upon the number of full years of the optionee's continuous employment or service with the Company, following the date of grant:
	Full years of continuous employment		Incremental percentage of			Cumulative percentage of
			option exercisable			option exercisable
	Less than one		—	%		—	%
	One		25	%		25	%
	Two		25	%		50	%
	Three		25	%		75	%
	Four		25	%		100	%
Schedule of Compensation Cost for Share-based Payment Arrangements, Allocation of Share-based Compensation Costs by Plan [Table Text Block]	'
	The following has been recorded to stock-based compensation expense for the periods presented:
			Three months ended June 30,							Six months ended June 30,
	(in thousands)		2014				2013			2014			2013
	Restricted stock award compensation		$	6,010			$	3,572		$	10,242		$	6,398
	Restricted stock option award compensation		1,010				891			1,805			1,282
	Restricted performance share unit award compensation		625				—			845			—
	Total stock-based compensation		7,645				4,463			12,892			7,680
	Less amounts capitalized in oil and natural gas properties		(1,249		)		—			(2,167		)	—
	Net stock-based compensation expense		$	6,396			$	4,463		$	10,725		$	7,680
Performance Shares	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Schedule of assumptions used to estimate the fair value of options granted	'
	The assumptions used to estimate the fair value of the Performance Share Awards are as follows:
	Risk-free rate(1)		0.63		%
	Dividend yield		—		%
	Expected volatility(2)		38.21		%
	Laredo stock closing price as of February 27, 2014		$	25.6
	Fair value per performance share		$	28.56
	______________________________________________________________________________
	-1	The risk-free rate was derived using a zero-coupon yield derived from the Treasury Constant Maturities yield curve on the grant date.
	-2	The Company utilized a peer historical look-back, weighted with the Company's own volatility, to develop the expected volatility.

Income_taxes_Tables

Income taxes (Tables)	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Schedule of income tax (benefit) expense	'
	The Company is subject to corporate income taxes and the Texas franchise tax. Income tax (expense) benefit attributable to income (loss) from continuing operations for the periods presented consisted of the following:
		Three months ended June 30,						Six months ended June 30,
	(in thousands)	2014			2013			2014			2013
	Current taxes	$	—		$	—		$	—		$	—
	Deferred taxes	10,374			(20,047		)	10,267			(21,157		)
	Income tax benefit (expense)	$	10,374		$	(20,047	)	$	10,267		$	(21,157	)
Schedule of comprehensive provision for income tax	'
	The following presents the comprehensive provision for income taxes for the periods presented:
		Three months ended June 30,						Six months ended June 30,
	(in thousands)	2014			2013			2014			2013
	Comprehensive provision for income taxes allocable to:
	Continuing operations	$	10,374		$	(20,047	)	$	10,267		$	(21,157	)
	Discontinued operations	—			(291		)	—			(444		)
	Comprehensive provision for income taxes	$	10,374		$	(20,338	)	$	10,267		$	(21,601	)
Schedule of reconciliation of income tax expense computed by applying the federal income tax rate of 35% to pre-tax income from operations	'
	Income tax benefit (expense) attributable to income (loss) from continuing operations before income taxes differed from amounts computed by applying the applicable federal income tax rate of 35% to pre-tax earnings as a result of the following:
		Three months ended June 30,						Six months ended June 30,
	(in thousands)	2014			2013			2014			2013
	Income tax benefit (expense) computed by applying the statutory rate	$	10,246		$	(18,816	)	$	10,283		$	(19,580	)
	State income tax, net of federal tax benefit and increase in valuation allowance	347			(551		)	1,634			(572		)
	Non-deductible stock-based compensation	(123		)	(164		)	(239		)	(339		)
	Stock-based compensation tax deficiency	(15		)	(120		)	(156		)	(411		)
	Change in deferred tax valuation allowance	(34		)	(20		)	(1,112		)	(29		)
	Other items	(47		)	(376		)	(143		)	(226		)
	Income tax benefit (expense)	$	10,374		$	(20,047	)	$	10,267		$	(21,157	)
Schedule of significant components of deferred tax assets and liabilities	'
	Significant components of the Company’s deferred tax liabilities for the periods presented are as follows:
	(in thousands)	30-Jun-14			31-Dec-13
	Net operating loss carry-forward	$	310,579		$	284,890
	Oil and natural gas properties and equipment	(351,515		)	(278,735		)
	Derivatives	30,969			(30,859		)
	Stock-based compensation	7,807			6,578
	Accrued bonus	2,368			3,740
	Capitalized interest	2,411			2,099
	Other	(3,739		)	(240		)
	Gross deferred tax liability	(1,120		)	(12,527		)
	Valuation allowance	(1,272		)	(132		)
	Net deferred tax liability	$	(2,392	)	$	(12,659	)
Schedule of net deferred tax assets and liabilities as classified in the consolidated balance sheets	'
	Net deferred tax assets and liabilities were classified in the unaudited consolidated balance sheets as follows for the periods presented:
	(in thousands)	30-Jun-14			31-Dec-13
	Deferred tax asset	$	13,588		$	3,634
	Deferred tax liability	(15,980		)	(16,293		)
	Net deferred tax liability	$	(2,392	)	$	(12,659	)

Derivatives_Tables

Derivatives (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Schedule of Derivative Instrument Activity	'
	The following table summarizes information about these additional commodity derivative contracts:
			Aggregate			Swap				Floor				Ceiling				Contract period
			volumes			price				price				price
	Oil (volumes in Bbl):
	Swap		288,000			$	103.56			$	—			$	—			July 2014 - December 2014
	Swap		672,000			$	96.56			$	—			$	—			January 2015 - December 2015
	Price collar		696,000			$	—			$	80			$	100.2			January 2016 - December 2016
	Swap		640,500			$	84.85			$	—			$	—			January 2016 - December 2016
	Swap		933,300			$	84.8			$	—			$	—			January 2016 - December 2016
	Natural gas (volumes in MMBtu):
	Swap(1)		5,508,000			$	4.32			$	—			$	—			March 2014 - December 2014
	Price collar(1)		3,797,500			$	—			$	4			$	5.5			May 2014 - December 2014
	Price collar(1)		20,440,000			$	—			$	3			$	5.95			January 2015 - December 2015
	Price collar(1)		18,666,000			$	—			$	3			$	5.6			January 2016 - December 2016
	______________________________________________________________________________
	(1)        These natural gas derivatives are settled based on the Inside FERC West Texas Waha index price for the calculation period.
Summary of open positions and derivatives in place	'
	The following table summarizes open positions as of June 30, 2014, and represents, as of such date, derivatives in place through December 2016, on annual production volumes:
			Remaining Year				Year				Year
			2014				2015				2016
	Oil positions:
	Puts:
	Hedged volume (Bbl)		270,000				456,000				—
	Weighted-average price ($/Bbl)		$	75			$	75			$	—
	Swaps:
	Hedged volume (Bbl)		1,371,998				672,000				1,573,800
	Weighted-average price ($/Bbl)		$	96.35			$	96.56			$	84.82
	Collars:
	Hedged volume (Bbl)		1,473,000				6,557,020				2,556,000
	Weighted-average floor price ($/Bbl)		$	86.42			$	79.81			$	80
	Weighted-average ceiling price ($/Bbl)		$	104.89			$	95.4			$	93.77
	Basis swaps:
	Hedged volume(1) (Bbl)		1,104,000				—				—
	Weighted-average price(1) ($/Bbl)		$	(1.00	)		$	—			$	—
	Natural gas positions:
	Swaps:
	Hedged volume (MMBtu)		3,312,000				—				—
	Weighted-average price ($/MMBtu)		$	4.32			$	—			$	—
	Collars:
	Hedged volume (MMBtu)		7,652,000				28,600,000				18,666,000
	Weighted-average floor price ($/MMBtu)		$	3.37			$	3			$	3
	Weighted-average ceiling price ($/MMBtu)		$	5.5			$	5.96			$	5.6
	_______________________________________________________________________________
	-1	The associated oil basis swap derivative is settled based on the differential between the WTI Argus index oil price and the Midland Argus oil futures.
Schedule of gains and losses on derivative instruments	'
	The following represents cash settlements (paid) received for matured derivatives for the periods presented:
			Three months ended June 30,								Six months ended June 30,
	(in thousands)		2014				2013				2014				2013
	Commodity derivatives (paid) received		$	(4,420	)		$	1,086			$	(5,851	)		$	4,863
	Interest rate derivatives paid		—				(105		)		—				(206		)
	Cash settlements (paid) received for matured derivatives, net		$	(4,420	)		$	981			$	(5,851	)		$	4,657
Summary of derivatives outstanding on a gross basis	'
	The following summarizes the fair value of derivatives outstanding on a gross basis as of June 30, 2014 and December 31, 2013, respectively:
	(in thousands)		30-Jun-14				31-Dec-13
	Assets:
	Commodity derivatives:
	Oil derivatives		$	20,484			$	140,496
	Natural gas derivatives		2,125				657
	Total assets		$	22,609			$	141,153
	Liabilities:
	Commodity derivatives:
	Oil derivatives(1)		$	96,749			$	56,818
	Natural gas derivatives(2)		5,191				2,278
	Total liabilities		$	101,940			$	59,096
	Net derivative position		$	(79,331	)		$	82,057
	______________________________________________________________________________
	-1	The oil derivatives fair value includes a deferred premium liability of $7.9 million and $11.1 million as of June 30, 2014 and December 31, 2013, respectively.
	-2	The natural gas derivatives fair value includes a deferred premium liability of $1.1 million and $1.6 million as of June 30, 2014 and December 31, 2013, respectively.

Fair_value_measurements_Tables

Fair value measurements (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of fair value hierarchy for assets and liabilities measured at fair value on a recurring basis	'
	The following presents the Company’s fair value hierarchy for assets and liabilities measured at fair value on a recurring basis for the periods presented:
	(in thousands)	Level 1			Level 2			Level 3			Total fair
											value
	As of June 30, 2014:
	Commodity derivatives	$	—		$	(70,306	)	$	—		$	(70,306	)
	Deferred premiums	—			—			(9,025		)	(9,025		)
	Total	$	—		$	(70,306	)	$	(9,025	)	$	(79,331	)
	(in thousands)	Level 1			Level 2			Level 3			Total fair
											value
	As of December 31, 2013:
	Commodity derivatives	$	—		$	94,741		$	—		$	94,741
	Deferred premiums	—			—			(12,684		)	(12,684		)
	Total	$	—		$	94,741		$	(12,684	)	$	82,057
Actual cash payments required for deferred premium contracts	'
	The following table presents actual cash payments required for deferred premium contracts in place as of June 30, 2014, and for the calendar years following:
	(in thousands)
	Remaining 2014	$	3,640
	2015	5,166
	2016	358
	Total	$	9,164
Summary of changes in assets (liability) classified as Level 3 measurements	'
	A summary of the changes in assets classified as Level 3 measurements for the periods presented are as follows:
		Three months ended June 30,						Six months ended June 30,
	(in thousands)	2014			2013			2014			2013
	Balance of Level 3 at beginning of period	$	(10,790	)	$	(22,438	)	$	(12,684	)	$	(24,709	)
	Change in net present value of deferred premiums for derivatives	(55		)	(131		)	(120		)	(282		)
	Settlements	1,820			2,827			3,779			5,249
	Balance of Level 3 at end of period	$	(9,025	)	$	(19,742	)	$	(9,025	)	$	(19,742	)

Net_income_loss_per_share_Tabl

Net income (loss) per share (Tables)	6 Months Ended
	Jun. 30, 2014
Earnings Per Share [Abstract]	'
Schedule of calculation of basic and diluted weighted average shares outstanding and net income per share	'
	The following is the calculation of basic and diluted weighted-average shares outstanding and net income (loss) per share for the periods presented:
		Three months ended June 30,					Six months ended June 30,
	(in thousands, except for per share data)	2014			2013		2014			2013
	Net income (loss) (numerator):
	Income (loss) from continuing operations—basic and diluted	$	(18,899	)	$	35,294	$	(19,112	)	$	36,431
	Income from discontinued operations, net of tax—basic and diluted	—			518		—			790
	Net income (loss)—basic and diluted	$	(18,899	)	$	35,812	$	(19,112	)	$	37,221
	Weighted-average shares (denominator):
	Weighted-average shares—basic	141,298			127,362		141,183			127,281
	Non-vested restricted stock	—			2,022		—			1,838
	Weighted-average shares—diluted	141,298			129,384		141,183			129,119
	Net income (loss) per share:
	Basic:
	Income (loss) from continuing operations	$	(0.13	)	$	0.28	$	(0.14	)	$	0.29
	Income from discontinued operations, net of tax	—			—		—			0.01
	Net income (loss) per share	$	(0.13	)	$	0.28	$	(0.14	)	$	0.3
	Diluted:
	Income (loss) from continuing operations	$	(0.13	)	$	0.27	$	(0.14	)	$	0.28
	Income from discontinued operations, net of tax	—			—		—			0.01
	Net income (loss) per share	$	(0.13	)	$	0.27	$	(0.14	)	$	0.29

Subsidiary_guarantees_Tables

Subsidiary guarantees (Tables)	6 Months Ended
	Jun. 30, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]	'
Schedule of condensed consolidating balance sheet	'
	Condensed consolidating balance sheet
	June 30, 2014
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Accounts receivable, net	$	95,604		$	116		$	—		$	95,720
	Other current assets	434,888			13			—			434,901
	Total oil and natural gas properties, net	2,475,094			—			—			2,475,094
	Total midstream service assets, net	—			74,258			—			74,258
	Total other fixed assets, net	28,574			290			—			28,864
	Investment in subsidiaries and equity method investee	88,330			40,871			(88,330		)	40,871
	Total other long-term assets	31,330			—			—			31,330
	Total assets	$	3,153,820		$	115,548		$	(88,330	)	$	3,181,038
	Accounts payable	$	18,017		$	370		$	—		$	18,387
	Other current liabilities	289,433			26,848			—			316,281
	Other long-term liabilities	80,642			—			—			80,642
	Long-term debt	1,501,419			—			—			1,501,419
	Stockholders’ equity	1,264,309			88,330			(88,330		)	1,264,309
	Total liabilities and stockholders’ equity	$	3,153,820		$	115,548		$	(88,330	)	$	3,181,038
	Condensed consolidating balance sheet
	December 31, 2013
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Accounts receivable, net	$	77,318		$	—		$	—		$	77,318
	Other current assets	230,291			—			—			230,291
	Total oil and natural gas properties, net	2,135,348			—			—			2,135,348
	Total midstream service assets, net	5,802			41,498			—			47,300
	Total other fixed assets, net	21,676			—			—			21,676
	Investment in subsidiaries and equity method investee	36,666			5,913			(36,666		)	5,913
	Total other long-term assets	105,914			—			—			105,914
	Total assets	$	2,613,015		$	47,411		$	(36,666	)	$	2,623,760
	Accounts payable	$	12,216		$	3,786		$	—		$	16,002
	Other current liabilities	231,008			6,959			—			237,967
	Other long-term liabilities	45,997			—			—			45,997
	Long-term debt	1,051,538			—			—			1,051,538
	Stockholders’ equity	1,272,256			36,666			(36,666		)	1,272,256
	Total liabilities and stockholders’ equity	$	2,613,015		$	47,411		$	(36,666	)	$	2,623,760
Schedule of condensed consolidating statement of operations	'
	Condensed consolidating statement of operations
	For the three months ended June 30, 2014
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Total operating revenues	$	182,872		$	1,542		$	(1,370	)	$	183,044
	Total operating costs and expenses	116,596			3,257			(1,370		)	118,483
	Income (loss) from operations	66,276			(1,715		)	—			64,561
	Interest expense, net	(30,463		)	—			—			(30,463		)
	Other, net	(65,086		)	(44		)	1,759			(63,371		)
	Loss from continuing operations before income tax	(29,273		)	(1,759		)	1,759			(29,273		)
	Deferred income tax benefit	10,374			—			—			10,374
	Loss from continuing operations	(18,899		)	(1,759		)	1,759			(18,899		)
	Net loss	$	(18,899	)	$	(1,759	)	$	1,759		$	(18,899	)
	Condensed consolidating statement of operations
	For the three months ended June 30, 2013
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Total operating revenues	$	177,296		$	2,718		$	(2,718	)	$	177,296
	Total operating costs and expenses	122,028			572			(2,718		)	119,882
	Income from operations	55,268			2,146			—			57,414
	Interest expense, net	(25,931		)	—			—			(25,931		)
	Other, net	27,049			(49		)	(3,142		)	23,858
	Income from continuing operations before income tax	56,386			2,097			(3,142		)	55,341
	Deferred income tax expense	(20,047		)	—			—			(20,047		)
	Income from continuing operations	36,339			2,097			(3,142		)	35,294
	Income (loss) from discontinued operations, net of tax	(527		)	1,045			—			518
	Net income	$	35,812		$	3,142		$	(3,142	)	$	35,812
	Condensed consolidating statement of operations
	For the six months ended June 30, 2014
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Total operating revenues	$	356,086		$	2,572		$	(2,304	)	$	356,354
	Total operating costs and expenses	229,106			4,953			(2,304		)	231,755
	Income (loss) from operations	126,980			(2,381		)	—			124,599
	Interest expense, net	(59,366		)	—			—			(59,366		)
	Other, net	(96,993		)	(77		)	2,458			(94,612		)
	Loss from continuing operations before income tax	(29,379		)	(2,458		)	2,458			(29,379		)
	Deferred income tax benefit	10,267			—			—			10,267
	Loss from continuing operations	(19,112		)	(2,458		)	2,458			(19,112		)
	Net loss	$	(19,112	)	$	(2,458	)	$	2,458		$	(19,112	)
	Condensed consolidating statement of operations
	For the six months ended June 30, 2013
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Total operating revenues	$	340,965		$	5,364		$	(5,328	)	$	341,001
	Total operating costs and expenses	242,859			1,551			(5,328		)	239,082
	Income from operations	98,106			3,813			—			101,919
	Interest expense, net	(51,265		)	—			—			(51,265		)
	Other, net	13,089			(113		)	(6,042		)	6,934
	Income from continuing operations before income tax	59,930			3,700			(6,042		)	57,588
	Deferred income tax expense	(21,157		)	—			—			(21,157		)
	Income from continuing operations	38,773			3,700			(6,042		)	36,431
	Income (loss) from discontinued operations, net of tax	(1,552		)	2,342			—			790
	Net income	$	37,221		$	6,042		$	(6,042	)	$	37,221
Schedule of condensed consolidating statement of cash flows	'
	Condensed consolidating statement of cash flows
	For the six months ended June 30, 2014
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Net cash flows provided by (used in) operating activities	$	240,880		$	(3,239	)	$	2,458		$	240,099
	Change in investments between affiliates	(44,202		)	46,660			(2,458		)	—
	Capital expenditures and other	(435,807		)	(43,421		)	—			(479,228		)
	Net cash flows provided by financing activities	440,482			—			—			440,482
	Net increase in cash and cash equivalents	201,353			—			—			201,353
	Cash and cash equivalents at beginning of period	198,153			—			—			198,153
	Cash and cash equivalents at end of period	$	399,506		$	—		$	—		$	399,506
	Condensed consolidating statement of cash flows
	For the six months ended June 30, 2013
	(Unaudited)
	(in thousands)	Laredo			Laredo Midstream			Intercompany			Consolidated
								eliminations			company
	Net cash flows provided by operating activities	$	177,967		$	6,365		$	(6,042	)	$	178,290
	Change in investments between affiliates	(11,266		)	5,224			6,042			—
	Capital expenditures and other	(384,704		)	(11,589		)	—			(396,293		)
	Net cash flows provided by financing activities	228,367			—			—			228,367
	Net increase in cash and cash equivalents	10,364			—			—			10,364
	Cash and cash equivalents at beginning of period	33,224			—			—			33,224
	Cash and cash equivalents at end of period	$	43,588		$	—		$	—		$	43,588

Supplementary_information_Tabl

Supplementary information (Tables)	6 Months Ended
	Jun. 30, 2014
Oil and Gas Exploration and Production Industries Disclosures [Abstract]	'
Schedule of costs incurred in the development of oil and natural gas properties	'
	Costs incurred in the acquisition, exploration and development of oil and natural gas assets are presented below for the periods presented:
			Three months ended June 30,				Six months ended June 30,
	(in thousands)		2014		2013		2014		2013
	Property acquisition costs:								—
	Proved		$	3,848	$	—	$	3,873	$	—
	Unproved		2,645		—		9,925		—
	Exploration		8,143		12,167		16,642		20,928
	Development costs(1)		220,240		165,416		408,553		322,732
	Total costs incurred		$	234,876	$	177,583	$	438,993	$	343,660
	____________________________________________________________________________
	-1	The costs incurred for oil and natural gas development activities include $0.9 million and $0.7 million in asset retirement obligations for the three months ended June 30, 2014 and 2013, respectively, and $1.5 million and $1.3 million for the six months ended June 30, 2014 and 2013, respectively.

Basis_of_presentation_and_sign3

Basis of presentation and significant accounting policies - Current assets and liabilities (Details) (USD $)	6 Months Ended
	Jun. 30, 2014		Dec. 31, 2013
	segment
Basis of presentation	'		'
Number of operating segments	1		'
Accounts receivable	'		'
Term of accounts receivable to be considered as past due (in days)	'30 days		'
Term of past due balances to be reviewed individually for collectability (in days)	'90 days		'
Oil and natural gas sales	$68,476,000		$57,647,000
Joint operations, net	23,274,000	[1]	16,629,000	[1]
Other	3,970,000		3,042,000
Total	95,720,000		77,318,000
Allowance for doubtful accounts of accounts receivable for joint operations	700,000		700,000
Other current liabilities	'		'
Accrued interest payable	37,065,000		25,885,000
Accrued compensation and benefits	11,804,000		16,711,000
Lease operating expense payable	11,056,000		10,637,000
Performance unit awards	2,971,000		0
Asset retirement obligations	886,000		265,000
Prepaid drilling liability	851,000		1,393,000
Other accrued liabilities	13,374,000		17,340,000
Total other current liabilities	$78,007,000		$72,231,000
[1]	Accounts receivable for joint operations are presented net of an allowance for doubtful accounts of $0.7 million as of June 30, 2014 and December 31, 2013.

Basis_of_presentation_and_sign4

Basis of presentation and significant accounting policies - Property and equipment (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Proved oil and natural gas properties	$3,698,051	'	$3,698,051	'	$3,276,578
Less accumulated depletion and impairment	-1,448,013	'	-1,448,013	'	-1,349,315
Proved oil and natural gas properties, net	2,250,038	'	2,250,038	'	1,927,263
Unproved properties not being amortized	225,056	'	225,056	'	208,085
Midstream service assets	80,265	'	80,265	'	51,704
Other fixed assets	42,016	'	42,016	'	32,832
Net property and equipment	2,578,216	'	2,578,216	'	2,204,324
Depletion expense in dollars per BOE	19.55	20.08	19.58	20.16	'
Well Services and Midstream Assets	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Less accumulated depreciation and amortization	-6,007	'	-6,007	'	-4,404
Net property and equipment	74,258	'	74,258	'	47,300
Other fixed assets	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Less accumulated depreciation and amortization	-13,152	'	-13,152	'	-11,156
Net property and equipment	$28,864	'	$28,864	'	$21,676

Basis_of_presentation_and_sign5

Basis of presentation and significant accounting policies - Deferred loan costs and asset retirement obligations (Details) (USD $)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Deferred loan costs	'	'	'	'	'
Capitalization of deferred loan costs	'	'	$7,791,000	$714,000	'
Deferred loan costs, net	31,088,000	'	31,088,000	'	25,933,000
Accumulated amortization	16,700,000	'	16,700,000	'	14,200,000
Write-off of deferred loan costs	0	0	124,000	0	'
Future amortization expense of deferred loan costs	'	'	'	'	'
Remaining 2014	2,627,000	'	2,627,000	'	'
2015	5,295,000	'	5,295,000	'	'
2016	5,361,000	'	5,361,000	'	'
2017	5,432,000	'	5,432,000	'	'
2018	5,222,000	'	5,222,000	'	'
Thereafter	7,151,000	'	7,151,000	'	'
Total	31,088,000	'	31,088,000	'	25,933,000
Reconciliation of asset retirement obligations liability	'	'	'	'	'
Liability at beginning of period	'	'	21,743,000	21,505,000	21,505,000
Liabilities added due to acquisitions, drilling and other	'	'	1,591,000	'	2,709,000
Accretion expense	422,000	410,000	837,000	804,000	1,475,000
Liabilities settled upon plugging and abandonment	'	'	-310,000	'	-226,000
Liabilities removed due to Anadarko Basin Sale(1)	'	'	0	'	-7,801,000
Revision of estimates	'	'	0	'	4,081,000
Liability at end of period	$23,861,000	'	$23,861,000	'	$21,743,000

Basis_of_presentation_and_sign6

Basis of presentation and significant accounting policies - Supplemental cash flow information (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Accounting Policies [Abstract]	'	'	'	'
Cash paid for interest, net of $0 and $212 of capitalized interest, respectively	'	'	$46,140	$48,348
Capitalized interest	'	'	0	212
Change in accrued capital expenditures	'	'	13,346	-33,892
Capitalized asset retirement cost	'	'	1,591	1,262
Capitalized stock-based compensation	1,249	0	2,167	0
Restricted deposits on pending sale	'	'	$0	$44,000

Acquisition_and_divestiture_Ac

Acquisition and divestiture Acquisition (Details) (USD $)	6 Months Ended		0 Months Ended			0 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 23, 2014	Feb. 25, 2014	Jun. 23, 2014	Jun. 11, 2014	Jun. 11, 2014
			Proved and Unproved Oil and Natural Gas Properties in Glasscock County Texas	Proved and Unproved Oil and Natural Gas Properties in Glasscock County Texas	Proved and Unproved Oil and Natural Gas Properties in Glasscock County Texas	Proved and Unproved Oil and Natural Gas Properties in Reagan County Texas	Proved and Unproved Oil and Natural Gas Properties in Reagan County Texas
				acre	acre		acre
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'	'	'
Area of Land	'	'	'	278	24	'	460
Acquisition of mineral interests	$7,305	$0	'	$7,300	'	'	'
Acquisition of oil and natural gas properties	$6,493	$0	$1,800	'	'	$4,700	'

Acquisition_and_divestiture_Di

Acquisition and divestiture Divestitures- Anadarko Basin Sale (Details) (USD $)

3 Months Ended

6 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

0 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Aug. 01, 2013

Jun. 30, 2013

Jun. 30, 2013

Dec. 31, 2013

Aug. 01, 2013

Aug. 01, 2013

Aug. 01, 2013

Andarko Basin

Andarko Basin

Andarko Basin

Andarko Basin

Oil and Gas Properties

Other Third Parties

EnerVest

Andarko Basin

Andarko Basin

Andarko Basin

Significant Acquisitions and Disposals [Line Items]

'

'

'

'

'

'

'

'

'

'

'

Proceeds from sale of oil and gas property and equipment, gross

'

'

'

'

'

'

'

'

'

$38,000,000

$400,000,000

Proceeds from Sale of Oil and Gas Property and Equipment

'

'

'

'

428,300,000

'

'

'

'

'

'

Proceeds from Divestiture of Businesses

'

'

'

'

'

'

'

'

388,000,000

'

'

Revenues

'

1,478,000

'

3,310,000

'

26,135,000

49,737,000

'

'

'

'

Expenses

'

'

'

'

'

19,918,000

[1]

40,837,000

[1]

'

'

'

'

Gain on disposition of assets

($205,000)

($59,000)

($226,000)

($59,000)

'

'

'

$3,200,000

'

'

'

[1]

Expenses include lease operating expense, production and ad valorem tax expense, accretion expense and depletion, depreciation and amortization expense.

Acquisition_and_divestiture_Di1

Acquisition and divestiture Divestitures (Details) (USD $)	3 Months Ended	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2013	Jun. 30, 2013
Revenues:	'	'
Midstream service revenue	$1,478	$3,310
Total revenues from discontinued operations	1,478	3,310
Cost and expenses:	'	'
Midstream service expense	669	1,449
Depletion, depreciation and amortization	0	627
Total costs and expenses from discontinued operations	669	2,076
Income from discontinued operations before income tax	809	1,234
Income tax expense	-291	-444
Income from discontinued operations	$518	$790

Debt_Interest_expense_and_deta

Debt - Interest expense and details of debt outstanding (Details) (USD $)

3 Months Ended

6 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jan. 20, 2011

Oct. 19, 2011

Apr. 27, 2012

Jun. 30, 2014

Jun. 30, 2014

Aug. 06, 2014

Senior Secured Credit Facility

Letter of Credit

January 2019 Notes

October 2019 Notes

May 2022 Notes

Minimum

Maximum

Subsequent Event

Senior Secured Credit Facility

Senior Secured Credit Facility

Senior Secured Credit Facility

Debt Disclosure [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

Cash payments for interest

$19,291,000

$20,816,000

$46,140,000

$48,560,000

'

'

'

'

'

'

'

'

Amortization of deferred loan costs and other adjustments

1,194,000

1,320,000

2,323,000

2,624,000

'

'

'

'

'

'

'

'

Change in accrued interest

10,172,000

3,924,000

11,180,000

320,000

'

'

'

'

'

'

'

'

Interest costs incurred

30,657,000

26,060,000

59,643,000

51,504,000

'

'

'

'

'

'

'

'

Less capitalized interest

0

-117,000

0

-212,000

'

'

'

'

'

'

'

'

Total interest expense

30,657,000

25,943,000

59,643,000

51,292,000

'

'

'

'

'

'

'

'

Debt

'

'

'

'

'

'

'

'

'

'

'

'

Debt issued

'

'

'

'

'

'

350,000,000

200,000,000

500,000,000

'

'

'

Interest rate (as a percent)

'

'

'

'

'

'

9.50%

9.50%

7.38%

'

'

'

Borrowing capacity

1,000,000,000

'

1,000,000,000

'

825,000,000

20,000,000

'

'

'

'

'

'

Outstanding amount

'

'

'

'

$0

'

'

'

'

'

'

$0

Line of credit facility, unused capacity, commitment fee percentage

'

'

'

'

'

'

'

'

'

0.38%

0.50%

'

Debt_January_2022_Notes_Detail

Debt -January 2022 Notes (Details) (Senior Notes, January 2022 Notes, USD $)	0 Months Ended	6 Months Ended
In Millions, unless otherwise specified	Jan. 23, 2014	Jun. 30, 2014
Debt Instrument [Line Items]	'	'
Face amount of debt	450	'
Interest rate (as a percent)	5.63%	'
Net proceeds from offering	442.2	'
Prior to January 15, 2015	'	'
Debt Instrument [Line Items]	'	'
Redemption price of debt instrument (as a percent)	110.00%	'
Debt instrument, redemption period, start date	'	23-Jan-14
Debt instrument, redemption period, end date	'	15-Jan-15
Prior to January 15, 2017	'	'
Debt Instrument [Line Items]	'	'
Redemption price of debt instrument (as a percent)	100.00%	'
Debt instrument redemption price percentage of principal amount that can be redeemed by equity offering	35.00%	'
Debt instrument redeemed by equity offering redemption price (percentage)	105.63%	'
Debt instrument redemption principal amount outstanding threshold (percentage)	65.00%	'
Debt instrument redemption principal amount outstanding threshold (in days)	'180 days	'
Debt instrument, redemption period, start date	'	23-Jan-14
Debt instrument, redemption period, end date	'	15-Jan-17

Debt_Fair_value_of_debt_Detail

Debt - Fair value of debt (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
Carrying value	'		'
Fair value of debt	'		'
Debt	$1,501,419,000		$1,051,538,000
Fair value	'		'
Fair value of debt	'		'
Debt	1,626,500,000		1,164,688,000
2019 Notes | Carrying value	'		'
Fair value of debt	'		'
Debt	551,419,000	[1]	551,538,000	[1]
2019 Notes | Fair value	'		'
Fair value of debt	'		'
Debt	599,500,000	[1]	615,313,000	[1]
October 2019 Notes	'		'
Fair value of debt	'		'
Unamortized bond premium	1,400,000		1,500,000
May 2022 Notes | Carrying value	'		'
Fair value of debt	'		'
Debt	500,000,000		500,000,000
May 2022 Notes | Fair value	'		'
Fair value of debt	'		'
Debt	561,250,000		549,375,000
Senior Notes | January 2022 Notes | Carrying value	'		'
Fair value of debt	'		'
Debt	450,000,000		0
Senior Notes | January 2022 Notes | Fair value	'		'
Fair value of debt	'		'
Debt	$465,750,000		$0
[1]	The carrying value of the 2019 Notes includes the October Notes unamortized bond premium of $1.4 million and $1.5 million as of June 30, 2014 and December 31, 2013, respectively.

Employee_compensation_Details

Employee compensation (Details) (USD $)

3 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

0 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Jun. 30, 2014

Feb. 27, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Long-Term Incentive Plan

Restricted Stock Awards

Restricted Stock Awards

Employee Stock Option

Employee Stock Option

Performance Shares

Performance Shares

Performance Unit Awards

Performance Unit Awards

Performance Unit Awards

Performance Unit Awards

Reorganization Grant Date

Annually After Reorganization Grant Date

One Year From Grant Date

Two Years From Grant Date

Three Years From Grant Date

Vesting In Two Years

Vesting In Three Years

One Year From Grant Date

Three Years From Grant Date

15-Feb-13

3-Feb-12

Long-Term Incentive Plan

Restricted Stock Awards

Restricted Stock Awards

Restricted Stock Awards

Restricted Stock Awards

Restricted Stock Awards

Restricted Stock Awards

Restricted Stock Awards

Restricted Stock Awards

Restricted Stock Awards

Performance Unit Awards

Performance Unit Awards

anniversary

Long-Term Incentive Plan

Long-Term Incentive Plan

Long-Term Incentive Plan

installment

Equity and stock-based compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares available for issuance

'

'

'

'

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based compensation arrangement by share-based payment award, award vesting rights (percentage)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20.00%

20.00%

33.00%

33.00%

34.00%

50.00%

50.00%

100.00%

100.00%

'

'

Stock-based compensation not yet recognized

'

'

'

'

'

$39,500,000

'

'

'

'

$6,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock-based compensation not yet recognized, period for recognition

'

'

'

'

'

'1 year 10 months 28 days

'

'2 years 9 months 14 days

'

'

'2 years 7 months 28 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of installments over which awards vest and are exercisable

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of anniversaries over which awards vest and are exercisable

'

'

'

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Requisite service period of the awards

'

'

'

'

'

'

'

'4 years

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based compensation, not yet recognized, stock options

'

'

'

'

'

'

'

10,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based compensation, expiration period

'

'

'

'

'

'

'

'10 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based compensation arrangement by share based payment award, vested awards, expiration period, termination caused by death

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based compensation arrangement by share based payment award, vested awards, expiration period, termination without cause

'

'

'

'

'

'

'

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding shares

'

'

'

'

'

2,383,000

1,799,000

'

'

'

271,667

'

'

'

'

'

'

'

'

'

'

'

'

'

44,481

27,381

Net stock-based compensation expense

$6,396,000

$4,463,000

$10,725,000

$7,680,000

'

'

'

'

'

'

'

$1,100,000

$2,100,000

$1,200,000

$2,200,000

'

'

'

'

'

'

'

'

'

'

'

Employee_compensation_Restrict

Employee compensation Restricted Stock Option Awards (Details 1) (USD $)	3 Months Ended		6 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013
Weighted-average grant date fair value	'	'	'		'
Tax deficiency related to vested stock awards	$0.10	$0.10	$0.20		$0.40
Restricted Stock Awards	'	'	'		'
Restricted stock awards	'	'	'		'
Outstanding at the beginning of the period (in shares)	'	'	1,799,000		'
Granted (in shares)	'	'	1,161,000		'
Forfeited (in shares)	'	'	-50,000		'
Vested (in shares)	'	'	-527,000	[1]	'
Outstanding at the end of the period (in shares)	2,383,000	'	2,383,000		'
Weighted-average grant date fair value	'	'	'		'
Outstanding at the beginning of the period (in dollars per share)	'	'	$19.17		'
Fair value per performance share	'	'	$25.75		'
Forfeited (in dollars per share)	'	'	$22.62		'
Vested (in dollars per share)	'	'	$17.70	[1]	'
Outstanding at the end of the period (in dollars per share)	$22.64	'	$22.64		'
Tax deficiency related to vested stock awards	'	$0.10	'		$0.40
[1]	The vesting of certain restricted stock awards could result in federal and state income tax expense or benefits related to the difference between the market price of the common stock at the date of vesting and the date of grant. For the three and six months ended June 30, 2014, the Company's recognized income tax expense related to the vesting of restricted stock awards was immaterial. The Company recognized income tax expense of $0.1 million and $0.4 million during the three and six months ended June 30, 2013, respectively, related to restricted stock awards, which were recorded as adjustments to deferred income taxes.

Employee_compensation_Restrict1

Employee compensation Restricted Stock Option Awards (Details 2) (USD $)	3 Months Ended				6 Months Ended				12 Months Ended
In Millions, except Share data, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013		Dec. 31, 2013
Weighted-average contractual term	'		'		'		'		'
Tax deficiency related to vested stock awards	$0.10		0.1		$0.20		0.4		'
Employee Stock Option	'		'		'		'		'
Restricted stock option awards	'		'		'		'		'
Outstanding at the beginning of the period (in shares)	'		'		1,229,000		'		'
Granted (in shares)	'		'		336,000		'		'
Exercised (in shares)	'		0	[1]	-91,000	[1]	0	[1]	'
Expired or canceled (in shares)	'		'		0		'		'
Forfeited (in shares)	'		'		-13,000		'		'
Outstanding at the end of the period (in shares)	1,461,000		'		1,461,000		'		1,229,000
Vested and exercisable at end of period (in shares)	355,000	[2]	'		355,000	[2]	'		'
Vested, exercisable, and expected to vest at end of period (in shares)	1,428,000	[3]	'		1,428,000	[3]	'		'
Weighted-average exercise price (per option)	'		'		'		'		'
Outstanding at the beginning of the period (in dollars per share)	'		'		$19.32		'		'
Granted (in dollars per share)	'		'		$25.60		'		'
Exercised (in dollars per share)	'		'		$20.02	[1]	'		'
Expired or cancelled (in dollars per share)	'		'		$0		'		'
Forfeited (in dollars per share)	'		'		$19.61		'		'
Outstanding at end of the period (in dollars per share)	$20.72		'		$20.72		'		$19.32
Exercisable, weighted average exercise price (in dollars per share)	$20.35	[2]	'		$20.35	[2]	'		'
Vested, exercisable, and expected to vest at end of period, weighted average exercise price (in dollars per share)	$20.71	[3]	'		$20.71	[3]	'		'
Weighted-average contractual term	'		'		'		'		'
Outstanding at the beginning of the period	'		'		'8 years 7 months 20 days		'		'8 years 9 months 26 days
Granted	'		'		'9 years 7 months 28 days		'		'
Exercised	'		'		'8 years 2 months 20 days	[1]	'		'
Outstanding at the end of the period	'		'		'8 years 7 months 20 days		'		'8 years 9 months 26 days
Vested and exercisable at the end of the period	'		'		'8 years 2 months 1 day	[2]	'		'
Vested, exercisable, and expected to vest at end of period	'		'		'8 years 7 months 20 days	[3]	'		'
Tax deficiency related to vested stock awards	0.1		'		0.2		'		'
Aggregate intrinsic value of vested and exercisable options	3.8		'		3.8		'		'
Aggregate intrinsic value of vested, exercisable and expected to vest options	$14.70		'		$14.70		'		'
[1]	The exercise of stock option awards could result in federal and state income tax expense or benefits related to the difference between the fair value of the stock option at the date of grant and the intrinsic value of the stock option when exercised. The Company recognized income tax expense of $0.1 million and $0.2 million during the three and six months ended June 30, 2014, respectively, related to stock options, which were recorded as adjustments to deferred income taxes. No stock options were exercised during the three and six months ended June 30, 2013.
[2]	The aggregate intrinsic value of vested and exercisable options at June 30, 2014 was $3.8 million.
[3]	The aggregate intrinsic value of vested, exercisable and expected to vest options at June 30, 2014 was $14.7 million.

Employee_compensation_Restrict2

Employee compensation Restricted Stock Option Awards (Details 3) (Employee Stock Option, USD $)	6 Months Ended
	Jun. 30, 2014
Employee Stock Option	'
Assumptions used to estimate the fair value of options granted	'
Risk-free interest rate (as a percent)	1.88%	[1]
Expected option life	'6 years 3 months	[2]
Expected volatility (as a percent)	53.21%	[3]
Fair value per option (in dollars per share)	$13.41
[1]	U.S. Treasury yields as of the grant date were utilized for the risk-free interest rate assumption, matching the treasury yield terms to the expected life of the option.
[2]	As the Company had limited exercise history at the time of valuation relating to terminations and modifications, expected option life assumptions were developed using the simplified method in accordance with GAAP.
[3]	The Company utilized a peer historical look-back, which was weighted with the Company’s own volatility, in order to develop the expected volatility.

Employee_compensation_Restrict3

Employee compensation Restricted Stock Option Awards (Details 4) (Employee Stock Option)	6 Months Ended
	Jun. 30, 2014
Less than one year of continuous employment	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Incremental percentage of option exercisable	0.00%
Cumulative percentage of option exercisable	0.00%
One year of continuous employment	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Incremental percentage of option exercisable	25.00%
Cumulative percentage of option exercisable	25.00%
Two years of continuous employment	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Incremental percentage of option exercisable	25.00%
Cumulative percentage of option exercisable	50.00%
Three years of continuous employment	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Incremental percentage of option exercisable	25.00%
Cumulative percentage of option exercisable	75.00%
Four years of continuous employment	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Incremental percentage of option exercisable	25.00%
Cumulative percentage of option exercisable	100.00%

Employee_compensation_Performa

Employee compensation Performance Share Awards (Details) (Performance Shares, USD $)	0 Months Ended
	Feb. 27, 2014		Feb. 27, 2014
Performance Shares	'		'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'		'
Requisite service period of the awards	'3 years		'
Risk-free interest rate (as a percent)	0.63%	[1]	'
Dividend yield	0.00%		'
Expected volatility (as a percent)	38.21%	[2]	'
Laredo stock closing price as of February 27, 2014	'		$25.60
Fair value per performance share	$28.56		'
[1]	The risk-free rate was derived using a zero-coupon yield derived from the Treasury Constant Maturities yield curve on the grant date.
[2]	The Company utilized a peer historical look-back, weighted with the Company's own volatility, to develop the expected volatility.

Employee_compensation_Stockbas

Employee compensation Stock-based Compensation Award Expense (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Total stock-based compensation	$7,645	$4,463	$12,892	$7,680
Less amounts capitalized in oil and natural gas properties	-1,249	0	-2,167	0
Net stock-based compensation expense	6,396	4,463	10,725	7,680
Restricted Stock Awards	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Total stock-based compensation	6,010	3,572	10,242	6,398
Restricted stock option awards	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Total stock-based compensation	1,010	891	1,805	1,282
Restricted Performance Shares	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Total stock-based compensation	$625	$0	$845	$0

Income_taxes_Details

Income taxes (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income Tax Disclosure [Abstract]	'	'	'	'
Current taxes	$0	$0	$0	$0
Deferred	10,374	-20,047	10,267	-21,157
Total income tax benefit (expense)	$10,374	($20,047)	$10,267	($21,157)

Income_taxes_Income_taxes_Deta

Income taxes Income taxes -(Details 2) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income Tax Disclosure [Abstract]	'	'	'	'
Continuing operations	$10,374	($20,047)	$10,267	($21,157)
Discontinued operations	0	-291	0	-444
Comprehensive provision for income taxes	$10,374	($20,338)	$10,267	($21,601)

Income_taxes_Income_taxes_Deta1

Income taxes Income taxes -(Details 3) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income Tax Disclosure [Abstract]	'	'	'	'
Income tax benefit (expense) computed by applying the statutory rate	$10,246	($18,816)	$10,283	($19,580)
State income tax, net of federal tax benefit and increase in valuation allowance	347	-551	1,634	-572
Non-deductible stock-based compensation	-123	-164	-239	-339
Stock-based compensation tax deficiency	-15	-120	-156	-411
Change in deferred tax valuation allowance	-34	-20	-1,112	-29
Other items	-47	-376	-143	-226
Total income tax benefit (expense)	$10,374	($20,047)	$10,267	($21,157)

Income_taxes_Details_4

Income taxes -(Details 4) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Significant components of deferred tax assets	'	'
Net operating loss carry-forward	$310,579	$284,890
Oil and natural gas properties and equipment	-351,515	-278,735
Derivatives	30,969	-30,859
Stock-based compensation	7,807	6,578
Accrued bonus	2,368	3,740
Capitalized interest	2,411	2,099
Other	-3,739	-240
Gross deferred tax liability	-1,120	-12,527
Valuation allowance	-1,272	-132
Net deferred tax liability	-2,392	-12,659
Net deferred tax assets and liabilities	'	'
Deferred tax asset	13,588	3,634
Deferred tax liability	-15,980	-16,293
Net deferred tax liability	($2,392)	($12,659)

Income_taxes_Additional_Inform

Income taxes - Additional Information (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Operating loss carry-forward	'	'	'	'	'
Unrecognized Tax Benefits	$0	'	$0	'	$0
Effective income tax rate (as a percent)	'	'	35.00%	'	'
Effective income tax rate reconciliation (as a percent)	35.00%	36.00%	35.00%	37.00%	'
Deferred Income Tax Stock Based Compensation Tax Deficiency	100,000	100,000	200,000	400,000	'
Adjustments to Additional Paid in Capital, Income Tax Benefit from Share-based Compensation, Potential Amount	'	'	4,200,000	'	'
Deferred Tax Assets, Valuation Allowance	1,272,000	'	1,272,000	'	132,000
Federal	'	'	'	'	'
Operating loss carry-forward	'	'	'	'	'
Net operating loss carry-forwards	879,000,000	'	879,000,000	'	'
State	'	'	'	'	'
Operating loss carry-forward	'	'	'	'	'
Net operating loss carry-forwards	112,800,000	'	112,800,000	'	'
Charitable Contribution Carryforward	'	'	'	'	'
Operating loss carry-forward	'	'	'	'	'
Net operating loss carry-forwards	3,600,000	'	3,600,000	'	'
Deferred Tax Assets, Valuation Allowance	$1,300,000	'	$1,300,000	'	'

Derivatives_Derivative_positio

Derivatives - Derivative positions (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013
Derivative financial instruments	'		'
Cash settlements received for early terminations of derivatives, net	$76,660		$0
Derivatives not designated as hedges	'		'
Derivative financial instruments	'		'
Number of open derivative contracts	48		'
Crude Oil | Derivatives not designated as hedges | Puts	'		'
Open positions	'		'
Hedged Volume (Bbl), Remaining Year 2014	270,000		'
Hedged Volume (Bbl), Year 2015	456,000		'
Hedged Volume (Bbl), Year 2016	0		'
Weighted-average price ($/bbl), Remaining Year 2014	75		'
Weighted-average price ($/bbl), Year 2015	75		'
Weighted-average price ($/bbl), Year 2016	0		'
Crude Oil | Derivatives not designated as hedges | Swaps	'		'
Open positions	'		'
Hedged Volume (Bbl), Remaining Year 2014	1,371,998		'
Hedged Volume (Bbl), Year 2015	672,000		'
Hedged Volume (Bbl), Year 2016	1,573,800		'
Weighted-average price ($/bbl), Remaining Year 2014	96.35		'
Weighted-average price ($/bbl), Year 2015	96.56		'
Weighted-average price ($/bbl), Year 2016	84.82		'
Crude Oil | Derivatives not designated as hedges | Swaps | Swap July 2014 - December 2014	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	288,000		'
Swap price	103.56		'
Floor price	0		'
Ceiling price	0		'
Crude Oil | Derivatives not designated as hedges | Swaps | Swap January 2015 - December 2015	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	672,000		'
Swap price	96.56		'
Floor price	0		'
Ceiling price	0		'
Crude Oil | Derivatives not designated as hedges | Swaps | Swap One January 2016 - December 2016	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	640,500		'
Swap price	84.85		'
Floor price	0		'
Ceiling price	0		'
Crude Oil | Derivatives not designated as hedges | Swaps | Swap Two January 2016 - December 2016	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	933,300		'
Swap price	84.8		'
Floor price	0		'
Ceiling price	0		'
Crude Oil | Derivatives not designated as hedges | Collars	'		'
Open positions	'		'
Hedged Volume (Bbl), Remaining Year 2014	1,473,000		'
Hedged Volume (Bbl), Year 2015	6,557,020		'
Hedged Volume (Bbl), Year 2016	2,556,000		'
Weighted-average floor price, Remaining Year 2014	86.42		'
Weighted-average floor price, Year 2015	79.81		'
Weighted-average floor price, Year 2016	80		'
Weighted-average ceiling price, Remaining Year 2014	104.89		'
Weighted-average ceiling price, Year 2015	95.4		'
Weighted-average ceiling price, Year 2016	93.77		'
Crude Oil | Derivatives not designated as hedges | Collars | Collar January 2016 - December 2016	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	696,000		'
Swap price	0		'
Floor price	80		'
Ceiling price	100.2		'
Crude Oil | Derivatives not designated as hedges | Oil Basis Swaps	'		'
Open positions	'		'
Hedged Volume (Bbl), Remaining Year 2014	1,104,000	[1]	'
Hedged Volume (Bbl), Year 2015	0	[1]	'
Hedged Volume (Bbl), Year 2016	0	[1]	'
Weighted-average price ($/bbl), Remaining Year 2014	-1	[1]	'
Weighted-average price ($/bbl), Year 2015	'	[1]	'
Weighted-average price ($/bbl), Year 2016	'	[1]	'
Natural Gas | Derivatives not designated as hedges | Swaps	'		'
Open positions	'		'
Hedged volume (MMBtu), Remaining Year 2014	3,312,000		'
Hedged volume (MMBtu), Year 2015	0		'
Hedged volume (MMBtu), Year 2016	0		'
Weighted-average price ($/MMBtu), Remaining Year 2014	4.32		'
Weighted-average price ($/MMBtu), Year 2015	'		'
Weighted-average price ($/MMBtu), Year 2016	'		'
Natural Gas | Derivatives not designated as hedges | Swaps | Swap March 2014 - December 2014	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	5,508,000	[2]	'
Swap price	4.315	[2]	'
Floor price	0	[2]	'
Ceiling price	0	[2]	'
Natural Gas | Derivatives not designated as hedges | Collars	'		'
Open positions	'		'
Hedged volume (MMBtu), Remaining Year 2014	7,652,000		'
Hedged volume (MMBtu), Year 2015	28,600,000		'
Hedged volume (MMBtu), Year 2016	18,666,000		'
Weighted-average floor price, Remaining Year 2014	3.37		'
Weighted-average floor price, Year 2015	3		'
Weighted-average floor price, Year 2016	3		'
Weighted-average ceiling price, Remaining Year 2014	5.5		'
Weighted-average ceiling price, Year 2015	5.96		'
Weighted-average ceiling price, Year 2016	5.6		'
Natural Gas | Derivatives not designated as hedges | Collars | Collar May 2014 - December 2014	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	3,797,500	[2]	'
Swap price	0	[2]	'
Floor price	4	[2]	'
Ceiling price	5.5	[2]	'
Natural Gas | Derivatives not designated as hedges | Collars | Collar January 2015 - December 2015	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	20,440,000	[2]	'
Swap price	0	[2]	'
Floor price	3	[2]	'
Ceiling price	5.95	[2]	'
Natural Gas | Derivatives not designated as hedges | Collars | Collar Two January 2016 - December 2016	'		'
Derivative financial instruments	'		'
Aggregate volumes (in Bbls/MMBtu)	18,666,000	[2]	'
Swap price	0	[2]	'
Floor price	3	[2]	'
Ceiling price	5.6	[2]	'
[1]	The associated oil basis swap derivative is settled based on the differential between the WTI Argus index oil price and the Midland Argus oil futures.
[2]	These natural gas derivatives are settled based on the Inside FERC West Texas Waha index price for the calculation period.

Derivatives_Gain_loss_on_deriv

Derivatives - Gain (loss) on derivatives (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Sep. 30, 2013
	derivative		derivative
Derivative financial instruments	'	'	'	'	'
Cash settlements (paid) received for matured derivatives, net	'	'	($5,851,000)	$4,657,000	'
Derivatives not designated as hedges	'	'	'	'	'
Derivative financial instruments	'	'	'	'	'
Cash settlements (paid) received for matured derivatives, net	-4,420,000	981,000	-5,851,000	4,657,000	'
Number of open derivative contracts	48	'	48	'	'
Commodity derivatives | Derivatives not designated as hedges	'	'	'	'	'
Derivative financial instruments	'	'	'	'	'
Cash settlements (paid) received for matured derivatives, net	-4,420,000	1,086,000	-5,851,000	4,863,000	'
Interest rate derivatives | Derivatives not designated as hedges	'	'	'	'	'
Derivative financial instruments	'	'	'	'	'
Cash settlements (paid) received for matured derivatives, net	0	-105,000	0	-206,000	'
Derivative, Notional Amount	'	'	'	'	$100,000,000
Number of open derivative contracts	0	'	0	'	'
Interest Rate Swap | Derivatives not designated as hedges	'	'	'	'	'
Derivative financial instruments	'	'	'	'	'
Number of Interest Rate Derivatives Held	'	'	'	'	1
Derivative, Fixed Interest Rate	'	'	'	'	1.11%
Interest Rate Cap | Derivatives not designated as hedges	'	'	'	'	'
Derivative financial instruments	'	'	'	'	'
Number of Interest Rate Derivatives Held	'	'	'	'	1
Derivative, Fixed Interest Rate	'	'	'	'	3.00%

Derivatives_Balance_sheet_pres

Derivatives - Balance sheet presentation (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
Oil derivatives	'		'
Fair value of derivatives outstanding on gross basis	'		'
Deferred premium liability	$7,900,000		$11,100,000
Natural gas derivatives	'		'
Fair value of derivatives outstanding on gross basis	'		'
Deferred premium liability	1,100,000		1,600,000
Derivatives not designated as hedges	'		'
Fair value of derivatives outstanding on gross basis	'		'
Fair value, derivative assets	22,609,000		141,153,000
Fair value, derivative liabilities	101,940,000		59,096,000
Net derivative position	-79,331,000		82,057,000
Derivatives not designated as hedges | Oil derivatives	'		'
Fair value of derivatives outstanding on gross basis	'		'
Fair value, derivative assets	20,484,000		140,496,000
Fair value, derivative liabilities	96,749,000	[1]	56,818,000	[1]
Derivatives not designated as hedges | Natural gas derivatives	'		'
Fair value of derivatives outstanding on gross basis	'		'
Fair value, derivative assets	2,125,000		657,000
Fair value, derivative liabilities	$5,191,000	[2]	$2,278,000	[2]
[1]	The oil derivatives fair value includes a deferred premium liability of $7.9 million and $11.1 million as of June 30, 2014 and December 31, 2013, respectively.
[2]	The natural gas derivatives fair value includes a deferred premium liability of $1.1 million and $1.6 million as of June 30, 2014 and December 31, 2013, respectively.

Fair_value_measurements_Fair_v

Fair value measurements - Fair value hierarchy (Details) (USD $)

6 Months Ended

In Thousands, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Minimum

Maximum

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Total fair value

Total fair value

Total fair value

Total fair value

Total fair value

Total fair value

Commodity derivatives

Commodity derivatives

Deferred Premiums

Deferred Premiums

Commodity derivatives

Commodity derivatives

Deferred Premiums

Deferred Premiums

Commodity derivatives

Commodity derivatives

Deferred Premiums

Deferred Premiums

Commodity derivatives

Commodity derivatives

Deferred Premiums

Deferred Premiums

Fair value measurement on a recurring basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Derivative Assets (Liabilities), at fair value, net

'

'

$0

$0

$0

$0

$0

$0

($70,306)

$94,741

($70,306)

$94,741

$0

$0

($9,025)

($12,684)

$0

$0

($9,025)

($12,684)

($79,331)

$82,057

($70,306)

$94,741

($9,025)

($12,684)

Discount rate used to discount deferred premium to net present value at contract trade date (as a percent)

2.00%

3.56%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair_value_measurements_Cash_p

Fair value measurements - Cash payments required for deferred premium contracts (Details) (USD $)	Jun. 30, 2014
In Thousands, unless otherwise specified
Fair Value Disclosures [Abstract]	'
Remaining 2014	$3,640
2015	5,166
2016	358
Total	$9,164

Fair_value_measurements_Summar

Fair value measurements - Summary of changes in assets (liabilities) classified as Level 3 (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Changes in assets classified as Level 3 measurements	'	'	'	'
Change in net present value of deferred premiums for derivatives	'	'	$120	$282
Deferred Premiums	'	'	'	'
Changes in assets classified as Level 3 measurements	'	'	'	'
Balance of Level 3 at beginning of period	-10,790	-22,438	-12,684	-24,709
Change in net present value of deferred premiums for derivatives	-55	-131	-120	-282
Settlements	1,820	2,827	3,779	5,249
Balance of Level 3 at end of period	($9,025)	($19,742)	($9,025)	($19,742)

Commitments_and_contingencies_

Commitments and contingencies (Details) (Drilling Contracts, USD $)	Jun. 30, 2014
In Millions, unless otherwise specified
Drilling Contracts	'
Unrecorded Unconditional Purchase Obligation [Line Items]	'
Future commitments	$34.80

Net_income_loss_per_share_Deta

Net income (loss) per share (Details) (USD $)	3 Months Ended	6 Months Ended
	Jun. 30, 2013	Jun. 30, 2013
February 2012 Awards	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'
Options, weighted average exercise price	24.11	24.11
February 2012 Awards | Employee Stock Option	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'
Antidilutive securities excluded from computation of net income per share	414,239	414,239
February 2013 Awards	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'
Options, weighted average exercise price	17.34	17.34
February 2013 Awards | Employee Stock Option	'	'
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]	'	'
Antidilutive securities excluded from computation of net income per share	968,938	968,938

Net_income_loss_per_share_Deta1

Net income (loss) per share - (Details 2) (USD $)	3 Months Ended		6 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Net income (loss) (numerator):	'	'	'	'
Income (loss) from continuing operations—basic and diluted	($18,899)	$35,294	($19,112)	$36,431
Income from discontinued operations, net of tax—basic and diluted	0	518	0	790
Net income (loss)—basic and diluted	($18,899)	$35,812	($19,112)	$37,221
Weighted average shares (denominator):	'	'	'	'
Weighted average shares-basic (in shares)	141,298	127,362	141,183	127,281
Non-vested restricted stock (in shares)	0	2,022	0	1,838
Weighted average shares-diluted (in shares)	141,298	129,384	141,183	129,119
Net income (loss) per share:	'	'	'	'
Income (loss) from continuing operations, per basic share	($0.13)	$0.28	($0.14)	$0.29
Income from discontinued operations, net of tax, per basic share	$0	$0	$0	$0.01
Basic (in dollars per share)	($0.13)	$0.28	($0.14)	$0.30
Income from continuing operations, per diluted share	($0.13)	$0.27	($0.14)	$0.28
Income from discontinued operations, net of tax, per diluted share	$0	$0	$0	$0.01
Diluted (in dollars per share)	($0.13)	$0.27	($0.14)	$0.29

Variable_interest_entity_Detai

Variable interest entity (Details) (USD $)	6 Months Ended			3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
				Medallion Gathering And Processing LLC	Medallion Gathering And Processing LLC	Medallion Gathering And Processing LLC	Medallion Gathering And Processing LLC	Medallion Gathering And Processing LLC	Medallion Gathering And Processing LLC	Medallion Gathering And Processing LLC
				Variable Interest Entity, Not Primary Beneficiary	Variable Interest Entity, Not Primary Beneficiary	Variable Interest Entity, Not Primary Beneficiary	Variable Interest Entity, Not Primary Beneficiary	Variable Interest Entity, Not Primary Beneficiary	Variable Interest Entity, Not Primary Beneficiary	Variable Interest Entity, Not Primary Beneficiary
								Financing Commitments	Financing Commitment Pipeline Cash Requirements	Financing Commitment Minimum Volume
Schedule of Equity Method Investments [Line Items]	'	'	'	'	'	'	'	'	'	'
Investment in equity method investee	$19,471,000	$3,287,000	'	$8,200,000	$2,300,000	$19,500,000	$3,200,000	'	'	'
Ownership percentage	'	'	'	49.00%	'	49.00%	'	'	'	'
Equity Method Investment Ownership Percentage Held By Investment Partner	'	'	'	51.00%	'	51.00%	'	'	'	'
Voting percentage required for key decisions	'	'	'	'	'	75.00%	'	'	'	'
Payments to Acquire Equity Method Investments In Next Twelve Months	'	'	'	'	'	'	'	21,600,000	'	'
Due to related parties	$20,104,000	'	$3,489,000	'	'	'	'	'	$18,100,000	$2,000,000

Subsidiary_guarantees_Condense

Subsidiary guarantees - Condensed consolidating balance sheet (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Subsidiary guarantees	'	'
Accounts receivable, net	$95,720	$77,318
Other current assets	434,901	230,291
Total oil and natural gas properties, net	2,475,094	2,135,348
Total midstream service assets, net	74,258	47,300
Total other fixed assets, net	28,864	21,676
Investment in subsidiaries and equity method investee	40,871	5,913
Total other long-term assets	31,330	105,914
Total assets	3,181,038	2,623,760
Accounts payable	18,387	16,002
Other current liabilities	316,281	237,967
Other long-term liabilities	80,642	45,997
Long-term debt	1,501,419	1,051,538
Stockholders’ equity	1,264,309	1,272,256
Total liabilities and stockholders’ equity	3,181,038	2,623,760
Intercompany eliminations	'	'
Subsidiary guarantees	'	'
Accounts receivable, net	0	0
Other current assets	0	0
Total oil and natural gas properties, net	0	0
Total midstream service assets, net	0	0
Total other fixed assets, net	0	0
Investment in subsidiaries and equity method investee	-88,330	-36,666
Total other long-term assets	0	0
Total assets	-88,330	-36,666
Accounts payable	0	0
Other current liabilities	0	0
Other long-term liabilities	0	0
Long-term debt	0	0
Stockholders’ equity	-88,330	-36,666
Total liabilities and stockholders’ equity	-88,330	-36,666
Laredo | Reportable Legal Entities	'	'
Subsidiary guarantees	'	'
Accounts receivable, net	95,604	77,318
Other current assets	434,888	230,291
Total oil and natural gas properties, net	2,475,094	2,135,348
Total midstream service assets, net	0	5,802
Total other fixed assets, net	28,574	21,676
Investment in subsidiaries and equity method investee	88,330	36,666
Total other long-term assets	31,330	105,914
Total assets	3,153,820	2,613,015
Accounts payable	18,017	12,216
Other current liabilities	289,433	231,008
Other long-term liabilities	80,642	45,997
Long-term debt	1,501,419	1,051,538
Stockholders’ equity	1,264,309	1,272,256
Total liabilities and stockholders’ equity	3,153,820	2,613,015
Subsidiary Guarantors | Reportable Legal Entities	'	'
Subsidiary guarantees	'	'
Accounts receivable, net	116	0
Other current assets	13	0
Total oil and natural gas properties, net	0	0
Total midstream service assets, net	74,258	41,498
Total other fixed assets, net	290	0
Investment in subsidiaries and equity method investee	40,871	5,913
Total other long-term assets	0	0
Total assets	115,548	47,411
Accounts payable	370	3,786
Other current liabilities	26,848	6,959
Other long-term liabilities	0	0
Long-term debt	0	0
Stockholders’ equity	88,330	36,666
Total liabilities and stockholders’ equity	$115,548	$47,411

Subsidiary_guarantees_Condense1

Subsidiary guarantees - Condensed consolidating statement of operations (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Subsidiary guarantees	'	'	'	'
Total operating revenues	$183,044	$177,296	$356,354	$341,001
Total operating costs and expenses	118,483	119,882	231,755	239,082
Income (loss) from operations	64,561	57,414	124,599	101,919
Interest expense, net	-30,463	-25,931	-59,366	-51,265
Other, net	-63,371	23,858	-94,612	6,934
Income (loss) from continuing operations before income tax	-29,273	55,341	-29,379	57,588
Deferred income tax benefit (expense)	10,374	-20,047	10,267	-21,157
Income (loss) from continuing operations	-18,899	35,294	-19,112	36,431
Income from discontinued operations, net of tax	0	518	0	790
Net income (loss)	-18,899	35,812	-19,112	37,221
Reportable Legal Entities | Laredo	'	'	'	'
Subsidiary guarantees	'	'	'	'
Total operating revenues	182,872	177,296	356,086	340,965
Total operating costs and expenses	116,596	122,028	229,106	242,859
Income (loss) from operations	66,276	55,268	126,980	98,106
Interest expense, net	-30,463	-25,931	-59,366	-51,265
Other, net	-65,086	27,049	-96,993	13,089
Income (loss) from continuing operations before income tax	-29,273	56,386	-29,379	59,930
Deferred income tax benefit (expense)	10,374	-20,047	10,267	-21,157
Income (loss) from continuing operations	-18,899	36,339	-19,112	38,773
Income from discontinued operations, net of tax	'	-527	'	-1,552
Net income (loss)	-18,899	35,812	-19,112	37,221
Reportable Legal Entities | Subsidiary Guarantors	'	'	'	'
Subsidiary guarantees	'	'	'	'
Total operating revenues	1,542	2,718	2,572	5,364
Total operating costs and expenses	3,257	572	4,953	1,551
Income (loss) from operations	-1,715	2,146	-2,381	3,813
Interest expense, net	0	0	0	0
Other, net	-44	-49	-77	-113
Income (loss) from continuing operations before income tax	-1,759	2,097	-2,458	3,700
Deferred income tax benefit (expense)	0	0	0	0
Income (loss) from continuing operations	-1,759	2,097	-2,458	3,700
Income from discontinued operations, net of tax	'	1,045	'	2,342
Net income (loss)	-1,759	3,142	-2,458	6,042
Intercompany eliminations	'	'	'	'
Subsidiary guarantees	'	'	'	'
Total operating revenues	-1,370	-2,718	-2,304	-5,328
Total operating costs and expenses	-1,370	-2,718	-2,304	-5,328
Income (loss) from operations	0	0	0	0
Interest expense, net	0	0	0	0
Other, net	1,759	-3,142	2,458	-6,042
Income (loss) from continuing operations before income tax	1,759	-3,142	2,458	-6,042
Deferred income tax benefit (expense)	0	0	0	0
Income (loss) from continuing operations	1,759	-3,142	2,458	-6,042
Income from discontinued operations, net of tax	'	0	'	0
Net income (loss)	$1,759	($3,142)	$2,458	($6,042)

Subsidiary_guarantees_Condense2

Subsidiary guarantees - Condensed consolidating statement of cash flows (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Subsidiary guarantees	'	'
Net cash flows provided by (used in) operating activities	$240,099	$178,290
Change in investments between affiliates	0	0
Capital expenditures and other	-479,228	-396,293
Net cash flows provided by financing activities	440,482	228,367
Net increase in cash and cash equivalents	201,353	10,364
Cash and cash equivalents at beginning of period	198,153	33,224
Cash and cash equivalents at end of period	399,506	43,588
Reportable Legal Entities | Laredo	'	'
Subsidiary guarantees	'	'
Net cash flows provided by (used in) operating activities	240,880	177,967
Change in investments between affiliates	-44,202	-11,266
Capital expenditures and other	-435,807	-384,704
Net cash flows provided by financing activities	440,482	228,367
Net increase in cash and cash equivalents	201,353	10,364
Cash and cash equivalents at beginning of period	198,153	33,224
Cash and cash equivalents at end of period	399,506	43,588
Reportable Legal Entities | Subsidiary Guarantors	'	'
Subsidiary guarantees	'	'
Net cash flows provided by (used in) operating activities	-3,239	6,365
Change in investments between affiliates	46,660	5,224
Capital expenditures and other	-43,421	-11,589
Net cash flows provided by financing activities	0	0
Net increase in cash and cash equivalents	0	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	0	0
Intercompany eliminations	'	'
Subsidiary guarantees	'	'
Net cash flows provided by (used in) operating activities	2,458	-6,042
Change in investments between affiliates	-2,458	6,042
Capital expenditures and other	0	0
Net cash flows provided by financing activities	0	0
Net increase in cash and cash equivalents	0	0
Cash and cash equivalents at beginning of period	0	0
Cash and cash equivalents at end of period	$0	$0

Subsequent_events_Subsequent_E

Subsequent events Subsequent Events (Details) (Proved and Unproved Oil and Natural Gas Properties in Reagan, Irion, Glasscock and Howard Counties, Subsequent Event, USD $)	Aug. 07, 2014
In Millions, unless otherwise specified	acre
Proved and Unproved Oil and Natural Gas Properties in Reagan, Irion, Glasscock and Howard Counties | Subsequent Event	'
Subsequent Event [Line Items]	'
Area of Land	8,777
Payments for leasehold acquisitions	$195.60

Supplementary_information_Deta

Supplementary information (Details) (USD $)	3 Months Ended				6 Months Ended
	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
Property acquisition costs:	'		'		'		'
Proved	$3,848,000		$0		$3,873,000		$0
Unproved	2,645,000		0		9,925,000		0
Exploration	8,143,000		12,167,000		16,642,000		20,928,000
Development costs	220,240,000	[1]	165,416,000	[1]	408,553,000	[1]	322,732,000	[1]
Total costs incurred	234,876,000		177,583,000		438,993,000		343,660,000
Asset retirement obligations included in development costs	$900,000		$700,000		$1,500,000		$1,300,000
[1]	The costs incurred for oil and natural gas development activities include $0.9 million and $0.7 million in asset retirement obligations for the three months ended June 30, 2014 and 2013, respectively, and $1.5 million and $1.3 million for the six months ended June 30, 2014 and 2013, respectively.