Range Resources (RRC) 10-Q 22 Apr 19 2019 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	Apr. 19, 2019
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	RRC
Entity Registrant Name	RANGE RESOURCES CORP
Entity Central Index Key	0000315852
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		251,148,010

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands		Mar. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents		$ 488	$ 545
Accounts receivable, less allowance for doubtful accounts of $6,118 and $6,118		356,716	490,723
Derivative assets		6,146	87,953
Inventory and other		25,128	22,964
Total current assets		388,478	602,185
Derivative assets		8,406	4,842
Natural gas and oil properties, successful efforts method	[1]	13,300,145	13,085,206
Accumulated depletion and depreciation	[1]	(4,194,876)	(4,062,021)
Natural gas and oil properties, successful efforts method, net	[1]	9,105,269	9,023,185
Other property and equipment		112,373	111,908
Accumulated depreciation and amortization		(103,548)	(102,132)
Other Property and equipment, net		8,825	9,776
Operating lease right-of-use assets		49,329
Other assets		74,757	68,166
Total assets		9,635,064	9,708,154
Current liabilities:
Accounts payable		215,073	227,344
Asset retirement obligations		5,485	5,485
Accrued liabilities		399,822	475,848
Accrued interest		37,051	41,990
Derivative liabilities		13,369	4,144
Total current liabilities		670,800	754,811
Bank debt		884,652	932,018
Senior notes		2,857,297	2,856,166
Senior subordinated notes		48,700	48,677
Deferred tax liabilities		672,376	666,668
Derivative liabilities		2,559	3,462
Deferred compensation liabilities		75,179	67,542
Operating lease liabilities		41,759
Asset retirement obligations and other liabilities		319,079	319,379
Total liabilities		5,572,401	5,648,723
Commitments and contingencies
Stockholders’ Equity
Preferred stock, $1 par, 10,000,000 shares authorized, none issued and outstanding
Common stock, $0.01 par, 475,000,000 shares authorized, 251,147,799 issued at March 31, 2019 and 249,519,687 issued at December 31, 2018		2,512	2,495
Common stock held in treasury, 9,665 shares at March 31, 2019 and 9,665 shares at December 31, 2018		(391)	(391)
Additional paid-in capital		5,635,210	5,628,447
Accumulated other comprehensive loss		(598)	(658)
Retained deficit		(1,574,070)	(1,570,462)
Total stockholders’ equity		4,062,663	4,059,431
Total liabilities and stockholders’ equity		$ 9,635,064	$ 9,708,154
[1]

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Allowance for doubtful accounts on accounts receivable	$ 6,118	$ 6,118
Preferred stock, par value	$ 1	$ 1
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	475,000,000	475,000,000
Common stock, shares issued	251,147,799	249,519,687
Common stock held in treasury, shares	9,665	9,665

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Revenues and other income:
Revenues and other income	$ 809,868,000	$ 756,608,000
Derivative fair value loss	(61,731,000)	(14,009,000)
Total revenues and other income	748,137,000	742,599,000
Costs and expenses:
Production and ad valorem taxes	11,310,000	9,926,000
Brokered natural gas and marketing	132,305,000	55,594,000
Exploration	8,211,000	7,719,000
Abandonment and impairment of unproved properties	12,659,000	11,773,000
General and administrative	46,638,000	68,417,000
Termination costs	0	(37,000)
Deferred compensation plan	3,581,000	(7,397,000)
Interest	51,537,000	52,385,000
Depletion, depreciation and amortization	138,718,000	162,266,000
Impairment of proved properties	0	7,312,000
Loss (gain) on the sale of assets	189,000	(23,000)
Total costs and expenses	741,030,000	650,685,000
Income before income taxes	7,107,000	91,914,000
Income tax expense:
Current	0	0
Deferred	5,688,000	42,676,000
Total (benefit) expense for income taxes	5,688,000	42,676,000
Net income	$ 1,419,000	$ 49,238,000
Net income per common share:
Basic	$ 0.01	$ 0.20
Diluted	0.01	0.20
Dividends paid per common share	$ 0.02	$ 0.02
Weighted average common shares outstanding:
Basic	247,776	245,709
Diluted	249,154	246,594
Natural Gas, NGLs and Oil Sales
Revenues and other income:
Revenues and other income	$ 671,654,000	$ 696,629,000
Brokered Natural Gas, Marketing and Other
Revenues and other income:
Revenues and other income	138,214,000	59,979,000
Direct Operating
Costs and expenses:
Costs and expenses	33,227,000	38,122,000
Transportation, Gathering, Processing and Compression
Costs and expenses:
Costs and expenses	$ 302,655,000	$ 244,628,000

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement Of Income And Comprehensive Income [Abstract]
Net income	$ 1,419	$ 49,238
Postretirement benefits
Prior service cost	92	92
Actuarial gain	(12)
Income tax expense	(20)	(23)
Total comprehensive income	$ 1,479	$ 49,307

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating activities:
Net income	$ 1,419,000	$ 49,238,000
Adjustments to reconcile net income to net cash provided from operating activities:
Deferred income tax expense	5,688,000	42,676,000
Depletion, depreciation and amortization and impairment	138,718,000	169,578,000
Exploration dry hole costs	0	2,000
Abandonment and impairment of unproved properties	12,659,000	11,773,000
Derivative fair value loss	61,731,000	14,009,000
Cash settlements on derivative financial instruments	24,834,000	8,925,000
Amortization of deferred financing costs and other	1,807,000	1,312,000
Deferred and stock-based compensation	14,112,000	18,527,000
Loss (gain) on the sale of assets	189,000	(23,000)
Changes in working capital:
Accounts receivable	134,006,000	53,913,000
Inventory and other	(4,763,000)	(5,294,000)
Accounts payable	(30,431,000)	47,453,000
Accrued liabilities and other	(99,275,000)	(41,517,000)
Net cash provided from operating activities	260,694,000	370,572,000
Investing activities:
Additions to natural gas and oil properties	(190,014,000)	(308,641,000)
Additions to field service assets	(576,000)	(239,000)
Acreage purchases	(23,646,000)	(25,355,000)
Proceeds from disposal of assets	332,000	40,000
Purchases of marketable securities held by the deferred compensation plan	(4,259,000)	(13,153,000)
Proceeds from the sales of marketable securities held by the deferred compensation plan	6,204,000	11,928,000
Net cash used in investing activities	(211,959,000)	(335,420,000)
Financing activities:
Borrowings on credit facilities	566,000,000	528,000,000
Repayments on credit facilities	(614,000,000)	(557,000,000)
Dividends paid	(5,023,000)	(4,971,000)
Taxes paid for shares withheld	(3,161,000)	(2,659,000)
Change in cash overdrafts	7,218,000	922,000
Proceeds from the sales of common stock held by the deferred compensation plan	174,000	635,000
Net cash used in financing activities	(48,792,000)	(35,073,000)
(Decrease) increase in cash and cash equivalents	(57,000)	79,000
Cash and cash equivalents at beginning of period	545,000	448,000
Cash and cash equivalents at end of period	$ 488,000	$ 527,000

CONSOLIDATED STATEMENTS OF SHAR

CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY - USD ($) $ in Thousands	Total	Common Stock	Treasury Stock	Additional Paid-in Capital	Retained Earnings	AOCI Attributable to Parent
Beginning balance at Dec. 31, 2017	$ 5,774,272	$ 2,481	$ (599)	$ 5,577,732	$ 195,990	$ (1,332)
Beginning balance Shares at Dec. 31, 2017		248,144,000
Issuance of common stock	(1,217)	$ 11		(1,228)
Issuance of common stock, shares		1,092,000
Stock-based compensation expense	17,201			17,201
Cash dividends paid ($0.02 per share)	(4,971)				(4,971)
Treasury stock issuance			30	(30)
Other comprehensive income	69					69
Net income	49,238				49,238
Ending balance at Mar. 31, 2018	5,834,592	$ 2,492	(569)	5,593,675	240,257	(1,263)
Ending balance Shares at Mar. 31, 2018		249,236,000
Beginning balance at Dec. 31, 2017	5,774,272	$ 2,481	(599)	5,577,732	195,990	(1,332)
Beginning balance Shares at Dec. 31, 2017		248,144,000
Ending balance at Dec. 31, 2018	$ 4,059,431	$ 2,495	(391)	5,628,447	(1,570,462)	(658)
Ending balance Shares at Dec. 31, 2018	249,519,687	249,520,000
Issuance of common stock	$ (2,379)	$ 17		(2,396)
Issuance of common stock, shares		1,628,000
Issuance of common stock upon vesting of PSUs				4	(4)
Stock-based compensation expense	9,155			9,155
Cash dividends paid ($0.02 per share)	(5,023)				(5,023)
Other comprehensive income	60					60
Net income	1,419				1,419
Ending balance at Mar. 31, 2019	$ 4,062,663	$ 2,512	$ (391)	$ 5,635,210	$ (1,574,070)	$ (598)
Ending balance Shares at Mar. 31, 2019	251,147,799	251,148,000

CONSOLIDATED STATEMENTS OF SH_2

CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement Of Stockholders Equity [Abstract]
Cash dividends paid per share	$ 0.02	$ 0.02

Summary of Organization and Nat

Summary of Organization and Nature of Business	3 Months Ended
	Mar. 31, 2019
Industry Specific Policies [Abstract]
Summary of Organization and Nature of Business	(1) SUMMARY OF ORGANIZATION AND NATURE OF BUSINESS Range Resources Corporation is a Fort Worth, Texas-based independent natural gas, natural gas liquids (“NGLs”) and oil company primarily engaged in the exploration, development and acquisition of natural gas and oil properties in the Appalachian and the North Louisiana regions of the United States. Our objective is to build stockholder value through consistent returns focused development, on a per share debt-adjusted basis, of both reserves and production on a cost-efficient basis. Range is a Delaware corporation with our common stock listed and traded on the New York Stock Exchange under the symbol “RRC”.

Basis of Presentation

Basis of Presentation	3 Months Ended
	Mar. 31, 2019
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Basis of Presentation	(2) BASIS OF PRESENTATION These consolidated financial statements are unaudited but, in the opinion of management, reflect all adjustments necessary for fair presentation of the results for the periods presented. All adjustments are of a normal recurring nature unless otherwise disclosed. These consolidated financial statements, including selected notes, have been prepared in accordance with the applicable rules of the SEC and do not include all of the information and disclosures required by accounting principles generally accepted in the United States of America (“U.S. GAAP”) for complete financial statements. These interim financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in the Range Resources Corporation 2018 Annual Report on Form 10-K filed with the Securities and Exchange Commission (the “SEC”) on February 25, 2019. The results of operations for the first quarter ended March 31, 2019 are not necessarily indicative of the results to be expected for the full year. Inventory. As of March 31, 2019, we had $7.4 million of material and supplies inventory compared to $8.0 million at December 31, 2018. Material and supplies inventory consists of primarily tubular goods and equipment used in our operations and is stated at lower of specific cost of each inventory item or net realized value, on a first-in, first-out basis. At March 31, 2019, we also had commodity inventory of $253,000 compared to $965,000 at December 31, 2018. Commodity inventory as of March 31, 2019 consists of NGLs held in storage or as line fill in pipelines.

New Accounting Standards

New Accounting Standards	3 Months Ended
	Mar. 31, 2019
New Accounting Pronouncements And Changes In Accounting Principles [Abstract]
New Accounting Standards	(3) NEW ACCOUNTING STANDARDS Not Yet Adopted Financial Instruments – Credit Losses In June 2016, an accounting standards update was issued that changes the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standards update requires the use of a forward-looking “expected loss” model as opposed to the current “incurred loss” model. This standards update is effective for us in first quarter 2020 and will be adopted on a modified retrospective basis through a cumulative-effect adjustment to retained earnings as of the beginning of the adoption period. Early adoption is permitted starting January 2019. We are evaluating the provisions of this accounting standards update and assessing the impact, if any, it may have on our consolidated results of operations, financial position and financial disclosures. Fair Value Measurement In August 2018, an accounting standards update was issued which provides additional disclosure requirements for fair value measurements. This new standards update eliminates the requirement to disclose transfers between Level 1 and Level 2 of the fair value hierarchy and provides for additional disclosures for Level 3 fair value measurements. This new standards update is effective for us in first quarter 2020 and will be adopted on a prospective or retrospective basis depending on the changes that apply. We are evaluating the provisions of this standards update and assessing the impact, if any, it may have on our financial disclosures. Recently Adopted Lease Accounting Standard In February 2016, an accounting standards update was issued that requires an entity to recognize a right-of-use (“ROU”) asset and lease liability for all leases. Classification of leases as either a finance or operating lease determines the recognition, measurement and presentation of expenses. This accounting standards update also requires certain quantitative and qualitative disclosures about leasing arrangements. The new standard was effective for us in first quarter 2019 and we adopted the new standard using a modified retrospective approach, with the date of initial application on January 1, 2019. Consequently, upon transition, we recognized a ROU asset (or operating lease right-of-use asset) and a lease liability with no retained earnings impact. We are applying the following practical expedients as provided in the standards update which provide elections to: • not apply the recognition requirements to short-term leases (a lease that at commencement date has a lease term of 12 months or less and does not contain a purchase option); • not reassess whether a contract contains a lease, lease classification and initial direct costs; and • not reassess certain land easements in existence prior to January 1, 2019. Through our implementation process, we evaluated each of our lease arrangements and enhanced our systems to track and calculate additional information required upon adoption of this standards update. Our adoption did not have a material impact on our consolidated balance sheet as of January 1, 2019, with the primary impact relating to the recognition of ROU assets and operating lease liabilities for operating leases which represents approximately a 1% change to total assets and total liabilities. The impact of adoption of this new standards update is as follows (in thousands): January 1, 2019 Adoption Reclassification (1) Total Adjustment Balance Sheet: Operating lease right-of-use assets $ 59,300 $ (7,925 ) $ 51,375 Accrued liabilities – current $ (14,811 ) $ — $ (14,811 ) Operating lease liabilities – long-term $ (44,489 ) $ — $ (44,489 ) Asset retirement obligations and other liabilities $ — $ 7,925 $ 7,925 (1) Adoption of the new standard did not impact our consolidated statements of operations, cash flows or stockholders’ equity. Leases acquired to explore for or use minerals, oil or natural gas resources, including the right to explore for those natural resources and rights to use the land in which those natural resources are contained, are not within the scope of the standards update. Pension Accounting Standard In March 2017, an accounting standards update was issued which provides additional guidance on the presentation of net benefit cost in the statement of operations. Employers will present the service cost component of net periodic benefit cost in the same consolidated results of operations line item as other employee compensation costs arising from services rendered during the period. This new standards update was effective for annual reporting periods in first quarter 2018 and must be applied retrospectively. We adopted this standards update in first quarter 2018. The adoption did not impact our consolidated results of operations, financial position, cash flows or disclosures. In 2018 and 2019, our service cost is recorded in general and administrative expense. Modification of Share – Based Awards In May 2017, an accounting standards update was issued which clarifies what constitutes a modification of a share-based award. This standards update is intended to provide clarity and reduce both diversity in practice and cost and complexity to a change to the terms or conditions of a share-based payment award. We adopted this standards update in first quarter 2018. The adoption of this standard did not have a material impact on our consolidated financial position or results of operations. Revenue Recognition Standard In May 2014, an accounting standards update was issued that superseded the existing revenue recognition requirements. This standard included a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Among other things, the standard also eliminated industry-specific revenue guidance, required enhanced disclosures about revenue, provided guidance for transactions that were not previously addressed comprehensively and improved guidance for multiple-element arrangements. This standard was effective for us in first quarter 2018 and we adopted the new standards update using the modified retrospective method to all open contracts as of January 1, 2018. Our implementation of this standard did not result in a cumulative-effect adjustment on date of adoption; however, our financial statement presentation related to revenue received from certain gas processing contracts changed. Based on previous accounting guidance, certain of our gas processing contracts were reported in revenue at the net price (net of processing costs) we receive. Upon adoption of this accounting standards update, these contracts are now reported as a gross price received at a delivery point and separate transportation, marketing and processing expense.

Dispositions

Dispositions	3 Months Ended
	Mar. 31, 2019
Business Combinations [Abstract]
Dispositions	(4) DISPOSITIONS We recognized a pretax net loss of $189,000 on the sale of assets in first quarter 2019 compared to a pretax net gain of $23,000 in the same period of the prior year. 2019 Dispositions Other . In first quarter 2019, we sold miscellaneous inventory and other assets for proceeds of $332,000, resulting in a pretax loss of $189,000. 2018 Dispositions Other . In first quarter 2018, we sold miscellaneous inventory and other assets for proceeds of $40,000, resulting in a pretax gain of $23,000.

Revenues from Contracts with Cu

Revenues from Contracts with Customers	3 Months Ended
	Mar. 31, 2019
Revenue From Contract With Customer [Abstract]
Revenues from Contracts with Customers	(5) REVENUES FROM CONTRACTS WITH CUSTOMERS Revenue Recognition Natural gas, NGLs and oil sales revenues are generally recognized at the point in time that control of the product is transferred to the customer and collectability is reasonably assured. Disaggregation of Revenue We have three material revenue streams in our business: natural gas sales, NGLs sales and oil sales. Brokered revenue attributable to each product sales type is included here because the volume of product that we purchase is subsequently sold to separate counterparties in accordance with existing sales contracts under which we also sell our production. Our net brokered margin was a gain of $5.6 million in first quarter 2019 compared to a gain of $3.1 million in first quarter 2018. Currently, our product sales that have a contractual term greater than one year have no long-term fixed consideration. Accounts receivable attributable to our revenue contracts with customers was $315.2 million at March 31, 2019 and $438.3 million at December 31, 2018. Revenue attributable to each of our identified revenue streams is disaggregated below (in thousands): Three Months Ended March 31, 2019 2018 Natural gas sales (a) $ 572,510 $ 491,248 NGLs sales (b) 198,237 202,831 Oil sales 39,121 62,529 Total $ 809,868 $ 756,608 (a) Natural gas sales revenue reported above for first quarter 2019 includes $134.8 million of brokered revenues and $3.0 million of marketing revenue. First quarter 2018 includes $55.9 million of brokered revenues and $3.8 million of marketing revenue. (b) NGLs sales revenue reported above for the first quarter 2019 includes $424,000 of brokered revenues and first quarter 2018 includes $304,000 of brokered revenues.

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2019
Income Tax Disclosure [Abstract]
Income Taxes	(6) INCOME TAXES Income tax expense was as follows (in thousands): Three Months Ended March 31, 2019 2018 Income tax expense $ 5,688 $ 42,676 Effective tax rate 80.0 % 46.4 % We compute our quarterly taxes under the effective tax rate method based on applying an anticipated annual effective rate to our year-to-date income, except for discrete items. Income taxes for discrete items are computed and recorded in the period that the specific transaction occurs. For first quarter 2019 and 2018, our overall effective tax rate was different than the federal statutory rate due primarily to state income taxes (including adjustments to state income tax valuation allowances), equity compensation and other tax items which are detailed below (in thousands). Three Months Ended March 31, 2019 2018 Total income before income taxes $ 7,107 $ 91,914 U.S. federal statutory rate 21 % 21 % Total tax expense at statutory rate 1,492 19,302 State and local income taxes, net of federal benefit 818 4,494 Equity compensation 3,391 664 Change in valuation allowances: State net operating loss carryforwards & other 352 15,678 Other 231 1,381 Permanent differences and other (596 ) 1,157 Total expense for income taxes $ 5,688 $ 42,676 Effective tax rate 80.0 % 46.4 %

Income (Loss) Per Common Share

Income (Loss) Per Common Share	3 Months Ended
	Mar. 31, 2019
Earnings Per Share [Abstract]
Income (Loss) Per Common Share	(7) INCOME (LOSS) PER COMMON SHARE Basic income or loss per share attributable to common shareholders is computed as (1) income or loss attributable to common shareholders (2) less income allocable to participating securities (3) divided by weighted average basic shares outstanding. Diluted income or loss per share attributable to common shareholders is computed as (1) basic income or loss attributable to common shareholders (2) plus diluted adjustments to income allocable to participating securities (3) divided by weighted average diluted shares outstanding. The following sets forth a reconciliation of income or loss attributable to common shareholders to basic income or loss attributable to common shareholders to diluted income or loss attributable to common shareholders (in thousands, except per share amounts): Three Months Ended March 31, 2019 2018 Net income, as reported $ 1,419 $ 49,238 Participating earnings (a) (14 ) (568 ) Basic net income attributed to common shareholders 1,405 48,670 Reallocation of participating earnings (a) — 2 Diluted net income attributed to common shareholders $ 1,405 $ 48,672 Net income per common share: Basic $ 0.01 $ 0.20 Diluted $ 0.01 $ 0.20 (a) Restricted Stock Awards represent participating securities because they participate in nonforfeitable dividends or distributions with common equity owners. Income allocable to participating securities represents the distributed and undistributed earnings attributable to the participating securities. Participating securities, however, do not participate in undistributed net losses The following provides a reconciliation of basic weighted average common shares outstanding to diluted weighted average common shares outstanding (in thousands): Three Months Ended March 31, 2019 2018 Weighted average common shares outstanding – basic 247,776 245,709 Effect of dilutive securities: Director and employee restricted stock and performance based equity awards 1,378 885 Weighted average common shares outstanding – diluted 249,154 246,594 Weighted average common shares outstanding-basic for first quarter 2019 excludes 2.5 million shares of restricted stock held in our deferred compensation plan compared to 2.9 million shares in first quarter 2018 (although all awards are issued and outstanding upon grant). For first quarter 2019, equity grants of 1.6 million were outstanding but not included in the computation of diluted net income per share because the grant prices were greater than the average market price of our common shares and would be anti-dilutive to the computations compared to equity grants of 1.5 million in first quarter 2018. For purposes of calculating diluted weighted average common shares, non-vested restricted stock and performance based equity awards are included in the computation using the treasury stock method with the deemed proceeds equal to the average unrecognized compensation during the period.

Leases

Leases	3 Months Ended
	Mar. 31, 2019
Leases [Abstract]
Leases	(8) LEASES We determine if an arrangement is a lease at inception of the arrangement. To the extent that we determine an arrangement represents a lease, we classify that lease as an operating lease or a finance lease. We currently do not have any finance leases. We capitalize our operating leases on our consolidated balance sheet through a ROU asset and a corresponding lease liability. ROU assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation to make lease payments arising from the lease. Short-term leases that have an initial term of one year or less are not capitalized but are disclosed below. Short-term lease costs exclude expenses related to leases with a lease term of one month or less. Our operating leases are reflected as operating lease ROU assets, accrued liabilities-current and operating lease liabilities on our consolidated balance sheet. Operating lease ROU assets and liabilities are recognized at the commencement date of an arrangement based on the present value of lease payments over the lease term. In addition to the present value of lease payments, the operating lease ROU asset also includes any lease payments made to the lessor prior to lease commencement less any lease incentives and initial direct costs incurred. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Nature of Leases We lease certain office space, field equipment, vehicles and other equipment under cancelable and non-cancelable leases to support our operations. A more detailed description of our significant lease types is included below. Office Agreements and Subleases We rent office space from third parties for our corporate and field locations. Our office agreements are typically structured with non-cancelable terms of one to fifteen years. We have concluded our office agreements represent operating leases with a lease term that equals the primary non-cancelable contract term. Upon completion of the primary term, both parties have substantive rights to terminate the lease. As a result, enforceable rights and obligations do not exist under the rental agreements subsequent to the primary term. We also sublease some of our office space to third parties. All of our subleases have terms that end in 2020 or 2022. The sublease agreements are non-cancelable through the end of the term and both parties have substantive rights to terminate the lease when the term is complete. Our sublease agreements are not capitalized and are recorded as sublease income (as a component of lease costs) in the period the rent is received. Field Equipment We rent compressors and coolers from third parties in order to facilitate the downstream movement of our production from our drilling operations to market. Our compressor and cooler arrangements are typically structured with a non-cancelable primary term of one to two years and continue thereafter on a month-to-month basis subject to termination by either party with thirty days notice. We have concluded that our compressor and cooler rental agreements represent operating leases with a lease term that equals the primary non-cancelable contract term. Upon completion of the primary term, both parties have substantive rights to terminate the lease. As a result, enforceable rights and obligations do not exist under the rental agreement subsequent to the primary term. We enter into daywork contracts for drilling rigs with third parties to support our drilling activities. Our drilling rig arrangements are typically structured with a term that is in effect until drilling operations are completed on a contractually specified well or well pad. Upon mutual agreement with the contractor, we typically have the option to extend the contract term for additional wells or well pads by providing thirty days notice prior to the end of the original contract term. We have concluded that our drilling rig arrangements represent short-term operating leases. The accounting guidance requires us to make an assessment at contract commencement if we are reasonably certain that we will exercise the option to extend the term. Due to the continuously evolving nature of our drilling schedules and the potential volatility in commodity prices in an annual period, our strategy to enter into shorter term drilling rig arrangements allows us the flexibility to respond to changes in our operating and economic environment. We exercise our discretion in choosing to extend or not extend contracts on a rig by rig basis depending on the conditions present at the time the contract expires. At the time of contract commencement, we have determined we cannot conclude with reasonable certainty if we will choose to extend the contract beyond its original term. Pursuant to the successful efforts method of accounting, these costs are capitalized as part of natural gas and oil properties on our balance sheet when paid. See also short-term lease costs below. Vehicles We rent our vehicle fleet from a third party for our drilling and operations personnel. Our vehicle agreements are non-cancelable for a minimum of one year and a maximum term of four to eight years depending on the type of vehicle. However, we have assumed a term of three years based on the period covered by options to terminate that we are reasonably certain to exercise. We have concluded our vehicle commitments are operating leases. Significant Judgments Transportation, Gathering and Processing Arrangements We engage in various types of transactions in which midstream entities transport, gather and/or process our product leveraging integrated systems and facilities wholly owned and operated by the midstream counterparty. Under most of these arrangements, we do not utilize substantially all of the underlying pipeline, gathering system or processing facilities, and thus, we have concluded that those underlying assets do not meet the definition of an identified asset. However, in limited circumstances, we do utilize substantially all of the capacity of a portion of the midstream system under our transportation gathering and/or processing service contract. These arrangements require judgment to determine whether our capacity of the underlying midstream asset represents a lease. Under all of these arrangements, we have concluded that (i) the midstream entity maintains control of and has the ability to optimize and/or expand the underlying system throughout the duration of the contract term and (ii) the portion of the system or facility we utilize is highly integrated and interconnected to a broader system servicing a diverse set of customers. Consequently, the transportation, gathering and/or processing contract does not represent a lease of the underlying portion of the midstream system or facilities. We currently have not identified any of these commitments as leases. Discount Rate Our leases typically do not provide an implicit rate. Accordingly, we are required to use our incremental borrowing rate in determining the present value of lease payments based on the information available at commencement date. Our incremental borrowing rate reflects the estimated rate of interest that we would pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment. We use the implicit rate in the limited circumstances in which that rate is readily determinable. Practical Expedients and Accounting Policy Elections Certain of our lease agreements include lease and non-lease components. For all existing asset classes with multiple component types, we have utilized the practical expedient that exempts us from separating lease components from non-lease components. Accordingly, we account for the lease and non-lease components in an arrangement as a single lease component. In addition, for all of our existing asset classes, we have made an accounting policy election not to apply the lease recognition requirements to our short-term leases (that is, a lease that, at commencement, has a lease term of 12 months or less and does not include an option to purchase the underlying asset that we are reasonably certain to exercise). Accordingly, we recognize lease payments related to our short-term leases in our statement of operations on a straight-line basis over the lease term which has not changed from our prior recognition. To the extent that there are variable lease payments, we recognize those payments in our statement of operations in the period in which the obligation for those payments is incurred. Refer to “Nature of Leases” The components of our total lease expense for the three months ended March 31, 2019, the majority of which is included in general and administrative expense, are as follows (in thousands): Three Months Ended March 31, 2019 Operating lease cost $ 3,080 Variable lease expense (1) 1,151 Short-term lease expense ( 2 ) 92 Sublease income (875 ) Total lease expense $ 3,448 Short-term lease costs (3) $ 9,164 (1) (2) (3) Supplemental cash flow information related to our operating leases is included in the table below (in thousands): Three Months Ended March 31, 2019 Cash paid for amounts included in the measurement of lease liabilities $ 3,003 ROU assets added in exchange for lease obligations (since adoption) $ 187 Supplemental balance sheet information related to our operating leases is included in the table below (in thousands): March 31, 2019 Operating lease ROU assets $ 49,329 Accrued liabilities – current $ (14,872 ) Operating lease liabilities – long-term $ (41,759 ) Our weighted average remaining lease term and weighted average discount rate for our operating leases are as follows (in thousands): March 31, 2019 Weighted Average Remaining Lease Term 6.4 Years Weighted Average Discount Rate 6.1% Our lease liabilities with enforceable contract terms that are greater than one year mature as follows (in thousands): Operating Leases Remainder of 2019 $ 14,872 2020 12,491 2021 9,618 2022 6,551 2023 6,479 Thereafter 20,113 Total lease payments $ 70,124 Less imputed interest (13,493 ) Total lease liability $ 56,631

Capitalized Costs and Accumulat

Capitalized Costs and Accumulated Depreciation, Depletion and Amortization	3 Months Ended
	Mar. 31, 2019
Extractive Industries [Abstract]
Capitalized Costs and Accumulated Depreciation, Depletion and Amortization	(9) Capitalized Costs and Accumulated Depreciation, Depletion and Amortization (a) March 31, December 31, (in thousands) Natural gas and oil properties: Properties subject to depletion $ 11,193,577 $ 10,974,929 Unproved properties 2,106,568 2,110,277 Total 13,300,145 13,085,206 Accumulated depreciation, depletion and amortization (4,194,876 ) (4,062,021 ) Net capitalized costs $ 9,105,269 $ 9,023,185 (a)

Indebtedness

Indebtedness	3 Months Ended
	Mar. 31, 2019
Debt Disclosure [Abstract]
Indebtedness	(10) INDEBTEDNESS We had the following debt outstanding as of the dates shown below (bank debt interest rate at March 31, 2019 is shown parenthetically). No interest was capitalized during the three months ended March 31, 2019 or the year ended December 31, 2018 (in thousands). March 31, 2019 December 31, 2018 Bank debt ( 4.0% $ 895,000 $ 943,000 Senior notes: 4.875% senior notes due 2025 750,000 750,000 5.00% senior notes due 2023 741,531 741,531 5.00% senior notes due 2022 580,032 580,032 5.75% senior notes due 2021 475,952 475,952 5.875% senior notes due 2022 329,244 329,244 Other senior notes due 2022 590 590 Total senior notes 2,877,349 2,877,349 Senior subordinated notes: 5.00% senior subordinated notes due 2023 7,712 7,712 5.00% senior subordinated notes due 2022 19,054 19,054 5.75% senior subordinated notes due 2021 22,214 22,214 Total senior subordinated notes 48,980 48,980 Total debt 3,821,329 3,869,329 Unamortized premium 4,408 4,741 Unamortized debt issuance costs (35,088 ) (37,209 ) Total debt net of debt issuance costs $ 3,790,649 $ 3,836,861 Bank Debt In April 2018, we entered into an amended and restated revolving bank facility, which we refer to as our bank debt or our bank credit facility, which is secured by substantially all of our assets and has a maturity date of April 13, 2023. The bank credit facility provides for a maximum facility amount of $4.0 billion and an initial borrowing base of $3.0 billion. The bank credit facility also provides for a borrowing base subject to redeterminations annually by May and for event-driven unscheduled redeterminations. As part of our annual redetermination completed on March 27, 2019, our borrowing base was reaffirmed for $3.0 billion and our bank commitment was also reaffirmed at $2.0 billion. As of March 31, 2019, our bank group was composed of twenty-seven financial institutions with no one bank holding more than 5.8% of the total facility. The borrowing base may be increased or decreased based on our request and sufficient proved reserves, as determined by the bank group. The commitment amount may be increased to the borrowing base, subject to payment of a mutually acceptable commitment fee to those banks agreeing to participate in the facility increase. On March 31, 2019, bank commitments totaled $2.0 billion and the outstanding balance under our bank credit facility was $895.0 million, before deducting debt issuance costs. Additionally, we had $279.8 million of undrawn letters of credit leaving $825.2 million of committed borrowing capacity available under the facility. During a non-investment grade period, borrowings under the bank credit facility can either be at the alternate base rate (“ABR,” as defined in the bank credit facility agreement) plus a spread ranging from 0.25% to 1.25% or LIBOR borrowings at the LIBOR Rate (as defined in the bank credit facility agreement) plus a spread ranging from 1.25% to 2.25%. The applicable spread is dependent upon borrowings relative to the borrowing base. We may elect, from time to time, to convert all or any part of our LIBOR loans to base rate loans or to convert all or any of the base rate loans to LIBOR loans. The weighted average interest rate was 4.0% for first quarter 2019 compared to 3.4% for first quarter 2018. A commitment fee is paid on the undrawn balance based on an annual rate of 0.30% to 0.375%. At March 31, 2019, the commitment fee was 0.30% and the interest rate margin was 1.50% on our LIBOR loans and 0.50% on our base rate loans. At any time during which we have an investment grade debt rating from Moody’s Investors Service, Inc. or Standard & Poor’s Ratings Services and we have elected, at our discretion, to effect the investment grade rating period, certain collateral security requirements, including the borrowing base requirement and restrictive covenants, will cease to apply and an additional financial covenant (as defined in the bank credit facility) will be imposed. During the investment grade period, borrowings under the credit facility can either be at the ABR plus a spread ranging from 0.125% to 0.75% or at the LIBOR Rate plus a spread ranging from 1.125% to 1.75% depending on our debt rating. The commitment fee paid on the undrawn balance would range from 0.15% to 0.30%. We currently do not have an investment grade debt rating. Senior Notes and Senior Subordinated Notes If we experience a change of control, noteholders may require us to repurchase all or a portion of our senior notes and senior subordinated notes at 101% of the aggregate principal amount plus accrued and unpaid interest, if any. All of the senior subordinated notes and the guarantees by our subsidiary guarantors are general, unsecured obligations and are subordinated to our bank debt and are subordinated to existing and future senior debt that we or our subsidiary guarantors are permitted to incur. Guarantees Range is a holding company which owns no operating assets and has no significant operations independent of its subsidiaries. The guarantees by our subsidiaries, which are directly or indirectly owned by Range, of our senior notes, senior subordinated notes and our bank credit facility are full and unconditional and joint and several, subject to certain customary release provisions. A subsidiary guarantor may be released from its obligations under the guarantee: • in the event of a sale or other disposition of all or substantially all of the assets of the subsidiary guarantor or a sale or other disposition of all the capital stock of the subsidiary guarantor, to any corporation or other person (including an unrestricted subsidiary of Range) by way of merger, consolidation, or otherwise; or • if Range designates any restricted subsidiary that is a guarantor to be an unrestricted subsidiary in accordance with the terms of the indenture. Debt Covenants Our bank credit facility contains negative covenants that limit our ability, among other things, to pay cash dividends, incur additional indebtedness, sell assets, enter into certain hedging contracts, change the nature of our business or operations, merge, consolidate or make certain investments. In addition, we are required to maintain a ratio of EBITDAX (as defined in the bank credit facility agreement) to cash interest expense of equal to or greater than 2.5 and a current ratio (as defined in the bank credit facility agreement) of no less than 1.0. In addition, the ratio of the present value of proved reserves (as defined in the credit agreement) to total debt must be equal to or greater than 1.5 until Range has two investment grade ratings. We were in compliance with applicable covenants under the bank credit facility at March 31, 2019.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2019
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(11) ASSET RETIREMENT OBLIGATIONS Our asset retirement obligations primarily represent the estimated present value of the amounts we will incur to plug, abandon and remediate our producing properties at the end of their productive lives. Significant inputs used in determining such obligations include estimates of plugging and abandonment costs, estimated future inflation rates and well lives. The inputs are calculated based on historical data as well as current estimated costs. A reconciliation of our liability for plugging and abandonment costs for the three months ended March 31, 2019 is as follows (in thousands): Three Months Ended March 31, 2019 Beginning of period $ 312,754 Liabilities incurred 1,719 Liabilities settled (896 ) Accretion expense 4,217 Change in estimate (187 ) End of period 317,607 Less current portion (5,485 ) Long-term asset retirement obligations $ 312,122 Accretion expense is recognized as a component of depreciation, depletion and amortization expense in the accompanying consolidated statements of operations.

Derivative Activities

Derivative Activities	3 Months Ended
	Mar. 31, 2019
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivative Activities	(12) DERIVATIVE ACTIVITIES We use commodity-based derivative contracts to manage exposure to commodity price fluctuations. We do not enter into these arrangements for speculative or trading purposes. We utilize commodity swaps, collars, calls or swaptions to (1) reduce the effect of price volatility of the commodities we produce and sell and (2) support our annual capital budget and expenditure plans. The fair value of our derivative contracts, represented by the estimated amount that would be realized upon termination, based on a comparison of the contract price and a reference price, generally the New York Mercantile Exchange (“NYMEX”) for natural gas and crude oil or Mont Belvieu for NGLs, approximated a net gain of $3.0 million at March 31, 2019. These contracts expire monthly through December 2020. The following table sets forth our commodity-based derivative volumes by year as of March 31, 2019, excluding our basis and freight swaps which are discussed separately below: Period Contract Type Volume Hedged Weighted Natural Gas 2019 Swaps 1,246,873 Mmbtu/day $ 2.80 2020 Swaps 190,000 Mmbtu/day $ 2.75 2019 Swaptions 150,000 Mmbtu/day $ 2.81 ( 1 ) 2020 Swaptions 140,000 Mmbtu/day $ 2.78 ( 1 ) November – December 2019 Swaptions 20,000 Mmbtu/day $ 3.20 (1) January – March 2020 Swaptions 20,000 Mmbtu/day $ 3.20 (1) Crude Oil 2019 Swaps 7,472 bbls/day $ 55.47 2020 Swaps 2,557 bbls/day $ 60.53 2019 Collars 1,000 bbls/day $ 63.00 − $ 73.02 NGLs (C2-Ethane) April – June 2019 Swaps 500 bbls/day $0.35/gallon NGLs (C3-Propane) April – June 2019 Swaps 8,500 bbls/day $ 0.88/gallon April – June 2019 Collars 1,000 bbls/day $ 0.90 − $ 0.96 NGLs (C5-Natural Gasoline) 2019 Swaps 2,658 bbls/day $ 1.39/gallon ( 1 ) Contains a combined derivative instrument consisting of a fixed price swap and a sold option to extend or double the volumes. We have swaps in place for 2019 for 150,000 Mmbtu/day on which the counterparty can elect to extend the contract through December 2020 at a weighted average price of $2.81. In addition, we have swaps in place for November and December 2019 where, if the counterparty elects to double the volume, we would have additional swaps in place for 20,000 Mmbtu/day at a weighted average price of $3.20. In 2020, if the counterparty elects to double the volume, we would have additional swaps in place for 140,000 Mmbtu/day at a weighted average price of $2.78. In addition, for January through March 2020, we have additional swaps in place, if the counterparty elects to double the volume, we would have an additional 20,000 Mmbtu/day at a weighted average price of $3.20. Every derivative instrument is required to be recorded on the balance sheet as either an asset or a liability measured at its fair value. We recognize all changes in fair value of these derivatives as earnings in derivative fair value income or loss in the periods in which they occur. Basis Swap Contracts In addition to the swaps, collars and swaptions described above, at March 31, 2019, we had natural gas basis swap contracts which lock in the differential between NYMEX Henry Hub and certain of our physical pricing indices. These contracts settle monthly through October 2021 and include a total volume of 69,775,000 Mmbtu. The fair value of these contracts was a loss of $3.4 million at March 31, 2019. At March 31, 2019, we also had propane spread swap contracts which lock in the differential between Mont Belvieu and international propane indices. The contracts settle monthly in April through June and October through December of 2019 and monthly in 2020 and include a total volume of 1,875,000 barrels. The fair value of these contracts was a loss of $809,000 at March 31, 2019. Freight Swap Contracts In connection with our international propane sales, we utilize propane swaps. To further hedge our propane price, at March 31, 2019, we had freight swap contracts on the Baltic Exchange which lock in the freight rate for a specific trade route. These contracts settle monthly through December 2019 and cover 10,000 metric tons per month with a fair value loss of $103,000 at March 31, 2019. Derivative Assets and Liabilities The combined fair value of derivatives included in the accompanying consolidated balance sheets as of March 31, 2019 and December 31, 2018 is summarized below. The assets and liabilities are netted where derivatives with both gain and loss positions are held by a single counterparty and we have master netting arrangements. The tables below provide additional information relating to our master netting arrangements with our derivative counterparties (in thousands): March 31, 2019 Gross Amounts of Recognized Assets Gross Amounts Offset in the Balance Sheet Net Amounts of Assets Presented in the Balance Sheet Derivative assets: Natural gas –swaps $ 15,883 $ (7,441 ) $ 8,442 –swaptions 6,487 (4,634 ) 1,853 –basis swaps 838 (838 ) — Crude oil –swaps 2,871 (4,648 ) (1,777 ) −collars 1,252 (750 ) 502 NGLs −C2 ethane swaps 216 (216 ) — –C3 propane swaps 7,471 (3,108 ) 4,363 −C3 propane collars 967 (967 ) — –C3 propane spread swaps 3,425 (3,425 ) — −C5 natural gasoline swaps 4,643 (3,474 ) 1,169 Freight −swaps 37 (37 ) — $ 44,090 $ (29,538 ) $ 14,552 March 31, 2019 Gross Amounts of Recognized (Liabilities) Gross Amounts Offset in the Balance Sheet Net Amounts of (Liabilities) Presented in the Balance Sheet Derivative (liabilities): Natural gas –swaps $ (13,030 ) $ 7,441 $ (5,589 ) –swaptions (12,550 ) 4,634 (7,916 ) –basis swaps (4,278 ) 838 (3,440 ) Crude oil –swaps (11,197 ) 4,648 (6,549 ) −collars — 750 750 NGLs −C2 ethane swaps — 216 216 –C3 propane swaps — 3,108 3,108 –C3 propane collars — 967 967 –C3 propane spread swaps (4,234 ) 3,425 (809 ) –C5 natural gasoline swaps (37 ) 3,474 3,437 Freight –swaps (140 ) 37 (103 ) $ (45,466 ) $ 29,538 $ (15,928 ) December 31, 2018 Gross Amounts of Recognized Assets Gross Amounts Offset in the Balance Sheet Net Amounts of Assets Presented in the Balance Sheet Derivative assets: Natural gas –swaps $ 20,834 $ (11,748 ) $ 9,086 –swaptions 5,200 (3,883 ) 1,317 –basis swaps 6,468 (2,822 ) 3,646 Crude oil –swaps 26,481 (651 ) 25,830 –collars 5,945 (707 ) 5,238 NGLs –C3 propane swaps 18,719 (589 ) 18,130 –C3 propane collars 8,538 — 8,538 –C3 propane spread swaps 8,984 (8,868 ) 116 –NC4 butane swaps 4,084 — 4,084 –C5 natural gasoline swaps 17,371 — 17,371 Freight –swaps — (561 ) (561 ) $ 122,624 $ (29,829 ) $ 92,795 December 31, 2018 Gross Amounts of Recognized (Liabilities) Gross Amounts Net Amounts of (Liabilities) Presented in the Balance Sheet Derivative (liabilities): Natural gas –swaps $ (18,332 ) $ 11,748 $ (6,584 ) –swaptions (7,972 ) 3,883 (4,089 ) –basis swaps (1,702 ) 2,822 1,120 Crude oil –swaps — 651 651 –collars — 707 707 NGLs –C3 propane swaps — 589 589 –C3 propane spread swaps (8,868 ) 8,868 — Freight –swaps (561 ) 561 — $ (37,435 ) $ 29,829 $ (7,606 ) The effects of our derivatives on our consolidated statements of operations are summarized below (in thousands): Derivative Fair Value (Loss) Income Three Months Ended March 31, 2019 2018 Commodity swaps $ (57,418 ) $ (16,536 ) Swaptions (3,291 ) 3,599 Collars (4,524 ) (77 ) Calls — 177 Basis swaps 3,415 (864 ) Freight swaps 87 (308 ) Total $ (61,731 ) $ (14,009 )

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	(13) FAIR VALUE MEASUREMENTS Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. There are three approaches for measuring the fair value of assets and liabilities: the market approach, the income approach and the cost approach, each of which includes multiple valuation techniques. The market approach uses prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities. The income approach uses valuation techniques to measure fair value by converting future amounts, such as cash flows or earnings, into a single present value amount using current market expectations about those future amounts. The cost approach is based on the amount that would currently be required to replace the service capacity of an asset. This is often referred to as current replacement cost. The cost approach assumes that the fair value would not exceed what it would cost a market participant to acquire or construct a substitute asset of comparable utility, adjusted for obsolescence. The fair value accounting standards do not prescribe which valuation technique should be used when measuring fair value and do not prioritize among the techniques. These standards establish a fair value hierarchy that prioritizes the inputs used in applying the various valuation techniques. Inputs broadly refer to the assumptions that market participants use to make pricing decisions, including assumptions about risk. Level 1 inputs are given the highest priority in the fair value hierarchy while Level 3 inputs are given the lowest priority. The three levels of the fair value hierarchy are as follows: • Level 1 – Observable inputs that reflect unadjusted quoted prices for identical assets or liabilities in active markets as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. • Level 2 – Observable market-based inputs or unobservable inputs that are corroborated by market data. These are inputs other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. • Level 3 – Unobservable inputs for which there is little, if any, market activity for the asset or liability being measured. These inputs reflect management’s best estimates of the assumptions market participants would use in determining fair value. Our Level 3 measurements consist of instruments using standard pricing models and other valuation methods that utilize unobservable pricing inputs that are significant to the overall fair value. Valuation techniques that maximize the use of observable inputs are favored. Assets and liabilities are classified in their entirety based on the lowest priority level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy. Significant uses of fair value measurements include: • impairment assessments of long-lived assets; and • recorded value of derivative instruments and trading securities. The need to test long-lived assets can be based on several indicators, including a significant reduction in prices of natural gas, oil and condensate, NGLs, unfavorable adjustments to reserves, significant changes in the expected timing of production, other changes to contracts or changes in the regulatory environment in which a property is located. Fair Values – Recurring We use a market approach for our recurring fair value measurements and endeavor to use the best information available. The following tables present the fair value hierarchy table for assets and liabilities measured at fair value, on a recurring basis (in thousands): Fair Value Measurements at March 31, 2019 using: Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Carrying Value as of March 31, 2019 Trading securities held in the deferred compensation plans $ 63,774 $ — $ — $ 63,774 Derivatives –swaps — 6,820 — 6,820 –collars — 1,252 967 2,219 –basis swaps — (4,249 ) — (4,249 ) –freight swaps — (103 ) — (103 ) –swaptions — — (6,063 ) (6,063 ) Fair Value Measurements at December 31, 2018 using: Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs (Level 2) Significant Unobservable (Level 3) Total Carrying Value as of December 31, 2018 Trading securities held in the deferred compensation plans $ 57,293 $ — $ — $ 57,293 Derivatives –swaps — 69,156 — 69,156 –collars — 5,945 8,538 14,483 –basis swaps — 4,883 — 4,883 –freight swaps — (561 ) — (561 ) –swaptions — — (2,772 ) (2,772 ) Our trading securities in Level 1 are exchange-traded and measured at fair value with a market approach using end of period market values. Derivatives in Level 2 are measured at fair value with a market approach using third-party pricing services which have been corroborated with data from active markets or broker quotes. As of March 31, 2019, a portion of our natural gas derivative instruments contains swaptions where the counterparty has the right, but not the obligation, to enter into a fixed price swap on a pre-determined date. Derivatives in Level 3 are measured at fair value with a market approach using third-party pricing services which have been corroborated with data from active markets or broker quotes. Subjectivity in the volatility factors utilized can cause a significant change in the fair value measurement of our swaptions. The following is a reconciliation of the beginning and ending balances for derivative instruments classified as Level 3 in the fair value hierarchy (in thousands): As of March 31, 2019 Balance at December 31, 2018 $ 5,766 Total losses: Included in earnings (3,442 ) Settlements (7,420 ) Balance at March 31, 2019 $ (5,096 ) Our trading securities held in the deferred compensation plan are accounted for using the mark-to-market accounting method and are included in other assets in the accompanying consolidated balance sheets. We elected to adopt the fair value option to simplify our accounting for the investments in our deferred compensation plan. Interest, dividends, and mark-to-market gains or losses are included in deferred compensation plan expense in the accompanying consolidated statements of operations. For first quarter 2019, interest and dividends were $179,000 and the mark-to-market adjustment was a gain of $5.1 million compared to interest and dividends of $168,000 and a mark-to-market loss of $7.5 million in first quarter 2018. Fair Values – Non-recurring Our proved natural gas and oil properties are reviewed for impairment periodically as events or changes in circumstances indicate the carrying amount may not be recoverable. In first quarter 2018, there were indicators that the carrying value of certain of our oil gas properties in Oklahoma may be impaired and undiscounted future cash flows attributed to these assets indicated their carrying amounts were not expected to be recovered. Their remaining fair value was measured using a market approach based upon the potential sale of these Oklahoma properties, which is a Level 3 input. We recorded non-cash charges in first quarter 2018 of $7.3 million related to these properties of which the fair value was determined to be $32.5 million. There were no impairment charges in first quarter 2019. Fair Values – Reported The following presents the carrying amounts and the fair values of our financial instruments as of March 31, 2019 and December 31, 2018 (in thousands): March 31, 2019 December 31, 2018 Carrying Fair Carrying Fair Assets: Commodity swaps, options and basis swaps $ 14,552 $ 14,552 $ 92,795 $ 92,795 Marketable securities (a) 63,774 63,774 57,293 57,293 (Liabilities): Commodity swaps, options and basis swaps (15,928 ) (15,928 ) (7,606 ) (7,606 ) Bank credit facility (b) (895,000 ) (895,000 ) (943,000 ) (943,000 ) 5.75% senior notes due 2021 (b) (475,952 ) (486,042 ) (475,952 ) (455,972 ) 5.00% senior notes due 2022 (b) (580,032 ) (574,139 ) (580,032 ) (519,343 ) 5.875% senior notes due 2022 (b) (329,244 ) (333,020 ) (329,244 ) (305,989 ) Other senior notes due 2022 (b) (590 ) (593 ) (590 ) (581 ) 5.00% senior notes due 2023 (b) (741,531 ) (718,996 ) (741,531 ) (654,683 ) 4.875% senior notes due 2025 (b) (750,000 ) (696,983 ) (750,000 ) (616,313 ) 5.75% senior subordinated notes due 2021 (b) (22,214 ) (22,539 ) (22,214 ) (21,638 ) 5.00% senior subordinated notes due 2022 (b) (19,054 ) (18,811 ) (19,054 ) (17,072 ) 5.00% senior subordinated notes due 2023 (b) (7,712 ) (7,085 ) (7,712 ) (6,690 ) Deferred compensation plan (c) (88,334 ) (88,334 ) (80,092 ) (80,092 ) (a) Marketable securities, which are held in our deferred compensation plans, are actively traded on major exchanges. (b) The book value of our bank debt approximates fair value because of its floating rate structure. The fair value of our senior notes and our senior subordinated notes is based on end of period market quotes which are Level 2 inputs. (c) The fair value of our deferred compensation plan is updated at the closing price on the balance sheet date which is a Level 1 input. Our current assets and liabilities include financial instruments, the most significant of which are trade accounts receivable and payable. We believe the carrying values of our current assets and liabilities approximate fair value. Our fair value assessment incorporates a variety of considerations, including (1) the short-term duration of the instruments and (2) our historical and expected incurrence of bad debt expense. Non-financial liabilities initially measured at fair value include asset retirement obligations and operating lease liabilities. For additional information, see Note 11. Concentrations of Credit Risk As of March 31, 2019, our primary concentrations of credit risk are the risks of not collecting accounts receivable and the risk of a counterparty’s failure to perform under derivative obligations. Most of our receivables are from a diverse group of companies, including major energy companies, pipeline companies, local distribution companies, financial institutions and end-users in various industries. Letters of credit or other appropriate securities are obtained as deemed necessary to limit our risk of loss. Our allowance for uncollectable receivables was $6.1 million at both March 31, 2019 and December 31, 2018. Our derivative exposure to credit risk is diversified primarily among major investment grade financial institutions, where we have master netting agreements which provide for offsetting payables against receivables from separate derivative contracts. To manage counterparty risk associated with our derivatives, we select and monitor our counterparties based on our assessment of their financial strength and/or credit ratings. We may also limit the level of exposure with any single counterparty. At March 31, 2019, our derivative counterparties include twenty financial institutions, of which all but four are secured lenders in our bank credit facility. At March 31, 2019, our net derivative liability includes a net payable of $3.9 million to these four counterparties that are not participants in our bank credit facility.

Stock-based Compensation Plans

Stock-based Compensation Plans	3 Months Ended
	Mar. 31, 2019
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Stock-based Compensation Plans	(14) STOCK-BASED COMPENSATION PLANS Stock-Based Awards We have one active equity-based stock plan, our Amended and Restated 2005 Equity-Based Incentive Compensation Plan, which we refer to as the 2005 Plan. Under this plan, various awards may be issued to non-employee directors and employees pursuant to decisions of the Compensation Committee, which is composed of only non-employee, independent directors. Total Stock-Based Compensation Expense Stock-based compensation represents amortization of restricted stock and performance units. Unlike the other forms of stock-based compensation, the mark-to-market adjustment of the liability related to the vested restricted stock held in our deferred compensation plan is directly tied to the change in our stock price and not directly related to the functional expenses and therefore, is not allocated to the functional categories. The following details the allocation of stock-based compensation to functional expense categories (in thousands): Three Months Ended March 31, 2019 2018 Direct operating expense $ 591 $ 591 Brokered natural gas and marketing expense 385 285 Exploration expense 373 751 General and administrative expense 8,815 23,911 Total stock-based compensation $ 10,164 $ 25,538 Stock-Based Awards Restricted Stock Awards . We grant restricted stock units under our equity-based stock compensation plan. These restricted stock units, which we refer to as restricted stock Equity Awards, generally vest over a three year period, contingent on the recipient’s continued employment. The grant date fair value of the Equity Awards is based on the fair market value of our common stock on the date of grant. The Compensation Committee also grants restricted stock to certain employees and non-employee directors of the board of directors as part of their compensation. We also grant restricted stock to certain employees for retention purposes. Compensation expense is recognized over the balance of the vesting period, which is typically three years for employee grants and immediate vesting for non-employee directors. All restricted stock awards are issued at prevailing market prices at the time of the grant and the vesting is based upon an employee’s continued employment with us. Prior to vesting, all restricted stock awards have the right to vote such stock and receive dividends thereon. Upon grant of these restricted shares, which we refer to as restricted stock Liability Awards, the majority of these shares are generally placed in our deferred compensation plan and, upon vesting, withdrawals are allowed in either cash or in stock. These Liability Awards are classified as a liability and are remeasured at fair value each reporting period. This mark-to-market amount is reported in deferred compensation plan expense in the accompanying consolidated statements of operations. Historically, we have used authorized but unissued shares of stock when restricted stock is granted. However, we also utilize treasury shares when available. Stock-Based Performance Units . We grant three types of performance share awards: two based on performance conditions measured against internal performance metrics (Production Growth Awards or “PG-PSUs” and Reserve Growth Awards or “RG-PSUs”) and one based on market conditions measured based on Range’s performance relative to a predetermined peer group (TSR Awards or “TSR-PSUs”). Each unit granted represents one share of our common stock. These units are settled in stock and the amount of the payout is based on (1) the vesting percentage, which can be from zero to 200% based on performance achieved and (2) the value of our common stock on the vesting date which is determined by the Compensation Committee. Dividend equivalents may accrue during the performance period and are paid in stock at the end of the performance period. The performance period for the TSR-PSUs is three years. The performance period for the PG/RG-PSUs is based on annual performance targets earned over a three-year period. SARs . At March 31, 2019, there were no SARs outstanding. Restricted Stock – Equity Awards In first three months 2019, we granted 2.8 million restricted stock Equity Awards to employees at an average price of $10.59 which generally vest over a three-year period compared to 1.8 million at an average price of $17.00 in first three months 2018. We recorded compensation expense for these awards of $7.1 million in first three months 2019 compared to $6.5 million in the same period of 2018. Restricted stock Equity Awards are not issued to employees until such time as they are vested and the employees do not have the option to receive cash. Restricted Stock – Liability Awards In first three months 2019, we granted 1.0 million shares of restricted stock Liability Awards as compensation to employees at an average price of $10.46 which vests generally over a three-year period. In first three months 2018, we granted 674,000 shares of restricted stock Liability Awards as compensation to employees at an average price of $15.21 with vesting generally over a three-year period. We recorded compensation expense for these Liability Awards of $1.0 million in first three months 2019 compared to $8.1 million in first three months 2018. The majority of these awards are held in our deferred compensation plan, are classified as a liability and are remeasured at fair value each reporting period. This mark-to-market amount is reported as deferred compensation expense in our consolidated statements of operations (see additional discussion below). The following is a summary of the status of our non-vested restricted stock outstanding at March 31, 2019: Restricted Stock Equity Awards Restricted Stock Liability Awards Shares Weighted Average Grant Date Fair Value Shares Weighted Average Grant Date Fair Value Outstanding at December 31, 2018 1,386,088 $ 20.04 184,579 $ 15.65 Granted 2,792,438 10.59 1,009,653 10.46 Vested (447,405 ) 16.10 (134,573 ) 11.71 Forfeited (103,093 ) 13.56 — — Outstanding at March 31, 2019 3,628,028 $ 13.44 1,059,659 $ 11.21 Stock-Based Performance Units Production Growth and Reserve Growth Awards. The PG-PSUs and RG-PSUs vest at the end of the three-year performance period. The performance metrics for each year are set by the Compensation Committee no later than March 31 of such year. If the performance metric for the applicable period is not met, then the portion is considered forfeited. The following is a summary of our non-vested PG/RG-PSUs awards outstanding at March 31, 2019: Number of Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2018 536,798 $ 15.61 Units granted (a) 345,202 10.32 Forfeited — — Outstanding at March 31, 2019 882,000 $ 11.70 (a) We recorded PG/RG-PSUs compensation expense of $1.6 million in first three months 2019 compared to $5.3 million in first three months 2018. TSR Awards. TSR-PSUs granted are earned, or not earned, based on the comparative performance of Range’s common stock measured against a predetermined group of companies in the peer group over a three-year performance period. The fair value of the TSR-PSUs is estimated on the date of grant using a Monte Carlo simulation model which utilizes multiple input variables that determine the probability of satisfying the market condition stipulated in the award grant and calculates the fair value of the award. The fair value is recognized as stock-based compensation expense over the three-year performance period. Expected volatilities utilized in the model were estimated using a combination of a historical period consistent with the remaining performance period of three years and option implied volatilities. The risk-free interest rate was based on the United States Treasury rate for a term commensurate with the life of the grant. The following assumptions were used to estimate the fair value of PSUs granted during first three months 2019 and 2018: Three Months Ended March 31, 2019 2018 Risk-free interest rate 2.4 % 2.4 % Expected annual volatility 46 % 47 % Grant date fair value per unit $ 11.34 $ 18.51 The following is a summary of our non-vested TSR – Units Weighted Average Fair Value Outstanding at December 31, 2018 1,067,886 $ 27.81 Units granted (a) 314,152 11.34 Vested and issued (b) (12,283 ) 30.47 Forfeited (79,058 ) 30.47 Outstanding at March 31, 2019 1,290,697 $ 23.62 (a) These (b) Includes 12,283 TSR-PSUs awards issued related to the 2016 performance period where the return on our common stock was in the 20 th We recorded TSR-PSUs compensation expense of $443,000 in first three months 2019 compared to $5.4 million in the same period of 2018. SARs Information with respect to our SARs activity is summarized below. Shares Weighted Average Exercise Price Outstanding at December 31, 2018 1,104 $ 81.74 Expired (1,104 ) 81.74 Outstanding at March 31, 2019 — $ — Other Postretirement Benefits Effective fourth quarter 2017, as part of our officer succession plan, we implemented a postretirement benefit plan to assist in providing health care to officers who are active employees (including their spouses) and have met certain age and service requirements. These benefits are not funded in advance and are provided up to age 65 or at the date they become eligible for Medicare, subject to various cost-sharing features. There were $92,000 of estimated prior service costs amortized from accumulated other comprehensive income into general and administrative expense in both the three months ended March 31, 2019 and 2018. Those employees that qualify for the new postretirement health care plan were also fully vested in all equity grants. Effective October 2018, officers who qualify for the plan are required to provide reasonable notice of retirement and beginning in 2019 are fully vested after providing one year of service after the grant date. Deferred Compensation Plan Our deferred compensation plan gives non-employee directors and officers the ability to defer all or a portion of their salaries, bonuses or director fees and invest in Range common stock or make other investments at the individual’s discretion. Range provides a partial matching contribution to officers which vests over three years. The assets of the plan are held in a grantor trust, which we refer to as the Rabbi Trust, and are therefore available to satisfy the claims of our general creditors in the event of bankruptcy or insolvency. Our stock held in the Rabbi Trust is treated as a liability award as employees are allowed to take withdrawals from the Rabbi Trust either in cash or in Range stock. The liability for the vested portion of the stock held in the Rabbi Trust is reflected as deferred compensation liability in the accompanying consolidated balance sheets and is adjusted to fair value each reporting period by a charge or credit to deferred compensation plan expense on our consolidated statements of operations. The assets of the Rabbi Trust, other than our common stock, are invested in marketable securities and reported at their market value as other assets in the accompanying consolidated balance sheets. The deferred compensation liability reflects the vested market value of the marketable securities and Range stock held in the Rabbi Trust. Changes in the market value of the marketable securities and changes in the fair value of the deferred compensation plan liability are charged or credited to deferred compensation plan expense each quarter. We recorded mark-to-market loss of $3.6

Capital Stock

Capital Stock	3 Months Ended
	Mar. 31, 2019
Equity [Abstract]
Capital Stock	(15) CAPITAL STOCK We have authorized capital stock of 485.0 million shares which includes 475.0 million shares of common stock and 10.0 million shares of preferred stock. We currently have no preferred stock issued or outstanding. The following is a schedule of changes in the number of common shares outstanding since the beginning of 2018: Three Months Year Beginning balance 249,510,022 248,129,430 Restricted stock grants 981,905 865,095 Restricted stock units vested 633,460 434,046 Performance stock units issued 12,283 73,985 Performance stock dividends 464 2,164 Treasury shares issued — 5,302 Ending balance 251,138,134 249,510,022

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	(16) SUPPLEMENTAL CASH FLOW INFORMATION Three Months Ended March 31, 2019 2018 (in thousands) Net cash provided from operating activities included: Income taxes refunded from taxing authorities $ — $ 7,518 Interest paid (54,632 ) (57,536 ) Non-cash investing and financing activities included: Increase in asset retirement costs capitalized 1,532 5,063 Increase (decrease) in accrued capital expenditures 22,764 (77,365 )

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2019
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	(17) COMMITMENTS AND CONTINGENCIES Litigation We are the subject of, or party to, a number of pending or threatened legal actions, administrative proceedings and claims arising in the ordinary course of our business. While many of these matters involve inherent uncertainty, we believe that the amount of the liability, if any, ultimately incurred with respect to these actions, proceedings or claims will not have a material adverse effect on our consolidated financial position as a whole or on our liquidity, capital resources or future annual results of operations. We estimate and provide for potential losses that may arise out of litigation and regulatory proceedings to the extent that such losses are probable and can be reasonably estimated. We will continue to evaluate our litigation and regulatory proceedings quarterly and will establish and adjust any estimated liability as appropriate to reflect our assessment of the then current status of litigation and regulatory proceedings. Significant judgment is required in making these estimates and our final liabilities may ultimately be materially different.

Suspended Exploratory Well Cost

Suspended Exploratory Well Costs	3 Months Ended
	Mar. 31, 2019
Extractive Industries [Abstract]
Suspended Exploratory Well Costs	(18) SUSPENDED EXPLORATORY WELL COSTS We capitalize exploratory well costs until a determination is made that the well has either found proved reserves or that it is impaired. Capitalized exploratory well costs are included in natural gas and oil properties in the accompanying consolidated balance sheets. If an exploratory well is determined to be impaired, the well costs are charged to exploration expense in the accompanying consolidated statements of operations. We do not have any suspended exploratory well costs as of March 31, 2019 or December 31, 2018.

Costs Incurred for Property Acq

Costs Incurred for Property Acquisition, Exploration and Development	3 Months Ended
	Mar. 31, 2019
Extractive Industries [Abstract]
Costs Incurred for Property Acquisition, Exploration and Development	(19) Costs Incurred for Property Acquisition, Exploration and Development (a) Three Months Ended March 31, 2019 Year Ended December 31, 2018 (in thousands) Acquisitions: Acreage purchases $ 14,634 $ 62,390 Oil and gas properties — 1,683 Development 209,827 834,552 Exploration: Drilling 542 1,380 Expense 7,837 32,196 Stock-based compensation expense 373 1,921 Gas gathering facilities: Development 1,063 10,218 Subtotal 234,276 944,340 Asset retirement obligations 1,532 28,826 Total costs incurred $ 235,808 $ 973,166 (a) Includes costs incurred whether capitalized or expensed.

Basis of Presentation (Policies

Basis of Presentation (Policies)	3 Months Ended
	Mar. 31, 2019
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Inventory	Inventory. As of March 31, 2019, we had $7.4 million of material and supplies inventory compared to $8.0 million at December 31, 2018. Material and supplies inventory consists of primarily tubular goods and equipment used in our operations and is stated at lower of specific cost of each inventory item or net realized value, on a first-in, first-out basis. At March 31, 2019, we also had commodity inventory of $253,000 compared to $965,000 at December 31, 2018. Commodity inventory as of March 31, 2019 consists of NGLs held in storage or as line fill in pipelines.
New Accounting Standards	Not Yet Adopted Financial Instruments – Credit Losses In June 2016, an accounting standards update was issued that changes the impairment model for trade receivables, net investments in leases, debt securities, loans and certain other instruments. The standards update requires the use of a forward-looking “expected loss” model as opposed to the current “incurred loss” model. This standards update is effective for us in first quarter 2020 and will be adopted on a modified retrospective basis through a cumulative-effect adjustment to retained earnings as of the beginning of the adoption period. Early adoption is permitted starting January 2019. We are evaluating the provisions of this accounting standards update and assessing the impact, if any, it may have on our consolidated results of operations, financial position and financial disclosures. Fair Value Measurement In August 2018, an accounting standards update was issued which provides additional disclosure requirements for fair value measurements. This new standards update eliminates the requirement to disclose transfers between Level 1 and Level 2 of the fair value hierarchy and provides for additional disclosures for Level 3 fair value measurements. This new standards update is effective for us in first quarter 2020 and will be adopted on a prospective or retrospective basis depending on the changes that apply. We are evaluating the provisions of this standards update and assessing the impact, if any, it may have on our financial disclosures. Recently Adopted Lease Accounting Standard In February 2016, an accounting standards update was issued that requires an entity to recognize a right-of-use (“ROU”) asset and lease liability for all leases. Classification of leases as either a finance or operating lease determines the recognition, measurement and presentation of expenses. This accounting standards update also requires certain quantitative and qualitative disclosures about leasing arrangements. The new standard was effective for us in first quarter 2019 and we adopted the new standard using a modified retrospective approach, with the date of initial application on January 1, 2019. Consequently, upon transition, we recognized a ROU asset (or operating lease right-of-use asset) and a lease liability with no retained earnings impact. We are applying the following practical expedients as provided in the standards update which provide elections to: • not apply the recognition requirements to short-term leases (a lease that at commencement date has a lease term of 12 months or less and does not contain a purchase option); • not reassess whether a contract contains a lease, lease classification and initial direct costs; and • not reassess certain land easements in existence prior to January 1, 2019. Through our implementation process, we evaluated each of our lease arrangements and enhanced our systems to track and calculate additional information required upon adoption of this standards update. Our adoption did not have a material impact on our consolidated balance sheet as of January 1, 2019, with the primary impact relating to the recognition of ROU assets and operating lease liabilities for operating leases which represents approximately a 1% change to total assets and total liabilities. The impact of adoption of this new standards update is as follows (in thousands): January 1, 2019 Adoption Reclassification (1) Total Adjustment Balance Sheet: Operating lease right-of-use assets $ 59,300 $ (7,925 ) $ 51,375 Accrued liabilities – current $ (14,811 ) $ — $ (14,811 ) Operating lease liabilities – long-term $ (44,489 ) $ — $ (44,489 ) Asset retirement obligations and other liabilities $ — $ 7,925 $ 7,925 (1) Adoption of the new standard did not impact our consolidated statements of operations, cash flows or stockholders’ equity. Leases acquired to explore for or use minerals, oil or natural gas resources, including the right to explore for those natural resources and rights to use the land in which those natural resources are contained, are not within the scope of the standards update. Pension Accounting Standard In March 2017, an accounting standards update was issued which provides additional guidance on the presentation of net benefit cost in the statement of operations. Employers will present the service cost component of net periodic benefit cost in the same consolidated results of operations line item as other employee compensation costs arising from services rendered during the period. This new standards update was effective for annual reporting periods in first quarter 2018 and must be applied retrospectively. We adopted this standards update in first quarter 2018. The adoption did not impact our consolidated results of operations, financial position, cash flows or disclosures. In 2018 and 2019, our service cost is recorded in general and administrative expense. Modification of Share – Based Awards In May 2017, an accounting standards update was issued which clarifies what constitutes a modification of a share-based award. This standards update is intended to provide clarity and reduce both diversity in practice and cost and complexity to a change to the terms or conditions of a share-based payment award. We adopted this standards update in first quarter 2018. The adoption of this standard did not have a material impact on our consolidated financial position or results of operations. Revenue Recognition Standard In May 2014, an accounting standards update was issued that superseded the existing revenue recognition requirements. This standard included a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration to which we expect to be entitled in exchange for those goods or services. Among other things, the standard also eliminated industry-specific revenue guidance, required enhanced disclosures about revenue, provided guidance for transactions that were not previously addressed comprehensively and improved guidance for multiple-element arrangements. This standard was effective for us in first quarter 2018 and we adopted the new standards update using the modified retrospective method to all open contracts as of January 1, 2018. Our implementation of this standard did not result in a cumulative-effect adjustment on date of adoption; however, our financial statement presentation related to revenue received from certain gas processing contracts changed. Based on previous accounting guidance, certain of our gas processing contracts were reported in revenue at the net price (net of processing costs) we receive. Upon adoption of this accounting standards update, these contracts are now reported as a gross price received at a delivery point and separate transportation, marketing and processing expense.

New Accounting Standards (Table

New Accounting Standards (Tables)	3 Months Ended
	Mar. 31, 2019
New Accounting Pronouncements And Changes In Accounting Principles [Abstract]
Schedule of Impact of Adoption of New Lease Accounting Standard	The impact of adoption of this new standards update is as follows (in thousands): January 1, 2019 Adoption Reclassification (1) Total Adjustment Balance Sheet: Operating lease right-of-use assets $ 59,300 $ (7,925 ) $ 51,375 Accrued liabilities – current $ (14,811 ) $ — $ (14,811 ) Operating lease liabilities – long-term $ (44,489 ) $ — $ (44,489 ) Asset retirement obligations and other liabilities $ — $ 7,925 $ 7,925 (1)

Revenues from Contracts with _2

Revenues from Contracts with Customers (Tables)	3 Months Ended
	Mar. 31, 2019
Revenue From Contract With Customer [Abstract]
Disaggregation of Revenue by Identified Revenue Stream	Revenue attributable to each of our identified revenue streams is disaggregated below (in thousands): Three Months Ended March 31, 2019 2018 Natural gas sales (a) $ 572,510 $ 491,248 NGLs sales (b) 198,237 202,831 Oil sales 39,121 62,529 Total $ 809,868 $ 756,608 (a) Natural gas sales revenue reported above for first quarter 2019 includes $134.8 million of brokered revenues and $3.0 million of marketing revenue. First quarter 2018 includes $55.9 million of brokered revenues and $3.8 million of marketing revenue. (b) NGLs sales revenue reported above for the first quarter 2019 includes $424,000 of brokered revenues and first quarter 2018 includes $304,000 of brokered revenues.

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2019
Income Tax Disclosure [Abstract]
Income Tax Expense	Income tax expense was as follows (in thousands): Three Months Ended March 31, 2019 2018 Income tax expense $ 5,688 $ 42,676 Effective tax rate 80.0 % 46.4 %
Summary of Differences In Effective Tax Rate and Federal Statutory Rate Due to State Income Taxes, Equity Compensation and Other Tax Items	For first quarter 2019 and 2018, our overall effective tax rate was different than the federal statutory rate due primarily to state income taxes (including adjustments to state income tax valuation allowances), equity compensation and other tax items which are detailed below (in thousands). Three Months Ended March 31, 2019 2018 Total income before income taxes $ 7,107 $ 91,914 U.S. federal statutory rate 21 % 21 % Total tax expense at statutory rate 1,492 19,302 State and local income taxes, net of federal benefit 818 4,494 Equity compensation 3,391 664 Change in valuation allowances: State net operating loss carryforwards & other 352 15,678 Other 231 1,381 Permanent differences and other (596 ) 1,157 Total expense for income taxes $ 5,688 $ 42,676 Effective tax rate 80.0 % 46.4 %

Income (Loss) Per Common Share

Income (Loss) Per Common Share (Tables)	3 Months Ended
	Mar. 31, 2019
Earnings Per Share [Abstract]
Computations of Basic and Diluted Income (Loss) Per Common Share	Basic income or loss per share attributable to common shareholders is computed as (1) income or loss attributable to common shareholders (2) less income allocable to participating securities (3) divided by weighted average basic shares outstanding. Diluted income or loss per share attributable to common shareholders is computed as (1) basic income or loss attributable to common shareholders (2) plus diluted adjustments to income allocable to participating securities (3) divided by weighted average diluted shares outstanding. The following sets forth a reconciliation of income or loss attributable to common shareholders to basic income or loss attributable to common shareholders to diluted income or loss attributable to common shareholders (in thousands, except per share amounts): Three Months Ended March 31, 2019 2018 Net income, as reported $ 1,419 $ 49,238 Participating earnings (a) (14 ) (568 ) Basic net income attributed to common shareholders 1,405 48,670 Reallocation of participating earnings (a) — 2 Diluted net income attributed to common shareholders $ 1,405 $ 48,672 Net income per common share: Basic $ 0.01 $ 0.20 Diluted $ 0.01 $ 0.20 (a) Restricted Stock Awards represent participating securities because they participate in nonforfeitable dividends or distributions with common equity owners. Income allocable to participating securities represents the distributed and undistributed earnings attributable to the participating securities. Participating securities, however, do not participate in undistributed net losses
Basic Weighted Average Common Shares Outstanding to Diluted Weighted Average Common Shares Outstanding	The following provides a reconciliation of basic weighted average common shares outstanding to diluted weighted average common shares outstanding (in thousands): Three Months Ended March 31, 2019 2018 Weighted average common shares outstanding – basic 247,776 245,709 Effect of dilutive securities: Director and employee restricted stock and performance based equity awards 1,378 885 Weighted average common shares outstanding – diluted 249,154 246,594

Leases (Tables)

Leases (Tables)	3 Months Ended
	Mar. 31, 2019
Leases [Abstract]
Schedule of Components of Lease Expense	The components of our total lease expense for the three months ended March 31, 2019, the majority of which is included in general and administrative expense, are as follows (in thousands): Three Months Ended March 31, 2019 Operating lease cost $ 3,080 Variable lease expense (1) 1,151 Short-term lease expense ( 2 ) 92 Sublease income (875 ) Total lease expense $ 3,448 Short-term lease costs (3) $ 9,164 (1) (2) (3)
Supplemental Cash Flow Information Related to Operating Leases	Supplemental cash flow information related to our operating leases is included in the table below (in thousands): Three Months Ended March 31, 2019 Cash paid for amounts included in the measurement of lease liabilities $ 3,003 ROU assets added in exchange for lease obligations (since adoption) $ 187
Supplemental Balance Sheet Information Related to Operating Leases	Supplemental balance sheet information related to our operating leases is included in the table below (in thousands): March 31, 2019 Operating lease ROU assets $ 49,329 Accrued liabilities – current $ (14,872 ) Operating lease liabilities – long-term $ (41,759 )
Schedule of Weighted Average Remaining Lease Term and Weighted Average Discount Rate for Operating Leases	Our weighted average remaining lease term and weighted average discount rate for our operating leases are as follows (in thousands): March 31, 2019 Weighted Average Remaining Lease Term 6.4 Years Weighted Average Discount Rate 6.1%
Schedule of Lease Liabilities with Enforceable Contract Terms are Greater Than One year Mature	Our lease liabilities with enforceable contract terms that are greater than one year mature as follows (in thousands): Operating Leases Remainder of 2019 $ 14,872 2020 12,491 2021 9,618 2022 6,551 2023 6,479 Thereafter 20,113 Total lease payments $ 70,124 Less imputed interest (13,493 ) Total lease liability $ 56,631

Capitalized Costs and Accumul_2

Capitalized Costs and Accumulated Depreciation, Depletion and Amortization (Tables)	3 Months Ended
	Mar. 31, 2019
Extractive Industries [Abstract]
Capitalized Costs and Accumulated Depreciation, Depletion and Amortization	March 31, December 31, (in thousands) Natural gas and oil properties: Properties subject to depletion $ 11,193,577 $ 10,974,929 Unproved properties 2,106,568 2,110,277 Total 13,300,145 13,085,206 Accumulated depreciation, depletion and amortization (4,194,876 ) (4,062,021 ) Net capitalized costs $ 9,105,269 $ 9,023,185 (a)

Indebtedness (Tables)

Indebtedness (Tables)	3 Months Ended
	Mar. 31, 2019
Debt Disclosure [Abstract]
Debt Outstanding	We had the following debt outstanding as of the dates shown below (bank debt interest rate at March 31, 2019 is shown parenthetically). No interest was capitalized during the three months ended March 31, 2019 or the year ended December 31, 2018 (in thousands). March 31, 2019 December 31, 2018 Bank debt ( 4.0% $ 895,000 $ 943,000 Senior notes: 4.875% senior notes due 2025 750,000 750,000 5.00% senior notes due 2023 741,531 741,531 5.00% senior notes due 2022 580,032 580,032 5.75% senior notes due 2021 475,952 475,952 5.875% senior notes due 2022 329,244 329,244 Other senior notes due 2022 590 590 Total senior notes 2,877,349 2,877,349 Senior subordinated notes: 5.00% senior subordinated notes due 2023 7,712 7,712 5.00% senior subordinated notes due 2022 19,054 19,054 5.75% senior subordinated notes due 2021 22,214 22,214 Total senior subordinated notes 48,980 48,980 Total debt 3,821,329 3,869,329 Unamortized premium 4,408 4,741 Unamortized debt issuance costs (35,088 ) (37,209 ) Total debt net of debt issuance costs $ 3,790,649 $ 3,836,861

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2019
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	A reconciliation of our liability for plugging and abandonment costs for the three months ended March 31, 2019 is as follows (in thousands): Three Months Ended March 31, 2019 Beginning of period $ 312,754 Liabilities incurred 1,719 Liabilities settled (896 ) Accretion expense 4,217 Change in estimate (187 ) End of period 317,607 Less current portion (5,485 ) Long-term asset retirement obligations $ 312,122

Derivative Activities (Tables)

Derivative Activities (Tables)	3 Months Ended
	Mar. 31, 2019
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivative Volumes Hedged and Average Hedge Prices	The following table sets forth our commodity-based derivative volumes by year as of March 31, 2019, excluding our basis and freight swaps which are discussed separately below: Period Contract Type Volume Hedged Weighted Natural Gas 2019 Swaps 1,246,873 Mmbtu/day $ 2.80 2020 Swaps 190,000 Mmbtu/day $ 2.75 2019 Swaptions 150,000 Mmbtu/day $ 2.81 ( 1 ) 2020 Swaptions 140,000 Mmbtu/day $ 2.78 ( 1 ) November – December 2019 Swaptions 20,000 Mmbtu/day $ 3.20 (1) January – March 2020 Swaptions 20,000 Mmbtu/day $ 3.20 (1) Crude Oil 2019 Swaps 7,472 bbls/day $ 55.47 2020 Swaps 2,557 bbls/day $ 60.53 2019 Collars 1,000 bbls/day $ 63.00 − $ 73.02 NGLs (C2-Ethane) April – June 2019 Swaps 500 bbls/day $0.35/gallon NGLs (C3-Propane) April – June 2019 Swaps 8,500 bbls/day $ 0.88/gallon April – June 2019 Collars 1,000 bbls/day $ 0.90 − $ 0.96 NGLs (C5-Natural Gasoline) 2019 Swaps 2,658 bbls/day $ 1.39/gallon ( 1 ) Contains a combined derivative instrument consisting of a fixed price swap and a sold option to extend or double the volumes. We have swaps in place for 2019 for 150,000 Mmbtu/day on which the counterparty can elect to extend the contract through December 2020 at a weighted average price of $2.81. In addition, we have swaps in place for November and December 2019 where, if the counterparty elects to double the volume, we would have additional swaps in place for 20,000 Mmbtu/day at a weighted average price of $3.20. In 2020, if the counterparty elects to double the volume, we would have additional swaps in place for 140,000 Mmbtu/day at a weighted average price of $2.78. In addition, for January through March 2020, we have additional swaps in place, if the counterparty elects to double the volume, we would have an additional 20,000 Mmbtu/day at a weighted average price of $3.20.
Combined Fair Value of Derivatives, by Consolidated Balance Sheets	The combined fair value of derivatives included in the accompanying consolidated balance sheets as of March 31, 2019 and December 31, 2018 is summarized below. The assets and liabilities are netted where derivatives with both gain and loss positions are held by a single counterparty and we have master netting arrangements. The tables below provide additional information relating to our master netting arrangements with our derivative counterparties (in thousands): March 31, 2019 Gross Amounts of Recognized Assets Gross Amounts Offset in the Balance Sheet Net Amounts of Assets Presented in the Balance Sheet Derivative assets: Natural gas –swaps $ 15,883 $ (7,441 ) $ 8,442 –swaptions 6,487 (4,634 ) 1,853 –basis swaps 838 (838 ) — Crude oil –swaps 2,871 (4,648 ) (1,777 ) −collars 1,252 (750 ) 502 NGLs −C2 ethane swaps 216 (216 ) — –C3 propane swaps 7,471 (3,108 ) 4,363 −C3 propane collars 967 (967 ) — –C3 propane spread swaps 3,425 (3,425 ) — −C5 natural gasoline swaps 4,643 (3,474 ) 1,169 Freight −swaps 37 (37 ) — $ 44,090 $ (29,538 ) $ 14,552 March 31, 2019 Gross Amounts of Recognized (Liabilities) Gross Amounts Offset in the Balance Sheet Net Amounts of (Liabilities) Presented in the Balance Sheet Derivative (liabilities): Natural gas –swaps $ (13,030 ) $ 7,441 $ (5,589 ) –swaptions (12,550 ) 4,634 (7,916 ) –basis swaps (4,278 ) 838 (3,440 ) Crude oil –swaps (11,197 ) 4,648 (6,549 ) −collars — 750 750 NGLs −C2 ethane swaps — 216 216 –C3 propane swaps — 3,108 3,108 –C3 propane collars — 967 967 –C3 propane spread swaps (4,234 ) 3,425 (809 ) –C5 natural gasoline swaps (37 ) 3,474 3,437 Freight –swaps (140 ) 37 (103 ) $ (45,466 ) $ 29,538 $ (15,928 ) December 31, 2018 Gross Amounts of Recognized Assets Gross Amounts Offset in the Balance Sheet Net Amounts of Assets Presented in the Balance Sheet Derivative assets: Natural gas –swaps $ 20,834 $ (11,748 ) $ 9,086 –swaptions 5,200 (3,883 ) 1,317 –basis swaps 6,468 (2,822 ) 3,646 Crude oil –swaps 26,481 (651 ) 25,830 –collars 5,945 (707 ) 5,238 NGLs –C3 propane swaps 18,719 (589 ) 18,130 –C3 propane collars 8,538 — 8,538 –C3 propane spread swaps 8,984 (8,868 ) 116 –NC4 butane swaps 4,084 — 4,084 –C5 natural gasoline swaps 17,371 — 17,371 Freight –swaps — (561 ) (561 ) $ 122,624 $ (29,829 ) $ 92,795 December 31, 2018 Gross Amounts of Recognized (Liabilities) Gross Amounts Net Amounts of (Liabilities) Presented in the Balance Sheet Derivative (liabilities): Natural gas –swaps $ (18,332 ) $ 11,748 $ (6,584 ) –swaptions (7,972 ) 3,883 (4,089 ) –basis swaps (1,702 ) 2,822 1,120 Crude oil –swaps — 651 651 –collars — 707 707 NGLs –C3 propane swaps — 589 589 –C3 propane spread swaps (8,868 ) 8,868 — Freight –swaps (561 ) 561 — $ (37,435 ) $ 29,829 $ (7,606 )
Effects of Derivatives on Consolidated Statements of Operations	The effects of our derivatives on our consolidated statements of operations are summarized below (in thousands): Derivative Fair Value (Loss) Income Three Months Ended March 31, 2019 2018 Commodity swaps $ (57,418 ) $ (16,536 ) Swaptions (3,291 ) 3,599 Collars (4,524 ) (77 ) Calls — 177 Basis swaps 3,415 (864 ) Freight swaps 87 (308 ) Total $ (61,731 ) $ (14,009 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2019
Fair Value Disclosures [Abstract]
Fair Value Hierarchy Table for Assets and Liabilities Measured at Fair Value	We use a market approach for our recurring fair value measurements and endeavor to use the best information available. The following tables present the fair value hierarchy table for assets and liabilities measured at fair value, on a recurring basis (in thousands): Fair Value Measurements at March 31, 2019 using: Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Total Carrying Value as of March 31, 2019 Trading securities held in the deferred compensation plans $ 63,774 $ — $ — $ 63,774 Derivatives –swaps — 6,820 — 6,820 –collars — 1,252 967 2,219 –basis swaps — (4,249 ) — (4,249 ) –freight swaps — (103 ) — (103 ) –swaptions — — (6,063 ) (6,063 ) Fair Value Measurements at December 31, 2018 using: Quoted Prices in Active Markets for Identical Assets Significant Other Observable Inputs (Level 2) Significant Unobservable (Level 3) Total Carrying Value as of December 31, 2018 Trading securities held in the deferred compensation plans $ 57,293 $ — $ — $ 57,293 Derivatives –swaps — 69,156 — 69,156 –collars — 5,945 8,538 14,483 –basis swaps — 4,883 — 4,883 –freight swaps — (561 ) — (561 ) –swaptions — — (2,772 ) (2,772 )
Reconciliation of the Beginning and Ending Balances for Derivative Instruments Classified as Level 3 in the Fair Value Hierarchy	The following is a reconciliation of the beginning and ending balances for derivative instruments classified as Level 3 in the fair value hierarchy (in thousands): As of March 31, 2019 Balance at December 31, 2018 $ 5,766 Total losses: Included in earnings (3,442 ) Settlements (7,420 ) Balance at March 31, 2019 $ (5,096 )
Carrying Amounts and Fair Values of Financial Instruments	The following presents the carrying amounts and the fair values of our financial instruments as of March 31, 2019 and December 31, 2018 (in thousands): March 31, 2019 December 31, 2018 Carrying Fair Carrying Fair Assets: Commodity swaps, options and basis swaps $ 14,552 $ 14,552 $ 92,795 $ 92,795 Marketable securities (a) 63,774 63,774 57,293 57,293 (Liabilities): Commodity swaps, options and basis swaps (15,928 ) (15,928 ) (7,606 ) (7,606 ) Bank credit facility (b) (895,000 ) (895,000 ) (943,000 ) (943,000 ) 5.75% senior notes due 2021 (b) (475,952 ) (486,042 ) (475,952 ) (455,972 ) 5.00% senior notes due 2022 (b) (580,032 ) (574,139 ) (580,032 ) (519,343 ) 5.875% senior notes due 2022 (b) (329,244 ) (333,020 ) (329,244 ) (305,989 ) Other senior notes due 2022 (b) (590 ) (593 ) (590 ) (581 ) 5.00% senior notes due 2023 (b) (741,531 ) (718,996 ) (741,531 ) (654,683 ) 4.875% senior notes due 2025 (b) (750,000 ) (696,983 ) (750,000 ) (616,313 ) 5.75% senior subordinated notes due 2021 (b) (22,214 ) (22,539 ) (22,214 ) (21,638 ) 5.00% senior subordinated notes due 2022 (b) (19,054 ) (18,811 ) (19,054 ) (17,072 ) 5.00% senior subordinated notes due 2023 (b) (7,712 ) (7,085 ) (7,712 ) (6,690 ) Deferred compensation plan (c) (88,334 ) (88,334 ) (80,092 ) (80,092 ) (a) Marketable securities, which are held in our deferred compensation plans, are actively traded on major exchanges. (b) The book value of our bank debt approximates fair value because of its floating rate structure. The fair value of our senior notes and our senior subordinated notes is based on end of period market quotes which are Level 2 inputs. (c) The fair value of our deferred compensation plan is updated at the closing price on the balance sheet date which is a Level 1 input.

Stock-based Compensation Plans

Stock-based Compensation Plans (Tables)	3 Months Ended
	Mar. 31, 2019
Allocation of Stock-Based Compensation by Functional Category	The following details the allocation of stock-based compensation to functional expense categories (in thousands): Three Months Ended March 31, 2019 2018 Direct operating expense $ 591 $ 591 Brokered natural gas and marketing expense 385 285 Exploration expense 373 751 General and administrative expense 8,815 23,911 Total stock-based compensation $ 10,164 $ 25,538
Restricted Stock and Restricted Stock Units Outstanding	The following is a summary of the status of our non-vested restricted stock outstanding at March 31, 2019: Restricted Stock Equity Awards Restricted Stock Liability Awards Shares Weighted Average Grant Date Fair Value Shares Weighted Average Grant Date Fair Value Outstanding at December 31, 2018 1,386,088 $ 20.04 184,579 $ 15.65 Granted 2,792,438 10.59 1,009,653 10.46 Vested (447,405 ) 16.10 (134,573 ) 11.71 Forfeited (103,093 ) 13.56 — — Outstanding at March 31, 2019 3,628,028 $ 13.44 1,059,659 $ 11.21
Schedule of Share Based Payment Award Performance Stock Awards Valuation Assumptions	The following assumptions were used to estimate the fair value of PSUs granted during first three months 2019 and 2018: Three Months Ended March 31, 2019 2018 Risk-free interest rate 2.4 % 2.4 % Expected annual volatility 46 % 47 % Grant date fair value per unit $ 11.34 $ 18.51
Stock Option and SARs Activities	Information with respect to our SARs activity is summarized below. Shares Weighted Average Exercise Price Outstanding at December 31, 2018 1,104 $ 81.74 Expired (1,104 ) 81.74 Outstanding at March 31, 2019 — $ —
Performance-based PG-PSUs and RG-PSUs
Summary of Non-Vested Awards Activities	The following is a summary of our non-vested PG/RG-PSUs awards outstanding at March Number of Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2018 536,798 $ 15.61 Units granted (a) 345,202 10.32 Forfeited — — Outstanding at March 31, 2019 882,000 $ 11.70 (a)
Performance Based TSR - PSUs
Summary of Non-Vested Awards Activities	The following is a summary of our non-vested TSR – Units Weighted Average Fair Value Outstanding at December 31, 2018 1,067,886 $ 27.81 Units granted (a) 314,152 11.34 Vested and issued (b) (12,283 ) 30.47 Forfeited (79,058 ) 30.47 Outstanding at March 31, 2019 1,290,697 $ 23.62 (a) These (b) Includes 12,283 TSR-PSUs awards issued related to the 2016 performance period where the return on our common stock was in the 20 th

Capital Stock (Tables)

Capital Stock (Tables)	3 Months Ended
	Mar. 31, 2019
Equity [Abstract]
Capital Stock	The following is a schedule of changes in the number of common shares outstanding since the beginning of 2018: Three Months Year Beginning balance 249,510,022 248,129,430 Restricted stock grants 981,905 865,095 Restricted stock units vested 633,460 434,046 Performance stock units issued 12,283 73,985 Performance stock dividends 464 2,164 Treasury shares issued — 5,302 Ending balance 251,138,134 249,510,022

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2019
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Three Months Ended March 31, 2019 2018 (in thousands) Net cash provided from operating activities included: Income taxes refunded from taxing authorities $ — $ 7,518 Interest paid (54,632 ) (57,536 ) Non-cash investing and financing activities included: Increase in asset retirement costs capitalized 1,532 5,063 Increase (decrease) in accrued capital expenditures 22,764 (77,365 )

Costs Incurred for Property A_2

Costs Incurred for Property Acquisition, Exploration and Development (Tables)	3 Months Ended
	Mar. 31, 2019
Extractive Industries [Abstract]
Costs Incurred for Property Acquisition, Exploration and Development	Three Months Ended March 31, 2019 Year Ended December 31, 2018 (in thousands) Acquisitions: Acreage purchases $ 14,634 $ 62,390 Oil and gas properties — 1,683 Development 209,827 834,552 Exploration: Drilling 542 1,380 Expense 7,837 32,196 Stock-based compensation expense 373 1,921 Gas gathering facilities: Development 1,063 10,218 Subtotal 234,276 944,340 Asset retirement obligations 1,532 28,826 Total costs incurred $ 235,808 $ 973,166 (a) Includes costs incurred whether capitalized or expensed.

Basis of Presentation - Invento

Basis of Presentation - Inventory - Additional Information (Detail) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Inventory [Line Items]
Inventory and other	$ 25,128,000	$ 22,964,000
Materials and supplies inventory
Inventory [Line Items]
Inventory and other	7,400,000	8,000,000
Commodity inventory
Inventory [Line Items]
Inventory and other	$ 253,000	$ 965,000

New Accounting Standards - Addi

New Accounting Standards - Additional Information (Detail)	Jan. 01, 2019
Accounting Standards Update 2016-02
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Impact of lease accounting standard recognition to total assets and total liabilities	1.00%

New Accounting Standards - Sche

New Accounting Standards - Schedule of Impact of Adoption of New Lease Accounting Standard (Detail) - USD ($) $ in Thousands		Mar. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Operating lease right-of-use assets		$ 49,329
Accrued liabilities		399,822		$ 475,848
Operating lease liabilities – long-term		41,759
Asset retirement obligations and other liabilities		$ 319,079		$ 319,379
Accounting Standards Update 2016-02
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Operating lease right-of-use assets			$ 51,375
Accrued liabilities			(14,811)
Operating lease liabilities – long-term			(44,489)
Asset retirement obligations and other liabilities			7,925
Accounting Standards Update 2016-02 | Before Adoption
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Operating lease right-of-use assets			59,300
Accrued liabilities			(14,811)
Operating lease liabilities – long-term			(44,489)
Accounting Standards Update 2016-02 | Reclassification
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Operating lease right-of-use assets	[1]		(7,925)
Asset retirement obligations and other liabilities	[1]		$ 7,925
[1]	As of December 31, 2018, we had $7.9 million primarily related to operating lease liabilities recorded as part of purchase price accounting related to building leases acquired because we did not expect to occupy the space or receive payments from our subleases. Lease incentives related to other buildings are also included. Upon adoption of the new standards update, these leases were included as part of our adoption but the ROU asset is reduced because we do not expect to use the asset.

New Accounting Standards - Sc_2

New Accounting Standards - Schedule of Impact of Adoption of New Lease Accounting Standard (Parenthetical) (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Operating lease liabilities	$ 56,631
Accounting Standards Update 2016-02
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Operating lease liabilities		$ 7,900

Dispositions - Additional Infor

Dispositions - Additional Information (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
(Loss) gain on the sale of assets	$ (189,000)	$ 23,000
Miscellaneous Proved, Unproved Properties and Surface Acreage
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
(Loss) gain on the sale of assets	(189,000)	23,000
Proceeds from sale of oil and gas properties	$ 332,000	$ 40,000

Revenues from Contracts with _3

Revenues from Contracts with Customers - Additional Information (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2019USD ($)Stream	Mar. 31, 2018USD ($)	Dec. 31, 2018USD ($)
Disaggregation of Revenue [Line Items]
Number of revenue streams | Stream	3
Net brokered margin gain	$ 5.6	$ 3.1
Revenue Contract with Customer
Disaggregation of Revenue [Line Items]
Accounts receivable	$ 315.2		$ 438.3

Revenues from Contracts with _4

Revenues from Contracts with Customers - Disaggregation of Revenue by Identified Revenue Stream (Detail) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Disaggregation of Revenue [Line Items]
Total Revenue		$ 809,868	$ 756,608
Natural gas sales
Disaggregation of Revenue [Line Items]
Total Revenue	[1]	572,510	491,248
NGLs sales
Disaggregation of Revenue [Line Items]
Total Revenue	[2]	198,237	202,831
Oil sales
Disaggregation of Revenue [Line Items]
Total Revenue		$ 39,121	$ 62,529
[1]	Natural gas sales revenue reported above for first quarter 2019 includes $134.8 million of brokered revenues and $3.0 million of marketing revenue. First quarter 2018 includes $55.9 million of brokered revenues and $3.8 million of marketing revenue.
[2]	NGLs sales revenue reported above for the first quarter 2019 includes $424,000 of brokered revenues and first quarter 2018 includes $304,000 of brokered revenues.

Revenues from Contracts with _5

Revenues from Contracts with Customers - Disaggregation of Revenue by Identified Revenue Stream (Parenthetical) (Detail) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Disaggregation of Revenue [Line Items]
Revenues		$ 809,868	$ 756,608
Natural gas sales
Disaggregation of Revenue [Line Items]
Revenues	[1]	572,510	491,248
NGLs sales
Disaggregation of Revenue [Line Items]
Revenues	[2]	198,237	202,831
Brokered | Natural gas sales
Disaggregation of Revenue [Line Items]
Revenues		134,800	55,900
Brokered | NGLs sales
Disaggregation of Revenue [Line Items]
Revenues		424,000	304,000
Marketing | Natural gas sales
Disaggregation of Revenue [Line Items]
Revenues		$ 3,000	$ 3,800
[1]	Natural gas sales revenue reported above for first quarter 2019 includes $134.8 million of brokered revenues and $3.0 million of marketing revenue. First quarter 2018 includes $55.9 million of brokered revenues and $3.8 million of marketing revenue.
[2]	NGLs sales revenue reported above for the first quarter 2019 includes $424,000 of brokered revenues and first quarter 2018 includes $304,000 of brokered revenues.

Income Taxes - Income Tax Expen

Income Taxes - Income Tax Expense (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Components Of Income Tax Expense Benefit Continuing Operations [Abstract]
Income tax expense	$ 5,688	$ 42,676
Effective tax rate	80.00%	46.40%

Income Taxes - Summary of Diffe

Income Taxes - Summary of Differences In Effective Tax Rate and Federal Statutory Rate Due to State Income Taxes, Equity Compensation and Other Tax Items (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Tax Disclosure [Abstract]
Total income before income taxes	$ 7,107	$ 91,914
U.S. federal statutory rate	21.00%	21.00%
Total tax expense at statutory rate	$ 1,492	$ 19,302
State and local income taxes, net of federal benefit	818	4,494
Equity compensation	3,391	664
Change in valuation allowances:
State net operating loss carryforwards & other	352	15,678
Other	231	1,381
Permanent differences and other	(596)	1,157
Total (benefit) expense for income taxes	$ 5,688	$ 42,676
Effective tax rate	80.00%	46.40%

Income (Loss) Per Common Shar_2

Income (Loss) Per Common Share - Computations of Basic and Diluted Income (Loss) Per Common Share (Detail) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Earnings Per Share Reconciliation [Abstract]
Net income		$ 1,419	$ 49,238
Participating earnings	[1]	(14)	(568)
Basic net income attributed to common shareholders		1,405	48,670
Reallocation of participating earnings	[1]		2
Diluted net income attributed to common shareholders		$ 1,405	$ 48,672
Net income per common share:
Basic		$ 0.01	$ 0.20
Diluted		$ 0.01	$ 0.20
[1]	Restricted Stock Awards represent participating securities because they participate in nonforfeitable dividends or distributions with common equity owners. Income allocable to participating securities represents the distributed and undistributed earnings attributable to the participating securities. Participating securities, however, do not participate in undistributed net losses

Income (Loss) Per Common Shar_3

Income (Loss) Per Common Share - Basic Weighted Average Common Shares Outstanding to Diluted Weighted Average Common Shares Outstanding (Detail) - shares shares in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Weighted Average Number Of Shares Outstanding [Abstract]
Weighted average common shares outstanding -basic	247,776	245,709
Effect of dilutive securities:
Director and employee restricted stock and performance based equity awards	1,378	885
Weighted average common shares outstanding – diluted	249,154	246,594

Income (Loss) Per Common Shar_4

Income (Loss) Per Common Share - Additional Information (Detail) - shares shares in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Restricted Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Stock excluded from earning per share calculation	2.5	2.9
Equity Grants
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Stock excluded from earning per share calculation	1.6	1.5

Leases - Additional Information

Leases - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019
Lessee Lease Description [Line Items]
Lease, practical expedients, package [true false]	true
Office Space
Lessee Lease Description [Line Items]
Lessee, operating sublease, option to terminate	All of our subleases have terms that end in 2020 or 2022. The sublease agreements are non-cancelable through the end of the term and both parties have substantive rights to terminate the lease when the term is complete.
Field Equipment
Lessee Lease Description [Line Items]
Lessee, operating lease, option to extend, description	Our compressor and cooler arrangements are typically structured with a non-cancelable primary term of one to two years and continue thereafter on a month-to-month basis subject to termination by either party with thirty days notice.
Lessee operating lease notice period for renewal	30 days
Vehicle Fleet
Lessee Lease Description [Line Items]
Lessee operating lease notice period for renewal	3 years
Lessee operating lease contract of team description	Our vehicle agreements are non-cancelable for a minimum of one year and a maximum term of four to eight years depending on the type of vehicle. However, we have assumed a term of three years based on the period covered by options to terminate that we are reasonably certain to exercise.
Maximum
Lessee Lease Description [Line Items]
Short-term leases initial term	1 year
Lessee, operating lease, contract term	1 month
Maximum | Office Space
Lessee Lease Description [Line Items]
Lessee, operating lease, contract term	15 years
Maximum | Field Equipment
Lessee Lease Description [Line Items]
Lessee, operating lease, contract term	2 years
Maximum | Vehicle Fleet
Lessee Lease Description [Line Items]
Lessee, operating lease, non-cancelable maximum contract term, depending on type of vehicle	8 years
Minimum | Office Space
Lessee Lease Description [Line Items]
Lessee, operating lease, contract term	1 year
Minimum | Field Equipment
Lessee Lease Description [Line Items]
Lessee, operating lease, contract term	1 year
Minimum | Vehicle Fleet
Lessee Lease Description [Line Items]
Lessee, operating lease, contract term	1 year
Lessee, operating lease, non-cancelable maximum contract term, depending on type of vehicle	4 years

Leases - Schedule of Components

Leases - Schedule of Components of Lease Expense (Detail) $ in Thousands	3 Months Ended
	Mar. 31, 2019USD ($)
Lessee Lease Description [Line Items]
Operating lease cost	$ 3,080
Variable lease expense	1,151	[1]
Short-term lease expense / costs	92	[2]
Sublease income	(875)
Total lease expense	3,448
Natural Gas and Oil Properties
Lessee Lease Description [Line Items]
Short-term lease expense / costs	$ 9,164	[3]
[1]	Variable lease payments that are not dependent on an index or rate are not included in the lease liability or ROU assets.
[2]	Short-term lease expense represents expense related to leases with a contract term of one year or less.
[3]	These short-term lease costs are related to leases with a contract term of one year or less and the majority of which are related to drilling rigs and are capitalized as part of natural gas and oil properties on our balance sheets

Leases - Supplemental Cash Flow

Leases - Supplemental Cash Flow Information Related to Operating Leases (Detail) $ in Thousands	3 Months Ended
	Mar. 31, 2019USD ($)
Leases [Abstract]
Cash paid for amounts included in the measurement of lease liabilities	$ 3,003
ROU assets added in exchange for lease obligations (since adoption)	$ 187

Leases - Supplemental Balance S

Leases - Supplemental Balance Sheet Information Related to Operating Leases (Detail) $ in Thousands	Mar. 31, 2019USD ($)
Leases [Abstract]
Operating lease right-of-use assets	$ 49,329
Accrued liabilities – current	(14,872)
Operating lease liabilities – long-term	$ (41,759)

Leases - Schedule of Weighted A

Leases - Schedule of Weighted Average Remaining Lease Term and Weighted Average Discount Rate for Operating Leases (Detail)	Mar. 31, 2019
Leases [Abstract]
Weighted Average Remaining Lease Term	6 years 4 months 24 days
Weighted Average Discount Rate	6.10%

Leases - Schedule of Lease Liab

Leases - Schedule of Lease Liabilities with Enforceable Contract Terms are Greater Than One year Mature (Detail) $ in Thousands	Mar. 31, 2019USD ($)
Leases [Abstract]
Remainder of 2019	$ 14,872
2020	12,491
2021	9,618
2022	6,551
2023	6,479
Thereafter	20,113
Total lease payments	70,124
Less imputed interest	(13,493)
Operating lease liabilities	$ 56,631

Capitalized Costs and Accumul_3

Capitalized Costs and Accumulated Depreciation, Depletion and Amortization (Detail) - USD ($) $ in Thousands		Mar. 31, 2019	Dec. 31, 2018
Natural gas and oil properties:
Properties subject to depletion	[1]	$ 11,193,577	$ 10,974,929
Unproved properties	[1]	2,106,568	2,110,277
Total	[1]	13,300,145	13,085,206
Accumulated depletion and depreciation	[1]	(4,194,876)	(4,062,021)
Natural gas and oil properties, successful efforts method, net	[1]	$ 9,105,269	$ 9,023,185
[1]

Indebtedness - Additional Infor

Indebtedness - Additional Information (Detail) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Debt Disclosure [Abstract]
Interest capitalized during the period	$ 0	$ 0

Indebtedness - Debt Outstanding

Indebtedness - Debt Outstanding (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Senior notes	$ 2,877,349	$ 2,877,349
Senior subordinated notes	48,980	48,980
Total debt	3,821,329	3,869,329
Unamortized premium	4,408	4,741
Unamortized debt issuance costs	(35,088)	(37,209)
Total debt net of debt issuance costs	3,790,649	3,836,861
4.0% Bank Debt | Notes Payable to Banks
Debt Instrument [Line Items]
Bank debt (4.0%)	895,000	943,000
4.875% Senior Notes Due 2025
Debt Instrument [Line Items]
Senior notes	750,000	750,000
5.00% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	741,531	741,531
5.00% Senior Notes Due 2022
Debt Instrument [Line Items]
Senior notes	580,032	580,032
5.75% Senior Notes Due 2021
Debt Instrument [Line Items]
Senior notes	475,952	475,952
5.875% Senior Notes Due 2022
Debt Instrument [Line Items]
Senior notes	329,244	329,244
Other Senior Notes Due 2022
Debt Instrument [Line Items]
Senior notes	590	590
5.00% Senior Subordinated Notes Due 2023
Debt Instrument [Line Items]
Senior subordinated notes	7,712	7,712
5.00% Senior Subordinated Notes Due 2022
Debt Instrument [Line Items]
Senior subordinated notes	19,054	19,054
5.75% Senior Subordinated Notes Due 2021
Debt Instrument [Line Items]
Senior subordinated notes	$ 22,214	$ 22,214

Indebtedness - Debt Outstandi_2

Indebtedness - Debt Outstanding (Parenthetical) (Detail)	Mar. 31, 2019	Dec. 31, 2018
4.875% Senior Notes Due 2025
Debt Instrument [Line Items]
Interest rate on notes	4.875%	4.875%
5.00% Senior Notes Due 2023
Debt Instrument [Line Items]
Interest rate on notes	5.00%	5.00%
5.00% Senior Notes Due 2022
Debt Instrument [Line Items]
Interest rate on notes	5.00%	5.00%
5.75% Senior Notes Due 2021
Debt Instrument [Line Items]
Interest rate on notes	5.75%	5.75%
5.875% Senior Notes Due 2022
Debt Instrument [Line Items]
Interest rate on notes	5.875%	5.875%
5.00% Senior Subordinated Notes Due 2023
Debt Instrument [Line Items]
Interest rate on notes	5.00%	5.00%
5.00% Senior Subordinated Notes Due 2022
Debt Instrument [Line Items]
Interest rate on notes	5.00%	5.00%
5.75% Senior Subordinated Notes Due 2021
Debt Instrument [Line Items]
Interest rate on notes	5.75%	5.75%
Notes Payable to Banks | 4.0% Bank Debt
Debt Instrument [Line Items]
Bank debt percentage	4.00%	4.00%

Indebtedness - Bank Debt - Addi

Indebtedness - Bank Debt - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019USD ($)CommercialBank	Mar. 31, 2018	Dec. 31, 2018USD ($)	Mar. 27, 2017USD ($)
Debt Instrument [Line Items]
Bank debt	$ 884,652,000		$ 932,018,000
Bank Credit Facility
Debt Instrument [Line Items]
Bank Credit facility, maximum amount	4,000,000,000
Bank Credit facility, borrowing base	$ 3,000,000,000			$ 3,000,000,000
Percentage holding of commercial banks, Maximum	5.80%
Number of commercial banks included in current bank group | CommercialBank	27
Maturity date of loan	Apr. 13, 2023
Bank commitments	$ 2,000,000,000			$ 2,000,000,000
Bank debt	895,000,000
Undrawn letters of credit	279,800,000
Borrowing capacity available under the commitment amount	$ 825,200,000
Weighted average interest rate on the bank credit facility	4.00%	3.40%
Annual rate of commitment fee paid on the undrawn balance	0.30%
Bank Credit Facility | Alternate Base Rate
Debt Instrument [Line Items]
Interest rate margin	0.50%
Bank Credit Facility | LIBOR Rate
Debt Instrument [Line Items]
Interest rate margin	1.50%
Bank Credit Facility | Minimum
Debt Instrument [Line Items]
Annual rate of commitment fee paid on the undrawn balance	0.30%
Bank Credit Facility | Minimum | Credit Facility
Debt Instrument [Line Items]
Annual rate of commitment fee paid on the undrawn balance	0.15%
Bank Credit Facility | Minimum | Alternate Base Rate
Debt Instrument [Line Items]
Base rate on debt	0.25%
Bank Credit Facility | Minimum | Alternate Base Rate | Credit Facility
Debt Instrument [Line Items]
Base rate on debt	0.125%
Bank Credit Facility | Minimum | LIBOR Rate
Debt Instrument [Line Items]
Base rate on debt	1.25%
Bank Credit Facility | Minimum | LIBOR Rate | Credit Facility
Debt Instrument [Line Items]
Base rate on debt	1.125%
Bank Credit Facility | Maximum
Debt Instrument [Line Items]
Annual rate of commitment fee paid on the undrawn balance	0.375%
Bank Credit Facility | Maximum | Credit Facility
Debt Instrument [Line Items]
Annual rate of commitment fee paid on the undrawn balance	0.30%
Bank Credit Facility | Maximum | Alternate Base Rate
Debt Instrument [Line Items]
Base rate on debt	1.25%
Bank Credit Facility | Maximum | Alternate Base Rate | Credit Facility
Debt Instrument [Line Items]
Base rate on debt	0.75%
Bank Credit Facility | Maximum | LIBOR Rate
Debt Instrument [Line Items]
Base rate on debt	2.25%
Bank Credit Facility | Maximum | LIBOR Rate | Credit Facility
Debt Instrument [Line Items]
Base rate on debt	1.75%

Indebtedness - Senior Subordina

Indebtedness - Senior Subordinated Notes - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019
Subordinated Debt
Debt Instrument [Line Items]
Maximum redemption price of notes as percentage of principal amount	101.00%

Indebtedness - Guarantees and D

Indebtedness - Guarantees and Debt Covenants - Additional Information (Detail) - Bank Credit Facility	3 Months Ended
	Mar. 31, 2019
Debt Instrument [Line Items]
Debt instrument, Covenant compliance	Our bank credit facility contains negative covenants that limit our ability, among other things, to pay cash dividends, incur additional indebtedness, sell assets, enter into certain hedging contracts, change the nature of our business or operations, merge, consolidate or make certain investments. In addition, we are required to maintain a ratio of EBITDAX (as defined in the bank credit facility agreement) to cash interest expense of equal to or greater than 2.5 and a current ratio (as defined in the bank credit facility agreement) of no less than 1.0. In addition, the ratio of the present value of proved reserves (as defined in the credit agreement) to total debt must be equal to or greater than 1.5 until Range has two investment grade ratings. We were in compliance with applicable covenants under the bank credit facility at March 31, 2019.
Minimum
Debt Instrument [Line Items]
Ratio of debt to EBITDAX	250.00%
Current ratio	100.00%
Present value of proved reserves to total debt	150.00%

Asset Retirement Obligations -

Asset Retirement Obligations - Asset Retirement Obligations (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation [Abstract]
Beginning of period	$ 312,754
Liabilities incurred	1,719
Liabilities settled	(896)
Accretion expense	4,217
Change in estimate	(187)
End of period	317,607
Less current portion	(5,485)	$ (5,485)
Long-term asset retirement obligations	$ 312,122

Derivative Activities - Additio

Derivative Activities - Additional Information (Detail)	Mar. 31, 2019USD ($)t_per_MMMBTUbbl
Derivatives Excluding Basis Swaps and Freight Swaps
Derivative [Line Items]
Derivative assets liabilities at fair value net	$ 3,000,000
Commodity | Natural Gas Basis Swaps
Derivative [Line Items]
Derivative assets liabilities at fair value net	$ (3,400,000)
Volume Hedged | MMBTU	69,775,000
Commodity | Propane Spread Swaps
Derivative [Line Items]
Derivative assets liabilities at fair value net	$ (809,000)
Volume Hedged | bbl	1,875,000
Commodity | Swaps | Freight | Level 2
Derivative [Line Items]
Derivative assets liabilities at fair value net	$ (103,000)
Volume Hedged | t_per_M	10,000

Derivative Activities - Derivat

Derivative Activities - Derivative Volumes Hedged and Average Hedge Prices (Detail)	Mar. 31, 2019MMBTU / dbbl / d$ / MMBTU$ / bbl$ / gal
2019 Commodity Contract | Swaps | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	1,246,873
Weighted Average Hedge Price | $ / MMBTU	2.80
2019 Commodity Contract | Swaps | Crude Oil
Derivative [Line Items]
Volume Hedged | bbl / d	7,472
Weighted Average Hedge Price | $ / bbl	55.47
2019 Commodity Contract | Swaps | NGLs (C5-Natural Gasoline)
Derivative [Line Items]
Volume Hedged | bbl / d	2,658
Weighted Average Hedge Price | $ / gal	1.39
2019 Commodity Contract | Swaptions | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	150,000
Weighted Average Hedge Price | $ / MMBTU	2.81	[1]
2019 Commodity Contract | Collars | Crude Oil
Derivative [Line Items]
Volume Hedged | bbl / d	1,000
2019 Commodity Contract | Collars | Crude Oil | Minimum
Derivative [Line Items]
Weighted Average Hedge Price | $ / gal	63
2019 Commodity Contract | Collars | Crude Oil | Maximum
Derivative [Line Items]
Weighted Average Hedge Price | $ / gal	73.02
2020 Commodity Contract | Swaps | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	190,000
Weighted Average Hedge Price | $ / MMBTU	2.75
2020 Commodity Contract | Swaps | Crude Oil
Derivative [Line Items]
Volume Hedged | bbl / d	2,557
Weighted Average Hedge Price | $ / bbl	60.53
2020 Commodity Contract | Swaptions | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	140,000
Weighted Average Hedge Price | $ / MMBTU	2.78	[1]
November-December 2019 Commodity Contract | Swaptions | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	20,000
Weighted Average Hedge Price | $ / MMBTU	3.20	[1]
January-March 2020 Commodity Contract | Swaptions | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	20,000
Weighted Average Hedge Price | $ / MMBTU	3.20	[1]
April-June 2019 Commodity Contract | Swaps | NGLs (C2-Ethane)
Derivative [Line Items]
Volume Hedged | bbl / d	500
Weighted Average Hedge Price | $ / gal	0.35
April-June 2019 Commodity Contract | Swaps | NGLs (C3-Propane)
Derivative [Line Items]
Volume Hedged | bbl / d	8,500
Weighted Average Hedge Price | $ / gal	0.88
April-June 2019 Commodity Contract | Collars | NGLs (C3-Propane)
Derivative [Line Items]
Volume Hedged | bbl / d	1,000
April-June 2019 Commodity Contract | Collars | NGLs (C3-Propane) | Minimum
Derivative [Line Items]
Weighted Average Hedge Price | $ / gal	0.90
April-June 2019 Commodity Contract | Collars | NGLs (C3-Propane) | Maximum
Derivative [Line Items]
Weighted Average Hedge Price | $ / gal	0.96
[1]	Contains a combined derivative instrument consisting of a fixed price swap and a sold option to extend or double the volumes. We have swaps in place for 2019 for 150,000 Mmbtu/day on which the counterparty can elect to extend the contract through December 2020 at a weighted average price of $2.81. In addition, we have swaps in place for November and December 2019 where, if the counterparty elects to double the volume, we would have additional swaps in place for 20,000 Mmbtu/day at a weighted average price of $3.20. In 2020, if the counterparty elects to double the volume, we would have additional swaps in place for 140,000 Mmbtu/day at a weighted average price of $2.78. In addition, for January through March 2020, we have additional swaps in place, if the counterparty elects to double the volume, we would have an additional 20,000 Mmbtu/day at a weighted average price of $3.20.

Derivative Activities - Deriv_2

Derivative Activities - Derivative Volumes Hedged and Average Hedge Prices (Parenthetical) (Detail) - Swaps - Natural Gas	Mar. 31, 2019MMBTU / d$ / MMBTU
November-December 2019 Commodity Contract | Counterparty Can Elect to Double The Volume
Derivative [Line Items]
Volume Hedged | MMBTU / d	20,000
Weighted average price of hedge | $ / MMBTU	3.20
2019 Commodity Contract
Derivative [Line Items]
Volume Hedged | MMBTU / d	1,246,873
Weighted average price of hedge | $ / MMBTU	2.80
2019 Commodity Contract | Counterparty Can Elect to Extend Contract
Derivative [Line Items]
Volume Hedged | MMBTU / d	150,000
Weighted average price of hedge | $ / MMBTU	2.81
2020 Commodity Contract
Derivative [Line Items]
Volume Hedged | MMBTU / d	190,000
Weighted average price of hedge | $ / MMBTU	2.75
2020 Commodity Contract | Counterparty Can Elect to Double The Volume
Derivative [Line Items]
Volume Hedged | MMBTU / d	140,000
Weighted average price of hedge | $ / MMBTU	2.78
January-March 2020 Commodity Contract | Counterparty Can Elect to Double The Volume
Derivative [Line Items]
Volume Hedged | MMBTU / d	20,000
Weighted average price of hedge | $ / MMBTU	3.20

Derivative Activities - Schedul

Derivative Activities - Schedule of Additional Information Related to Master Netting Arrangements with Derivative Counterparties (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Derivative [Line Items]
Gross Amounts of Recognized Assets	$ 44,090	$ 122,624
Gross Amounts Offset in the Balance Sheet	(29,538)	(29,829)
Net Amounts of Assets Presented in the Balance Sheet	14,552	92,795
Gross Amounts of Recognized (Liabilities)	(45,466)	(37,435)
Gross Amounts Offset in the Balance Sheet	29,538	29,829
Net Amounts of (Liabilities) Presented in the Balance Sheet	(15,928)	(7,606)
Commodity | Swaps | Natural Gas
Derivative [Line Items]
Gross Amounts of Recognized Assets	15,883	20,834
Gross Amounts Offset in the Balance Sheet	(7,441)	(11,748)
Net Amounts of Assets Presented in the Balance Sheet	8,442	9,086
Gross Amounts of Recognized (Liabilities)	(13,030)	(18,332)
Gross Amounts Offset in the Balance Sheet	7,441	11,748
Net Amounts of (Liabilities) Presented in the Balance Sheet	(5,589)	(6,584)
Commodity | Swaps | Crude Oil
Derivative [Line Items]
Gross Amounts of Recognized Assets	2,871	26,481
Gross Amounts Offset in the Balance Sheet	(4,648)	(651)
Net Amounts of Assets Presented in the Balance Sheet	(1,777)	25,830
Gross Amounts of Recognized (Liabilities)	(11,197)	0
Gross Amounts Offset in the Balance Sheet	4,648	651
Net Amounts of (Liabilities) Presented in the Balance Sheet	(6,549)	651
Commodity | Swaps | NGLs (C2-Ethane)
Derivative [Line Items]
Gross Amounts of Recognized Assets	216
Gross Amounts Offset in the Balance Sheet	(216)
Net Amounts of Assets Presented in the Balance Sheet	0
Gross Amounts of Recognized (Liabilities)	0
Gross Amounts Offset in the Balance Sheet	216
Net Amounts of (Liabilities) Presented in the Balance Sheet	216
Commodity | Swaps | NGLs (C3-Propane)
Derivative [Line Items]
Gross Amounts of Recognized Assets	7,471	18,719
Gross Amounts Offset in the Balance Sheet	(3,108)	(589)
Net Amounts of Assets Presented in the Balance Sheet	4,363	18,130
Gross Amounts of Recognized (Liabilities)	0	0
Gross Amounts Offset in the Balance Sheet	3,108	589
Net Amounts of (Liabilities) Presented in the Balance Sheet	3,108	589
Commodity | Swaps | NGLs (C5-Natural Gasoline)
Derivative [Line Items]
Gross Amounts of Recognized Assets	4,643	17,371
Gross Amounts Offset in the Balance Sheet	(3,474)	0
Net Amounts of Assets Presented in the Balance Sheet	1,169	17,371
Gross Amounts of Recognized (Liabilities)	(37)
Gross Amounts Offset in the Balance Sheet	3,474
Net Amounts of (Liabilities) Presented in the Balance Sheet	3,437
Commodity | Swaps | Freight
Derivative [Line Items]
Gross Amounts of Recognized Assets	37	0
Gross Amounts Offset in the Balance Sheet	(37)	(561)
Net Amounts of Assets Presented in the Balance Sheet	0	(561)
Gross Amounts of Recognized (Liabilities)	(140)	(561)
Gross Amounts Offset in the Balance Sheet	37	561
Net Amounts of (Liabilities) Presented in the Balance Sheet	(103)	0
Commodity | Swaps | NGLs (NC4-Normal Butane)
Derivative [Line Items]
Gross Amounts of Recognized Assets		4,084
Gross Amounts Offset in the Balance Sheet		0
Net Amounts of Assets Presented in the Balance Sheet		4,084
Commodity | Swaptions | Natural Gas
Derivative [Line Items]
Gross Amounts of Recognized Assets	6,487	5,200
Gross Amounts Offset in the Balance Sheet	(4,634)	(3,883)
Net Amounts of Assets Presented in the Balance Sheet	1,853	1,317
Gross Amounts of Recognized (Liabilities)	(12,550)	(7,972)
Gross Amounts Offset in the Balance Sheet	4,634	3,883
Net Amounts of (Liabilities) Presented in the Balance Sheet	(7,916)	(4,089)
Commodity | Basis Swaps | Natural Gas
Derivative [Line Items]
Gross Amounts of Recognized Assets	838	6,468
Gross Amounts Offset in the Balance Sheet	(838)	(2,822)
Net Amounts of Assets Presented in the Balance Sheet	0	3,646
Gross Amounts of Recognized (Liabilities)	(4,278)	(1,702)
Gross Amounts Offset in the Balance Sheet	838	2,822
Net Amounts of (Liabilities) Presented in the Balance Sheet	(3,440)	1,120
Commodity | Collars | Crude Oil
Derivative [Line Items]
Gross Amounts of Recognized Assets	1,252	5,945
Gross Amounts Offset in the Balance Sheet	(750)	(707)
Net Amounts of Assets Presented in the Balance Sheet	502	5,238
Gross Amounts of Recognized (Liabilities)	0	0
Gross Amounts Offset in the Balance Sheet	750	707
Net Amounts of (Liabilities) Presented in the Balance Sheet	750	707
Commodity | Collars | NGLs (C3-Propane)
Derivative [Line Items]
Gross Amounts of Recognized Assets	967	8,538
Gross Amounts Offset in the Balance Sheet	(967)	0
Net Amounts of Assets Presented in the Balance Sheet	0	8,538
Gross Amounts of Recognized (Liabilities)	0
Gross Amounts Offset in the Balance Sheet	967
Net Amounts of (Liabilities) Presented in the Balance Sheet	967
Commodity | Spread Swaps | NGLs (C3-Propane)
Derivative [Line Items]
Gross Amounts of Recognized Assets	3,425	8,984
Gross Amounts Offset in the Balance Sheet	(3,425)	(8,868)
Net Amounts of Assets Presented in the Balance Sheet	0	116
Gross Amounts of Recognized (Liabilities)	(4,234)	(8,868)
Gross Amounts Offset in the Balance Sheet	3,425	8,868
Net Amounts of (Liabilities) Presented in the Balance Sheet	$ (809)	$ 0

Derivative Activities - Effects

Derivative Activities - Effects of Derivatives on Consolidated Statements of Operations (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Derivative [Line Items]
Derivative Fair Value (Loss) Income	$ (61,731)	$ (14,009)
Swaptions
Derivative [Line Items]
Derivative Fair Value (Loss) Income	(3,291)	3,599
Collars
Derivative [Line Items]
Derivative Fair Value (Loss) Income	(4,524)	(77)
Calls
Derivative [Line Items]
Derivative Fair Value (Loss) Income	0	177
Basis Swaps
Derivative [Line Items]
Derivative Fair Value (Loss) Income	3,415	(864)
Commodity | Swaps
Derivative [Line Items]
Derivative Fair Value (Loss) Income	(57,418)	(16,536)
Freight | Commodity | Swaps
Derivative [Line Items]
Derivative Fair Value (Loss) Income	$ 87	$ (308)

Fair Value Measurements - Fair

Fair Value Measurements - Fair Value Hierarchy Table for Assets and Liabilities Measured at Fair Value (Detail) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Trading securities held in the deferred compensation plans	$ 63,774	$ 57,293
Fair Value, Inputs, Level 1
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Trading securities held in the deferred compensation plans	63,774	57,293
Swaps
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	6,820	69,156
Swaps | Freight
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(103)	(561)
Swaps | Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	6,820	69,156
Swaps | Level 2 | Freight
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(103)	(561)
Collars
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	2,219	14,483
Collars | Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	1,252	5,945
Collars | Fair Value, Inputs, Level 3
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	967	8,538
Basis Swaps
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(4,249)	4,883
Basis Swaps | Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(4,249)	4,883
Swaptions
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(6,063)	(2,772)
Swaptions | Fair Value, Inputs, Level 3
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	$ (6,063)	$ (2,772)

Fair Value Measurements - Recon

Fair Value Measurements - Reconciliation of the Beginning and Ending Balances for Derivative Instruments Classified as Level 3 in the Fair Value Hierarchy (Detail) - Level 3 $ in Thousands	3 Months Ended
	Mar. 31, 2019USD ($)
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Balance at December 31, 2018	$ 5,766
Total losses included in earnings	(3,442)
Settlements	(7,420)
Balance at March 31, 2019	$ (5,096)

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019USD ($)Counterparty	Mar. 31, 2018USD ($)	Dec. 31, 2018USD ($)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Interest and dividends	$ 179,000	$ 168,000
Mark-to-market gain (loss)	5,100,000	(7,500,000)
Allowance for doubtful accounts on accounts receivable	$ 6,118,000		$ 6,118,000
Number of derivative counterparties | Counterparty	20
Number of counter parties that are not participants in bank credit facility | Counterparty	4
Counterparties not in Facility
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Net derivative liability	$ (3,900,000)
Natural Gas and Oil Properties | Fair Value, Measurements, Nonrecurring
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Impairment on natural gas and oil properties	$ 0
Oklahoma
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Impairment on natural gas and oil properties		7,300,000
Oklahoma | Natural Gas and Oil Properties | Fair Value, Measurements, Nonrecurring
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair value		$ 32,500,000

Fair Value Measurements - Carry

Fair Value Measurements - Carrying Amounts and Fair Values of Financial Instruments (Detail) - USD ($) $ in Thousands		Mar. 31, 2019	Dec. 31, 2018
Carrying Value
Assets:
Commodity swaps, options and basis swaps		$ 14,552	$ 92,795
Marketable securities	[1]	63,774	57,293
(Liabilities):
Commodity swaps, options and basis swaps		(15,928)	(7,606)
Bank credit facility	[2]	(895,000)	(943,000)
Deferred compensation plan	[3]	(88,334)	(80,092)
Fair Value
Assets:
Commodity swaps, options and basis swaps		14,552	92,795
Marketable securities	[1]	63,774	57,293
(Liabilities):
Commodity swaps, options and basis swaps		(15,928)	(7,606)
Bank credit facility	[2]	(895,000)	(943,000)
Deferred compensation plan	[3]	(88,334)	(80,092)
5.75% Senior Notes Due 2021 | Carrying Value
(Liabilities):
Senior notes	[2]	(475,952)	(475,952)
5.75% Senior Notes Due 2021 | Fair Value
(Liabilities):
Senior notes	[2]	(486,042)	(455,972)
5.00% Senior Notes Due 2022 | Carrying Value
(Liabilities):
Senior notes	[2]	(580,032)	(580,032)
5.00% Senior Notes Due 2022 | Fair Value
(Liabilities):
Senior notes	[2]	(574,139)	(519,343)
5.875% Senior Notes Due 2022 | Carrying Value
(Liabilities):
Senior notes	[2]	(329,244)	(329,244)
5.875% Senior Notes Due 2022 | Fair Value
(Liabilities):
Senior notes	[2]	(333,020)	(305,989)
Other Senior Notes Due 2022 | Carrying Value
(Liabilities):
Senior notes	[2]	(590)	(590)
Other Senior Notes Due 2022 | Fair Value
(Liabilities):
Senior notes	[2]	(593)	(581)
5.00% Senior Notes Due 2023 | Carrying Value
(Liabilities):
Senior notes	[2]	(741,531)	(741,531)
5.00% Senior Notes Due 2023 | Fair Value
(Liabilities):
Senior notes	[2]	(718,996)	(654,683)
4.875% Senior Notes Due 2025 | Carrying Value
(Liabilities):
Senior notes	[2]	(750,000)	(750,000)
4.875% Senior Notes Due 2025 | Fair Value
(Liabilities):
Senior notes	[2]	(696,983)	(616,313)
5.75% Senior Subordinated Notes Due 2021 | Carrying Value
(Liabilities):
Subordinated debt	[2]	(22,214)	(22,214)
5.75% Senior Subordinated Notes Due 2021 | Fair Value
(Liabilities):
Subordinated debt	[2]	(22,539)	(21,638)
5.00% Senior Subordinated Notes Due 2022 | Carrying Value
(Liabilities):
Subordinated debt	[2]	(19,054)	(19,054)
5.00% Senior Subordinated Notes Due 2022 | Fair Value
(Liabilities):
Subordinated debt	[2]	(18,811)	(17,072)
5.00% Senior Subordinated Notes Due 2023 | Carrying Value
(Liabilities):
Subordinated debt	[2]	(7,712)	(7,712)
5.00% Senior Subordinated Notes Due 2023 | Fair Value
(Liabilities):
Subordinated debt	[2]	$ (7,085)	$ (6,690)
[1]	Marketable securities, which are held in our deferred compensation plans, are actively traded on major exchanges.
[2]	The book value of our bank debt approximates fair value because of its floating rate structure. The fair value of our senior notes and our senior subordinated notes is based on end of period market quotes which are Level 2 inputs.
[3]	The fair value of our deferred compensation plan is updated at the closing price on the balance sheet date which is a Level 1 input.

Fair Value Measurements - Car_2

Fair Value Measurements - Carrying Amounts and Fair Values of Financial Instruments (Parenthetical) (Detail)	Mar. 31, 2019	Dec. 31, 2018
5.75% Senior Notes Due 2021
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.75%	5.75%
5.00% Senior Notes Due 2022
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.00%	5.00%
5.875% Senior Notes Due 2022
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.875%	5.875%
5.00% Senior Notes Due 2023
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.00%	5.00%
4.875% Senior Notes Due 2025
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	4.875%	4.875%
5.75% Senior Subordinated Notes Due 2021
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.75%	5.75%
5.00% Senior Subordinated Notes Due 2022
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.00%	5.00%
5.00% Senior Subordinated Notes Due 2023
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.00%	5.00%

Stock-based Compensation Plan_2

Stock-based Compensation Plans - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019Plans
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Active equity-based stock plans	1

Stock-based Compensation Plan_3

Stock-based Compensation Plans - Allocation of Stock-Based Compensation by Functional Category (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	$ 10,164	$ 25,538
Direct Operating Expense
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	591	591
Brokered Natural Gas and Marketing Expense
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	385	285
Exploration Expense
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	373	751
General and Administrative Expense
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	$ 8,815	$ 23,911

Stock-based Compensation Plan_4

Stock-based Compensation Plans - Additional Information 1 (Detail)	3 Months Ended
	Mar. 31, 2019Awardshares	Dec. 31, 2018shares
Restricted Stock Equity Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	3 years
Performance Share
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of awards available for grant	3
Performance Share | Common Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of share value each unit represents at grant date | shares	1
Performance-based PG-PSUs and RG-PSUs
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	3 years
Number of awards available for grant	2
Performance-based PG-PSUs and RG-PSUs | Minimum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Potential payout of shares granted	0.00%
Performance-based PG-PSUs and RG-PSUs | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Potential payout of shares granted	200.00%
Performance Based TSR - PSUs
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	3 years
Number of awards available for grant	1
Performance Based TSR - PSUs | Minimum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Potential payout of shares granted	0.00%
Performance Based TSR - PSUs | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Potential payout of shares granted	200.00%
Stock Appreciation Rights (SARs)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of stock option outstanding | shares	0	1,104

Stock-based Compensation Plan_5

Stock-based Compensation Plans - Additional Information 2 (Detail) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Restricted Stock Equity Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	2,792,438	1,800,000
Granted, weighted average grant date fair value	$ 10.59	$ 17
Vesting period	3 years
Stock-based compensation expense	$ 7.1	$ 6.5
Restricted Stock Liability Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	1,009,653
Granted, weighted average grant date fair value	$ 10.46
Stock-based compensation expense	$ 1	$ 8.1
Restricted Stock Liability Awards | Employees
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	1,000,000	674,000
Granted, weighted average grant date fair value	$ 10.46	$ 15.21
Vesting period	3 years	3 years

Stock-based Compensation Plan_6

Stock-based Compensation Plans - Restricted Stock and Restricted Stock Units Outstanding (Detail) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Restricted Stock Equity Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Beginning Balance	1,386,088
Granted	2,792,438	1,800,000
Vested	(447,405)
Forfeited	(103,093)
Outstanding, Ending Balance	3,628,028
Outstanding, Beginning Balance, weighted average grant date fair value	$ 20.04
Granted, weighted average grant date fair value	10.59	$ 17
Vested, weighted average grant date fair value	16.10
Forfeited, weighted average grant date fair value	13.56
Outstanding, Ending Balance, weighted average grant date fair value	$ 13.44
Restricted Stock Liability Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Beginning Balance	184,579
Granted	1,009,653
Vested	(134,573)
Outstanding, Ending Balance	1,059,659
Outstanding, Beginning Balance, weighted average grant date fair value	$ 15.65
Granted, weighted average grant date fair value	10.46
Vested, weighted average grant date fair value	11.71
Outstanding, Ending Balance, weighted average grant date fair value	$ 11.21

Stock-based Compensation Plan_7

Stock-based Compensation Plans - Additional Information 3 (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Performance-based PG-PSUs and RG-PSUs
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	3 years
Stock-based compensation expense	$ 1,600,000	$ 5,300,000
Performance Based TSR - PSUs
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	3 years
Stock-based compensation expense	$ 443,000	$ 5,400,000

Stock-based Compensation Plan_8

Stock-based Compensation Plans - PG/RG-PSUs Activities (Detail) - Performance-based PG-PSUs and RG-PSUs	3 Months Ended
	Mar. 31, 2019$ / sharesshares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Beginning Balance | shares	536,798
Granted | shares	345,202	[1]
Outstanding, Ending Balance | shares	882,000
Outstanding, Beginning Balance, weighted average grant date fair value | $ / shares	$ 15.61
Granted, weighted average grant date fair value | $ / shares	10.32	[1]
Outstanding, Ending Balance, weighted average grant date fair value | $ / shares	$ 11.70
[1]	Amounts granted reflect the number of performance units granted; however, the actual payout of shares will be between zero and 200% depending on achievement of specifically identified performance targets

Stock-based Compensation Plan_9

Stock-based Compensation Plans - PG/RG-PSUs Activities (Parenthetical) (Detail) - Performance-based PG-PSUs and RG-PSUs	3 Months Ended
	Mar. 31, 2019
Minimum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Potential payout of shares granted	0.00%
Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Potential payout of shares granted	200.00%

Stock-based Compensation Pla_10

Stock-based Compensation Plans - Valuation Assumptions for Grant Date Fair Value of Performance Awards (Detail) - Performance Shares - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk-free interest rate	2.40%	2.40%
Expected annual volatility	46.00%	47.00%
Grant date fair value per unit	$ 11.34	$ 18.51

Stock-based Compensation Pla_11

Stock-based Compensation Plans - TSR - PSUs Activities (Detail) - Performance Based TSR - PSUs	3 Months Ended
	Mar. 31, 2019$ / sharesshares
Summary of Performance Share Unit Awards outstanding, Number of Units
Outstanding, Beginning Balance | shares	1,067,886
Granted | shares	314,152	[1]
Vested and issued | shares	(12,283)	[2]
Forfeited | shares	(79,058)
Outstanding, Ending Balance | shares	1,290,697
Summary of Performance Share Unit Awards outstanding, Weighted Average Grant Date Fair Value
Outstanding, Beginning Balance, weighted average grant date fair value | $ / shares	$ 27.81
Granted, weighted average grant date fair value | $ / shares	11.34	[1]
Vested, weighted average grant date fair value | $ / shares	30.47	[2]
Forfeited, weighted average grant date fair value | $ / shares	30.47
Outstanding, Ending Balance, weighted average grant date fair value | $ / shares	$ 23.62
[1]	These
[2]	Includes 12,283 TSR-PSUs awards issued related to the 2016 performance period where the return on our common stock was in the 20 th

Stock-based Compensation Pla_12

Stock-based Compensation Plans - TSR - PSUs Activities (Parenthetical) (Detail) - Performance Based TSR - PSUs	3 Months Ended
	Mar. 31, 2019shares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares vested and issued related to performance period number of common stock	12,283	[1]
February 2016 Grant
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Return on common stock percentile	20.00%
Minimum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Potential payout of shares on performance units granted	0.00%
Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Potential payout of shares on performance units granted	200.00%
[1]	Includes 12,283 TSR-PSUs awards issued related to the 2016 performance period where the return on our common stock was in the 20 th

Stock-based Compensation Pla_13

Stock-based Compensation Plans - Stock Option and SARs Activity (Detail) - Stock Appreciation Rights (SARs)	3 Months Ended
	Mar. 31, 2019$ / sharesshares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Beginning Balance, Shares	1,104
Expired, Shares	(1,104)
Ending Balance, Shares	0
Beginning Balance, Weighted Average Exercise Price | $ / shares	$ 81.74
Expired, Weighted Average Exercise Price | $ / shares	$ 81.74

Stock-based Compensation Pla_14

Stock-based Compensation Plans - Additional Information 4 (Detail) - USD ($) shares in Millions	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Deferred compensation plan vesting period	3 years
Deferred compensation plan	$ (3,581,000)	$ 7,397,000
Shares held in rabbi trust total	3.5		2.6
Vested shares held in rabbi trust	2.4		2.4
Post-Retirement Medical Plan
Defined Benefit Plan Disclosure [Line Items]
Estimated prior service cost amortized from accumulated other comprehensive income into general and administrative expense	$ 92,000	$ 92,000

Capital Stock - Additional Info

Capital Stock - Additional Information (Detail) - shares	Mar. 31, 2019	Dec. 31, 2018
Class Of Stock Disclosures [Abstract]
Authorized capital stock	485,000,000	485,000,000
Common stock, shares authorized	475,000,000	475,000,000
Preferred stock, shares authorized	10,000,000	10,000,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0

Capital Stock (Detail)

Capital Stock (Detail) - shares	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Class Of Stock [Line Items]
Beginning balance	249,510,022	248,129,430
Restricted stock grants	981,905	865,095
Treasury shares issued		5,302
Ending balance	251,138,134	249,510,022
Restricted Stock
Class Of Stock [Line Items]
Restricted stock units vested	633,460	434,046
Performance Share
Class Of Stock [Line Items]
Performance stock units issued	12,283	73,985
Performance stock dividends	464	2,164

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information - Supplemental Cash Flow Information (Detail) - USD ($) $ in Thousands	3 Months Ended			12 Months Ended
	Mar. 31, 2019		Mar. 31, 2018	Dec. 31, 2018	[1]
Net cash provided from operating activities included:
Income taxes refunded from taxing authorities			$ 7,518
Interest paid	$ (54,632)		(57,536)
Non-cash investing and financing activities included:
Increase in asset retirement costs capitalized	1,532	[1]	5,063	$ 28,826
Increase (decrease) in accrued capital expenditures	$ 22,764		$ (77,365)
[1]	Includes costs incurred whether capitalized or expensed.

Suspended Exploratory Well Co_2

Suspended Exploratory Well Costs - Additional Information (Detail) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Extractive Industries [Abstract]
Suspended exploratory well costs	$ 0	$ 0

Costs Incurred for Property A_3

Costs Incurred for Property Acquisition, Exploration and Development (Detail) - USD ($) $ in Thousands		3 Months Ended			12 Months Ended
		Mar. 31, 2019		Mar. 31, 2018	Dec. 31, 2018
Acquisitions:
Acreage purchases	[1]	$ 14,634			$ 62,390
Oil and gas properties	[1]				1,683
Development	[1]	209,827			834,552
Exploration:
Exploration drilling costs incurred	[1]	542			1,380
Gas gathering facilities:
Development	[1]	1,063			10,218
Subtotal	[1]	234,276			944,340
Asset retirement obligations		1,532	[1]	$ 5,063	28,826	[1]
Total costs incurred	[1]	235,808			973,166
Expense
Exploration:
Exploration costs incurred	[1]	7,837			32,196
Stock-based compensation expense	[1]	$ 373			$ 1,921
[1]	Includes costs incurred whether capitalized or expensed.