Range Resources (RRC) 10-Q 23 Oct 18 2018 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2018	Oct. 19, 2018
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q3
Trading Symbol	RRC
Entity Registrant Name	RANGE RESOURCES CORP
Entity Central Index Key	315,852
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		249,505,145

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands		Sep. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents		$ 357	$ 448
Accounts receivable, less allowance for doubtful accounts of $5,862 and $7,111		397,536	348,833
Derivative assets		103	58,607
Inventory and other		24,488	21,346
Total current assets		422,484	429,234
Derivative assets		1,114	273
Goodwill		1,641,197	1,641,197
Natural gas and oil properties, successful efforts method	[1]	13,643,196	13,216,453
Accumulated depletion and depreciation	[1]	(3,929,060)	(3,649,716)
Natural gas and oil properties, successful efforts method, net	[1]	9,714,136	9,566,737
Other property and equipment		112,404	114,361
Accumulated depreciation and amortization		(101,402)	(99,695)
Other Property and equipment, net		11,002	14,666
Other assets		76,203	76,734
Total assets		11,866,136	11,728,841
Current liabilities:
Accounts payable		225,874	343,871
Asset retirement obligations		6,327	6,327
Accrued liabilities		386,671	317,531
Accrued interest		37,739	43,511
Derivative liabilities		97,256	44,233
Total current liabilities		753,867	755,473
Bank debt		1,257,199	1,208,467
Senior notes		2,855,048	2,851,754
Senior subordinated notes		48,653	48,585
Deferred tax liabilities		731,723	693,356
Derivative liabilities		11,751	9,789
Deferred compensation liabilities		86,794	101,102
Asset retirement obligations and other liabilities		303,813	286,043
Total liabilities		6,048,848	5,954,569
Commitments and contingencies
Stockholders’ Equity
Preferred stock, $1 par, 10,000,000 shares authorized, none issued and outstanding		0	0
Common stock, $0.01 par, 475,000,000 shares authorized, 249,504,124 issued at September 30, 2018 and 248,144,397 issued at December 31, 2017		2,495	2,481
Common stock held in treasury, 10,067 shares at September 30, 2018 and 14,967 shares at December 31, 2017		(404)	(599)
Additional paid-in capital		5,617,371	5,577,732
Accumulated other comprehensive loss		(1,124)	(1,332)
Retained earnings		198,950	195,990
Total stockholders’ equity		5,817,288	5,774,272
Total liabilities and stockholders’ equity		$ 11,866,136	$ 11,728,841
[1]	Includes capitalized asset retirement costs and the associated accumulated amortization.

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Statement Of Financial Position [Abstract]
Allowance for doubtful accounts on accounts receivable	$ 5,862	$ 7,111
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	249,504,124	248,144,397
Common stock held in treasury, shares	10,067	14,967

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Revenues and other income:
Revenues and other income	$ 845,816,000		$ 2,361,898,000
Derivative fair value (loss) income	(34,591,000)	$ (88,426,000)	(151,890,000)	$ 188,326,000
Total revenues and other income	811,225,000	482,232,000	2,210,008,000	1,931,998,000
Costs and expenses:
Production and ad valorem taxes	9,427,000	11,993,000	29,493,000	31,125,000
Brokered natural gas and marketing	116,080,000	59,773,000	274,421,000	169,180,000
Exploration	8,299,000	22,767,000	23,517,000	45,769,000
Abandonment and impairment of unproved properties	6,549,000	42,568,000	73,244,000	52,181,000
General and administrative	43,722,000	53,035,000	159,722,000	152,853,000
Termination costs	(336,000)	(47,000)	(373,000)	4,049,000
Deferred compensation plan	223,000	(9,203,000)	(559,000)	(36,838,000)
Interest	54,801,000	49,179,000	161,048,000	144,206,000
Depletion, depreciation and amortization	164,266,000	159,749,000	487,558,000	462,074,000
Impairment of proved properties	0	63,679,000	22,614,000	63,679,000
Loss (gain) on the sale of assets	30,000	(102,000)	(149,000)	(23,509,000)
Total costs and expenses	738,549,000	681,924,000	2,153,772,000	1,721,983,000
Income (loss) before income taxes	72,676,000	(199,692,000)	56,236,000	210,015,000
Income tax expense (benefit):
Current	0	0	0	0
Deferred	24,137,000	(71,992,000)	38,295,000	98,054,000
Total expense (benefit) for income taxes	24,137,000	(71,992,000)	38,295,000	98,054,000
Net income (loss)	$ 48,539,000	$ (127,700,000)	$ 17,941,000	$ 111,961,000
Net income (loss) per common share:
Basic	$ 0.19	$ (0.52)	$ 0.07	$ 0.45
Diluted	0.19	(0.52)	0.07	0.45
Dividends paid per common share	$ 0.02	$ 0.02	$ 0.06	$ 0.06
Weighted average common shares outstanding:
Basic	246,451	245,244	246,016	245,027
Diluted	247,166	245,244	246,879	245,280
Natural Gas, NGLs and Oil Sales
Revenues and other income:
Revenues and other income	$ 736,431,000	$ 507,541,000	$ 2,094,450,000	$ 1,573,128,000
Brokered Natural Gas, Marketing and Other
Revenues and other income:
Revenues and other income	109,385,000	63,117,000	267,448,000	170,544,000
Direct Operating
Costs and expenses:
Costs and expenses	30,926,000	36,888,000	104,136,000	96,331,000
Transportation, Gathering, Processing and Compression
Costs and expenses:
Costs and expenses	$ 304,562,000	$ 191,645,000	$ 819,100,000	$ 560,883,000

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Statement Of Income And Comprehensive Income [Abstract]
Net income (loss)	$ 48,539	$ (127,700)	$ 17,941	$ 111,961
Postretirement benefits:
Prior service cost	91	0	276	0
Income tax benefit	(22)	0	(68)	0
Total comprehensive income (loss)	$ 48,608	$ (127,700)	$ 18,149	$ 111,961

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($)	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Operating activities:
Net income	$ 17,941,000	$ 111,961,000
Adjustments to reconcile net income to net cash provided from operating activities:
Deferred income tax expense	38,295,000	98,054,000
Depletion, depreciation and amortization and impairment	510,172,000	525,753,000
Exploration dry hole costs	4,000	9,166,000
Abandonment and impairment of unproved properties	73,244,000	52,181,000
Derivative fair value loss (income)	151,890,000	(188,326,000)
Cash settlements on derivative financial instruments	(40,272,000)	16,062,000
Allowance for bad debts	(1,250,000)	1,050,000
Amortization of deferred financing costs and other	4,163,000	4,184,000
Deferred and stock-based compensation	41,252,000	3,937,000
Gain on the sale of assets	(149,000)	(23,509,000)
Changes in working capital:
Accounts receivable	(49,713,000)	(39,694,000)
Inventory and other	(822,000)	(1,504,000)
Accounts payable	(6,529,000)	44,715,000
Accrued liabilities and other	36,721,000	(13,498,000)
Net cash provided from operating activities	774,947,000	600,532,000
Investing activities:
Additions to natural gas and oil properties	(781,554,000)	(771,067,000)
Additions to field service assets	(1,230,000)	(4,687,000)
Acreage purchases	(50,461,000)	(46,967,000)
Proceeds from disposal of assets	24,339,000	27,583,000
Purchases of marketable securities held by the deferred compensation plan	(34,953,000)	(25,410,000)
Proceeds from the sales of marketable securities held by the deferred compensation plan	37,311,000	28,755,000
Net cash used in investing activities	(806,548,000)	(791,793,000)
Financing activities:
Borrowings on credit facilities	1,602,000,000	1,486,000,000
Repayments on credit facilities	(1,547,000,000)	(1,282,000,000)
Repayment of senior notes	0	(500,000)
Dividends paid	(14,950,000)	(14,876,000)
Debt issuance costs	(8,257,000)	(247,000)
Taxes paid for shares withheld	(3,143,000)	(6,971,000)
Change in cash overdrafts	(5,653,000)	5,588,000
Proceeds from the sales of common stock held by the deferred compensation plan	8,513,000	4,482,000
Net cash provided from financing activities	31,510,000	191,476,000
(Decrease) increase in cash and cash equivalents	(91,000)	215,000
Cash and cash equivalents at beginning of period	448,000	314,000
Cash and cash equivalents at end of period	$ 357,000	$ 529,000

Summary of Organization and Nat

Summary of Organization and Nature of Business	9 Months Ended
	Sep. 30, 2018
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 growth, 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	9 Months Ended
	Sep. 30, 2018
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 2017 Annual Report on Form 10-K filed with the Securities and Exchange Commission (the “SEC”) on February 28, 2018. The results of operations for the third quarter and the nine months ended September 30, 2018 are not necessarily indicative of the results to be expected for the full year. Inventory. As of September 30, 2018, we had $9.1 million of material and supplies inventory compared to $12.1 million at December 31, 2017. 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 September 30, 2018, we also had commodity inventory of $1.5 million compared to $508,000 at December 31, 2017. Commodity inventory as of September 30, 2018 consists of NGLs held in storage or as line fill in pipelines. Unproved Properties. Impairment of a significant portion of our unproved properties is assessed and amortized on an aggregate basis based on our average holding period, expected forfeiture rate and anticipated drilling success. In certain circumstances, our future plans to develop acreage may accelerate our impairment.

New Accounting Standards

New Accounting Standards	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements And Changes In Accounting Principles [Abstract]
New Accounting Standards	(3) NEW ACCOUNTING STANDARDS Not Yet Adopted Lease Accounting Standard In February 2016, an accounting standards update was issued that requires an entity to recognize a right-of-use asset and lease liability for all leases with terms of more than twelve months. Classification of leases as either a finance or operating lease will determine the recognition, measurement and presentation of expenses. This accounting standards update also requires certain quantitative and qualitative disclosures about leasing arrangements. This standard does not apply to leases 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. We are evaluating each of our lease arrangements and are currently enhancing our systems to track and calculate additional information necessary for adoption of this standard. We are evaluating the provisions of this accounting standards update and assessing the impact it will have on our consolidated results of operations, financial position and financial disclosures, in addition to developing any control changes necessary. While we have yet to finalize the impact this standards update will have on our consolidated financial statements, we believe the adoption will likely increase our recorded assets and liabilities related to our leases. We will adopt this new standards update in first quarter 2019 using a modified retrospective approach and will recognize a right of use asset and lease liability on the adoption date. We plan to apply practical expedients provided in the standards update that allow, among other things, not to reassess contracts that commenced prior to the adoption. We also anticipate to elect a policy not to recognize right of use assets and lease liabilities related to short-term leases. 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 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. We had no service cost recorded prior to 2018 due to the implementation of our postretirement benefit plan at the end of 2017. In 2018, 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 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. The impact of adoption of the new revenue recognition standard on our current period results is as follows (in thousands): Three Months Ended September 30, 2018 As Reported Previous Revenue Recognition Method $ $ Per mcfe $ $ Per mcfe Increase $ Per mcfe Revenues: Natural gas, NGLs and oil sales $ 736,431 $ 3.53 $ 688,684 $ 3.30 $ 47,747 $ 0.23 Costs and expenses: Transportation, gathering, processing and compression $ 304,562 $ 1.46 $ 256,815 $ 1.23 $ 47,747 $ 0.23 Net income $ 48,539 $ 48,539 $ — Nine Months Ended September 30, 2018 As Reported Previous Revenue Recognition Method $ $ Per mcfe $ $ Per mcfe Increase $ Per mcfe Revenues: Natural gas, NGLs and oil sales $ 2,094,450 $ 3.45 $ 1,966,731 $ 3.24 $ 127,719 $ 0.21 Costs and expenses: Transportation, gathering, processing and compression $ 819,100 $ 1.35 $ 691,381 $ 1.14 $ 127,719 $ 0.21 Net income $ 17,941 $ 17,941 $ — Changes to natural gas, NGLs and oil sales and transportation, gathering, processing, and compression expenses is due to the conclusion that we represent the role of principal in a certain gas processing and marketing agreement with a midstream entity in accordance with the new accounting standard. This represents a change from our previous conclusion utilizing the principal versus agent indication that we acted as the agent in that agreement. As a result, we were required to modify our presentation to present revenue on a gross basis for amounts expected to be received from third-party customers through the marketing process, with expenses incurred prior to control of the products transferring to the midstream entity at the tailgate of the plant presented as transportation, gathering, processing and compression expense. Goodwill Standard In January 2017, an accounting standards update was issued that eliminates the requirements to calculate the implied fair value of goodwill to measure goodwill impairment charge. Instead, entities will record an impairment charge based on the excess of a reporting unit’s carrying amount over its fair value. This standard is effective for annual periods beginning after December 15, 2019 and should be applied on a prospective basis. Early adoption is permitted for any goodwill impairment tests performed in first quarter 2017 or later. We elected to adopt this accounting standards update in first quarter 2017. The adoption did not have a significant impact on our consolidated results of operations, financial position, cash flows or disclosures; however, this standard did change our policy for our annual goodwill impairment assessment by eliminating the requirement to calculate the implied fair value of goodwill. Inventory Standard In July 2015, an accounting standards update was issued that requires an entity to measure inventory at the lower of cost or net realizable value. This excludes inventory measured using LIFO or the retail inventory method. This standard was effective for us in first quarter 2017 and was applied prospectively. Adoption of this standard did not have an impact on our consolidated results of operations, financial position or cash flows. Classification in the Statement of Cash Flows In August 2016, an accounting standards update was issued that clarifies how entities classify certain cash receipts and cash payments on the statement of cash flows. The guidance is effective for us in first quarter 2018 and should be applied retrospectively with early adoption permitted. We adopted this new standard in fourth quarter 2017 on a retrospective basis. Adoption of this standard did not have an impact on our consolidated cash flow statement presentation. Definition of a Business In January 2017, an accounting standards update was issued which clarifies the definition of a business. This new standard is effective for us in first quarter 2018 with early adoption permitted. We adopted this new standard in fourth quarter 2017. Adoption of this standard did not have a significant impact on our consolidated results of operations, financial position or cash flows.

Dispositions

Dispositions	9 Months Ended
	Sep. 30, 2018
Business Combinations [Abstract]
Dispositions	(4) DISPOSITIONS We recognized a pretax net loss on the sale of assets of $30,000 in third quarter 2018 compared to a pretax net gain of $102,000 in the same period of the prior year and a pretax net gain on the sale of assets of $149,000 in first nine months 2018 compared to a pretax net gain on the sale of assets of $23.5 million in first nine months 2017. 2018 Fourth Quarter Disposition Announcement On October 15, 2018, we announced the simultaneous signing and closing of an agreement to sell a proportionately reduced 1% royalty on all our current Washington County, Pennsylvania leases for $300.0 million in proceeds. The transaction is subject to customary terms and conditions. 2018 Dispositions Northern Oklahoma. In third quarter 2018, we sold properties in Northern Oklahoma for proceeds of $23.3 million and we recorded a net loss of $39,000 related to this sale, after closing adjustments. Other . In third quarter 2018, we sold miscellaneous inventory and other assets for proceeds of $673,000, resulting in a pretax gain of $9,000. In first six months 2018, we sold miscellaneous inventory and other assets for proceeds of $366,000 resulting in a pretax gain of $179,000. 2017 Dispositions Western Oklahoma. In first nine months 2017, we sold properties in Western Oklahoma for proceeds of $26.0 million and we recorded a gain of $22.1 million related to this sale, after closing adjustments and transaction fees. Other . In third quarter 2017, we sold miscellaneous inventory and other assets for proceeds of $295,000, resulting in a pretax gain of $102,000. In first six months 2017, we sold miscellaneous unproved property, inventory and other assets for proceeds of $1.3 million resulting in a pretax gain of $1.3 million.

Revenues from Contracts with Cu

Revenues from Contracts with Customers	9 Months Ended
	Sep. 30, 2018
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. See a more detailed summary of our product types below. Natural Gas and NGLs Sales Under our gas processing contracts, we deliver natural gas to a midstream processing entity at the wellhead or the inlet of the midstream processing entity’s system. The midstream processing entity processes the natural gas and remits proceeds to us for the resulting sales of NGLs and residue gas. In these scenarios, we evaluate whether we are the principal or the agent in the transaction. For those contracts that we have concluded that we are the principal, the ultimate third party is our customer and we recognize revenue on a gross basis, with gathering, compression, processing, and transportation fees presented as an expense. Alternatively, for those contracts that we have concluded that we are the agent, the midstream processing entity is our customer and we recognize revenue based on the net amount of the proceeds received from the midstream processing entity. In certain natural gas processing agreements, we may elect to take our residue gas and/or NGLs in-kind at the tailgate of the midstream entity’s processing plant and subsequently market the product on our own. Through the marketing process, we deliver product to the ultimate third party purchaser at a contractually agreed upon delivery point and receive a specified index price from the purchaser. In this scenario, we recognize revenue when control transfers to the purchaser at the delivery point based on the index price received from the purchaser. The gathering, processing and compression fees attributable to the gas processing contract, as well as any transportation fees incurred to deliver the product to the purchaser, are presented as transportation, gathering, processing and compression expense. Oil Sales Our oil sales contracts are generally structured in one of the following ways: • We sell oil production at the wellhead and collect an agreed upon index price, net of transportation incurred by the purchaser (that is, a netback arrangement). In this scenario, we recognize revenue when control transfers to the purchaser at the wellhead at the net price received. • We deliver oil to the purchaser at a contractually agreed upon delivery point at which the purchaser takes custody, title, and risk of loss of the product. Under this arrangement, we pay a third party to transport the product and receive a specified index price from the purchaser with no deduction. In this scenario, we recognize revenue when control transfers to the purchaser at the delivery point based on the price received from the purchaser. The third party costs are recorded as transportation, gathering, processing and compression expense. Brokered Natural Gas, Marketing and Other We realize brokered margins as a result of buying natural gas or NGLs utilizing separate purchase transactions, generally with separate counterparties and subsequently selling that natural gas or NGLs under our existing contracts to fulfill our contract commitments or utilizing existing infrastructure contracts to economically utilize available capacity. In these arrangements, we take control of the natural gas purchased prior to delivery of that gas under our existing gas contracts with a separate counterparty. Revenues and expenses related to brokering natural gas are reported gross as part of revenues and expenses in accordance with applicable accounting standards. Our net brokered margin was a loss of $6.7 million in third quarter 2018 and a loss of $7.0 million in first nine months 2018. Disaggregation of Revenue We have identified 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. Revenue attributable to each of our identified revenue streams is disaggregated below (in thousands): Three Months Ended September 30, 2018 Nine Months Ended September 30, 2018 Natural gas sales (a) $ 500,194 $ 1,449,148 NGLs sales (b) 278,410 706,673 Oil sales 67,212 206,077 Total $ 845,816 $ 2,361,898 (a) Natural gas sales revenue reported above for the third quarter includes $105.8 million of brokered revenues and $3.7 million of marketing revenue. The nine months includes $255.1 million of brokered revenues and $11.4 million of marketing revenue. (b) NGLs sales revenue reported above for the third quarter includes ($153,000) of brokered revenues and for nine months includes $880,000 Principal versus Agent We engage in various types of transactions in which midstream entities process our wet gas and, in some scenarios, subsequently market the resulting NGLs and residue gas to third-party customers on our behalf. These types of transactions require judgment to determine whether we are the principal or the agent in the contract and, as a result, whether revenues are recorded gross or net. Transaction Price Allocated to Remaining Performance Obligations A significant number of our product sales are short-term in nature with a contract term of one year or less. For those contracts, we have utilized the practical expedient allowed in the new revenue accounting standard that exempts us from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. For our product sales that have a contract term greater than one year, we have also utilized the practical expedient that states that we are not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of product generally represents a separate performance obligation; therefore, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. Currently, our product sales that have a contractual term greater than one year have no long-term fixed consideration. Contract Balances Under our sales contracts, we invoice customers once our performance obligations have been satisfied, at which point payment is unconditional. Accordingly, our product sales contracts do not give rise to contract assets or liabilities. Accounts receivable attributable to our revenue contracts with customers was $354.4 million at September 30, 2018 and $305.7 million at December 31, 2017. Prior−Period Performance Obligations We record revenue in the month production is delivered to the purchaser. However, settlement statements for certain gas and NGLs sales may be received for 30 to 90 days after the date production is delivered, and as a result, we are required to estimate the amount of production that was delivered to the purchaser and the price that will be received for the sale of the product. We record the differences between our estimates and the actual amounts for product sales in the month that payment is received from the purchaser. We have internal controls in place for our estimation process and any identified differences between our revenue estimates and actual revenue received historically have not been significant. For the three months and the nine months ended September 30, 2018, revenue recognized in the reporting period related to performance obligations satisfied in prior reporting periods was not material.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Income Taxes	(6) INCOME TAXES Income tax expense (benefit) was as follows (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Income tax expense (benefit) $ 24,137 $ (71,992 ) $ 38,295 $ 98,054 Effective tax rate 33.2 % 36.1 % 68.1 % 46.7 % 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 third quarter and first nine months ended 2018 and 2017, 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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Total income (loss) before income taxes $ 72,676 $ (199,692 ) $ 56,236 $ 210,015 U.S. federal statutory rate 21 % 35 % 21 % 35 % Total tax expense (benefit) at statutory rate 15,262 (69,892 ) 11,810 73,505 State and local income taxes, net of federal benefit 2,691 (6,537 ) 3,439 6,591 Non-deductible executive compensation 48 296 601 436 Equity compensation 6 56 2,146 4,808 Change in valuation allowances: Federal net operating loss carryforwards & other — 69 — 3,487 State net operating loss carryforwards & other 5,558 4,286 19,194 10,498 Rabbi trust and other 100 (508 ) 1,499 (1,561 ) Permanent differences and other 472 238 (394 ) 290 Total expense (benefit) for income taxes $ 24,137 $ (71,992 ) $ 38,295 $ 98,054 Effective tax rate 33.2 % 36.1 % 68.1 % 46.7 % On December 22, 2017, the Tax Cuts and Jobs Act of 2017 was signed into law. The law significantly reformed the Internal Revenue Code of 1986, as amended. The reduction in the corporate tax rate required a one-time revaluation of certain tax related assets and liabilities to reflect their value at the lower corporate tax rate of 21%. Due to the complexities involved in the accounting for the enactment of the new law, the SEC Staff Accounting Bulletin (“SAB”) 118 allowed a provisional estimate for the year ended December 31, 2017, which we made. As of September 30, 2018, we have not made any material adjustments to our provisional estimate at year-end 2017. We have made a reasonable estimate of the effect on our deferred tax balances. We will continue to analyze the impact of the new law and additional impacts will be recorded as they are identified during the measurement period provided for in SAB 118.

Income (Loss) Per Common Share

Income (Loss) Per Common Share	9 Months Ended
	Sep. 30, 2018
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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Net income (loss), as reported $ 48,539 $ (127,700 ) $ 17,941 $ 111,961 Participating earnings (a) (590 ) (58 ) (224 ) (1,251 ) Basic net income (loss) attributed to common shareholders 47,949 (127,758 ) 17,717 110,710 Reallocation of participating earnings (a) 2 — — 1 Diluted net income (loss) attributed to common shareholders $ 47,951 $ (127,758 ) $ 17,717 $ 110,711 Net income (loss) per common share: Basic $ 0.19 $ (0.52 ) $ 0.07 $ 0.45 Diluted $ 0.19 $ (0.52 ) $ 0.07 $ 0.45 (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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Weighted average common shares outstanding – basic 246,451 245,244 246,016 245,027 Effect of dilutive securities: Director and employee PSUs and RSUs 715 — 863 253 Weighted average common shares outstanding – diluted 247,166 245,244 246,879 245,280 Weighted average common shares outstanding-basic for third quarter 2018 excludes 3.0 million shares of restricted stock held in our deferred compensation plan compared to 2.9 million shares in third quarter 2017 (although all awards are issued and outstanding upon grant). Weighted average common shares outstanding-basic for first nine months 2018 excludes 3.1 million shares of restricted stock compared to 2.8 million for first nine months 2017. For third quarter 2018, equity grants of 506,000 and for first nine months 2018, equity grants of 755,000 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. Due to our net loss in third quarter 2017, all outstanding equity grants have been excluded from the computation of diluted net loss per share because the effect would have been anti-dilutive to the computations. For first nine months 2017, equity grants of 1.1 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. 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.

Capitalized Costs and Accumulat

Capitalized Costs and Accumulated Depreciation, Depletion and Amortization	9 Months Ended
	Sep. 30, 2018
Extractive Industries [Abstract]
Capitalized Costs and Accumulated Depreciation, Depletion and Amortization	(8) Capitalized Costs and Accumulated Depreciation, Depletion and Amortization (a) September 30, December 31, (in thousands) Natural gas and oil properties: Properties subject to depletion $ 11,041,412 $ 10,572,453 Unproved properties 2,601,784 2,644,000 Total 13,643,196 13,216,453 Accumulated depreciation, depletion and amortization (3,929,060 ) (3,649,716 ) Net capitalized costs $ 9,714,136 $ 9,566,737 (a) Includes capitalized asset retirement costs and the associated accumulated amortization.

Indebtedness

Indebtedness	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Indebtedness	(9) INDEBTEDNESS We had the following debt outstanding as of the dates shown below (bank debt interest rate at September 30, 2018 is shown parenthetically). No interest was capitalized during the three months or nine months ended September 30, 2018 or the year ended December 31, 2017 (in thousands). September 30, 2018 December 31, 2017 Bank debt (3.9%) $ 1,266,000 $ 1,211,000 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 4,192,329 4,137,329 Unamortized premium 5,070 6,027 Unamortized debt issuance costs (36,499 ) (34,550 ) Total debt net of debt issuance costs $ 4,160,900 $ 4,108,806 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 provides for a borrowing base subject to redeterminations annually by May and for event-driven unscheduled redeterminations. As of September 30, 2018, 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 September 30, 2018, bank commitments total $2.0 billion and the outstanding balance under our bank credit facility was $1.3 billion, before deducting debt issuance costs. Additionally, we had $281.4 million of undrawn letters of credit leaving $452.6 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 3.9% for third quarter 2018 compared to 2.8% for third quarter 2017. The weighted average interest rate was 3.7% for first nine months 2018 compared to 2.6% for first nine months 2017. A commitment fee is paid on the undrawn balance based on an annual rate of 0.30% to 0.375%. At September 30, 2018, the commitment fee was 0.35% and the interest rate margin was 1.75% on our LIBOR loans and 0.75% 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 In September 2016, in conjunction with the acquisition of Memorial Resource Development Corp. (the “MRD Merger”), we issued $329.2 million senior unsecured 5.875% notes due 2022 (the “5.875% Notes”). In addition, we also completed a debt exchange offer to exchange senior subordinated notes for the following senior notes (in thousands): Principal Amount 5.00% senior notes due 2023 $ 741,531 5.00% senior notes due 2022 $ 580,032 5.75% senior notes due 2021 $ 475,952 All of the notes were offered to qualified institutional buyers and to non-U.S. persons outside the United States in compliance with Rule 144A and Regulation S under the Securities Act of 1933, as amended (the “Securities Act”). On October 5, 2017, the 5.875% Notes, the 5.00% senior notes due 2023, the 5.00% senior notes due 2022 and the 5.75% senior notes due 2021 (collectively, the “Old Notes”) were exchanged for an equal principal amount of registered notes pursuant to an effective registration statement on Form S-4 filed with the SEC on August 9, 2017 under the Securities Act (the “New Notes”). The New Notes are identical to the Old Notes except the New Notes are registered under the Securities Act and do not have restrictions on transfer, registration rights or provisions for additional interest. Under certain circumstances, if we experience a change of control, noteholders may require us to repurchase all of our senior notes at 101% of the aggregate principal amount plus accrued and unpaid interest, if any. Senior Subordinated Notes If we experience a change of control, noteholders may require us to repurchase all or a portion of our 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 September 30, 2018.

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(10) 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 nine months ended September 30, 2018 is as follows (in thousands): Nine Months Ended September 30, 2018 Beginning of period $ 276,855 Liabilities incurred 2,668 Disposition of wells (8,665 ) Acquisitions 13,438 Liabilities settled (3,803 ) Accretion expense 12,132 Change in estimate 4,347 End of period 296,972 Less current portion (6,327 ) Long-term asset retirement obligations $ 290,645 Accretion expense is recognized as a component of depreciation, depletion and amortization expense in the accompanying consolidated statements of operations. Acquisitions include an increase in our interest in certain properties in Northwest Pennsylvania.

Derivative Activities

Derivative Activities	9 Months Ended
	Sep. 30, 2018
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivative Activities	(11) 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 loss of $104.8 million at September 30, 2018. These contracts expire monthly through December 2020. The following table sets forth our commodity-based derivative volumes by year as of September 30, 2018, excluding our basis and freight swaps which are discussed separately below: Period Contract Type Volume Hedged Weighted Natural Gas 2018 Swaps 1,193,370 Mmbtu/day $ 2.96 2019 Swaps 594,589 Mmbtu/day $ 2.82 2018 Calls 70,000 Mmbtu/day $ 3.10 (1) 2018 Swaptions 160,000 Mmbtu/day $ 3.07 (2) 2019 Swaptions 298,014 Mmbtu/day $ 2.86 (2) 2020 Swaptions 10,000 Mmbtu/day $ 2.75 (2) Crude Oil 2018 Swaps 8,500 bbls/day $ 53.20 2019 Swaps 7,000 bbls/day $ 55.26 2020 Swaps 1,500 bbls/day $ 60.63 2019 Collars 1,000 bbls/day $ 63.00 − $ 73.03 NGLs (C3-Propane) 2018 Swaps 11,668 bbls/day $ 0.74/gallon January – June 2019 Swaps 7,500 bbls/day $ 0.92/gallon 2018 Collars 5,000 bbls/day $ 0.95 − $ 1.04 January – March 2019 Collars 6,500 bbls/day $ 0.92 − $1.02 NGLs (NC4-Normal Butane) 2018 Swaps 5,500 bbls/day $ 0.91/gallon January – March 2019 Swaps 2,250 bbls/day $ 1.22/gallon NGLs (C5-Natural Gasoline) 2018 Swaps 5,402 bbls/day $ 1.24/gallon 2019 Swaps 2,178 bbls/day $ 1.42/gallon (1) (2) Contains a combined derivative instrument consisting of a fixed price swap and a sold option to extend or double the volume. For October through December of 2018, we have swaps in place for 160,000 Mmbtu per day on which the counterparty can elect to extend the contract through December 2019 at a weighted average price of $3.07. We have swaps in place for 2019 for 185,000 Mmbtu/day on which the counterparty can elect to double the volume at a weighted average price of $2.89. We also have swaps in place for 2019 for 150,000 Mmbtu per day on which the counterparty can elect to extend the contract through December 2020 at a weighted average price of $2.81. For 2020, we have swaps in place for 10,000 Mmbtu/day on which the counterparty can elect to double the volume at a weighted average price of $2.75. 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, calls and swaptions described above, at September 30, 2018, 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 September 2021 and include a total volume of 73,660,000 Mmbtu. The fair value of these contracts was a loss of $1.3 million at September 30, 2018. At September 30, 2018, we also had propane spread swap contracts which lock in the differential between Mont Belvieu and international propane indices. The contracts settle monthly through December 2019 and include a total volume of 1,943,000 barrels. The fair value of these contracts was a loss of $2.0 million at September 30, 2018. Freight Swap Contracts In connection with our international propane sales, we utilize propane swaps. To further hedge our propane price, at September 30, 2018, 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 5,000 metric tons per month with a fair value gain of $301,000 at September 30, 2018. These contracts use observable third-party pricing inputs that we consider to be Level 2 fair value classification. Derivative Assets and Liabilities The combined fair value of derivatives included in the accompanying consolidated balance sheets as of September 30, 2018 and December 31, 2017 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): September 30, 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 $ 6,503 $ (4,745 ) $ 1,758 –swaptions 12,893 (12,700 ) 193 –basis swaps 1,246 (1,112 ) 134 Crude oil –swaps — (799 ) (799 ) −collars — (69 ) (69 ) NGLs –C3 propane swaps 3 (3 ) — –C3 propane spread swaps 25,747 (25,747 ) — Freight −swaps 301 (301 ) — $ 46,693 $ (45,476 ) $ 1,217 September 30, 2018 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 $ (10,030 ) $ 4,745 $ (5,285 ) –swaptions (8,759 ) 12,700 3,941 –basis swaps (2,548 ) 1,112 (1,436 ) –calls (504 ) — (504 ) Crude oil –swaps (57,424 ) 799 (56,625 ) −collars (717 ) 69 (648 ) NGLs –C3 propane swaps (20,363 ) 3 (20,360 ) –C3 propane collars (3,237 ) — (3,237 ) –C3 propane spread swaps (27,741 ) 25,747 (1,994 ) –NC4 butane swaps (8,223 ) — (8,223 ) –C5 natural gasoline swaps (14,937 ) — (14,937 ) Freight –swaps — 301 301 $ (154,483 ) $ 45,476 $ (109,007 ) December 31, 2017 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 $ 87,794 $ (4,106 ) $ 83,688 –swaptions 18,817 (8,103 ) 10,714 –basis swaps 1,815 (6,673 ) (4,858 ) –collars 3,039 (500 ) 2,539 Crude oil –swaps 2 (7,928 ) (7,926 ) NGLs –C2 ethane swaps 57 — 57 –C3 propane swaps — (12,556 ) (12,556 ) –C3 propane collars 85 (85 ) — –C3 propane spread swaps 12,762 (12,762 ) — –NC4 butane swaps — (6,051 ) (6,051 ) –C5 natural gasoline swaps — (6,727 ) (6,727 ) Freight –swaps 276 (276 ) — $ 124,647 $ (65,767 ) $ 58,880 December 31, 2017 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 $ (216 ) $ 4,106 $ 3,890 –swaptions (12,283 ) 8,103 (4,180 ) –basis swaps (9,580 ) 6,673 (2,907 ) –collars — 500 500 Crude oil –swaps (24,726 ) 7,928 (16,798 ) NGLs –C3 propane swaps (34,325 ) 12,556 (21,769 ) –C3 propane collars — 85 85 –C3 propane spread swaps (13,983 ) 12,762 (1,221 ) –NC4 butane swaps (11,188 ) 6,051 (5,137 ) –C5 natural gasoline swaps (13,488 ) 6,727 (6,761 ) Freight –swaps — 276 276 $ (119,789 ) $ 65,767 $ (54,022 ) The effects of our derivatives on our consolidated statements of operations are summarized below (in thousands): Derivative Fair Value (Loss) Income Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Commodity swaps $ (35,868 ) $ (87,861 ) $ (143,598 ) $ 172,457 Swaptions 7,093 (7,602 ) 4,100 (7,602 ) Collars (3,965 ) 956 (4,031 ) 15,221 Puts — (73 ) — 9,646 Calls 197 104 526 1,144 Basis swaps (2,350 ) 6,113 (9,043 ) (2,554 ) Freight swaps 302 (63 ) 156 14 Total $ (34,591 ) $ (88,426 ) $ (151,890 ) $ 188,326

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	(12) 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; • impairment assessments of goodwill; and • recorded value of derivative instruments and trading securities. The need to test long-lived assets and goodwill can be based on several indicators, including a significant reduction in prices of natural gas, oil and condensate, NGLs, sustained declines in our common stock, 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 September 30, 2018 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 September 30, 2018 Trading securities held in the deferred compensation plans $ 67,108 $ — $ — $ 67,108 Derivatives – — (104,471 ) — (104,471 ) –collars — (717 ) (3,237 ) (3,954 ) –calls — (504 ) — (504 ) –basis swaps — (3,296 ) — (3,296 ) –freight swaps — 301 — 301 –swaptions — — 4,134 4,134 Fair Value Measurements at December 31, 2017 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, 2017 Trading securities held in the deferred compensation plans $ 67,117 $ — $ — $ 67,117 Derivatives –swaps — 3,910 — 3,910 –collars — 3,039 85 3,124 –basis swaps — (9,025 ) 39 (8,986 ) –freight swaps — 276 — 276 –swaptions — — 6,534 6,534 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 September 30, 2018, 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 September 30, 2018 Balance at December 31, 2017 $ 6,658 Total losses: Included in earnings 1,876 Settlements (4,690 ) Transfer out of Level 3 (1) (2,947 ) Balance at September 30, 2018 $ 897 (1 ) 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 third quarter 2018, interest and dividends were $225,000 and the mark-to-market adjustment was a gain of $1.3 million compared to interest and dividends of $1.5 million and a mark-to-market gain of $1.1 million in third quarter 2017. For first nine months 2018, interest and dividends were $606,000 and the mark-to-market gain was $522,000 compared to interest and dividends of $2.4 million and mark-to-market gain of $4.1 million in the same period of the prior year. Fair Values—Goodwill During 2016, we recorded goodwill associated with the MRD Merger, which represented the cost of the acquired entity over the net amounts assigned to assets acquired and liabilities assumed. Goodwill is assessed for impairment whenever events or circumstances indicate that impairment of the carrying value of goodwill is likely, but no less often than annually. Our policy is to first assess qualitative factors in order to determine whether fair value is more likely than not less than carrying value. Certain qualitative factors used in our evaluation include, among other things, the result of the most recent quantitative assessment of the goodwill impairment test, macroeconomic conditions; industry and market conditions (including commodity prices and cost factors); overall financial performance; and others relevant entity-specific events. If, after considering these events and circumstances, we determine that it is more likely than not that the fair value is less than carrying value, a quantitative goodwill test is performed. During fourth quarter 2017, we performed our annual qualitative assessment of goodwill to determine whether it was more likely than not that the fair value of our business (our reporting unit) was less than its carrying amount. Based on the results of this assessment, we determined it was not likely that goodwill was impaired. We are not aware of any events or circumstances that occurred during first nine months 2018 that would have more likely than not reduced the fair value of our reporting unit below its carrying value. 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 second quarter 2018, we increased our interest in certain properties in our shallow legacy oil and natural gas assets in Northwest Pennsylvania for a minimal dollar amount for which the fair value was previously determined to be zero. As a result, in second quarter 2018, we recorded additional impairment of $15.3 million related to these properties. 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 properties, which is a Level 3 input. We recorded non-cash charges in first quarter 2018 of $7.3 million related to these properties. In third quarter 2017, there were indicators that the carrying value of certain of our properties in Oklahoma and the Texas Panhandle may be impaired and undiscounted future cash flows attributed to these assets indicated their carrying amounts were not expected to be recovered. We also considered the potential sale of these assets. We recorded non-cash charges in third quarter 2017 of $63.7 million related to these properties. The following presents the value of these assets measured at fair value on a non-recurring basis at the time impairment was recorded (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Fair Value Impairment Fair Value Impairment Fair Value Impairment Fair Value Impairment Natural gas and oil properties $ — $ — $ 85,597 $ 63,679 $ 32,516 $ 22,614 $ 85,597 $ 63,679 Fair Values—Reported The following presents the carrying amounts and the fair values of our financial instruments as of September 30, 2018 and December 31, 2017 (in thousands): September 30, 2018 December 31, 2017 Carrying Fair Carrying Fair Assets: Commodity swaps, options and basis swaps $ 1,217 $ 1,217 $ 58,880 $ 58,880 Marketable securities (a) 67,108 67,108 67,117 67,117 (Liabilities): Commodity swaps, options and basis swaps (109,007 ) (109,007 ) (54,022 ) (54,022 ) Bank credit facility (b) (1,266,000 ) (1,266,000 ) (1,211,000 ) (1,211,000 ) 5.75% senior notes due 2021 (b) (475,952 ) (489,555 ) (475,952 ) (493,872 ) 5.00% senior notes due 2022 (b) (580,032 ) (574,493 ) (580,032 ) (578,727 ) 5.875% senior notes due 2022 (b) (329,244 ) (334,439 ) (329,244 ) (339,200 ) Other senior notes due 2022 (b) (590 ) (586 ) (590 ) (591 ) 5.00% senior notes due 2023 (b) (741,531 ) (728,576 ) (741,531 ) (735,614 ) 4.875% senior notes due 2025 (b) (750,000 ) (712,193 ) (750,000 ) (733,755 ) 5.75% senior subordinated notes due 2021 (b) (22,214 ) (22,825 ) (22,214 ) (22,192 ) 5.00% senior subordinated notes due 2022 (b) (19,054 ) (18,863 ) (19,054 ) (18,741 ) 5.00% senior subordinated notes due 2023 (b) (7,712 ) (7,567 ) (7,712 ) (7,614 ) Deferred compensation plan (c) (112,827 ) (112,827 ) (114,414 ) (114,414 ) (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. For additional information, see Note 10. Concentrations of Credit Risk As of September 30, 2018, 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 $5.9 million at September 30, 2018 and $7.1 million at December 31, 2017. 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 September 30, 2018, our derivative counterparties include twenty-one financial institutions, of which all but five are secured lenders in our bank credit facility. At September 30, 2018, our net derivative liability includes a net payable of $23.9 million to these five counterparties that are not participants in our bank credit facility.

Stock-based Compensation Plans

Stock-based Compensation Plans	9 Months Ended
	Sep. 30, 2018
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Stock-based Compensation Plans	(13) 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. To better align the timing of senior officer equity awards with our proxy statement filing in 2018, senior officer equity grants were in March 2018 rather than May, as in previous years. 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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Direct operating expense $ 537 $ 517 $ 1,667 $ 1,563 Brokered natural gas and marketing expense 403 389 1,001 1,040 Exploration expense 405 561 1,527 1,596 General and administrative expense 5,607 9,959 38,332 35,156 Termination costs — (31 ) — 1,665 Total stock-based compensation $ 6,952 $ 11,395 $ 42,527 $ 41,020 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 would be 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 September 30, 2018, there were 1,104 SARs outstanding. Restricted Stock – Equity Awards In first nine months 2018, we granted 1.8 million restricted stock Equity Awards to employees at an average price of $16.97 which generally vest over a three-year period compared to 883,000 at an average price of $32.81 in first nine months 2017. We recorded compensation expense for these awards of $18.2 million in first nine months 2018 compared to $18.1 million in the same period of 2017. 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 nine months 2018, we granted 877,000 shares of restricted stock Liability Awards as compensation to employees at an average price of $15.30 which vests generally over a three-year period and 138,000 shares were granted to non-employee directors at an average price of $15.54 with immediate vesting. The timing of equity grants to senior officers was moved to March 2018 to align with our proxy statement filings compared to grants in May in previous years. In first nine months 2017, we granted 451,000 shares of restricted stock Liability Awards as compensation to employees at an average price of $25.95 with vesting generally over a three-year period and 90,000 shares were granted to non-employee directors at an average price of $25.01 with immediate vesting. We recorded compensation expense for these Liability Awards of $11.0 million in first nine months 2018 compared to $12.0 million in first nine months 2017. 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 September 30, 2018: 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, 2017 833,058 $ 31.64 55,202 $ 32.26 Granted 1,816,432 16.97 877,191 15.30 Vested (792,382 ) 23.76 (733,634 ) 15.99 Forfeited (191,332 ) 21.74 (23,900 ) 19.76 Outstanding at September 30, 2018 1,665,776 $ 20.53 174,859 $ 17.14 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 September 30, 2018: Number of Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2017 122,921 $ 18.66 Units granted (a) 440,938 15.22 Forfeited (b) (27,061 ) 23.03 Outstanding at September 30, 2018 536,798 $ 15.61 (a) 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. (b) The first of three tranches of PG-PSUs granted in 2017 are considered forfeited as the performance metric was not met. We recorded PG/RG-PSUs compensation expense of $5.8 million in first nine months 2018 compared to $124,000 in first nine months 2017. 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 nine months 2018 and 2017: Nine Months Ended September 30, 2018 2017 Risk-free interest rate 2.42 % 1.49 % Expected annual volatility 48 % 44 % Grant date fair value per unit $ 18.51 $ 26.26 The following is a summary of our non-vested TSR – Units Weighted Average Fair Value Outstanding at December 31, 2017 1,009,842 $ 38.38 Units granted (a) 329,486 18.51 Vested and issued (b) (73,985 ) 56.81 Forfeited (197,457 ) 55.46 Outstanding at September 30, 2018 1,067,886 $ 27.81 (a) These (b) Includes 73,985 TSR-PSUs awards issued related to the 2015 performance period where the return on our common stock was the 46 th th We recorded TSR-PSUs compensation expense of $6.1 million in first nine months 2018 compared to $9.7 million in the same period of 2017. SARs Information with respect to our SARs activities is summarized below. Shares Weighted Average Exercise Price Outstanding at December 31, 2017 382,779 $ 76.54 Expired/forfeited (381,675 ) 75.97 Outstanding at September 30, 2018 1,104 $ 81.74 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. In first nine months 2018, there were $276,000 of estimated prior service costs amortized from accumulated other comprehensive income into general and administrative expense. Those employees that qualify for the new postretirement health care plan are also fully vested in all equity grants. 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 $223,000 in third quarter 2018 compared to mark-to-market gain of $9.2 million in third quarter 2017. We recorded mark-to-market gain of $559,000 in first nine months 2018 compared to a mark-to-market gain of $36.8 million in first nine months 2017. The Rabbi Trust held 2.9 million shares (2.7 million of which were vested) of Range stock at September 30, 2018 compared to 2.9 million shares (2.8 million of which were vested) at December 31, 2017.

Capital Stock

Capital Stock	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Capital Stock	(14) 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 2017: Nine Months Year Beginning balance 248,129,430 247,144,356 Restricted stock grants 853,291 539,096 Restricted stock units vested 430,287 344,937 Performance stock units issued 73,985 85,461 Performance stock dividends 2,164 — Treasury shares issued 4,900 15,580 Ending balance 249,494,057 248,129,430

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	(15) SUPPLEMENTAL CASH FLOW INFORMATION Nine Months Ended September 30, 2018 2017 (in thousands) Net cash provided from operating activities included: Income taxes refunded (paid) to taxing authorities $ 7,521 $ (98 ) Interest paid (161,444 ) (136,863 ) Non-cash investing and financing activities included: Increase in asset retirement costs capitalized 20,452 6,460 (Decrease) increase in accrued capital expenditures (107,070 ) 52,289

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2018
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	(16) 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. Transportation and Gathering Contracts In first nine months 2018, our transportation and gathering commitments increased by approximately $2.4

Office Closing and Termination

Office Closing and Termination Costs	9 Months Ended
	Sep. 30, 2018
Restructuring And Related Activities [Abstract]
Office Closing and Termination Costs	(17) OFFICE CLOSING AND TERMINATION COSTS In first quarter 2017, we recorded accruals for severance, other personnel costs and accelerated vesting of stock-based compensation as part of a continuing effort to reduce our general and administrative expenses due, in part, to the lower commodity price environment. The following summarizes our termination costs for the three months and nine months ended September 30, 2018 and 2017 (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Severance costs $ (356 ) $ — $ (356 ) $ 2,422 Building lease 20 (16 ) (17 ) (37 ) Stock-based compensation — (31 ) — 1,664 Total termination costs $ (336 ) $ (47 ) $ (373 ) $ 4,049 The following details our accrued liability as of September 30, 2018 (in thousands): September 30, 2018 Beginning balance at December 31, 2017 $ 1,855 Accrued severance costs (356 ) Accrued building rent (17 ) Payments (1,417 ) Ending balance at September 30, 2018 $ 65

Suspended Exploratory Well Cost

Suspended Exploratory Well Costs	9 Months Ended
	Sep. 30, 2018
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 September 30, 2018 or December 31, 2017.

Costs Incurred for Property Acq

Costs Incurred for Property Acquisition, Exploration and Development	9 Months Ended
	Sep. 30, 2018
Extractive Industries [Abstract]
Costs Incurred for Property Acquisition, Exploration and Development	(19) Costs Incurred for Property Acquisition, Exploration and Development (a) Nine Months Ended September 30, 2018 Year Ended December 31, 2017 (in thousands) Acquisitions: Acreage purchases $ 40,811 $ 62,075 Oil and gas properties 1,683 18,269 Development 676,896 1,177,526 Exploration: Drilling 805 2,030 Expense 21,990 50,920 Stock-based compensation expense 1,527 2,742 Gas gathering facilities: Development 6,076 15,097 Subtotal 749,788 1,328,659 Asset retirement obligations 20,452 20,245 Total costs incurred $ 770,240 $ 1,348,904 (a) Includes costs incurred whether capitalized or expensed.

Basis of Presentation (Policies

Basis of Presentation (Policies)	9 Months Ended
	Sep. 30, 2018
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Inventory	Inventory. As of September 30, 2018, we had $9.1 million of material and supplies inventory compared to $12.1 million at December 31, 2017. 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 September 30, 2018, we also had commodity inventory of $1.5 million compared to $508,000 at December 31, 2017. Commodity inventory as of September 30, 2018 consists of NGLs held in storage or as line fill in pipelines
Unproved Properties	Unproved Properties. Impairment of a significant portion of our unproved properties is assessed and amortized on an aggregate basis based on our average holding period, expected forfeiture rate and anticipated drilling success. In certain circumstances, our future plans to develop acreage may accelerate our impairment.
New Accounting Standards	Not Yet Adopted Lease Accounting Standard In February 2016, an accounting standards update was issued that requires an entity to recognize a right-of-use asset and lease liability for all leases with terms of more than twelve months. Classification of leases as either a finance or operating lease will determine the recognition, measurement and presentation of expenses. This accounting standards update also requires certain quantitative and qualitative disclosures about leasing arrangements. This standard does not apply to leases 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. We are evaluating each of our lease arrangements and are currently enhancing our systems to track and calculate additional information necessary for adoption of this standard. We are evaluating the provisions of this accounting standards update and assessing the impact it will have on our consolidated results of operations, financial position and financial disclosures, in addition to developing any control changes necessary. While we have yet to finalize the impact this standards update will have on our consolidated financial statements, we believe the adoption will likely increase our recorded assets and liabilities related to our leases. We will adopt this new standards update in first quarter 2019 using a modified retrospective approach and will recognize a right of use asset and lease liability on the adoption date. We plan to apply practical expedients provided in the standards update that allow, among other things, not to reassess contracts that commenced prior to the adoption. We also anticipate to elect a policy not to recognize right of use assets and lease liabilities related to short-term leases. 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 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. We had no service cost recorded prior to 2018 due to the implementation of our postretirement benefit plan at the end of 2017. In 2018, 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 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. The impact of adoption of the new revenue recognition standard on our current period results is as follows (in thousands): Three Months Ended September 30, 2018 As Reported Previous Revenue Recognition Method $ $ Per mcfe $ $ Per mcfe Increase $ Per mcfe Revenues: Natural gas, NGLs and oil sales $ 736,431 $ 3.53 $ 688,684 $ 3.30 $ 47,747 $ 0.23 Costs and expenses: Transportation, gathering, processing and compression $ 304,562 $ 1.46 $ 256,815 $ 1.23 $ 47,747 $ 0.23 Net income $ 48,539 $ 48,539 $ — Nine Months Ended September 30, 2018 As Reported Previous Revenue Recognition Method $ $ Per mcfe $ $ Per mcfe Increase $ Per mcfe Revenues: Natural gas, NGLs and oil sales $ 2,094,450 $ 3.45 $ 1,966,731 $ 3.24 $ 127,719 $ 0.21 Costs and expenses: Transportation, gathering, processing and compression $ 819,100 $ 1.35 $ 691,381 $ 1.14 $ 127,719 $ 0.21 Net income $ 17,941 $ 17,941 $ — Changes to natural gas, NGLs and oil sales and transportation, gathering, processing, and compression expenses is due to the conclusion that we represent the role of principal in a certain gas processing and marketing agreement with a midstream entity in accordance with the new accounting standard. This represents a change from our previous conclusion utilizing the principal versus agent indication that we acted as the agent in that agreement. As a result, we were required to modify our presentation to present revenue on a gross basis for amounts expected to be received from third-party customers through the marketing process, with expenses incurred prior to control of the products transferring to the midstream entity at the tailgate of the plant presented as transportation, gathering, processing and compression expense. Goodwill Standard In January 2017, an accounting standards update was issued that eliminates the requirements to calculate the implied fair value of goodwill to measure goodwill impairment charge. Instead, entities will record an impairment charge based on the excess of a reporting unit’s carrying amount over its fair value. This standard is effective for annual periods beginning after December 15, 2019 and should be applied on a prospective basis. Early adoption is permitted for any goodwill impairment tests performed in first quarter 2017 or later. We elected to adopt this accounting standards update in first quarter 2017. The adoption did not have a significant impact on our consolidated results of operations, financial position, cash flows or disclosures; however, this standard did change our policy for our annual goodwill impairment assessment by eliminating the requirement to calculate the implied fair value of goodwill. Inventory Standard In July 2015, an accounting standards update was issued that requires an entity to measure inventory at the lower of cost or net realizable value. This excludes inventory measured using LIFO or the retail inventory method. This standard was effective for us in first quarter 2017 and was applied prospectively. Adoption of this standard did not have an impact on our consolidated results of operations, financial position or cash flows. Classification in the Statement of Cash Flows In August 2016, an accounting standards update was issued that clarifies how entities classify certain cash receipts and cash payments on the statement of cash flows. The guidance is effective for us in first quarter 2018 and should be applied retrospectively with early adoption permitted. We adopted this new standard in fourth quarter 2017 on a retrospective basis. Adoption of this standard did not have an impact on our consolidated cash flow statement presentation. Definition of a Business In January 2017, an accounting standards update was issued which clarifies the definition of a business. This new standard is effective for us in first quarter 2018 with early adoption permitted. We adopted this new standard in fourth quarter 2017. Adoption of this standard did not have a significant impact on our consolidated results of operations, financial position or cash flows.

New Accounting Standards (Table

New Accounting Standards (Tables)	9 Months Ended
	Sep. 30, 2018
New Accounting Pronouncements And Changes In Accounting Principles [Abstract]
Schedule of Impact of Adoption of New Revenue Recognition Standard	The impact of adoption of the new revenue recognition standard on our current period results is as follows (in thousands): Three Months Ended September 30, 2018 As Reported Previous Revenue Recognition Method $ $ Per mcfe $ $ Per mcfe Increase $ Per mcfe Revenues: Natural gas, NGLs and oil sales $ 736,431 $ 3.53 $ 688,684 $ 3.30 $ 47,747 $ 0.23 Costs and expenses: Transportation, gathering, processing and compression $ 304,562 $ 1.46 $ 256,815 $ 1.23 $ 47,747 $ 0.23 Net income $ 48,539 $ 48,539 $ — Nine Months Ended September 30, 2018 As Reported Previous Revenue Recognition Method $ $ Per mcfe $ $ Per mcfe Increase $ Per mcfe Revenues: Natural gas, NGLs and oil sales $ 2,094,450 $ 3.45 $ 1,966,731 $ 3.24 $ 127,719 $ 0.21 Costs and expenses: Transportation, gathering, processing and compression $ 819,100 $ 1.35 $ 691,381 $ 1.14 $ 127,719 $ 0.21 Net income $ 17,941 $ 17,941 $ —

Revenues from Contracts with _2

Revenues from Contracts with Customers (Tables)	9 Months Ended
	Sep. 30, 2018
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 September 30, 2018 Nine Months Ended September 30, 2018 Natural gas sales (a) $ 500,194 $ 1,449,148 NGLs sales (b) 278,410 706,673 Oil sales 67,212 206,077 Total $ 845,816 $ 2,361,898 (a) Natural gas sales revenue reported above for the third quarter includes $105.8 million of brokered revenues and $3.7 million of marketing revenue. The nine months includes $255.1 million of brokered revenues and $11.4 million of marketing revenue. (b) NGLs sales revenue reported above for the third quarter includes ($153,000) of brokered revenues and for nine months includes $880,000

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2018
Income Tax Disclosure [Abstract]
Income Tax Expense (Benefit)	Income tax expense (benefit) was as follows (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Income tax expense (benefit) $ 24,137 $ (71,992 ) $ 38,295 $ 98,054 Effective tax rate 33.2 % 36.1 % 68.1 % 46.7 %
Summary of Differences In Effective Tax Rate and Federal Statutory Rate Due to State Income Taxes, Equity Compensation and Other Tax Items	For third quarter and first nine months ended 2018 and 2017, 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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Total income (loss) before income taxes $ 72,676 $ (199,692 ) $ 56,236 $ 210,015 U.S. federal statutory rate 21 % 35 % 21 % 35 % Total tax expense (benefit) at statutory rate 15,262 (69,892 ) 11,810 73,505 State and local income taxes, net of federal benefit 2,691 (6,537 ) 3,439 6,591 Non-deductible executive compensation 48 296 601 436 Equity compensation 6 56 2,146 4,808 Change in valuation allowances: Federal net operating loss carryforwards & other — 69 — 3,487 State net operating loss carryforwards & other 5,558 4,286 19,194 10,498 Rabbi trust and other 100 (508 ) 1,499 (1,561 ) Permanent differences and other 472 238 (394 ) 290 Total expense (benefit) for income taxes $ 24,137 $ (71,992 ) $ 38,295 $ 98,054 Effective tax rate 33.2 % 36.1 % 68.1 % 46.7 %

Income (Loss) Per Common Share

Income (Loss) Per Common Share (Tables)	9 Months Ended
	Sep. 30, 2018
Earnings Per Share [Abstract]
Computations of Basic and Diluted (Loss) Income 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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Net income (loss), as reported $ 48,539 $ (127,700 ) $ 17,941 $ 111,961 Participating earnings (a) (590 ) (58 ) (224 ) (1,251 ) Basic net income (loss) attributed to common shareholders 47,949 (127,758 ) 17,717 110,710 Reallocation of participating earnings (a) 2 — — 1 Diluted net income (loss) attributed to common shareholders $ 47,951 $ (127,758 ) $ 17,717 $ 110,711 Net income (loss) per common share: Basic $ 0.19 $ (0.52 ) $ 0.07 $ 0.45 Diluted $ 0.19 $ (0.52 ) $ 0.07 $ 0.45 (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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Weighted average common shares outstanding – basic 246,451 245,244 246,016 245,027 Effect of dilutive securities: Director and employee PSUs and RSUs 715 — 863 253 Weighted average common shares outstanding – diluted 247,166 245,244 246,879 245,280

Capitalized Costs and Accumul_2

Capitalized Costs and Accumulated Depreciation, Depletion and Amortization (Tables)	9 Months Ended
	Sep. 30, 2018
Extractive Industries [Abstract]
Capitalized Costs and Accumulated Depreciation, Depletion and Amortization	September 30, December 31, (in thousands) Natural gas and oil properties: Properties subject to depletion $ 11,041,412 $ 10,572,453 Unproved properties 2,601,784 2,644,000 Total 13,643,196 13,216,453 Accumulated depreciation, depletion and amortization (3,929,060 ) (3,649,716 ) Net capitalized costs $ 9,714,136 $ 9,566,737 (a) Includes capitalized asset retirement costs and the associated accumulated amortization.

Indebtedness (Tables)

Indebtedness (Tables)	9 Months Ended
	Sep. 30, 2018
Debt Disclosure [Abstract]
Debt Outstanding	We had the following debt outstanding as of the dates shown below (bank debt interest rate at September 30, 2018 is shown parenthetically). No interest was capitalized during the three months or nine months ended September 30, 2018 or the year ended December 31, 2017 (in thousands). September 30, 2018 December 31, 2017 Bank debt (3.9%) $ 1,266,000 $ 1,211,000 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 4,192,329 4,137,329 Unamortized premium 5,070 6,027 Unamortized debt issuance costs (36,499 ) (34,550 ) Total debt net of debt issuance costs $ 4,160,900 $ 4,108,806
Summary of Senior Notes Principal Subsequent to Debt Exchange	In September 2016, in conjunction with the acquisition of Memorial Resource Development Corp. (the “MRD Merger”), we issued $329.2 million senior unsecured 5.875% notes due 2022 (the “5.875% Notes”). In addition, we also completed a debt exchange offer to exchange senior subordinated notes for the following senior notes (in thousands): Principal Amount 5.00% senior notes due 2023 $ 741,531 5.00% senior notes due 2022 $ 580,032 5.75% senior notes due 2021 $ 475,952

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	A reconciliation of our liability for plugging and abandonment costs for the nine months ended September 30, 2018 is as follows (in thousands): Nine Months Ended September 30, 2018 Beginning of period $ 276,855 Liabilities incurred 2,668 Disposition of wells (8,665 ) Acquisitions 13,438 Liabilities settled (3,803 ) Accretion expense 12,132 Change in estimate 4,347 End of period 296,972 Less current portion (6,327 ) Long-term asset retirement obligations $ 290,645

Derivative Activities (Tables)

Derivative Activities (Tables)	9 Months Ended
	Sep. 30, 2018
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 September 30, 2018, excluding our basis and freight swaps which are discussed separately below: Period Contract Type Volume Hedged Weighted Natural Gas 2018 Swaps 1,193,370 Mmbtu/day $ 2.96 2019 Swaps 594,589 Mmbtu/day $ 2.82 2018 Calls 70,000 Mmbtu/day $ 3.10 (1) 2018 Swaptions 160,000 Mmbtu/day $ 3.07 (2) 2019 Swaptions 298,014 Mmbtu/day $ 2.86 (2) 2020 Swaptions 10,000 Mmbtu/day $ 2.75 (2) Crude Oil 2018 Swaps 8,500 bbls/day $ 53.20 2019 Swaps 7,000 bbls/day $ 55.26 2020 Swaps 1,500 bbls/day $ 60.63 2019 Collars 1,000 bbls/day $ 63.00 − $ 73.03 NGLs (C3-Propane) 2018 Swaps 11,668 bbls/day $ 0.74/gallon January – June 2019 Swaps 7,500 bbls/day $ 0.92/gallon 2018 Collars 5,000 bbls/day $ 0.95 − $ 1.04 January – March 2019 Collars 6,500 bbls/day $ 0.92 − $1.02 NGLs (NC4-Normal Butane) 2018 Swaps 5,500 bbls/day $ 0.91/gallon January – March 2019 Swaps 2,250 bbls/day $ 1.22/gallon NGLs (C5-Natural Gasoline) 2018 Swaps 5,402 bbls/day $ 1.24/gallon 2019 Swaps 2,178 bbls/day $ 1.42/gallon (1) (2) Contains a combined derivative instrument consisting of a fixed price swap and a sold option to extend or double the volume. For October through December of 2018, we have swaps in place for 160,000 Mmbtu per day on which the counterparty can elect to extend the contract through December 2019 at a weighted average price of $3.07. We have swaps in place for 2019 for 185,000 Mmbtu/day on which the counterparty can elect to double the volume at a weighted average price of $2.89. We also have swaps in place for 2019 for 150,000 Mmbtu per day on which the counterparty can elect to extend the contract through December 2020 at a weighted average price of $2.81. For 2020, we have swaps in place for 10,000 Mmbtu/day on which the counterparty can elect to double the volume at a weighted average price of $2.75.
Combined Fair Value of Derivatives, by Consolidated Balance Sheets	The combined fair value of derivatives included in the accompanying consolidated balance sheets as of September 30, 2018 and December 31, 2017 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): September 30, 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 $ 6,503 $ (4,745 ) $ 1,758 –swaptions 12,893 (12,700 ) 193 –basis swaps 1,246 (1,112 ) 134 Crude oil –swaps — (799 ) (799 ) −collars — (69 ) (69 ) NGLs –C3 propane swaps 3 (3 ) — –C3 propane spread swaps 25,747 (25,747 ) — Freight −swaps 301 (301 ) — $ 46,693 $ (45,476 ) $ 1,217 September 30, 2018 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 $ (10,030 ) $ 4,745 $ (5,285 ) –swaptions (8,759 ) 12,700 3,941 –basis swaps (2,548 ) 1,112 (1,436 ) –calls (504 ) — (504 ) Crude oil –swaps (57,424 ) 799 (56,625 ) −collars (717 ) 69 (648 ) NGLs –C3 propane swaps (20,363 ) 3 (20,360 ) –C3 propane collars (3,237 ) — (3,237 ) –C3 propane spread swaps (27,741 ) 25,747 (1,994 ) –NC4 butane swaps (8,223 ) — (8,223 ) –C5 natural gasoline swaps (14,937 ) — (14,937 ) Freight –swaps — 301 301 $ (154,483 ) $ 45,476 $ (109,007 ) December 31, 2017 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 $ 87,794 $ (4,106 ) $ 83,688 –swaptions 18,817 (8,103 ) 10,714 –basis swaps 1,815 (6,673 ) (4,858 ) –collars 3,039 (500 ) 2,539 Crude oil –swaps 2 (7,928 ) (7,926 ) NGLs –C2 ethane swaps 57 — 57 –C3 propane swaps — (12,556 ) (12,556 ) –C3 propane collars 85 (85 ) — –C3 propane spread swaps 12,762 (12,762 ) — –NC4 butane swaps — (6,051 ) (6,051 ) –C5 natural gasoline swaps — (6,727 ) (6,727 ) Freight –swaps 276 (276 ) — $ 124,647 $ (65,767 ) $ 58,880 December 31, 2017 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 $ (216 ) $ 4,106 $ 3,890 –swaptions (12,283 ) 8,103 (4,180 ) –basis swaps (9,580 ) 6,673 (2,907 ) –collars — 500 500 Crude oil –swaps (24,726 ) 7,928 (16,798 ) NGLs –C3 propane swaps (34,325 ) 12,556 (21,769 ) –C3 propane collars — 85 85 –C3 propane spread swaps (13,983 ) 12,762 (1,221 ) –NC4 butane swaps (11,188 ) 6,051 (5,137 ) –C5 natural gasoline swaps (13,488 ) 6,727 (6,761 ) Freight –swaps — 276 276 $ (119,789 ) $ 65,767 $ (54,022 )
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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Commodity swaps $ (35,868 ) $ (87,861 ) $ (143,598 ) $ 172,457 Swaptions 7,093 (7,602 ) 4,100 (7,602 ) Collars (3,965 ) 956 (4,031 ) 15,221 Puts — (73 ) — 9,646 Calls 197 104 526 1,144 Basis swaps (2,350 ) 6,113 (9,043 ) (2,554 ) Freight swaps 302 (63 ) 156 14 Total $ (34,591 ) $ (88,426 ) $ (151,890 ) $ 188,326

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2018
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 September 30, 2018 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 September 30, 2018 Trading securities held in the deferred compensation plans $ 67,108 $ — $ — $ 67,108 Derivatives – — (104,471 ) — (104,471 ) –collars — (717 ) (3,237 ) (3,954 ) –calls — (504 ) — (504 ) –basis swaps — (3,296 ) — (3,296 ) –freight swaps — 301 — 301 –swaptions — — 4,134 4,134 Fair Value Measurements at December 31, 2017 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, 2017 Trading securities held in the deferred compensation plans $ 67,117 $ — $ — $ 67,117 Derivatives –swaps — 3,910 — 3,910 –collars — 3,039 85 3,124 –basis swaps — (9,025 ) 39 (8,986 ) –freight swaps — 276 — 276 –swaptions — — 6,534 6,534
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 September 30, 2018 Balance at December 31, 2017 $ 6,658 Total losses: Included in earnings 1,876 Settlements (4,690 ) Transfer out of Level 3 (1) (2,947 ) Balance at September 30, 2018 $ 897 (1 )
Value of Assets Measured at Fair Value on Nonrecurring Basis	The following presents the value of these assets measured at fair value on a non-recurring basis at the time impairment was recorded (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Fair Value Impairment Fair Value Impairment Fair Value Impairment Fair Value Impairment Natural gas and oil properties $ — $ — $ 85,597 $ 63,679 $ 32,516 $ 22,614 $ 85,597 $ 63,679
Carrying Amounts and Fair Values of Financial Instruments	The following presents the carrying amounts and the fair values of our financial instruments as of September 30, 2018 and December 31, 2017 (in thousands): September 30, 2018 December 31, 2017 Carrying Fair Carrying Fair Assets: Commodity swaps, options and basis swaps $ 1,217 $ 1,217 $ 58,880 $ 58,880 Marketable securities (a) 67,108 67,108 67,117 67,117 (Liabilities): Commodity swaps, options and basis swaps (109,007 ) (109,007 ) (54,022 ) (54,022 ) Bank credit facility (b) (1,266,000 ) (1,266,000 ) (1,211,000 ) (1,211,000 ) 5.75% senior notes due 2021 (b) (475,952 ) (489,555 ) (475,952 ) (493,872 ) 5.00% senior notes due 2022 (b) (580,032 ) (574,493 ) (580,032 ) (578,727 ) 5.875% senior notes due 2022 (b) (329,244 ) (334,439 ) (329,244 ) (339,200 ) Other senior notes due 2022 (b) (590 ) (586 ) (590 ) (591 ) 5.00% senior notes due 2023 (b) (741,531 ) (728,576 ) (741,531 ) (735,614 ) 4.875% senior notes due 2025 (b) (750,000 ) (712,193 ) (750,000 ) (733,755 ) 5.75% senior subordinated notes due 2021 (b) (22,214 ) (22,825 ) (22,214 ) (22,192 ) 5.00% senior subordinated notes due 2022 (b) (19,054 ) (18,863 ) (19,054 ) (18,741 ) 5.00% senior subordinated notes due 2023 (b) (7,712 ) (7,567 ) (7,712 ) (7,614 ) Deferred compensation plan (c) (112,827 ) (112,827 ) (114,414 ) (114,414 ) (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)	9 Months Ended
	Sep. 30, 2018
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 September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Direct operating expense $ 537 $ 517 $ 1,667 $ 1,563 Brokered natural gas and marketing expense 403 389 1,001 1,040 Exploration expense 405 561 1,527 1,596 General and administrative expense 5,607 9,959 38,332 35,156 Termination costs — (31 ) — 1,665 Total stock-based compensation $ 6,952 $ 11,395 $ 42,527 $ 41,020
Restricted Stock and Restricted Stock Units Outstanding	The following is a summary of the status of our non-vested restricted stock outstanding at September 30, 2018: 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, 2017 833,058 $ 31.64 55,202 $ 32.26 Granted 1,816,432 16.97 877,191 15.30 Vested (792,382 ) 23.76 (733,634 ) 15.99 Forfeited (191,332 ) 21.74 (23,900 ) 19.76 Outstanding at September 30, 2018 1,665,776 $ 20.53 174,859 $ 17.14
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 nine months 2018 and 2017: Nine Months Ended September 30, 2018 2017 Risk-free interest rate 2.42 % 1.49 % Expected annual volatility 48 % 44 % Grant date fair value per unit $ 18.51 $ 26.26
Stock Option and SARs Activities	Information with respect to our SARs activities is summarized below. Shares Weighted Average Exercise Price Outstanding at December 31, 2017 382,779 $ 76.54 Expired/forfeited (381,675 ) 75.97 Outstanding at September 30, 2018 1,104 $ 81.74
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 September Number of Units Weighted Average Grant Date Fair Value Outstanding at December 31, 2017 122,921 $ 18.66 Units granted (a) 440,938 15.22 Forfeited (b) (27,061 ) 23.03 Outstanding at September 30, 2018 536,798 $ 15.61 (a) 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. (b) The first of three tranches of PG-PSUs granted in 2017 are considered forfeited as the performance metric was not met.
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, 2017 1,009,842 $ 38.38 Units granted (a) 329,486 18.51 Vested and issued (b) (73,985 ) 56.81 Forfeited (197,457 ) 55.46 Outstanding at September 30, 2018 1,067,886 $ 27.81 (a) These (b) Includes 73,985 TSR-PSUs awards issued related to the 2015 performance period where the return on our common stock was the 46 th th

Capital Stock (Tables)

Capital Stock (Tables)	9 Months Ended
	Sep. 30, 2018
Equity [Abstract]
Capital Stock	The following is a schedule of changes in the number of common shares outstanding since the beginning of 2017: Nine Months Year Beginning balance 248,129,430 247,144,356 Restricted stock grants 853,291 539,096 Restricted stock units vested 430,287 344,937 Performance stock units issued 73,985 85,461 Performance stock dividends 2,164 — Treasury shares issued 4,900 15,580 Ending balance 249,494,057 248,129,430

Supplemental Cash Flow Inform_2

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Nine Months Ended September 30, 2018 2017 (in thousands) Net cash provided from operating activities included: Income taxes refunded (paid) to taxing authorities $ 7,521 $ (98 ) Interest paid (161,444 ) (136,863 ) Non-cash investing and financing activities included: Increase in asset retirement costs capitalized 20,452 6,460 (Decrease) increase in accrued capital expenditures (107,070 ) 52,289

Office Closing and Terminatio_2

Office Closing and Termination Costs (Tables)	9 Months Ended
	Sep. 30, 2018
Restructuring And Related Activities [Abstract]
Summary of Termination Costs	The following summarizes our termination costs for the three months and nine months ended September 30, 2018 and 2017 (in thousands): Three Months Ended September 30, Nine Months Ended September 30, 2018 2017 2018 2017 Severance costs $ (356 ) $ — $ (356 ) $ 2,422 Building lease 20 (16 ) (17 ) (37 ) Stock-based compensation — (31 ) — 1,664 Total termination costs $ (336 ) $ (47 ) $ (373 ) $ 4,049
Exit Costs Included in Accrued Liabilities in Consolidated Balance Sheet	The following details our accrued liability as of September 30, 2018 (in thousands): September 30, 2018 Beginning balance at December 31, 2017 $ 1,855 Accrued severance costs (356 ) Accrued building rent (17 ) Payments (1,417 ) Ending balance at September 30, 2018 $ 65

Costs Incurred for Property A_2

Costs Incurred for Property Acquisition, Exploration and Development (Tables)	9 Months Ended
	Sep. 30, 2018
Extractive Industries [Abstract]
Costs Incurred for Property Acquisition, Exploration and Development	Nine Months Ended September 30, 2018 Year Ended December 31, 2017 (in thousands) Acquisitions: Acreage purchases $ 40,811 $ 62,075 Oil and gas properties 1,683 18,269 Development 676,896 1,177,526 Exploration: Drilling 805 2,030 Expense 21,990 50,920 Stock-based compensation expense 1,527 2,742 Gas gathering facilities: Development 6,076 15,097 Subtotal 749,788 1,328,659 Asset retirement obligations 20,452 20,245 Total costs incurred $ 770,240 $ 1,348,904 (a) Includes costs incurred whether capitalized or expensed.

Basis of Presentation - Invento

Basis of Presentation - Inventory - Additional Information (Detail) - USD ($)	Sep. 30, 2018	Dec. 31, 2017
Inventory [Line Items]
Inventory and other	$ 24,488,000	$ 21,346,000
Materials and supplies inventory
Inventory [Line Items]
Inventory and other	9,100,000	12,100,000
Commodity inventory
Inventory [Line Items]
Inventory and other	$ 1,500,000	$ 508,000

New Accounting Standards - Sche

New Accounting Standards - Schedule of Impact of Adoption of New Revenue Recognition Standard (Detail) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018USD ($)$ / Mcfe	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)$ / Mcfe	Sep. 30, 2017USD ($)
Revenues:
Revenues	$ 845,816		$ 2,361,898
Natural gas, NGLs and oil sales | $ / Mcfe	3.53		3.45
Costs and expenses:
Transportation, gathering, processing and compression | $ / Mcfe	1.46		1.35
Net income	$ 48,539	$ (127,700)	$ 17,941	$ 111,961
Natural Gas, NGLs and Oil Sales
Revenues:
Revenues	736,431	507,541	2,094,450	1,573,128
Transportation, Gathering, Processing and Compression
Costs and expenses:
Costs and expenses	$ 304,562	$ 191,645	$ 819,100	$ 560,883
Accounting Standards Update 2014-09 | Previous Revenue Recognition
Revenues:
Natural gas, NGLs and oil sales | $ / Mcfe	3.30		3.24
Costs and expenses:
Transportation, gathering, processing and compression | $ / Mcfe	1.23		1.14
Net income	$ 48,539		$ 17,941
Accounting Standards Update 2014-09 | Increase
Revenues:
Natural gas, NGLs and oil sales | $ / Mcfe	0.23		0.21
Costs and expenses:
Transportation, gathering, processing and compression | $ / Mcfe	0.23		0.21
Net income	$ 0		$ 0
Accounting Standards Update 2014-09 | Natural Gas, NGLs and Oil Sales | Previous Revenue Recognition
Revenues:
Revenues	688,684		1,966,731
Accounting Standards Update 2014-09 | Natural Gas, NGLs and Oil Sales | Increase
Revenues:
Revenues	47,747		127,719
Accounting Standards Update 2014-09 | Transportation, Gathering, Processing and Compression | Previous Revenue Recognition
Costs and expenses:
Costs and expenses	256,815		691,381
Accounting Standards Update 2014-09 | Transportation, Gathering, Processing and Compression | Increase
Costs and expenses:
Costs and expenses	$ 47,747		$ 127,719

Dispositions - Additional Infor

Dispositions - Additional Information (Detail) - USD ($)	Oct. 15, 2018	Sep. 30, 2018	Sep. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
(Loss) gain on the sale of assets		$ (30,000)	$ 102,000			$ 149,000	$ 23,509,000
Northern Oklahoma
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
(Loss) gain on the sale of assets		(39,000)
Proceeds from sale of oil and gas properties		23,300,000
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		9,000	102,000	$ 179,000	$ 1,300,000
Proceeds from sale of oil and gas properties		$ 673,000	$ 295,000	$ 366,000	$ 1,300,000
Western Oklahoma Property
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
(Loss) gain on the sale of assets							22,100,000
Proceeds from sale of oil and gas properties							$ 26,000,000
Subsequent Event | Pennsylvania
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Percentage of royalty disposed	1.00%
Proceeds from leases	$ 300,000,000

Revenues from Contracts with _3

Revenues from Contracts with Customers - Additional Information (Detail) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2018USD ($)	Sep. 30, 2018USD ($)Stream	Dec. 31, 2017USD ($)
Disaggregation of Revenue [Line Items]
Net brokered margin gain (loss)	$ (6.7)	$ (7)
Number of revenue streams | Stream		3
Revenue Contract with Customer
Disaggregation of Revenue [Line Items]
Accounts receivable	$ 354.4	$ 354.4	$ 305.7

Revenues from Contracts with _4

Revenues from Contracts with Customers - Disaggregation of Revenue by Identified Revenue Stream (Detail) - USD ($) $ in Thousands		3 Months Ended	9 Months Ended
		Sep. 30, 2018	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Total Revenue		$ 845,816	$ 2,361,898
Natural gas sales
Disaggregation of Revenue [Line Items]
Total Revenue	[1]	500,194	1,449,148
NGLs sales
Disaggregation of Revenue [Line Items]
Total Revenue	[2]	278,410	706,673
Oil sales
Disaggregation of Revenue [Line Items]
Total Revenue		$ 67,212	$ 206,077
[1]	Natural gas sales revenue reported above for the third quarter includes $105.8 million of brokered revenues and $3.7 million of marketing revenue. The nine months includes $255.1 million of brokered revenues and $11.4 million of marketing revenue.
[2]	NGLs sales revenue reported above for the third quarter includes ($153,000) of brokered revenues and for nine months includes $880,000 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	9 Months Ended
		Sep. 30, 2018	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues		$ 845,816	$ 2,361,898
Natural gas sales
Disaggregation of Revenue [Line Items]
Revenues	[1]	500,194	1,449,148
NGLs sales
Disaggregation of Revenue [Line Items]
Revenues	[2]	278,410	706,673
Brokered | Natural gas sales
Disaggregation of Revenue [Line Items]
Revenues		105,800	255,100
Brokered | NGLs sales
Disaggregation of Revenue [Line Items]
Revenues		(153,000)	880,000
Marketing | Natural gas sales
Disaggregation of Revenue [Line Items]
Revenues		$ 3,700	$ 11,400
[1]	Natural gas sales revenue reported above for the third quarter includes $105.8 million of brokered revenues and $3.7 million of marketing revenue. The nine months includes $255.1 million of brokered revenues and $11.4 million of marketing revenue.
[2]	NGLs sales revenue reported above for the third quarter includes ($153,000) of brokered revenues and for nine months includes $880,000 of brokered revenues.

Income Taxes - Income Tax Expen

Income Taxes - Income Tax Expense (Benefit) (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Components Of Income Tax Expense Benefit Continuing Operations [Abstract]
Income tax expense (benefit)	$ 24,137	$ (71,992)	$ 38,295	$ 98,054
Effective tax rate	33.20%	36.10%	68.10%	46.70%

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		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Income Tax Disclosure [Abstract]
Total income (loss) before income taxes	$ 72,676	$ (199,692)	$ 56,236	$ 210,015
U.S. federal statutory rate	21.00%	35.00%	21.00%	35.00%
Total tax expense (benefit) at statutory rate	$ 15,262	$ (69,892)	$ 11,810	$ 73,505
State and local income taxes, net of federal benefit	2,691	(6,537)	3,439	6,591
Non-deductible executive compensation	48	296	601	436
Equity compensation	6	56	2,146	4,808
Change in valuation allowances:
Federal net operating loss carryforwards & other	0	69	0	3,487
State net operating loss carryforwards & other	5,558	4,286	19,194	10,498
Rabbi trust and other	100	(508)	1,499	(1,561)
Permanent differences and other	472	238	(394)	290
Total expense (benefit) for income taxes	$ 24,137	$ (71,992)	$ 38,295	$ 98,054
Effective tax rate	33.20%	36.10%	68.10%	46.70%

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail)	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Income Taxes [Line Items]
Corporate tax rate	21.00%	35.00%	21.00%	35.00%
Amendment on Internal Revenue Code of 1986
Income Taxes [Line Items]
Corporate tax rate			21.00%

Income (Loss) Per Common Shar_2

Income (Loss) Per Common Share - Computations of Basic and Diluted (Loss) Income Per Common Share (Detail) - USD ($) $ / shares in Units, $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Earnings Per Share Reconciliation [Abstract]
Net income (loss)		$ 48,539	$ (127,700)	$ 17,941	$ 111,961
Participating earnings	[1]	(590)	(58)	(224)	(1,251)
Basic net income (loss) attributed to common shareholders		47,949	(127,758)	17,717	110,710
Reallocation of participating earnings	[1]	2	0	0	1
Diluted net income (loss) attributed to common shareholders		$ 47,951	$ (127,758)	$ 17,717	$ 110,711
Net income (loss) per common share:
Basic		$ 0.19	$ (0.52)	$ 0.07	$ 0.45
Diluted		$ 0.19	$ (0.52)	$ 0.07	$ 0.45
[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		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Weighted Average Number Of Shares Outstanding [Abstract]
Weighted average common shares outstanding -basic	246,451	245,244	246,016	245,027
Effect of dilutive securities:
Director and employee PSUs and RSUs	715	0	863	253
Weighted average common shares outstanding – diluted	247,166	245,244	246,879	245,280

Income (Loss) Per Common Shar_4

Income (Loss) Per Common Share - Additional Information (Detail) - shares	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Restricted Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Stock excluded from earning per share calculation	3,000,000	2,900,000	3,100,000	2,800,000
Equity Grants
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Stock excluded from earning per share calculation	506,000		755,000	1,100,000

Capitalized Costs and Accumul_3

Capitalized Costs and Accumulated Depreciation, Depletion and Amortization (Detail) - USD ($) $ in Thousands		Sep. 30, 2018	Dec. 31, 2017
Natural gas and oil properties:
Properties subject to depletion	[1]	$ 11,041,412	$ 10,572,453
Unproved properties	[1]	2,601,784	2,644,000
Total	[1]	13,643,196	13,216,453
Accumulated depletion and depreciation	[1]	(3,929,060)	(3,649,716)
Natural gas and oil properties, successful efforts method, net	[1]	$ 9,714,136	$ 9,566,737
[1]	Includes capitalized asset retirement costs and the associated accumulated amortization.

Indebtedness - Additional Infor

Indebtedness - Additional Information (Detail) - USD ($)	3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2018	Sep. 30, 2018	Dec. 31, 2017
Debt Disclosure [Abstract]
Interest capitalized during the period	$ 0	$ 0	$ 0

Indebtedness - Debt Outstanding

Indebtedness - Debt Outstanding (Detail) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Senior notes	$ 2,877,349	$ 2,877,349
Senior subordinated notes	48,980	48,980
Total debt	4,192,329	4,137,329
Unamortized premium	5,070	6,027
Unamortized debt issuance costs	(36,499)	(34,550)
Total debt net of debt issuance costs	4,160,900	4,108,806
3.9% Bank Debt | Notes Payable to Banks
Debt Instrument [Line Items]
Bank debt (3.9%)	1,266,000	1,211,000
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)	Sep. 30, 2018	Dec. 31, 2017	Oct. 05, 2017	Sep. 30, 2016
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%	5.00%
5.00% Senior Notes Due 2022
Debt Instrument [Line Items]
Interest rate on notes	5.00%	5.00%	5.00%	5.00%
5.75% Senior Notes Due 2021
Debt Instrument [Line Items]
Interest rate on notes	5.75%	5.75%	5.75%	5.75%
5.875% Senior Notes Due 2022
Debt Instrument [Line Items]
Interest rate on notes	5.875%	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 | 3.9% Bank Debt
Debt Instrument [Line Items]
Bank debt percentage	3.90%	3.90%

Indebtedness - Bank Debt - Addi

Indebtedness - Bank Debt - Additional Information (Detail) - Bank Credit Facility	3 Months Ended		9 Months Ended
	Sep. 30, 2018USD ($)CommercialBank	Sep. 30, 2017	Sep. 30, 2018USD ($)CommercialBank	Sep. 30, 2017
Debt Instrument [Line Items]
Bank Credit facility, maximum amount	$ 4,000,000,000		$ 4,000,000,000
Bank Credit facility, initial borrowing base	$ 3,000,000,000		$ 3,000,000,000
Percentage holding of commercial banks, Maximum	5.80%		5.80%
Number of commercial banks included in current bank group | CommercialBank	27		27
Maturity date of loan			Apr. 13, 2023
Bank commitments	$ 2,000,000,000		$ 2,000,000,000
Bank debt	1,300,000,000		1,300,000,000
Undrawn letters of credit	281,400,000		281,400,000
Borrowing capacity available under the commitment amount	$ 452,600,000		$ 452,600,000
Weighted average interest rate on the bank credit facility	3.90%	2.80%	3.70%	2.60%
Annual rate of commitment fee paid on the undrawn balance			0.35%
Alternate Base Rate
Debt Instrument [Line Items]
Interest rate margin			0.75%
LIBOR Rate
Debt Instrument [Line Items]
Interest rate margin			1.75%
Minimum
Debt Instrument [Line Items]
Annual rate of commitment fee paid on the undrawn balance			0.30%
Minimum | Credit Facility
Debt Instrument [Line Items]
Annual rate of commitment fee paid on the undrawn balance			0.15%
Minimum | Alternate Base Rate
Debt Instrument [Line Items]
Base rate on debt	0.25%		0.25%
Minimum | Alternate Base Rate | Credit Facility
Debt Instrument [Line Items]
Base rate on debt	0.125%		0.125%
Minimum | LIBOR Rate
Debt Instrument [Line Items]
Base rate on debt	1.25%		1.25%
Minimum | LIBOR Rate | Credit Facility
Debt Instrument [Line Items]
Base rate on debt	1.125%		1.125%
Maximum
Debt Instrument [Line Items]
Annual rate of commitment fee paid on the undrawn balance			0.375%
Maximum | Credit Facility
Debt Instrument [Line Items]
Annual rate of commitment fee paid on the undrawn balance			0.30%
Maximum | Alternate Base Rate
Debt Instrument [Line Items]
Base rate on debt	1.25%		1.25%
Maximum | Alternate Base Rate | Credit Facility
Debt Instrument [Line Items]
Base rate on debt	0.75%		0.75%
Maximum | LIBOR Rate
Debt Instrument [Line Items]
Base rate on debt	2.25%		2.25%
Maximum | LIBOR Rate | Credit Facility
Debt Instrument [Line Items]
Base rate on debt	1.75%		1.75%

Indebtedness - Senior Notes - A

Indebtedness - Senior Notes - Additional Information (Detail) - USD ($) $ in Thousands	1 Months Ended	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2018	Dec. 31, 2017	Oct. 05, 2017
Senior Notes
Debt Instrument [Line Items]
Maximum redemption price of notes as percentage of principal amount		101.00%
5.875% Senior Notes Due 2022
Debt Instrument [Line Items]
Interest rate on notes		5.875%	5.875%	5.875%
5.875% Senior Notes Due 2022 | Senior Notes Exchange Offer | Unsecured Debt
Debt Instrument [Line Items]
Senior notes exchange amount	$ 329,200
Interest rate on notes	5.875%
5.00% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes exchange amount	$ 741,531
Interest rate on notes	5.00%	5.00%	5.00%	5.00%
5.00% Senior Notes Due 2022
Debt Instrument [Line Items]
Senior notes exchange amount	$ 580,032
Interest rate on notes	5.00%	5.00%	5.00%	5.00%
5.75% Senior Notes Due 2021
Debt Instrument [Line Items]
Senior notes exchange amount	$ 475,952
Interest rate on notes	5.75%	5.75%	5.75%	5.75%

Indebtedness - Summary of Debt

Indebtedness - Summary of Debt Exchange Offer to Exchange Senior Subordinated Notes (Detail) $ in Thousands	1 Months Ended
	Sep. 30, 2016USD ($)
5.00% Senior Notes Due 2023
Debt Instrument [Line Items]
Senior notes	$ 741,531
5.00% Senior Notes Due 2022
Debt Instrument [Line Items]
Senior notes	580,032
5.75% Senior Notes Due 2021
Debt Instrument [Line Items]
Senior notes	$ 475,952

Indebtedness - Summary of Deb_2

Indebtedness - Summary of Debt Exchange Offer to Exchange Senior Subordinated Notes (Parenthetical) (Detail)	Sep. 30, 2018	Dec. 31, 2017	Oct. 05, 2017	Sep. 30, 2016
5.00% Senior Notes Due 2023
Debt Instrument [Line Items]
Interest rate on notes	5.00%	5.00%	5.00%	5.00%
5.00% Senior Notes Due 2022
Debt Instrument [Line Items]
Interest rate on notes	5.00%	5.00%	5.00%	5.00%
5.75% Senior Notes Due 2021
Debt Instrument [Line Items]
Interest rate on notes	5.75%	5.75%	5.75%	5.75%

Indebtedness - Senior Subordina

Indebtedness - Senior Subordinated Notes - Additional Information (Detail)	9 Months Ended
	Sep. 30, 2018
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	9 Months Ended
	Sep. 30, 2018
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 September 30, 2018.
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	9 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Asset Retirement Obligation [Abstract]
Beginning of period	$ 276,855
Liabilities incurred	2,668
Disposition of wells	(8,665)
Acquisitions	13,438
Liabilities settled	(3,803)
Accretion expense	12,132
Change in estimate	4,347
End of period	296,972
Less current portion	(6,327)	$ (6,327)
Long-term asset retirement obligations	$ 290,645

Derivative Activities - Additio

Derivative Activities - Additional Information (Detail)	Sep. 30, 2018USD ($)t_per_MMMBTUbbl
Derivatives Excluding Basis Swaps and Freight Swaps
Derivative [Line Items]
Derivative assets liabilities at fair value net	$ (104,800,000)
Commodity | Basis Swaps | Natural Gas
Derivative [Line Items]
Derivative assets liabilities at fair value net	$ (1,300,000)
Volume Hedged | MMBTU	73,660,000
Commodity | Basis Swaps | Propane
Derivative [Line Items]
Derivative assets liabilities at fair value net	$ (2,000,000)
Commodity | Swaps | Freight | Level 2
Derivative [Line Items]
Derivative assets liabilities at fair value net	$ 301,000
Volume Hedged | t_per_M	5,000
2019 Commodity Contract | Basis Swaps | Propane
Derivative [Line Items]
Volume Hedged | bbl	1,943,000

Derivative Activities - Derivat

Derivative Activities - Derivative Volumes Hedged and Average Hedge Prices (Detail)	Sep. 30, 2018MMBTU / dbbl / d$ / MMBTU$ / bbl$ / gal
2018 Commodity Contract | Swaps | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	1,193,370
Weighted Average Hedge Price | $ / MMBTU	2.96
2018 Commodity Contract | Swaps | Crude Oil
Derivative [Line Items]
Volume Hedged	8,500
Weighted Average Hedge Price | $ / bbl	53.20
2018 Commodity Contract | Swaps | NGLs (C3-Propane)
Derivative [Line Items]
Volume Hedged	11,668
Weighted Average Hedge Price | $ / gal	0.74
2018 Commodity Contract | Swaps | NGLs (NC4-Normal Butane)
Derivative [Line Items]
Volume Hedged	5,500
Weighted Average Hedge Price | $ / gal	0.91
2018 Commodity Contract | Swaps | NGLs (C5-Natural Gasoline)
Derivative [Line Items]
Volume Hedged	5,402
Weighted Average Hedge Price | $ / gal	1.24
2018 Commodity Contract | Calls | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	70,000
Weighted Average Hedge Price | $ / MMBTU	3.10	[1]
2018 Commodity Contract | Swaptions | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	160,000
Weighted Average Hedge Price | $ / MMBTU	3.07	[2]
2018 Commodity Contract | Collars | NGLs (C3-Propane)
Derivative [Line Items]
Volume Hedged	5,000
2018 Commodity Contract | Collars | NGLs (C3-Propane) | Minimum
Derivative [Line Items]
Weighted Average Hedge Price | $ / bbl	0.95
2018 Commodity Contract | Collars | NGLs (C3-Propane) | Maximum
Derivative [Line Items]
Weighted Average Hedge Price | $ / bbl	1.04
2019 Commodity Contract | Swaps | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	594,589
Weighted Average Hedge Price | $ / MMBTU	2.82
2019 Commodity Contract | Swaps | Crude Oil
Derivative [Line Items]
Volume Hedged	7,000
Weighted Average Hedge Price | $ / bbl	55.26
2019 Commodity Contract | Swaps | NGLs (C5-Natural Gasoline)
Derivative [Line Items]
Volume Hedged	2,178
Weighted Average Hedge Price | $ / gal	1.42
2019 Commodity Contract | Swaptions | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	298,014
Weighted Average Hedge Price | $ / MMBTU	2.86	[2]
2019 Commodity Contract | Collars | Crude Oil
Derivative [Line Items]
Volume Hedged	1,000
2019 Commodity Contract | Collars | Crude Oil | Minimum
Derivative [Line Items]
Weighted Average Hedge Price | $ / bbl	63
2019 Commodity Contract | Collars | Crude Oil | Maximum
Derivative [Line Items]
Weighted Average Hedge Price | $ / bbl	73.03
2020 Commodity Contract | Swaps | Crude Oil
Derivative [Line Items]
Volume Hedged	1,500
Weighted Average Hedge Price | $ / bbl	60.63
2020 Commodity Contract | Swaptions | Natural Gas
Derivative [Line Items]
Volume Hedged | MMBTU / d	10,000
Weighted Average Hedge Price | $ / MMBTU	2.75	[2]
January – March 2019 Commodity Contract | Swaps | NGLs (NC4-Normal Butane)
Derivative [Line Items]
Volume Hedged	2,250
Weighted Average Hedge Price | $ / gal	1.22
January – March 2019 Commodity Contract | Collars | NGLs (C3-Propane)
Derivative [Line Items]
Volume Hedged	6,500
January – March 2019 Commodity Contract | Collars | NGLs (C3-Propane) | Minimum
Derivative [Line Items]
Weighted Average Hedge Price | $ / bbl	0.92
January – March 2019 Commodity Contract | Collars | NGLs (C3-Propane) | Maximum
Derivative [Line Items]
Weighted Average Hedge Price | $ / bbl	1.02
January – June 2019 Commodity Contract | Swaps | NGLs (C3-Propane)
Derivative [Line Items]
Volume Hedged	7,500
Weighted Average Hedge Price | $ / gal	0.92
[1]	Weighted average deferred premium of $0.16.
[2]	Contains a combined derivative instrument consisting of a fixed price swap and a sold option to extend or double the volume. For October through December of 2018, we have swaps in place for 160,000 Mmbtu per day on which the counterparty can elect to extend the contract through December 2019 at a weighted average price of $3.07. We have swaps in place for 2019 for 185,000 Mmbtu/day on which the counterparty can elect to double the volume at a weighted average price of $2.89. We also have swaps in place for 2019 for 150,000 Mmbtu per day on which the counterparty can elect to extend the contract through December 2020 at a weighted average price of $2.81. For 2020, we have swaps in place for 10,000 Mmbtu/day on which the counterparty can elect to double the volume at a weighted average price of $2.75.

Derivative Activities - Deriv_2

Derivative Activities - Derivative Volumes Hedged and Average Hedge Prices (Parenthetical) (Detail) - Natural Gas	Sep. 30, 2018MMBTU / d$ / shares$ / MMBTU
October-December 2018 Commodity Contract | Swaps | Counterparty Can Elect to Extend Contract
Derivative [Line Items]
Volume Hedged	160,000
Weighted average price of hedge | $ / shares	3.07
2019 Commodity Contract | Swaps
Derivative [Line Items]
Volume Hedged	594,589
Weighted average price of hedge | $ / MMBTU	2.82
2019 Commodity Contract | Swaps | Counterparty Can Elect to Extend Contract
Derivative [Line Items]
Volume Hedged	150,000
Weighted average price of hedge | $ / shares	2.81
2019 Commodity Contract | Swaps | Counterparty Can Elect To Double Volume
Derivative [Line Items]
Volume Hedged	185,000
Weighted average price of hedge | $ / shares	2.89
2020 Commodity Contract | Swaps | Counterparty Can Elect To Double Volume
Derivative [Line Items]
Volume Hedged	10,000
Weighted average price of hedge | $ / shares	2.75
2018 Commodity Contract | Swaps
Derivative [Line Items]
Volume Hedged	1,193,370
Weighted average price of hedge | $ / MMBTU	2.96
2018 Commodity Contract | Calls
Derivative [Line Items]
Volume Hedged	70,000
Weighted average price of hedge | $ / MMBTU	3.10	[1]
Weighted average deferred premium | $ / MMBTU	0.16
[1]	Weighted average deferred premium of $0.16.

Derivative Activities - Schedul

Derivative Activities - Schedule of Additional Information Related to Master Netting Arrangements with Derivative Counterparties (Detail) - USD ($) $ in Thousands	Sep. 30, 2018	Dec. 31, 2017
Derivative [Line Items]
Gross Amounts of Recognized Assets	$ 46,693	$ 124,647
Gross Amounts Offset in the Balance Sheet	(45,476)	(65,767)
Net Amounts of Assets Presented in the Balance Sheet	1,217	58,880
Gross Amounts of Recognized (Liabilities)	(154,483)	(119,789)
Gross Amounts Offset in the Balance Sheet	45,476	65,767
Net Amounts of (Liabilities) Presented in the Balance Sheet	(109,007)	(54,022)
Commodity | Swaps | Natural Gas
Derivative [Line Items]
Gross Amounts of Recognized Assets	6,503	87,794
Gross Amounts Offset in the Balance Sheet	(4,745)	(4,106)
Net Amounts of Assets Presented in the Balance Sheet	1,758	83,688
Gross Amounts of Recognized (Liabilities)	(10,030)	(216)
Gross Amounts Offset in the Balance Sheet	4,745	4,106
Net Amounts of (Liabilities) Presented in the Balance Sheet	(5,285)	3,890
Commodity | Swaps | Crude Oil
Derivative [Line Items]
Gross Amounts of Recognized Assets	0	2
Gross Amounts Offset in the Balance Sheet	(799)	(7,928)
Net Amounts of Assets Presented in the Balance Sheet	(799)	(7,926)
Gross Amounts of Recognized (Liabilities)	(57,424)	(24,726)
Gross Amounts Offset in the Balance Sheet	799	7,928
Net Amounts of (Liabilities) Presented in the Balance Sheet	(56,625)	(16,798)
Commodity | Swaps | NGLs (C2-Ethane)
Derivative [Line Items]
Gross Amounts of Recognized Assets		57
Gross Amounts Offset in the Balance Sheet		0
Net Amounts of Assets Presented in the Balance Sheet		57
Commodity | Swaps | NGLs (C3-Propane)
Derivative [Line Items]
Gross Amounts of Recognized Assets	3	0
Gross Amounts Offset in the Balance Sheet	(3)	(12,556)
Net Amounts of Assets Presented in the Balance Sheet	0	(12,556)
Gross Amounts of Recognized (Liabilities)	(20,363)	(34,325)
Gross Amounts Offset in the Balance Sheet	3	12,556
Net Amounts of (Liabilities) Presented in the Balance Sheet	(20,360)	(21,769)
Commodity | Swaps | Freight
Derivative [Line Items]
Gross Amounts of Recognized Assets	301	276
Gross Amounts Offset in the Balance Sheet	(301)	(276)
Net Amounts of Assets Presented in the Balance Sheet	0	0
Gross Amounts of Recognized (Liabilities)	0	0
Gross Amounts Offset in the Balance Sheet	301	276
Net Amounts of (Liabilities) Presented in the Balance Sheet	301	276
Commodity | Swaps | NGLs (NC4-Normal Butane)
Derivative [Line Items]
Gross Amounts of Recognized Assets		0
Gross Amounts Offset in the Balance Sheet		(6,051)
Net Amounts of Assets Presented in the Balance Sheet		(6,051)
Gross Amounts of Recognized (Liabilities)	(8,223)	(11,188)
Gross Amounts Offset in the Balance Sheet	0	6,051
Net Amounts of (Liabilities) Presented in the Balance Sheet	(8,223)	(5,137)
Commodity | Swaps | NGLs (C5-Natural Gasoline)
Derivative [Line Items]
Gross Amounts of Recognized Assets		0
Gross Amounts Offset in the Balance Sheet		(6,727)
Net Amounts of Assets Presented in the Balance Sheet		(6,727)
Gross Amounts of Recognized (Liabilities)	(14,937)	(13,488)
Gross Amounts Offset in the Balance Sheet	0	6,727
Net Amounts of (Liabilities) Presented in the Balance Sheet	(14,937)	(6,761)
Commodity | Swaptions | Natural Gas
Derivative [Line Items]
Gross Amounts of Recognized Assets	12,893	18,817
Gross Amounts Offset in the Balance Sheet	(12,700)	(8,103)
Net Amounts of Assets Presented in the Balance Sheet	193	10,714
Gross Amounts of Recognized (Liabilities)	(8,759)	(12,283)
Gross Amounts Offset in the Balance Sheet	12,700	8,103
Net Amounts of (Liabilities) Presented in the Balance Sheet	3,941	(4,180)
Commodity | Basis Swaps | Natural Gas
Derivative [Line Items]
Gross Amounts of Recognized Assets	1,246	1,815
Gross Amounts Offset in the Balance Sheet	(1,112)	(6,673)
Net Amounts of Assets Presented in the Balance Sheet	134	(4,858)
Gross Amounts of Recognized (Liabilities)	(2,548)	(9,580)
Gross Amounts Offset in the Balance Sheet	1,112	6,673
Net Amounts of (Liabilities) Presented in the Balance Sheet	(1,436)	(2,907)
Commodity | Collars | Natural Gas
Derivative [Line Items]
Gross Amounts of Recognized Assets		3,039
Gross Amounts Offset in the Balance Sheet		(500)
Net Amounts of Assets Presented in the Balance Sheet		2,539
Gross Amounts of Recognized (Liabilities)		0
Gross Amounts Offset in the Balance Sheet		500
Net Amounts of (Liabilities) Presented in the Balance Sheet		500
Commodity | Collars | Crude Oil
Derivative [Line Items]
Gross Amounts of Recognized Assets	0
Gross Amounts Offset in the Balance Sheet	(69)
Net Amounts of Assets Presented in the Balance Sheet	(69)
Gross Amounts of Recognized (Liabilities)	(717)
Gross Amounts Offset in the Balance Sheet	69
Net Amounts of (Liabilities) Presented in the Balance Sheet	(648)
Commodity | Collars | NGLs (C3-Propane)
Derivative [Line Items]
Gross Amounts of Recognized Assets		85
Gross Amounts Offset in the Balance Sheet		(85)
Net Amounts of Assets Presented in the Balance Sheet		0
Gross Amounts of Recognized (Liabilities)	(3,237)	0
Gross Amounts Offset in the Balance Sheet	0	85
Net Amounts of (Liabilities) Presented in the Balance Sheet	(3,237)	85
Commodity | Spread Swaps | NGLs (C3-Propane)
Derivative [Line Items]
Gross Amounts of Recognized Assets	25,747	12,762
Gross Amounts Offset in the Balance Sheet	(25,747)	(12,762)
Net Amounts of Assets Presented in the Balance Sheet	0	0
Gross Amounts of Recognized (Liabilities)	(27,741)	(13,983)
Gross Amounts Offset in the Balance Sheet	25,747	12,762
Net Amounts of (Liabilities) Presented in the Balance Sheet	(1,994)	$ (1,221)
Commodity | Calls | Natural Gas
Derivative [Line Items]
Gross Amounts of Recognized (Liabilities)	(504)
Gross Amounts Offset in the Balance Sheet	0
Net Amounts of (Liabilities) Presented in the Balance Sheet	$ (504)

Derivative Activities - Effects

Derivative Activities - Effects of Derivatives on Consolidated Statements of Operations (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Derivative [Line Items]
Derivative Fair Value (Loss) Income	$ (34,591)	$ (88,426)	$ (151,890)	$ 188,326
Swaptions
Derivative [Line Items]
Derivative Fair Value (Loss) Income	7,093	(7,602)	4,100	(7,602)
Collars
Derivative [Line Items]
Derivative Fair Value (Loss) Income	(3,965)	956	(4,031)	15,221
Puts
Derivative [Line Items]
Derivative Fair Value (Loss) Income	0	(73)	0	9,646
Calls
Derivative [Line Items]
Derivative Fair Value (Loss) Income	197	104	526	1,144
Basis Swaps
Derivative [Line Items]
Derivative Fair Value (Loss) Income	(2,350)	6,113	(9,043)	(2,554)
Commodity | Swaps
Derivative [Line Items]
Derivative Fair Value (Loss) Income	(35,868)	(87,861)	(143,598)	172,457
Freight | Commodity | Swaps
Derivative [Line Items]
Derivative Fair Value (Loss) Income	$ 302	$ (63)	$ 156	$ 14

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	Sep. 30, 2018	Dec. 31, 2017
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Trading securities held in the deferred compensation plans	$ 67,108	$ 67,117
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	67,108	67,117
Swaps
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(104,471)	3,910
Swaps | Freight
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	301	276
Swaps | Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(104,471)	3,910
Swaps | Fair Value, Inputs, Level 2 | Freight
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	301	276
Collars
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(3,954)	3,124
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	(3,237)	85
Collars | Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(717)	3,039
Calls
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(504)
Calls | Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(504)
Basis Swaps
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(3,296)	(8,986)
Basis Swaps | 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		39
Basis Swaps | Fair Value, Inputs, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	(3,296)	(9,025)
Swaptions
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivative assets liabilities at fair value net	4,134	6,534
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	$ 4,134	$ 6,534

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	9 Months Ended
	Sep. 30, 2018USD ($)
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Balance at December 31, 2017	$ 6,658
Total losses included in earnings	1,876
Settlements	(4,690)
Transfer out of Level 3	(2,947)	[1]
Balance at September 30, 2018	$ 897
[1]	During first nine months 2018, we transferred $2.9 million of swaption contracts out of Level 3 due to the exercise of these swaptions by our counterparties.

Fair Value Measurements - Rec_2

Fair Value Measurements - Reconciliation of the Beginning and Ending Balances for Derivative Instruments Classified as Level 3 in the Fair Value Hierarchy (Parenthetical) (Detail) $ in Thousands	9 Months Ended
	Sep. 30, 2018USD ($)
Fair Value, Inputs, Level 3
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Transfer out of Level 3	$ 2,947	[1]
[1]	During first nine months 2018, we transferred $2.9 million of swaption contracts out of Level 3 due to the exercise of these swaptions by our counterparties.

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail)	3 Months Ended				9 Months Ended
	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Sep. 30, 2017USD ($)	Sep. 30, 2018USD ($)Counterparty	Sep. 30, 2017USD ($)	Dec. 31, 2017USD ($)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Interest and dividends	$ 225,000			$ 1,500,000	$ 606,000	$ 2,400,000
Mark-to-market gain	1,300,000			1,100,000	522,000	4,100,000
Impairment on natural gas and oil properties	0			63,679,000	22,614,000	$ 63,679,000
Allowance for doubtful accounts on accounts receivable	5,862,000				$ 5,862,000		$ 7,111,000
Number of financial institutions included in counter parties | Counterparty					21
Number of counterparties | Counterparty					5
Net derivative liability	$ 23,900,000				$ 23,900,000
Oklahoma
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Impairment on natural gas and oil properties			$ 7,300,000
Northwest Pennsylvania
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets, fair value		$ 0
Impairment on natural gas and oil properties		$ 15,300,000
Oklahoma And Texas Panhandle
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Impairment on natural gas and oil properties				$ 63,700,000

Fair Value Measurements - Value

Fair Value Measurements - Value of Assets Measured at Fair Value on Nonrecurring Basis (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Impairment of proved properties	$ 0	$ 63,679	$ 22,614	$ 63,679
Fair Value, Measurements, Nonrecurring | Natural Gas and Oil Properties
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Fair Value	$ 32,516	85,597	32,516	85,597
Impairment of proved properties		$ 63,679	$ 22,614	$ 63,679

Fair Value Measurements - Carry

Fair Value Measurements - Carrying Amounts and Fair Values of Financial Instruments (Detail) - USD ($) $ in Thousands		Sep. 30, 2018	Dec. 31, 2017
Carrying Value
Assets:
Commodity swaps, options and basis swaps		$ 1,217	$ 58,880
Marketable securities	[1]	67,108	67,117
(Liabilities):
Commodity swaps, options and basis swaps		(109,007)	(54,022)
Bank credit facility	[2]	(1,266,000)	(1,211,000)
Deferred compensation plan	[3]	(112,827)	(114,414)
Fair Value
Assets:
Commodity swaps, options and basis swaps		1,217	58,880
Marketable securities	[1]	67,108	67,117
(Liabilities):
Commodity swaps, options and basis swaps		(109,007)	(54,022)
Bank credit facility	[2]	(1,266,000)	(1,211,000)
Deferred compensation plan	[3]	(112,827)	(114,414)
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]	(489,555)	(493,872)
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]	(574,493)	(578,727)
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]	(334,439)	(339,200)
Other Senior Notes Due 2022 | Carrying Value
(Liabilities):
Senior notes	[2]	(590)	(590)
Other Senior Notes Due 2022 | Fair Value
(Liabilities):
Senior notes	[2]	(586)	(591)
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]	(728,576)	(735,614)
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]	(712,193)	(733,755)
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]	(22,825)	(22,192)
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]	(18,863)	(18,741)
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]	$ (7,567)	$ (7,614)
[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)	Sep. 30, 2018	Dec. 31, 2017	Oct. 05, 2017	Sep. 30, 2016
5.75% Senior Notes Due 2021
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.75%	5.75%	5.75%	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%	5.00%	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%	5.875%
5.00% Senior Notes Due 2023
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Interest rate on notes	5.00%	5.00%	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)	9 Months Ended
	Sep. 30, 2018Plans
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		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	$ 6,952	$ 11,395	$ 42,527	$ 41,020
Direct Operating Expense
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	537	517	1,667	1,563
Brokered Natural Gas and Marketing Expense
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	403	389	1,001	1,040
Exploration Expense
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	405	561	1,527	1,596
General and Administrative Expense
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	5,607	9,959	38,332	35,156
Termination Costs
Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Line Items]
Stock-based compensation expense	$ 0	$ (31)	$ 0	$ 1,665

Stock-based Compensation Plan_4

Stock-based Compensation Plans - Additional Information 1 (Detail)	9 Months Ended
	Sep. 30, 2018Awardshares	Dec. 31, 2017shares
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 granted represents | 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	1,104	382,779

Stock-based Compensation Plan_5

Stock-based Compensation Plans - Additional Information 2 (Detail) - USD ($) $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Restricted Stock Equity Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	1,816,432	883,000
Granted, weighted average grant date fair value	$ 16.97	$ 32.81
Vesting period	3 years
Stock-based compensation expense	$ 18.2	$ 18.1
Restricted Stock Liability Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	877,191
Granted, weighted average grant date fair value	$ 15.30
Stock-based compensation expense	$ 11	$ 12
Restricted Stock Liability Awards | Employees
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	877,000	451,000
Granted, weighted average grant date fair value	$ 15.30	$ 25.95
Vesting period	3 years	3 years
Restricted Stock Liability Awards | Non-Employee Directors
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	138,000	90,000
Granted, weighted average grant date fair value	$ 15.54	$ 25.01

Stock-based Compensation Plan_6

Stock-based Compensation Plans - Restricted Stock and Restricted Stock Units Outstanding (Detail) - $ / shares	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Restricted Stock Equity Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Beginning Balance	833,058
Granted	1,816,432	883,000
Vested	(792,382)
Forfeited	(191,332)
Outstanding, Ending Balance	1,665,776
Outstanding, Beginning Balance, weighted average grant date fair value	$ 31.64
Granted, weighted average grant date fair value	16.97	$ 32.81
Vested, weighted average grant date fair value	23.76
Forfeited, weighted average grant date fair value	21.74
Outstanding, Ending Balance, weighted average grant date fair value	$ 20.53
Restricted Stock Liability Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Beginning Balance	55,202
Granted	877,191
Vested	(733,634)
Forfeited	(23,900)
Outstanding, Ending Balance	174,859
Outstanding, Beginning Balance, weighted average grant date fair value	$ 32.26
Granted, weighted average grant date fair value	15.30
Vested, weighted average grant date fair value	15.99
Forfeited, weighted average grant date fair value	19.76
Outstanding, Ending Balance, weighted average grant date fair value	$ 17.14

Stock-based Compensation Plan_7

Stock-based Compensation Plans - Additional Information 3 (Detail) - USD ($)	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
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	$ 5,800,000	$ 124,000
Performance Based TSR - PSUs
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vesting period	3 years
Stock-based compensation expense	$ 6,100,000	$ 9,700,000

Stock-based Compensation Plan_8

Stock-based Compensation Plans - PG/RG-PSUs Activities (Detail) - Performance-based PG-PSUs and RG-PSUs	9 Months Ended
	Sep. 30, 2018$ / sharesshares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding, Beginning Balance | shares	122,921
Granted | shares	440,938	[1]
Forfeited | shares	(27,061)	[2]
Outstanding, Ending Balance | shares	536,798
Outstanding, Beginning Balance, weighted average grant date fair value | $ / shares	$ 18.66
Granted, weighted average grant date fair value | $ / shares	15.22	[1]
Forfeited, weighted average grant date fair value | $ / shares	23.03	[2]
Outstanding, Ending Balance, weighted average grant date fair value | $ / shares	$ 15.61
[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.
[2]	The first of three tranches of PG-PSUs granted in 2017 are considered forfeited as the performance metric was not met.

Stock-based Compensation Plan_9

Stock-based Compensation Plans - PG/RG-PSUs Activities (Parenthetical) (Detail) - Performance-based PG-PSUs and RG-PSUs	9 Months Ended
	Sep. 30, 2018Tranche
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of tranches forfeited	1
Total Number of tranches in PSU	3
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	9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Risk-free interest rate	2.42%	1.49%
Expected annual volatility	48.00%	44.00%
Grant date fair value per unit	$ 18.51	$ 26.26

Stock-based Compensation Pla_11

Stock-based Compensation Plans - TSR - PSUs Activities (Detail) - Performance Based TSR - PSUs	9 Months Ended
	Sep. 30, 2018$ / sharesshares
Summary of Performance Share Unit Awards outstanding, Number of Units
Outstanding, Beginning Balance | shares	1,009,842
Granted | shares	329,486	[1]
Vested and issued | shares	(73,985)	[2]
Forfeited | shares	(197,457)
Outstanding, Ending Balance | shares	1,067,886
Summary of Performance Share Unit Awards outstanding, Weighted Average Grant Date Fair Value
Outstanding, Beginning Balance, weighted average grant date fair value | $ / shares	$ 38.38
Granted, weighted average grant date fair value | $ / shares	18.51	[1]
Vested, weighted average grant date fair value | $ / shares	56.81	[2]
Forfeited, weighted average grant date fair value | $ / shares	55.46
Outstanding, Ending Balance, weighted average grant date fair value | $ / shares	$ 27.81
[1]	These amounts reflect the number of performance units granted. The actual payout of shares may be between zero and 200% of the performance units granted depending on the total shareholder return ranking compared to our peer companies at the vesting date.
[2]	Includes 73,985 TSR-PSUs awards issued related to the 2015 performance period where the return on our common stock was the 46th percentile for the February 2015 grant and 36th percentile for the May 2015 grant. The remaining 2015 awards are considered to be forfeited.

Stock-based Compensation Pla_12

Stock-based Compensation Plans - TSR - PSUs Activities (Parenthetical) (Detail) - Performance Based TSR - PSUs	9 Months Ended
	Sep. 30, 2018shares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares vested and issued related to performance period number of common stock	73,985	[1]
February 2015 Grant
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Return on common stock percentile	46.00%
May 2015 Grant
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Return on common stock percentile	36.00%
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 73,985 TSR-PSUs awards issued related to the 2015 performance period where the return on our common stock was the 46th percentile for the February 2015 grant and 36th percentile for the May 2015 grant. The remaining 2015 awards are considered to be forfeited.

Stock-based Compensation Pla_13

Stock-based Compensation Plans - Stock Option and SARs Activities (Detail) - Stock Appreciation Rights (SARs)	9 Months Ended
	Sep. 30, 2018$ / sharesshares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Beginning Balance, Shares | shares	382,779
Expired/forfeited, Shares | shares	(381,675)
Ending Balance, Shares | shares	1,104
Beginning Balance, Weighted Average Exercise Price | $ / shares	$ 76.54
Expired/forfeited, Weighted Average Exercise Price | $ / shares	75.97
Ending Balance, 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		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Deferred compensation plan vesting period			3 years
Deferred compensation plan	$ (223,000)	$ 9,203,000	$ 559,000	$ 36,838,000
Shares held in rabbi trust total	2.9		2.9		2.9
Vested shares held in rabbi trust	2.7		2.7		2.8
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			$ 276,000

Capital Stock - Additional Info

Capital Stock - Additional Information (Detail) - shares	Sep. 30, 2018	Dec. 31, 2017
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	9 Months Ended	12 Months Ended
	Sep. 30, 2018	Dec. 31, 2017
Class Of Stock [Line Items]
Beginning balance	248,129,430	247,144,356
Restricted stock grants	853,291	539,096
Treasury shares issued	4,900	15,580
Ending balance	249,494,057	248,129,430
Restricted Stock
Class Of Stock [Line Items]
Restricted stock units vested	430,287	344,937
Performance Share
Class Of Stock [Line Items]
Performance stock units issued	73,985	85,461
Performance stock dividends	2,164

Supplemental Cash Flow Inform_3

Supplemental Cash Flow Information - Supplemental Cash Flow Information (Detail) - USD ($) $ in Thousands	9 Months Ended			12 Months Ended
	Sep. 30, 2018		Sep. 30, 2017	Dec. 31, 2017	[1]
Net cash provided from operating activities included:
Income taxes refunded (paid) to taxing authorities	$ 7,521		$ (98)
Interest paid	(161,444)		(136,863)
Non-cash investing and financing activities included:
Increase in asset retirement costs capitalized	20,452	[1]	6,460	$ 20,245
(Decrease) increase in accrued capital expenditures	$ (107,070)		$ 52,289
[1]	Includes costs incurred whether capitalized or expensed.

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail) $ in Billions	9 Months Ended
	Sep. 30, 2018USD ($)
Commitments And Contingencies Disclosure [Abstract]
Transportation commitments future minimum transportation fees due to nine months change	$ 2.4
Period of transportation commitments future minimum transportation fees due to nine months change	20 years
Transportation commitments future minimum transportation fees due to nine months change, end year	2,038

Office Closing and Terminatio_3

Office Closing and Termination Costs - Summary of Termination Costs (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Restructuring And Related Activities [Abstract]
Severance costs	$ (356)	$ 0	$ (356)	$ 2,422
Building lease	20	(16)	(17)	(37)
Stock-based compensation	0	(31)	0	1,664
Total termination costs	$ (336)	$ (47)	$ (373)	$ 4,049

Office Closing and Terminatio_4

Office Closing and Termination Costs - Exit Costs Included in Accrued Liabilities in Consolidated Balance Sheet (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2018	Sep. 30, 2017	Sep. 30, 2018	Sep. 30, 2017
Exit costs included in accrued liabilities in consolidated balance sheet
Beginning balance at December 31, 2017			$ 1,855
Accrued severance costs	$ (356)	$ 0	(356)	$ 2,422
Accrued building rent			(17)
Payments			(1,417)
Ending balance at September 30, 2018	$ 65		$ 65

Suspended Exploratory Well Co_2

Suspended Exploratory Well Costs - Additional Information (Detail) - USD ($)	Sep. 30, 2018	Dec. 31, 2017
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		9 Months Ended			12 Months Ended
		Sep. 30, 2018		Sep. 30, 2017	Dec. 31, 2017
Acquisitions:
Acreage purchases	[1]	$ 40,811			$ 62,075
Oil and gas properties	[1]	1,683			18,269
Development	[1]	676,896			1,177,526
Exploration:
Exploration drilling costs incurred	[1]	805			2,030
Gas gathering facilities:
Development	[1]	6,076			15,097
Subtotal	[1]	749,788			1,328,659
Asset retirement obligations		20,452	[1]	$ 6,460	20,245	[1]
Total costs incurred	[1]	770,240			1,348,904
Expense
Exploration:
Exploration costs incurred	[1]	21,990			50,920
Stock-based compensation expense	[1]	$ 1,527			$ 2,742
[1]	Includes costs incurred whether capitalized or expensed.