EQT (EQT) 10-Q 26 Jul 18 2018 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information shares in Millions	6 Months Ended
	Jun. 30, 2018shares
Document and Entity Information
Entity Registrant Name	EQT Corp
Entity Central Index Key	33,213
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Amendment Flag	false
Entity Common Stock, Shares Outstanding	264

Statements of Consolidated Oper

Statements of Consolidated Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Revenues:
Sales of natural gas, oil and NGLs	$ 1,104,779		$ 2,454,977
(Loss) gain on derivatives not designated as hedges	(53,897)	$ 46,326	8,695	$ 187,068
Total operating revenues	1,054,671	688,742	2,488,254	1,582,911
Operating expenses:
Transportation and processing	200,050	134,818	390,190	268,524
Operation and maintenance	25,302	18,315	52,326	35,132
Production	47,881	44,276	106,720	89,948
Exploration	21,182	3,481	26,286	6,603
Selling, general and administrative	77,813	52,670	130,428	124,628
Depreciation and depletion	417,672	240,817	855,565	472,735
Impairment/loss on sale of long-lived assets	118,114	0	2,447,159	0
Transaction costs	25,959	4,238	61,670	4,238
Amortization of intangible assets	20,729	0	41,457	0
Total operating expenses	954,702	498,615	4,111,801	1,001,808
Operating income (loss)	99,969	190,127	(1,623,547)	581,103
Other income	11,752	6,305	21,337	9,354
Interest expense	77,004	44,078	147,017	86,733
Income (loss) before income taxes	34,717	152,354	(1,749,227)	503,724
Income tax (benefit) expense	(101,629)	29,709	(440,594)	130,374
Net income (loss)	136,346	122,645	(1,308,633)	373,350
Less: Net income attributable to noncontrolling interests	118,540	81,519	259,555	168,232
Net income (loss) attributable to EQT Corporation	$ 17,806	$ 41,126	$ (1,568,188)	$ 205,118
Basic:
Weighted average common stock outstanding (in shares)	265,030	173,462	264,920	173,320
Net income (loss) (in dollars per share)	$ 0.07	$ 0.24	$ (5.92)	$ 1.18
Diluted:
Weighted average common stock outstanding (in shares)	265,154	173,582	264,920	173,525
Net income (loss) (in dollars per share)	$ 0.07	$ 0.24	$ (5.92)	$ 1.18
Dividends declared per common share (in dollars per share)	$ 0.03	$ 0.03	$ 0.06	$ 0.06
Sales of natural gas, oil and NGLs
Revenues:
Sales of natural gas, oil and NGLs	$ 991,365	$ 576,714	$ 2,217,739	$ 1,250,179
Pipeline, water and net marketing services
Revenues:
Pipeline, water and net marketing services	$ 117,203	$ 65,702	$ 261,820	$ 145,664

Statements of Consolidated Comp

Statements of Consolidated Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Net income (loss)	$ 136,346	$ 122,645	$ (1,308,633)	$ 373,350
Net change in cash flow hedges:
Natural gas, net of tax benefit of $(163), $(1,101), $(263), and $(1,685)	(466)	(1,672)	(753)	(2,560)
Interest rate, net of tax expense of $26, $27, $44, and $52	36	36	80	72
Other post-retirement benefits liability adjustment, net of tax expense of $30, $49, $60, and $98	86	77	172	153
Other comprehensive loss	(344)	(1,559)	(501)	(2,335)
Comprehensive income (loss)	136,002	121,086	(1,309,134)	371,015
Less: Comprehensive income attributable to noncontrolling interests	118,540	81,519	259,555	168,232
Comprehensive income (loss) attributable to EQT Corporation	$ 17,462	$ 39,567	$ (1,568,689)	$ 202,783

Statements of Consolidated Com4

Statements of Consolidated Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Statement of Comprehensive Income [Abstract]
Natural gas, tax benefit	$ (163)	$ (1,101)	$ (263)	$ (1,685)
Interest rate, tax expense	26	27	44	52
Other post-retirement benefits liability adjustment, tax expense	$ 30	$ 49	$ 60	$ 98

Statements of Condensed Consoli

Statements of Condensed Consolidated Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Cash flows from operating activities:
Net income (loss)	$ (1,308,633)	$ 373,350
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Deferred income taxes	(440,342)	130,088
Depreciation and depletion	855,565	472,735
Amortization of intangible assets	41,457	0
Amortization of financing costs	5,805	0
Asset and lease impairments	2,470,567	4,101
Provision for losses on accounts receivable	(191)	(962)
Other income	(21,337)	(9,354)
Stock-based compensation expense	14,548	21,297
Gain on derivatives not designated as hedges	(8,695)	(187,068)
Cash settlements paid on derivatives not designated as hedges	(13,116)	(20,158)
Changes in other assets and liabilities:
Accounts receivable	46,741	32,013
Accounts payable	(18,368)	5,759
Other items, net	(82,877)	(12,807)
Net cash provided by operating activities	1,541,124	808,994
Cash flows from investing activities:
Capital expenditures	(1,697,090)	(680,456)
Capital expenditures for acquisitions	0	(811,207)
Deposit received for Huron Divestiture (see Note Q)	57,500	0
Sales of investments in trading securities	0	283,758
Capital contributions to Mountain Valley Pipeline, LLC	(182,805)	(59,940)
Proceeds from sale of Permian Basin assets	60,157	0
Net cash used in investing activities	(1,762,238)	(1,267,845)
Cash flows from financing activities:
Proceeds from issuance of EQT Midstream Partners, LP Senior Notes	2,500,000	0
Increase in borrowings on credit facilities	4,377,500	0
Repayment of borrowings on credit facilities	(5,638,500)	0
Dividends paid	(15,898)	(10,413)
Distributions to noncontrolling interests	(180,745)	(111,994)
Repayments and retirements of Senior Notes	(7,999)	0
Proceeds from awards under employee compensation plans	1,946	0
Cash paid for taxes related to net settlement of share-based incentive awards	(20,483)	(17,573)
Acquisition of 25% of Strike Force Midstream LLC	(175,000)	0
Repurchase and retirement of common stock	(38,677)	0
Repurchase of common stock	(18)	(15)
Net cash provided by (used in) financing activities	771,831	(147,345)
Net change in cash, cash equivalents and restricted cash	550,717	(606,196)
Cash, cash equivalents and restricted cash at beginning of period	147,315	1,178,540
Cash and cash equivalents at end of period	698,032	572,344
Cash paid during the period for:
Interest, net of amount capitalized	145,334	89,554
Income taxes, net	156	9,702
Senior Notes
Cash flows from financing activities:
Debt discount and issuance costs	(30,295)	0
Bridge Loan
Cash flows from financing activities:
Debt discount and issuance costs	$ 0	$ (7,350)

Statements of Condensed Consol6

Statements of Condensed Consolidated Cash Flows (Unaudited) Statements of Condensed Consolidated Cash Flows (Unaudited) (Parenthetical)	Jun. 30, 2018
Statement of Cash Flows [Abstract]
Percentage of voting interests acquired	25.00%

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 698,032	$ 147,315
Accounts receivable (less accumulated provision for doubtful accounts: $8,036 at June 30, 2018 and $8,226 at December 31, 2017)	774,702	725,236
Derivative instruments, at fair value	270,288	241,952
Prepaid expenses and other	37,790	48,552
Total current assets	1,780,812	1,163,055
Property, plant and equipment	27,722,025	30,990,309
Less: accumulated depreciation and depletion	4,557,359	6,105,294
Net property, plant and equipment	23,164,666	24,885,015
Intangible assets, net	694,903	736,360
Goodwill	1,998,726	1,998,726
Investment in nonconsolidated entity	1,003,299	460,546
Other assets	320,822	278,902
Total assets	28,963,228	29,522,604
Current liabilities:
Current portion of Senior Notes	699,324	7,999
Accounts payable	754,120	654,624
Derivative instruments, at fair value	146,061	139,089
Other current liabilities	756,738	430,525
Total current liabilities	2,356,243	1,232,237
Credit facility borrowings	500,000	1,761,000
Senior Notes	7,333,587	5,562,555
Deferred income taxes	1,324,352	1,768,900
Other liabilities and credits	746,427	783,299
Total liabilities	12,260,609	11,107,991
Shareholders’ equity:
Common stock, no par value, authorized 320,000 shares, shares issued: 267,171 at June 30, 2018 and 267,871 at December 31, 2017	9,316,209	9,388,903
Treasury stock, shares at cost: 2,840 at June 30, 2018 (including 298 held in rabbi trust) and 3,551 at December 31, 2017 (including 253 held in rabbi trust)	(50,769)	(63,602)
Retained earnings	2,416,802	3,996,775
Accumulated other comprehensive loss	(2,959)	(2,458)
Total common shareholders’ equity	11,679,283	13,319,618
Noncontrolling interests in consolidated subsidiaries	5,023,336	5,094,995
Total equity	16,702,619	18,414,613
Total liabilities and equity	$ 28,963,228	$ 29,522,604

Condensed Consolidated Balance8

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Accounts receivable, accumulated provision for doubtful accounts	$ 8,036	$ 8,226
Common stock, par value (in dollars per share)	$ 0	$ 0
Common stock, authorized shares (in shares)	320,000,000	320,000,000
Common stock, shares issued (in shares)	267,171,000	267,871,000
Treasury stock, shares at cost (in shares)	2,840,000	3,551,000
Treasury stock, shares held in rabbi trust (in shares)	298,000	253,000

Statements of Condensed Consol9

Statements of Condensed Consolidated Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands		Total	Common Stock	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests in Consolidated Subsidiaries
Beginning Balance (in shares) at Dec. 31, 2016			172,827
Beginning Balance at Dec. 31, 2016		$ 9,119,247	$ 3,349,166	$ 2,509,073	$ 2,042	$ 3,258,966
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net income (loss)		373,350		205,118		168,232
Net change in cash flow hedges:
Natural gas, net of tax benefit		(2,560)			(2,560)
Interest rate, net of tax expense		72			72
Other post-retirement benefit liability adjustment, net of tax expense		153			153
Dividends		(10,413)		(10,413)
Stock-based compensation plans, net (in shares)			500
Stock-based compensation plans, net		9,715	$ 9,525			190
Distributions to noncontrolling interests		(111,994)				(111,994)
Ending Balance (in shares) at Jun. 30, 2017			173,327
Ending Balance at Jun. 30, 2017		9,377,570	$ 3,358,691	2,703,778	(293)	3,315,394
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net income (loss)		122,645
Net change in cash flow hedges:
Natural gas, net of tax benefit		(1,672)
Other post-retirement benefit liability adjustment, net of tax expense		77
Ending Balance (in shares) at Jun. 30, 2017			173,327
Ending Balance at Jun. 30, 2017		9,377,570	$ 3,358,691	2,703,778	(293)	3,315,394
Net change in cash flow hedges:
Change in accounting principle	[1]	4,113		4,113
Beginning Balance (in shares) at Dec. 31, 2017			264,320
Beginning Balance at Dec. 31, 2017		18,414,613	$ 9,325,301	3,996,775	(2,458)	5,094,995
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net income (loss)		(1,308,633)		(1,568,188)		259,555
Net change in cash flow hedges:
Natural gas, net of tax benefit		(753)			(753)
Interest rate, net of tax expense		80			80
Other post-retirement benefit liability adjustment, net of tax expense		172			172
Dividends		(15,898)		(15,898)
Stock-based compensation plans, net (in shares)			711
Stock-based compensation plans, net		(2,788)	$ (3,279)			491
Distributions to noncontrolling interests		(180,745)				(180,745)
Repurchase and retirement of common stock (in shares)			(700)
Repurchase and retirement of common stock		(38,677)	$ (38,677)
Purchase of Strike Force Midstream LLC noncontrolling interests		(175,000)	1,818			(176,818)
Change in ownership of consolidated subsidiaries		6,135	$ (19,723)			25,858
Ending Balance (in shares) at Jun. 30, 2018			264,331
Ending Balance at Jun. 30, 2018		16,702,619	$ 9,265,440	2,416,802	(2,959)	5,023,336
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net income (loss)		136,346
Net change in cash flow hedges:
Natural gas, net of tax benefit		(466)
Other post-retirement benefit liability adjustment, net of tax expense		86
Ending Balance (in shares) at Jun. 30, 2018			264,331
Ending Balance at Jun. 30, 2018		$ 16,702,619	$ 9,265,440	$ 2,416,802	$ (2,959)	$ 5,023,336
[1]	Related to adoption of ASU No. 2016-01. See Notes K and S for additional information.

Statements of Condensed Conso10

Statements of Condensed Consolidated Equity (Unaudited) (Parenthetical) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Natural gas, tax expense (benefit)	$ (263)	$ (1,685)
Interest rate, tax expense (benefit)	44	52
Other post-retirement benefits liability adjustment, tax expense	$ 60	$ 98
Dividends (in dollars per share)	$ 0.06	$ 0.06
EQM
Distributions to noncontrolling interests (in dollars per share)	2.09	1.74
EQGP
Distributions to noncontrolling interests (in dollars per share)	0.502	$ 0.368
Rice Midstream Partners, LP
Distributions to noncontrolling interests (in dollars per share)	$ 0.5966

Financial Statements

Financial Statements	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Financial Statements	Financial Statements The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with United States generally accepted accounting principles (GAAP) for interim financial information and with the requirements of Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by United States GAAP for complete financial statements. In the opinion of management, these statements include all adjustments (consisting of only normal recurring accruals, unless otherwise disclosed in this Quarterly Report on Form 10-Q) necessary for a fair presentation of the financial position of EQT Corporation and subsidiaries as of June 30, 2018 and December 31, 2017 , the results of its operations for the three and six month periods ended June 30, 2018 and 2017 and its cash flows and equity for the six month periods ended June 30, 2018 and 2017 . Certain previously reported amounts have been reclassified to conform to the current year presentation. In this Quarterly Report on Form 10-Q, references to “we,” “us,” “our,” “EQT,” “EQT Corporation,” and the “Company” refer collectively to EQT Corporation and its consolidated subsidiaries. The balance sheet at December 31, 2017 has been derived from the audited financial statements at that date but does not include all of the information and footnotes required by GAAP for complete financial statements. For further information, refer to the consolidated financial statements and related footnotes as well as “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 . On November 13, 2017, the Company completed its previously announced acquisition of Rice Energy Inc. (Rice) pursuant to the Agreement and Plan of Merger, dated June 19, 2017 (as amended, the Rice Merger Agreement), by and among the Company, Rice and a wholly owned indirect subsidiary of the Company (RE Merger Sub). Pursuant to the terms of the Rice Merger Agreement, on November 13, 2017, RE Merger Sub merged with and into Rice (the Rice Merger) with Rice continuing as the surviving corporation and a wholly owned indirect subsidiary of the Company. Immediately thereafter, Rice merged with and into another wholly owned indirect subsidiary of the Company. As a result of the Rice Merger, the Company also acquired Rice's interests in Rice Midstream Partners LP (RMP). See Note E . Unaudited Pro Forma Information The following unaudited pro forma combined financial information presents the Company’s results as though the Rice Merger had been completed at January 1, 2017. The pro forma combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the Rice Merger taken place on January 1, 2017; furthermore, the financial information is not intended to be a projection of future results. (in thousands, except per share data) (unaudited) Three Months Ended June 30, 2017 Six Months Ended June 30, 2017 Pro forma operating revenues $ 1,183,044 $ 2,449,427 Pro forma net income $ 246,313 $ 482,383 Pro forma net income attributable to noncontrolling interests $ (111,108 ) $ (220,193 ) Pro forma net income attributable to EQT $ 135,205 $ 262,190 Pro forma income per share (basic) $ 0.51 $ 0.99 Pro forma income per share (diluted) $ 0.51 $ 0.99

Midstream Streamlining Transact

Midstream Streamlining Transactions and Financing	6 Months Ended
	Jun. 30, 2018
Business Combinations [Abstract]
Midstream Streamlining Transactions and Financing	In February 2018, the Company's Board of Directors unanimously approved a plan to separate its upstream and midstream businesses, creating a standalone publicly traded corporation (SpinCo) that will focus on midstream operations (the Separation). SpinCo will own the midstream interests held by EQT. The Separation is intended to qualify as tax-free to EQT shareholders for U.S. federal income tax purposes. Under the Separation plan, EQT shareholders will retain their shares of the Company's stock and receive a pro-rata distribution of 80.1% of the outstanding shares of SpinCo common stock. In connection with announcing the planned Separation, the Company also announced its plans to pursue (i) a sale of Rice retained midstream assets acquired by EQT in connection with the Rice Merger to EQT Midstream Partners, LP (EQM) (NYSE: EQM); (ii) a merger of EQM and RMP; and (iii) a sale of RMP’s incentive distribution rights (IDRs) to EQT GP Holdings, LP (EQGP) (NYSE: EQGP)((i), (ii) and (iii) collectively, the Midstream Streamlining Transactions). On April 25, 2018, EQT, Rice Midstream Holdings LLC (Rice Midstream), a wholly owned subsidiary of the Company, EQM and EQM Gathering Holdings, LLC (EQM Gathering), a wholly owned subsidiary of EQM, entered into a contribution and sale agreement pursuant to which EQM Gathering agreed to acquire all the outstanding limited liability company interests in each of (i) Rice West Virginia Midstream LLC (Rice West Virginia), (ii) Rice Olympus Midstream LLC (Rice Olympus) and (iii) Strike Force Midstream Holdings LLC (Strike Force Holdings), which owns a 75% limited liability company interest in Strike Force Midstream LLC (Strike Force Midstream), in exchange for an aggregate of 5,889,282 EQM common units and cash consideration of $1.15 billion , plus working capital adjustments (the Drop-Down Transaction). The Drop-Down Transaction was completed on May 22, 2018 with an effective date of May 1, 2018. In connection with the Drop-Down Transaction, the Company recorded a $15.5 million gain to additional paid-in-capital, a decrease in noncontrolling interest in consolidated subsidiary of $20.3 million and an increase to deferred tax liability of $4.8 million . On May 1, 2018, pursuant to the Purchase and Sale Agreement dated April 25, 2018, by and among EQM, EQM Gathering, Gulfport Energy Corporation (Gulfport) and an affiliate of Gulfport, EQM Gathering acquired the remaining 25% limited liability company interest in Strike Force Midstream not owned by Strike Force Holdings for $175 million (the Gulfport Transaction). As a result, EQM has owned 100% of Strike Force Midstream since May 1, 2018. On May 22, 2018, pursuant to an Incentive Distribution Rights Purchase and Sale agreement dated April 25, 2018, by and among the Company, Rice Midstream GP Holdings (Rice Midstream GP Holdings), a wholly owned subsidiary of the Company that owned the RMP IDRs, and EQGP, EQGP acquired all of the issued and outstanding RMP IDRs in exchange for 36,293,766 EQGP common units (the RMP IDR Purchase). As a result of the RMP IDR Purchase, EQT's percentage ownership of the outstanding EQGP common units increased from approximately 90.1% to approximately 91.3% . In connection with the RMP IDR Purchase, the Company recorded a $35.1 million loss to additional paid-in-capital, an increase in noncontrolling interest in consolidated subsidiary of $46.1 million and a decrease to deferred tax liability of $11.0 million . On April 25, 2018, EQM entered into an Agreement and Plan of Merger (the Midstream Merger Agreement) with RMP, Rice Midstream Management LLC, the general partner of RMP (the RMP General Partner), EQT Midstream Services, LLC, the general partner of EQM (the EQM General Partner), EQM Acquisition Sub, LLC, a wholly owned subsidiary of EQM (Merger Sub), EQM GP Acquisition Sub, LLC, a wholly owned subsidiary of EQM (GP Merger Sub), and, solely for certain limited purposes set forth therein, the Company. Pursuant to the Midstream Merger Agreement, on July 23, 2018, Merger Sub and GP Merger Sub merged with and into RMP and the RMP General Partner, respectively, with RMP and the RMP General Partner surviving as wholly owned subsidiaries of EQM (the Midstream Mergers). Pursuant to the Midstream Merger Agreement, each RMP common unit issued and outstanding immediately prior to the effective time of the Midstream Mergers was converted into the right to receive 0.3319 EQM common units (the Midstream Mergers Consideration), the issued and outstanding RMP IDRs were canceled and each outstanding award of phantom units in respect of RMP common units fully vested and converted into the right to receive the Midstream Mergers Consideration, less applicable tax withholding, in respect of each RMP common unit subject thereto. The aggregate Midstream Mergers Consideration consisted of approximately 34 million EQM common units. As a result of the Midstream Mergers, RMP's common units are no longer publicly traded. Also in connection with the completion of the Midstream Mergers, on July 23, 2018, EQM repaid approximately $260 million of borrowings outstanding under the Credit Agreement, dated as of December 22, 2014, by and among RMP, as parent guarantor, Rice Midstream OpCo LLC, a wholly owned subsidiary of RMP (RMP OpCo), as borrower, Wells Fargo Bank, N.A., as administrative agent, and the lenders and other parties from time to time party thereto (the RMP Credit Agreement), and the RMP Credit Agreement was terminated. On April 25, 2018, EQM entered a $2.5 billion unsecured multi-draw 364-day term loan facility with a syndicate of lenders (the EQM Term Loan Facility). The EQM Term Loan Facility was used to fund the cash consideration for the Drop-Down Transaction, to repay borrowings under EQM’s $1 billion credit facility, and for other general partnership purposes. During the second quarter of 2018, the balance outstanding under the EQM Term Loan Facility was repaid, and the EQM Term Loan Facility was terminated on June 25, 2018 in connection with EQM's issuance of the EQM 2018 Senior Notes (described in the following section). As a result of the termination of the EQM Term Loan Facility, EQM expensed $3 million of deferred issuance costs. From April 25, 2018 through June 25, 2018, the maximum amount of EQM's outstanding borrowings under the EQM Term Loan Facility at any time was $1,825 million and the average daily balance was approximately $1,231 million . EQM incurred interest at a weighted average annual interest rate of approximately 3.3% for the period from April 25, 2018 through June 25, 2018. During the second quarter of 2018, EQM issued 4.75% senior notes due July 15, 2023 in the aggregate principal amount of $1.1 billion , 5.50% senior notes due July 15, 2028 in the aggregate principal amount of $850 million and 6.50% senior notes due July 15, 2048 in the aggregate principal amount of $550 million (collectively, the EQM 2018 Senior Notes). The offering of the EQM 2018 Senior Notes resulted in net proceeds of approximately $2,465.8 million , inclusive of a discount of $11.8 million and estimated debt issuance costs of $22.4 million . The net proceeds were used to repay the balance outstanding under the EQM Term Loan Facility and the RMP Credit Agreement and the remainder is expected to be used for general partnership purposes. The EQM 2018 Senior Notes were issued pursuant to new supplemental indentures to EQM's existing indenture dated August 1, 2014. The EQM 2018 Senior Notes contain covenants that limit EQM's ability to, among other things, incur certain liens securing indebtedness, engage in certain sale and leaseback transactions, and enter into certain consolidations, mergers, conveyances, transfers or leases of all of substantially all of EQM's assets. As a result of the Midstream Mergers, on July 23, 2018, an indirect wholly owned subsidiary of the Company received 9,554,530 EQM common units as Midstream Mergers Consideration. Acquisitions On February 1, 2017, the Company acquired approximately 14,000 net Marcellus acres located in Marion, Monongalia and Wetzel Counties of West Virginia from a third-party. On February 27, 2017, the Company acquired approximately 85,000 net Marcellus acres, including drilling rights on approximately 44,000 net Utica acres and current natural gas production of approximately 110 MMcfe per day, from Stone Energy Corporation. The acquired acres are primarily located in Wetzel, Marshall, Tyler and Marion Counties of West Virginia. The acquired assets also included 174 Marcellus wells, 120 of which were producing at the time of the acquisition, and 20 miles of gathering pipeline. During the first half of 2017, the Company paid net cash of $736.0 million and assumed liabilities estimated at $11.9 million as of June 30, 2017. Furthermore, the Company paid $75.2 million and recorded a deduction of $2.2 million of non-cash capital expenditures as a result of post-closing adjustments on 2016 acquisitions in the second quarter 2017. Fair Value Measurement As these acquisitions qualified as business combinations under GAAP, the fair value of the acquired assets was determined using a market approach for the undeveloped acreage and a discounted cash flow model under the income approach for the wells. Significant unobservable inputs used in the analysis included the determination of estimated developed reserves and forward pricing estimates. As a result, valuation of the acquired assets was a Level 3 fair value measurement.

EQT GP Holdings, LP

EQT GP Holdings, LP	6 Months Ended
	Jun. 30, 2018
Equity [Abstract]
EQT GP Holdings, LP	EQT GP Holdings, LP In January 2015, the Company formed EQGP to own the Company's partnership interests in EQM. EQGP issued an additional 36,293,766 common units to Rice Midstream GP Holdings in the RMP IDR Purchase, which increased EQT's limited partner interest in EQGP. As of June 30, 2018, EQT owns 276,008,766 EQGP common units, which represent a 91.3% limited partner interest, and the entire non-economic general partner interest in EQGP. EQGP owned the following EQM partnership interests as of June 30, 2018 , which represent EQGP’s only cash-generating assets: 21,811,643 EQM common units, representing a 24.8% limited partner interest in EQM; 1,443,015 EQM general partner units, representing a 1.6% general partner interest in EQM; and all of EQM’s IDRs, which entitle EQGP to receive up to 48.0% of all incremental cash distributed in a quarter after $0.5250 has been distributed in respect of each common unit and general partner unit of EQM for that quarter. Through EQGP's general partner interest, limited partner interest and IDRs in EQM, EQGP has a controlling financial interest in EQM; therefore, EQGP consolidates EQM. The Company is the ultimate parent company of EQGP and EQM. On July 24, 2018, the Board of Directors of EQGP's general partner declared a cash distribution to EQGP’s unitholders for the second quarter of 2018 of $0.306 per common unit, or approximately $92.6 million . The distribution will be paid on August 23, 2018 to unitholders of record, including the Company, at the close of business on August 3, 2018. Based on the EQGP common units outstanding on July 26, 2018 , the cash distributions by EQGP to EQT for the second quarter 2018 will be approximately $84.5 million . EQT Midstream Partners, LP In January 2012, the Company formed EQM to own, operate, acquire and develop midstream assets in the Appalachian Basin. EQM provides midstream services to the Company and third parties. EQM is consolidated in the Company’s financial statements. The Company records the noncontrolling interest of the EQM public limited partners in its financial statements. As a result of the Drop-Down Transaction, in addition to the EQM common units owned by EQGP, as of June 30, 2018, EQT owned 5,889,282 EQM common units representing an additional 6.7% limited partner interest in EQM. On July 24, 2018, the Board of Directors of EQM's general partner declared a cash distribution to EQM’s unitholders for the second quarter of 2018 of $1.09 per common unit. The cash distribution will be paid on August 14, 2018 to unitholders of record, including EQGP, at the close of business on August 3, 2018. Based on the EQM common units outstanding on July 26, 2018 , the cash distributions by EQM to EQGP for the second quarter 2018 will be approximately $94.3 million consisting of: $23.8 million in respect of its limited partner interest, $2.4 million in respect of its general partner interest and $68.1 million in respect of its IDRs. The distribution amounts to EQGP related to its general partner interest and IDRs in EQM are subject to change if EQM issues additional common units on or prior to the record date for the second quarter 2018 distribution. Based on the EQM common units outstanding on July 26, 2018 , the cash distributions by EQM to EQT for the second quarter 2018 will be approximately $16.8 million .

EQT Midstream Partners, LP

EQT Midstream Partners, LP	6 Months Ended
	Jun. 30, 2018
Equity [Abstract]
EQT Midstream Partners, LP	EQT GP Holdings, LP In January 2015, the Company formed EQGP to own the Company's partnership interests in EQM. EQGP issued an additional 36,293,766 common units to Rice Midstream GP Holdings in the RMP IDR Purchase, which increased EQT's limited partner interest in EQGP. As of June 30, 2018, EQT owns 276,008,766 EQGP common units, which represent a 91.3% limited partner interest, and the entire non-economic general partner interest in EQGP. EQGP owned the following EQM partnership interests as of June 30, 2018 , which represent EQGP’s only cash-generating assets: 21,811,643 EQM common units, representing a 24.8% limited partner interest in EQM; 1,443,015 EQM general partner units, representing a 1.6% general partner interest in EQM; and all of EQM’s IDRs, which entitle EQGP to receive up to 48.0% of all incremental cash distributed in a quarter after $0.5250 has been distributed in respect of each common unit and general partner unit of EQM for that quarter. Through EQGP's general partner interest, limited partner interest and IDRs in EQM, EQGP has a controlling financial interest in EQM; therefore, EQGP consolidates EQM. The Company is the ultimate parent company of EQGP and EQM. On July 24, 2018, the Board of Directors of EQGP's general partner declared a cash distribution to EQGP’s unitholders for the second quarter of 2018 of $0.306 per common unit, or approximately $92.6 million . The distribution will be paid on August 23, 2018 to unitholders of record, including the Company, at the close of business on August 3, 2018. Based on the EQGP common units outstanding on July 26, 2018 , the cash distributions by EQGP to EQT for the second quarter 2018 will be approximately $84.5 million . EQT Midstream Partners, LP In January 2012, the Company formed EQM to own, operate, acquire and develop midstream assets in the Appalachian Basin. EQM provides midstream services to the Company and third parties. EQM is consolidated in the Company’s financial statements. The Company records the noncontrolling interest of the EQM public limited partners in its financial statements. As a result of the Drop-Down Transaction, in addition to the EQM common units owned by EQGP, as of June 30, 2018, EQT owned 5,889,282 EQM common units representing an additional 6.7% limited partner interest in EQM. On July 24, 2018, the Board of Directors of EQM's general partner declared a cash distribution to EQM’s unitholders for the second quarter of 2018 of $1.09 per common unit. The cash distribution will be paid on August 14, 2018 to unitholders of record, including EQGP, at the close of business on August 3, 2018. Based on the EQM common units outstanding on July 26, 2018 , the cash distributions by EQM to EQGP for the second quarter 2018 will be approximately $94.3 million consisting of: $23.8 million in respect of its limited partner interest, $2.4 million in respect of its general partner interest and $68.1 million in respect of its IDRs. The distribution amounts to EQGP related to its general partner interest and IDRs in EQM are subject to change if EQM issues additional common units on or prior to the record date for the second quarter 2018 distribution. Based on the EQM common units outstanding on July 26, 2018 , the cash distributions by EQM to EQT for the second quarter 2018 will be approximately $16.8 million .

Rice Midstream Partners LP Rice

Rice Midstream Partners LP Rice Midstream Partners LP	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Rice Midstream Partners LP	Rice Midstream Partners LP In connection with the Rice Merger, the Company acquired a 28.1% limited partner interest, all of the IDRs and the entire non-economic general partner interest in RMP. See the discussion of the RMP IDR Purchase and Midstream Mergers in Note B . Due to the timing of the Midstream Mergers, RMP did not declare a cash distribution for the second quarter 2018. Investment in Nonconsolidated Entity The Mountain Valley Pipeline, LLC (MVP Joint Venture) is constructing the Mountain Valley Pipeline (MVP), an estimated 300 -mile natural gas interstate pipeline spanning from northern West Virginia to southern Virginia. EQM is the operator of the MVP and owned a 45.5% interest in the MVP Joint Venture as of June 30, 2018 . The MVP Joint Venture is a variable interest entity because it has insufficient equity to finance its activities during the construction stage of the project. EQM is not the primary beneficiary because it does not have the power to direct the activities of the MVP Joint Venture that most significantly impact its economic performance. Certain business decisions require the approval of owners holding more than a 66 2/3% interest in the MVP Joint Venture and no one member owns more than a 66 2/3% interest. The MVP Joint Venture is an equity method investment for accounting purposes as EQM has the ability to exercise significant influence over operating and financial policies of the MVP Joint Venture. The MVP Joint Venture has modified its construction schedule for the MVP and now anticipates a first quarter 2019 in-service date. As currently designed, the total cost for the MVP is expected to be $3.5 billion to $3.7 billion , excluding Allowance for Funds Used During Construction (AFUDC). In May 2018, the MVP Joint Venture issued a capital call notice to MVP Holdco, LLC (MVP Holdco), a direct wholly owned subsidiary of EQM, for $445.9 million , of which $193.4 million was paid in July 2018 and $252.5 million is expected to be paid in the third quarter of 2018. The capital contribution payable has been reflected on the Condensed Consolidated Balance Sheet as of June 30, 2018 with a corresponding increase to the Company's investment in the MVP Joint Venture. Equity income is primarily EQM's portion of the MVP Joint Venture's AFUDC on construction of the MVP. As of June 30, 2018 , EQM had issued a $91 million performance guarantee in favor of the MVP Joint Venture to provide performance assurances for MVP Holdco's obligations to fund its proportionate share of the construction budget for the MVP. As of June 30, 2018 , EQM's maximum financial statement exposure related to the MVP Joint Venture was approximately $1,094 million , which consists of the investment in nonconsolidated entity balance on the Condensed Consolidated Balance Sheet as of June 30, 2018 and amounts that could have become due under EQM's performance guarantee as of that date. In April 2018, the MVP Joint Venture announced the MVP Southgate project, a proposed 70 -mile interstate pipeline that will extend from the MVP at Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina. The MVP Southgate project is anchored by a firm capacity commitment from PSNC Energy. The preliminary MVP Southgate project cost estimate is $350 million to $500 million , which is expected to be spent in 2019 and 2020. EQM is expected to have between 33% and 48% ownership in the MVP Southgate project and will operate the pipeline. Subject to approval by the FERC, the MVP Southgate has a targeted in-service date of the fourth quarter 2020.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	Revenue from Contracts with Customers As discussed in Note S , the Company adopted Accounting Standard Update (ASU) No. 2014-09, Revenue from Contracts with Customers (Topic 606) , on January 1, 2018 using the modified retrospective method of adoption. Adoption of the ASU did not require an adjustment to the opening balance of equity and did not materially change the Company's amount and timing of revenues. The Company applied the ASU only to contracts that were not completed as of January 1, 2018. The Company has elected to exclude all taxes from the measurement of transaction price. For the sale of natural gas, oil and natural gas liquids (NGLs), the Company generally considers the delivery of each unit (MMBtu or Bbl) to be a separate performance obligation that is satisfied upon delivery. These contracts typically require payment within 25 days of the end of the calendar month in which the gas is delivered. A significant number of these contracts contain variable consideration because the payment terms refer to market prices at future delivery dates. In these situations, the Company has not identified a standalone selling price because the terms of the variable payments relate specifically to the Company’s efforts to satisfy the performance obligations. Other contracts contain fixed consideration (i.e. fixed price contracts or contracts with a fixed differential to NYMEX or index prices). The fixed consideration is allocated to each performance obligation on a relative standalone selling price basis, which requires judgment from management. For these contracts, the Company generally concludes that the fixed price or fixed differentials in the contracts are representative of the standalone selling price. Based on management’s judgment, the performance obligations for the sale of natural gas, oil and NGLs are satisfied at a point in time because the customer obtains control and legal title of the asset when the natural gas, oil or NGL is delivered to the designated sales point. The sales of natural gas, oil and NGLs as presented on the Statements of Consolidated Operations represent the Company’s share of revenues net of royalties and excluding revenue interests owned by others. When selling natural gas, oil and NGLs on behalf of royalty owners or working interest owners, the Company is acting as an agent and thus reports the revenue on a net basis. The Company provides gathering, transmission and storage services in two manners: firm service and interruptible service. Firm service contracts are typically long term and include firm reservation fees, which are fixed, monthly charges for the guaranteed reservation of pipeline or storage capacity. Volumetric based fees under firm contracts include usage fees and charges for actual volumes transported, gathered or stored in excess of firm contracted volume. Interruptible service contracts include volumetric based fees, which are charges for the volume of gas actually gathered, transported or stored and do not guarantee access to the pipeline or storage facility. These contracts can be short or long term. Firm and interruptible contracts are billed at the end of each calendar month, with payment typically due within 21 days. Based on total projected contractual revenues and including contracts associated with expected future capacity from expansion projects that are not yet fully constructed but for which EQM has entered into firm contracts, EQM's firm gathering contracts and firm transmission and storage contracts had weighted average remaining terms of approximately 8 and 15 years, respectively, as of December 31, 2017. Under a firm contract, the Company has a stand-ready obligation to provide the service over the life of the contract. The performance obligation for firm reservation fee revenue is satisfied over time as the pipeline capacity is made available to the customer. As such, the Company recognizes firm reservation fee revenue evenly over the contract period, using a time-elapsed output method to measure progress. The performance obligation for volumetric based fee revenues for usage fees under firm and interruptible contracts is generally satisfied upon the Company's monthly billing to the customer for actual volumes gathered, transported or stored during the month. The amount billed corresponds directly to the value of the Company’s performance to date as the customer obtains value as each volume is gathered, transported or stored. Certain of EQM's gas gathering agreements are structured with minimum volume commitments (MVC), which specify quantities for which a customer will be charged regardless of actual quantities gathered under the contract. Revenue is recognized for MVCs when the performance obligation has been met, which is the earlier of when the gas is gathered or when it is remote that the producer will be able to meet its MVC. Water services revenues primarily represent fees charged by RMP for the delivery of fresh water to a customer at a specified delivery point. All of RMP’s water services revenues are generated pursuant to variable price per volume contracts with customers in the Appalachian Basin. For water services contracts, the only performance obligation in each contract is for RMP to provide water (usually a minimum daily volume) to the customer at any designated delivery point. This performance obligation is generally satisfied upon RMP’s monthly billing to the customer for the volume of water provided during the month. For water services arrangements, the customer is typically invoiced on a monthly basis with payment due 21 days after the receipt of the invoice. Because the Company's performance obligations have been satisfied and an unconditional right to consideration exists as of the balance sheet date, the Company has recognized amounts due from contracts with customers of $441.1 million as accounts receivable within the Condensed Consolidated Balance Sheet. The table below provides disaggregated information regarding the Company’s revenues, presented consistently with the Company’s segment reporting. Certain contracts that provide for the release of capacity that is not used to transport the Company’s produced volumes were deemed to be outside the scope of Revenue from Contracts with Customers. The cost of, and recoveries on, that capacity are reported within pipeline and net marketing services at EQT Production. Derivative contracts are also outside the scope of Revenue from Contracts with Customers. Three Months Ended June 30, 2018 Revenues from contracts with customers Other sources of revenue Total (Thousands) Natural gas sales $ 855,924 $ — $ 855,924 NGLs sales 125,657 — 125,657 Oil sales 9,784 — 9,784 Sales of natural gas, oil and NGLs $ 991,365 $ — $ 991,365 Pipeline and net marketing services at EQT Production $ 9,391 $ 3,789 $ 13,180 EQM Gathering: Firm reservation fee revenues 111,702 — 111,702 Volumetric based fee revenues: Usage fees under firm contracts 9,956 — 9,956 Usage fees under interruptible contracts 58,958 — 58,958 EQM Transmission: Firm reservation fee revenues 82,222 — 82,222 Volumetric based fee revenues: Usage fees under firm contracts 4,828 — 4,828 Usage fees under interruptible contracts 2,095 — 2,095 RMP Gathering: Gathering revenues 52,966 — 52,966 Compression revenues 9,315 — 9,315 Water services at RMP Water 42,655 — 42,655 Intersegment eliminations (270,674 ) — (270,674 ) Pipeline, water and net marketing services $ 113,414 $ 3,789 $ 117,203 Loss on derivatives not designated as hedges $ — $ (53,897 ) $ (53,897 ) Total operating revenues $ 1,104,779 $ (50,108 ) $ 1,054,671 Six Months Ended June 30, 2018 Revenues from contracts with customers Other sources of revenue Total (Thousands) Natural gas sales $ 1,945,684 $ — $ 1,945,684 NGLs sales 251,125 — 251,125 Oil sales 20,930 — 20,930 Sales of natural gas, oil and NGLs $ 2,217,739 $ — $ 2,217,739 Pipeline and net marketing services at EQT Production $ 11,668 $ 24,582 $ 36,250 EQM Gathering: Firm reservation fee revenues 221,635 — 221,635 Volumetric based fee revenues: Usage fees under firm contracts 22,064 — 22,064 Usage fees under interruptible contracts 116,545 — 116,545 EQM Transmission: Firm reservation fee revenues 179,997 — 179,997 Volumetric based fee revenues: Usage fees under firm contracts 8,650 — 8,650 Usage fees under interruptible contracts 7,432 — 7,432 RMP Gathering: Gathering revenues 105,696 — 105,696 Compression revenues 18,086 — 18,086 Water services at RMP Water 65,618 — 65,618 Intersegment eliminations (520,153 ) — (520,153 ) Pipeline, water and net marketing services $ 237,238 $ 24,582 $ 261,820 Gain on derivatives not designated as hedges $ — $ 8,695 $ 8,695 Total operating revenues $ 2,454,977 $ 33,277 $ 2,488,254 The following table includes the transaction price allocated to the Company's remaining performance obligations on all contracts with fixed consideration. The table excludes all contracts that qualified for the exception to the relative standalone selling price method. Gathering firm reservation fees and transmission and storage firm reservation fees include amounts related to affiliate contracts. 2018 (a) 2019 2020 2021 2022 Thereafter Total (Thousands) Natural gas sales $ 36,865 $ 24,841 $ 1,275 $ — $ — $ — $ 62,981 Gathering firm reservation fees $ 227,675 $ 476,730 $ 552,308 $ 562,307 $ 561,019 $ 2,841,280 $ 5,221,319 Gathering revenues supported by MVCs $ — $ 65,700 $ 71,370 $ 71,175 $ 71,175 $ 136,875 $ 416,295 Transmission and storage firm reservation fees $ 179,786 $ 347,061 $ 347,261 $ 341,769 $ 338,010 $ 2,602,572 $ 4,156,459 (a) July 1 through December 31.

Investment in Nonconsolidated E

Investment in Nonconsolidated Entity	6 Months Ended
	Jun. 30, 2018
Equity Method Investments and Joint Ventures [Abstract]
Investment in Nonconsolidated Entity	Rice Midstream Partners LP In connection with the Rice Merger, the Company acquired a 28.1% limited partner interest, all of the IDRs and the entire non-economic general partner interest in RMP. See the discussion of the RMP IDR Purchase and Midstream Mergers in Note B . Due to the timing of the Midstream Mergers, RMP did not declare a cash distribution for the second quarter 2018. Investment in Nonconsolidated Entity The Mountain Valley Pipeline, LLC (MVP Joint Venture) is constructing the Mountain Valley Pipeline (MVP), an estimated 300 -mile natural gas interstate pipeline spanning from northern West Virginia to southern Virginia. EQM is the operator of the MVP and owned a 45.5% interest in the MVP Joint Venture as of June 30, 2018 . The MVP Joint Venture is a variable interest entity because it has insufficient equity to finance its activities during the construction stage of the project. EQM is not the primary beneficiary because it does not have the power to direct the activities of the MVP Joint Venture that most significantly impact its economic performance. Certain business decisions require the approval of owners holding more than a 66 2/3% interest in the MVP Joint Venture and no one member owns more than a 66 2/3% interest. The MVP Joint Venture is an equity method investment for accounting purposes as EQM has the ability to exercise significant influence over operating and financial policies of the MVP Joint Venture. The MVP Joint Venture has modified its construction schedule for the MVP and now anticipates a first quarter 2019 in-service date. As currently designed, the total cost for the MVP is expected to be $3.5 billion to $3.7 billion , excluding Allowance for Funds Used During Construction (AFUDC). In May 2018, the MVP Joint Venture issued a capital call notice to MVP Holdco, LLC (MVP Holdco), a direct wholly owned subsidiary of EQM, for $445.9 million , of which $193.4 million was paid in July 2018 and $252.5 million is expected to be paid in the third quarter of 2018. The capital contribution payable has been reflected on the Condensed Consolidated Balance Sheet as of June 30, 2018 with a corresponding increase to the Company's investment in the MVP Joint Venture. Equity income is primarily EQM's portion of the MVP Joint Venture's AFUDC on construction of the MVP. As of June 30, 2018 , EQM had issued a $91 million performance guarantee in favor of the MVP Joint Venture to provide performance assurances for MVP Holdco's obligations to fund its proportionate share of the construction budget for the MVP. As of June 30, 2018 , EQM's maximum financial statement exposure related to the MVP Joint Venture was approximately $1,094 million , which consists of the investment in nonconsolidated entity balance on the Condensed Consolidated Balance Sheet as of June 30, 2018 and amounts that could have become due under EQM's performance guarantee as of that date. In April 2018, the MVP Joint Venture announced the MVP Southgate project, a proposed 70 -mile interstate pipeline that will extend from the MVP at Pittsylvania County, Virginia to new delivery points in Rockingham and Alamance Counties, North Carolina. The MVP Southgate project is anchored by a firm capacity commitment from PSNC Energy. The preliminary MVP Southgate project cost estimate is $350 million to $500 million , which is expected to be spent in 2019 and 2020. EQM is expected to have between 33% and 48% ownership in the MVP Southgate project and will operate the pipeline. Subject to approval by the FERC, the MVP Southgate has a targeted in-service date of the fourth quarter 2020.

Consolidated Variable Interest

Consolidated Variable Interest Entities	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Consolidated Variable Interest Entities	Consolidated Variable Interest Entities As of June 30, 2018, the Company determined EQGP, EQM and RMP to be variable interest entities. Through EQT's ownership and control of EQGP's general partner, EQM's general partner and RMP's general partner, EQT has the power to direct the activities that most significantly impact the economic performance of EQGP, EQM and RMP. In addition, through EQT's limited partner interest in EQGP and EQGP's general partner interest, limited partner interest and IDRs in EQM, EQT has the obligation to absorb the losses of EQGP and EQM and the right to receive benefits from EQGP and EQM, in accordance with such interests. Furthermore, through EQT's limited partner interest and IDRs in RMP, EQT had the obligation to absorb the losses of RMP and the right to receive benefits from RMP, in accordance with such interests. As EQT has a controlling financial interest in, and is primary beneficiary of, EQGP, EQM and RMP, EQT consolidates EQGP, EQM and RMP. See Note 13 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 for additional information related to the consolidated variable interest entities. The risks associated with the operations of EQGP, EQM and RMP are discussed in their respective Annual Reports on Form 10-K for the year ended December 31, 2017 , as updated by any Quarterly Reports on Form 10-Q. See further discussion of the impact that EQT's ownership and control of EQGP, EQM and RMP have on EQT's financial position, results of operations and cash flows included in EQT's Annual Report on Form 10-K for the year ended December 31, 2017 , including in the section captioned "Management's Discussion and Analysis of Financial Condition and Results of Operations." See Notes C , D and E for further discussion of EQGP, EQM and RMP, respectively. The following table presents amounts included in the Company's Condensed Consolidated Balance Sheets that were for the use or obligation of EQGP or EQM as of June 30, 2018 and December 31, 2017 . Classification June 30, 2018 December 31, 2017 (Thousands) Assets: Cash and cash equivalents $ 684,456 $ 2,857 Accounts receivable 47,587 28,804 Prepaid expenses and other 9,556 8,470 Property, plant and equipment, net 3,922,144 2,804,059 Goodwill 37,954 — Intangible assets, net 596,887 — Other assets 1,028,418 483,004 Liabilities: Accounts payable $ 84,969 $ 47,042 Other current liabilities 484,884 133,531 Credit facility borrowings — 180,000 Senior Notes 3,453,975 987,352 Other liabilities and credits 21,442 20,273 The following table summarizes EQGP's Statements of Consolidated Operations and Cash Flows for the three and six months ended June 30, 2018 and 2017 , inclusive of affiliate amounts. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Operating revenues $ 269,761 $ 198,966 $ 556,323 $ 402,392 Operating expenses 89,419 58,463 166,875 117,988 Other expenses 8,777 1,949 9,768 3,862 Net income $ 171,565 $ 138,554 $ 379,680 $ 280,542 Net cash provided by operating activities $ 219,297 $ 158,886 $ 440,071 $ 319,655 Net cash used in investing activities (1,422,852 ) (125,612 ) (1,676,669 ) (207,299 ) Net cash provided by (used in) financing activities 1,852,799 (63,255 ) 1,876,692 (160,022 ) The following table presents amounts included in the Company’s Condensed Consolidated Balance Sheets that are for the use or obligation of RMP as of June 30, 2018 and December 31, 2017 . Classification June 30, 2018 December 31, 2017 (Thousands) Assets: Cash and cash equivalents $ 17,339 $ 10,538 Accounts receivable 9,016 12,246 Prepaid expenses and other 541 1,327 Property, plant and equipment, net 1,479,671 1,431,802 Goodwill 1,346,918 1,346,918 Other assets 8,871 — Liabilities: Accounts payable $ 30,966 $ 24,634 Other current liabilities 2,338 4,200 Credit facility borrowings 260,000 286,000 Other liabilities and credits 9,572 9,360 The following table summarizes RMP’s Statements of Consolidated Operations and Cash Flows for the three and six months ended June 30, 2018 and 2017 , inclusive of affiliate amounts. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Operating revenues $ 104,936 $ — $ 189,400 $ — Operating expenses 41,341 — 70,340 — Other expenses 2,382 — 4,330 — Net income $ 61,213 $ — $ 114,730 $ — Net cash provided by operating activities $ 118,725 $ — $ 181,261 $ — Net cash used in investing activities (47,358 ) — (80,070 ) — Net cash used in financing activities (100,546 ) — (94,390 ) —

Financial Information by Busine

Financial Information by Business Segment	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Financial Information by Business Segment	Financial Information by Business Segment Prior to the Rice Merger, the Company reported its results of operations through three business segments: EQT Production, EQT Gathering and EQT Transmission. These reporting segments reflected the Company's lines of business and were reported in the same manner in which the Company evaluated its operating performance through September 30, 2017. Following the Rice Merger, the Company adjusted its internal reporting structure to incorporate the newly acquired assets. The Company now conducts its business through five business segments: EQT Production, EQM Gathering (formerly known as EQT Gathering), EQM Transmission (formerly known as EQT Transmission), RMP Gathering and RMP Water. Rice Olympus, Strike Force Holdings and Rice West Virginia were businesses and the Drop-Down Transaction was a transaction between entities under common control; therefore, EQM recorded the assets and liabilities of these entities at their carrying amounts to EQT on the effective date of the transaction. EQM also recast its consolidated financial statements to retrospectively reflect the pre-acquisition results as if the entities were owned by EQM from the date of the Rice Merger, November 13, 2017, as that is the date those entities came under the common control of EQT. EQT has recast its segment information consistent with the EQM recast, including recasting the $78.4 million of goodwill assigned to the Rice retained midstream assets in the purchase price accounting for the Rice Merger from EQT Production to EQM Gathering. In addition, the assets associated with the investment in the MVP JV were included within the headquarters segment assets balance prior to June 30, 2018. The investment in the MVP JV is now included in the transmission segment as this segment classification better aligns with the ultimate operations of the MVP. Segment asset balances at December 31, 2017 have been reclassified to conform to this presentation. Three Months Ended June 30, 2018 EQT Production EQM Gathering EQM Transmission RMP RMP Intersegment Eliminations EQT Corporation Revenues: (Thousands) Sales of natural gas, oil and NGLs $ 991,365 $ — $ — $ — $ — $ — $ 991,365 Pipeline, water and net marketing services 13,180 180,616 89,145 62,281 42,655 (270,674 ) 117,203 Loss on derivatives not designated as hedges (53,897 ) — — — — — (53,897 ) Total operating revenues $ 950,648 $ 180,616 $ 89,145 $ 62,281 $ 42,655 $ (270,674 ) $ 1,054,671 Three Months Ended June 30, 2017 EQT Production EQM Gathering EQM Transmission Intersegment Eliminations EQT Corporation Revenues: (Thousands) Sales of natural gas, oil and NGLs $ 576,714 $ — $ — $ — $ 576,714 Pipeline and net marketing services 8,061 112,145 84,670 (139,174 ) 65,702 Gain on derivatives not designated as hedges 46,326 — — — 46,326 Total operating revenues $ 631,101 $ 112,145 $ 84,670 $ (139,174 ) $ 688,742 Six Months Ended June 30, 2018 EQT Production EQM Gathering EQM Transmission RMP Gathering RMP Water Intersegment Eliminations EQT Corporation Revenues: (Thousands) Sales of natural gas, oil and NGLs $ 2,217,739 $ — $ — $ — $ — $ — $ 2,217,739 Pipeline and net marketing services 36,250 360,244 196,079 123,782 65,618 (520,153 ) 261,820 Gain on derivatives not designated as hedges 8,695 — — — — — 8,695 Total operating revenues $ 2,262,684 $ 360,244 $ 196,079 $ 123,782 $ 65,618 $ (520,153 ) $ 2,488,254 Six Months Ended June 30, 2017 EQT Production EQM Gathering EQM Transmission Intersegment Eliminations EQT Corporation Revenues: (Thousands) Sales of natural gas, oil and NGLs $ 1,250,179 $ — $ — $ — $ 1,250,179 Pipeline and net marketing services 22,516 214,474 182,413 (273,739 ) 145,664 Gain on derivatives not designated as hedges 187,068 — — — 187,068 Total operating revenues $ 1,459,763 $ 214,474 $ 182,413 $ (273,739 ) $ 1,582,911 Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Operating income (loss): EQT Production (a) $ (79,846 ) $ 52,884 $ (2,005,645 ) $ 310,433 EQM Gathering 121,631 83,425 252,513 157,129 EQM Transmission 60,642 57,863 140,093 129,467 RMP Gathering 39,614 — 83,709 — RMP Water 23,981 — 35,351 — Unallocated expenses and intersegment eliminations (b) (66,053 ) (4,045 ) (129,568 ) (15,926 ) Total operating income (loss) $ 99,969 $ 190,127 $ (1,623,547 ) $ 581,103 (a) Impairment of long-lived assets of $0.1 billion is included in EQT Production operating income for the three months ended June 30, 2018 and $2.4 billion for the six months ended June 30, 2018 . See Note Q . (b) Unallocated expenses consist of compensation expense and administrative costs, including transaction costs of $19.7 million for the three months ended June 30, 2018 and $54.5 million for the six months ended June 30, 2018 . Intersegment eliminations include the profit on water services that are provided to EQT Production and capitalized as part of development costs of $24.9 million for the three months ended June 30, 2018 and $47.5 million for the six months ended June 30, 2018 . Reconciliation of operating income (loss) to net income (loss): Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Total operating income (loss) $ 99,969 $ 190,127 $ (1,623,547 ) $ 581,103 Other income 11,752 6,305 21,337 9,354 Interest expense 77,004 44,078 147,017 86,733 Income tax (benefit) expense (101,629 ) 29,709 (440,594 ) 130,374 Net income (loss) $ 136,346 $ 122,645 $ (1,308,633 ) $ 373,350 June 30, 2018 December 31, 2017 (Thousands) Segment assets: EQT Production $ 19,393,931 $ 21,015,132 EQM Gathering 3,151,655 2,961,099 EQM Transmission 2,486,059 1,923,427 RMP Gathering 2,800,534 2,720,305 RMP Water 165,476 185,079 Total operating segments 27,997,655 28,805,042 Headquarters assets, including cash and short-term investments 965,573 717,562 Total assets $ 28,963,228 $ 29,522,604 Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Depreciation and depletion: (c) EQT Production $ 374,782 $ 219,211 $ 770,635 $ 430,308 EQM Gathering 15,646 9,555 30,590 18,415 EQM Transmission 12,430 11,845 24,871 23,532 RMP Gathering 8,236 — 16,360 — RMP Water 5,798 — 11,569 — Other 780 206 1,540 480 Total $ 417,672 $ 240,817 $ 855,565 $ 472,735 Expenditures for segment assets: (d) EQT Production (e) $ 739,183 $ 455,721 $ 1,369,941 $ 1,401,179 EQM Gathering 139,099 53,708 252,297 102,546 EQM Transmission 27,962 29,978 46,891 51,367 RMP Gathering 47,358 — 68,298 — RMP Water 7,002 — 9,377 — Other and intersegment eliminations (f) (21,889 ) 2,967 (43,112 ) 4,595 Total $ 938,715 $ 542,374 $ 1,703,692 $ 1,559,687 (c) Excludes amortization of intangible assets. (d) Includes the capitalized portion of non-cash stock-based compensation costs, non-cash acquisitions and the impact of capital accruals. The impact of accrued capital expenditures includes the reversal of the prior period accrual as well as the current period estimate, both of which are non-cash items. The net impact of these non-cash items was $(34.3) million and $37.4 million for the three months ended June 30, 2018 and 2017 , respectively, and $6.6 million and $58.4 million for the six months ended June 30, 2018 and 2017 , respectively. These non-cash items are excluded from capital expenditures on the Statements of Condensed Consolidated Cash Flows. Expenditures for segment assets does not include consideration for the Rice Merger. (e) Expenditures for segment assets in the EQT Production segment included $41.3 million and $47.0 million for fill-ins and bolt-ons associated with legacy EQT acreage for the three months ended June 30, 2018 and 2017 , respectively, and $78.1 million and $89.7 million for fill-ins and bolt-ons associated with legacy EQT acreage for the six months ended June 30, 2018 and 2017 , respectively. The three and six months ended June 30, 2017 included $141.7 million and $811.2 million of cash capital expenditures, respectively, and $9.7 million of non-cash capital expenditures for the six months ended June 30, 2017 , for the acquisitions discussed in Note P . (f) Intersegment eliminations include profit on water services that are provided to EQT Production and capitalized as part of development costs.

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments The Company’s primary market risk exposure is the volatility of future prices for natural gas and NGLs, which can affect the operating results of the Company primarily at EQT Production. The Company’s overall objective in its hedging program is to protect cash flows from undue exposure to the risk of changing commodity prices. The Company uses over the counter (OTC) derivative commodity instruments, primarily swap, collar and option agreements that are typically placed with financial institutions. The creditworthiness of all counterparties is regularly monitored. Swap agreements involve payments to or receipts from counterparties based on the differential between two prices for the commodity. Collar agreements require the counterparty to pay the Company if the index price falls below the floor price and the Company to pay the counterparty if the index price rises above the cap price. The Company also sells call options that require the Company to pay the counterparty if the index price rises above the strike price. The Company engages in basis swaps to protect earnings from undue exposure to the risk of geographic disparities in commodity prices and interest rate swaps to hedge exposure to fluctuations in interest rates. The Company has also engaged in a limited number of swaptions that are recorded as derivative commodity instruments for accounting purposes. The Company recognizes all derivative instruments as either assets or liabilities at fair value on a gross basis. These derivative instruments are reported as either current assets or current liabilities due to their highly liquid nature. The Company can net settle its derivative instruments at any time. The Company discontinued cash flow hedge accounting in 2014; therefore, all changes in fair value of the Company’s derivative instruments are recognized within operating revenues in the Statements of Consolidated Operations. In connection with the Rice Merger, the Company assumed all outstanding derivative commodity instruments held by Rice. The assets and liabilities assumed were recognized at fair value at the closing date and subsequent changes in fair value were recognized within operating revenues in the Statements of Consolidated Operations. The derivative commodity instruments assumed were substantially similar to instruments previously held by the Company. Contracts which result in physical delivery of a commodity expected to be used or sold by the Company in the normal course of business are designated as normal purchases and sales and are exempt from derivative accounting. OTC arrangements require settlement in cash. Settlements of derivative commodity instruments are reported as a component of cash flows from operations in the accompanying Statements of Condensed Consolidated Cash Flows. With respect to the derivative commodity instruments held by the Company, the Company hedged portions of expected sales of equity production and portions of its basis exposure covering approximately 2,874 Bcf of natural gas and 1,012 Mbbls of NGLs as of June 30, 2018 , and 2,148 Bcf of natural gas and 1,460 Mbbls of NGLs as of December 31, 2017 . The open positions at June 30, 2018 and December 31, 2017 had maturities extending through December 2024 and December 2022, respectively. The Company has netting agreements with financial institutions and its brokers that permit net settlement of gross commodity derivative assets against gross commodity derivative liabilities. The table below reflects the impact of netting agreements and margin deposits on gross derivative assets and liabilities as of June 30, 2018 and December 31, 2017 . As of June 30, 2018 Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross Derivative instruments subject to master netting agreements Margin deposits remitted to counterparties Derivative instruments, net (Thousands) Asset derivatives: Derivative instruments, at fair value $ 270,288 $ (94,320 ) $ (3,105 ) $ 172,863 Liability derivatives: Derivative instruments, at fair value $ 146,061 $ (94,320 ) $ — $ 51,741 As of December 31, 2017 Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross Derivative instruments subject to master netting agreements Margin deposits remitted to counterparties Derivative instruments, net (Thousands) Asset derivatives: Derivative instruments, at fair value $ 241,952 $ (86,856 ) $ — $ 155,096 Liability derivatives: Derivative instruments, at fair value $ 139,089 $ (86,856 ) $ — $ 52,233 Certain of the Company’s derivative instrument contracts provide that if the Company’s credit ratings by Standard & Poor’s Rating Service (S&P) or Moody’s Investors Service (Moody’s) are lowered below investment grade, additional collateral must be deposited with the counterparty if the amounts outstanding on those contracts exceed certain thresholds. The additional collateral can be up to 100% of the derivative liability. As of June 30, 2018 , the aggregate fair value of all derivative instruments with credit risk-related contingent features that were in a net liability position was $70.7 million , for which the Company had no collateral posted on June 30, 2018 . If the Company’s credit rating by S&P or Moody’s had been downgraded below investment grade on June 30, 2018 , the Company would not have been required to post any additional collateral under the agreements with the respective counterparties. The required margin on the Company’s derivative instruments is subject to significant change as a result of factors other than credit rating, such as gas prices and credit thresholds set forth in agreements between the hedging counterparties and the Company. Investment grade refers to the quality of the Company’s credit as assessed by one or more credit rating agencies. The Company’s senior unsecured debt was rated BBB by S&P and Baa3 by Moody’s at June 30, 2018 . In order to be considered investment grade, the Company must be rated BBB- or higher by S&P and Baa3 or higher by Moody’s. Anything below these ratings is considered non-investment grade. See also "Security Ratings and Financing Triggers" under Part I, Item 2, "Management's Discussion and Analysis of Financial Condition and Results of Operations."

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements The Company records its financial instruments, principally derivative instruments, at fair value in its Condensed Consolidated Balance Sheets. The Company estimates the fair value using quoted market prices, where available. If quoted market prices are not available, fair value is based upon models that use market-based parameters as inputs, including forward curves, discount rates, volatilities and nonperformance risk. Nonperformance risk considers the effect of the Company’s credit standing on the fair value of liabilities and the effect of the counterparty’s credit standing on the fair value of assets. The Company estimates nonperformance risk by analyzing publicly available market information, including a comparison of the yield on debt instruments with credit ratings similar to the Company’s or counterparty’s credit rating and the yield of a risk-free instrument and credit default swaps rates where available. The Company has categorized its assets and liabilities recorded at fair value into a three-level fair value hierarchy, based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). Assets and liabilities in Level 2 primarily include the Company’s swap, collar and option agreements. The fair value of the commodity swaps included in Level 2 is based on standard industry income approach models that use significant observable inputs, including but not limited to New York Mercantile Exchange (NYMEX) natural gas and propane forward curves, LIBOR-based discount rates and basis forward curves. The Company’s collars, options and swaptions are valued using standard industry income approach option models. The significant observable inputs utilized by the option pricing models include NYMEX forward curves, natural gas volatilities and LIBOR-based discount rates. The NYMEX natural gas and propane forward curves, LIBOR-based discount rates, natural gas volatilities and basis forward curves are validated to external sources at least monthly. The following assets and liabilities were measured at fair value on a recurring basis during the applicable period: Fair value measurements at reporting date using Description As of June 30, 2018 Quoted prices in active markets for identical assets (Level 1) Significant other observable inputs (Level 2) Significant unobservable inputs (Level 3) (Thousands) Assets Derivative instruments, at fair value $ 270,288 $ — $ 270,288 $ — Liabilities Derivative instruments, at fair value $ 146,061 $ — $ 146,061 $ — Fair value measurements at reporting date using Description As of December 31, 2017 Quoted prices in active markets for identical assets (Level 1) Significant other observable inputs (Level 2) Significant unobservable inputs (Level 3) (Thousands) Assets Derivative instruments, at fair value $ 241,952 $ — $ 241,952 $ — Liabilities Derivative instruments, at fair value $ 139,089 $ — $ 139,089 $ — The carrying values of cash equivalents, accounts receivable and accounts payable approximate fair value due to the short-term maturity of the instruments. The carrying values of borrowings under the Company's various credit facilities approximate fair value as the interest rates are based on prevailing market rates. The Company also has an immaterial investment in a fund that invests in companies developing technology and operating solutions for exploration and production companies for which it recognized a cumulative effect of accounting change in the first quarter 2018. The Company estimates the fair value of its Senior Notes using its established fair value methodology. Because not all of the Company’s Senior Notes are actively traded, the fair value of the Company's Senior Notes are a Level 2 fair value measurement. Fair value for the Company's non-traded Senior Notes are estimated using a standard industry income approach model that utilizes a discount rate based on market rates for debt with similar remaining time to maturity and credit risk. The estimated fair value of Senior Notes (including EQM’s Senior Notes) on the Condensed Consolidated Balance Sheets was approximately $8.1 billion at June 30, 2018 and $5.7 billion at December 31, 2017 . The Company recognizes transfers between Levels as of the actual date of the event or change in circumstances that caused the transfer. There were no transfers between Levels 1, 2 and 3 during the periods presented. For information on the fair values of assets related to the impairments of proved and unproved oil and gas properties and of other long-lived assets, see Note Q and Note 1 in EQT's Annual Report on Form 10-K for the year ended December 31, 2017 . For information on the assets acquired in the Rice Merger and the assets acquired in other acquisition transactions, see Notes A and P .

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes On December 22, 2017, the U.S. Congress enacted the law known as the Tax Cuts and Jobs Act of 2017 (Tax Reform Legislation), which made significant changes to U.S. federal income tax law, including lowering the federal corporate tax rate to 21% from 35% beginning January 1, 2018. The Company is still analyzing certain aspects of the Tax Reform Legislation and refining calculations, which could potentially impact the measurement of deferred tax balances or potentially give rise to new deferred tax amounts. The Company will refine its estimates to incorporate new or better information as it comes available through the filing date of its 2017 U.S. income tax returns in the fourth quarter of 2018. For the six months ended June 30, 2018 and 2017 , the Company calculated the provision for income taxes by applying the annual effective tax rate for the full fiscal year to “ordinary” income or loss (pre-tax income or loss excluding unusual or infrequently occurring items) for the quarter. All of EQGP's, RMP’s and Strike Force Midstream’s income is included in the Company's pre-tax income (loss). However, the Company is not required to record income tax expense with respect to the portion of EQGP's and RMP’s income allocated to the noncontrolling public limited partners of EQGP, EQM and RMP or to the portion of Strike Force Midstream’s income allocated to the minority owner prior to the closing of the Gulfport Transaction, which reduces the Company's effective tax rate in periods when the Company has consolidated pre-tax income and increases the Company's effective tax rate in periods when the Company has consolidated pre-tax loss. The Company recorded income tax benefit at an effective tax rate of 25.2% for the six months ended June 30, 2018 and income tax expense at an effective tax rate of 25.9% for the six months ended June 30, 2017 . The Company’s forecasted annual effective tax rate for the period ended December 31, 2018 was higher than the statutory rate due to the impact of income allocated to non-controlling limited partners on a forecasted consolidated pre-tax loss and the impact of state taxes. The state taxes increased the forecasted annual effective tax rate as compared to the statutory rate as a result of the pre-tax loss on entities with higher state applicable rates and pre-tax income on entities with lower state applicable rates. The Company’s effective tax rate for the six months ended June 30, 2018 was significantly lower because the amount of benefit recorded for the year-to-date is limited to the amount of benefit forecasted for the entire year. There were no material changes to the Company’s methodology for determining unrecognized tax benefits during the three months ended June 30, 2018 .

Revolving Credit Facilities

Revolving Credit Facilities	6 Months Ended
	Jun. 30, 2018
Short-term Debt [Abstract]
Revolving Credit Facilities	Revolving Credit Facilities The Company has a $2.5 billion revolving credit facility that expires in July 2022. The Company had $0.2 billion in borrowings and no letters of credit outstanding under the credit facility as of June 30, 2018 . The Company had $1.3 billion in borrowings and $159.4 million of letters of credit outstanding under the credit facility as of December 31, 2017 . The maximum amount of outstanding borrowings at any time under the credit facility during the three and six months ended June 30, 2018 was $1.5 billion and $1.6 billion , respectively, and the average daily balance of borrowings outstanding was approximately $0.9 billion and $1.2 billion , respectively, at a weighted average annual interest rate of approximately 3.4% and 3.2% , respectively. The Company had no borrowings or letters of credit outstanding under its credit facility any time during the three and six months ended June 30, 2017 . EQM has a $1 billion revolving credit facility that expires in July 2022. EQM had no borrowings and no letters of credit outstanding under the credit facility as of June 30, 2018 . EQM had $180 million in borrowings and no letters of credit outstanding under the credit facility as of December 31, 2017 . The maximum amount of outstanding borrowings under EQM’s revolving credit facility at any time during the three and six months ended June 30, 2018 was $338 million and $420 million , respectively, and the average daily balance of borrowings outstanding was approximately $122 million and $211 million , respectively. EQM incurred interest at a weighted average annual interest rate of approximately 3.4% and 3.2% for the three and six months ended June 30, 2018 , respectively. EQM had no borrowings or letters of credit outstanding under its revolving credit facility any time during the three and six months ended June 30, 2017 . During the third quarter, EQM intends to increase its borrowing capacity from $1 billion to up to $2 billion . See discussion of the termination of the RMP Credit Agreement in Note B . RMP OpCo had $260 million in borrowings and $1 million of letters of credit outstanding under the RMP Credit Agreement as of June 30, 2018 . RMP OpCo had $286 million in borrowings and $1 million of letters of credit outstanding under the RMP Credit Agreement as of December 31, 2017 . The maximum amount of outstanding borrowings under the RMP Credit Agreement at any time during the three and six months ended June 30, 2018 was $375 million and the average daily balance of borrowings outstanding was approximately $305 million and $306 million , respectively, at a weighted average annual interest rate of approximately 3.9% and 3.8% , respectively.

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2018
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share In periods when the Company reports a net loss, all options and restricted stock are excluded from the calculation of diluted weighted average shares outstanding because of their anti-dilutive effect on loss per share. As a result, all options and all restricted stock were excluded from the calculation of diluted earnings per share for the six months ended June 30, 2018 . Potentially dilutive securities (options and restricted stock awards) included in the calculation of diluted earnings per share totaled 123,973 for the three months ended June 30, 2018, and 120,228 and 204,430 for the three and six months ended June 30, 2017 , respectively. Options to purchase common stock excluded from potentially dilutive securities because they were anti-dilutive totaled 1,201,900 and 1,283,753 for the three and six months ended June 30, 2018 , respectively, and 713,800 and 473,700 for the three and six months ended June 30, 2017 . The impact of EQM’s, EQGP’s and RMP's dilutive units did not have a material impact on the Company’s earnings per share calculations for any of the periods presented.

Changes in Accumulated Other Co

Changes in Accumulated Other Comprehensive Income by Component	6 Months Ended
	Jun. 30, 2018
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Changes in Accumulated Other Comprehensive Income by Component	Changes in Accumulated Other Comprehensive Income by Component The following tables explain the changes in accumulated other comprehensive income (OCI) by component during the applicable period: Three Months Ended June 30, 2018 Natural gas cash flow hedges, net of tax Interest rate cash flow hedges, net of tax Other post- retirement benefit liability adjustment, net of tax Accumulated OCI, net of tax (Thousands) Accumulated OCI (loss), net of tax, as of April 1, 2018 $ 4,338 $ (511 ) $ (6,442 ) $ (2,615 ) (Gains) losses reclassified from accumulated OCI, net of tax (466 ) (a) 36 (a) 86 (b) (344 ) Accumulated OCI (loss), net of tax, as of June 30, 2018 $ 3,872 $ (475 ) $ (6,356 ) $ (2,959 ) Three Months Ended June 30, 2017 Natural gas cash Interest rate Other post- Accumulated (Thousands) Accumulated OCI (loss), net of tax, as of April 1, 2017 $ 8,719 $ (663 ) $ (6,790 ) $ 1,266 (Gains) losses reclassified from accumulated OCI, net of tax (1,672 ) (a) 36 (a) 77 (b) (1,559 ) Accumulated OCI (loss), net of tax, as of June 30, 2017 $ 7,047 $ (627 ) $ (6,713 ) $ (293 ) Six Months Ended June 30, 2018 Natural gas cash flow hedges, net of tax Interest rate cash flow hedges, net of tax Other post- retirement benefit liability adjustment, net of tax Accumulated OCI, net of tax (Thousands) Accumulated OCI (loss), net of tax, as of January 1, 2018 $ 4,625 $ (555 ) $ (6,528 ) $ (2,458 ) (Gains) losses reclassified from accumulated OCI, net of tax (753 ) (a) 80 (a) 172 (b) (501 ) Accumulated OCI (loss), net of tax, as of June 30, 2018 $ 3,872 $ (475 ) $ (6,356 ) $ (2,959 ) Six Months Ended June 30, 2017 Natural gas cash flow hedges, net of tax Interest rate cash flow hedges, net of tax Pension and other post- retirement benefits liability adjustment, net of tax Accumulated OCI, net of tax (Thousands) Accumulated OCI (loss), net of tax, as of January 1, 2017 $ 9,607 $ (699 ) $ (6,866 ) $ 2,042 (Gains) losses reclassified from accumulated OCI, net of tax (2,560 ) (a) 72 (a) 153 (b) (2,335 ) Accumulated OCI (loss), net of tax, as of June 30, 2017 $ 7,047 $ (627 ) $ (6,713 ) $ (293 ) (a) (Gains) losses reclassified from accumulated OCI, net of tax related to natural gas cash flow hedges were reclassified into operating revenues. Losses from accumulated OCI, net of tax related to interest rate cash flow hedges were reclassified into interest expense. (b) The accumulated OCI reclassification is attributable to the net actuarial loss and net prior service cost related to the Company’s post-retirement benefit plans. See Note 1 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 for additional information.

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2018
Business Combinations [Abstract]
Acquisitions	In February 2018, the Company's Board of Directors unanimously approved a plan to separate its upstream and midstream businesses, creating a standalone publicly traded corporation (SpinCo) that will focus on midstream operations (the Separation). SpinCo will own the midstream interests held by EQT. The Separation is intended to qualify as tax-free to EQT shareholders for U.S. federal income tax purposes. Under the Separation plan, EQT shareholders will retain their shares of the Company's stock and receive a pro-rata distribution of 80.1% of the outstanding shares of SpinCo common stock. In connection with announcing the planned Separation, the Company also announced its plans to pursue (i) a sale of Rice retained midstream assets acquired by EQT in connection with the Rice Merger to EQT Midstream Partners, LP (EQM) (NYSE: EQM); (ii) a merger of EQM and RMP; and (iii) a sale of RMP’s incentive distribution rights (IDRs) to EQT GP Holdings, LP (EQGP) (NYSE: EQGP)((i), (ii) and (iii) collectively, the Midstream Streamlining Transactions). On April 25, 2018, EQT, Rice Midstream Holdings LLC (Rice Midstream), a wholly owned subsidiary of the Company, EQM and EQM Gathering Holdings, LLC (EQM Gathering), a wholly owned subsidiary of EQM, entered into a contribution and sale agreement pursuant to which EQM Gathering agreed to acquire all the outstanding limited liability company interests in each of (i) Rice West Virginia Midstream LLC (Rice West Virginia), (ii) Rice Olympus Midstream LLC (Rice Olympus) and (iii) Strike Force Midstream Holdings LLC (Strike Force Holdings), which owns a 75% limited liability company interest in Strike Force Midstream LLC (Strike Force Midstream), in exchange for an aggregate of 5,889,282 EQM common units and cash consideration of $1.15 billion , plus working capital adjustments (the Drop-Down Transaction). The Drop-Down Transaction was completed on May 22, 2018 with an effective date of May 1, 2018. In connection with the Drop-Down Transaction, the Company recorded a $15.5 million gain to additional paid-in-capital, a decrease in noncontrolling interest in consolidated subsidiary of $20.3 million and an increase to deferred tax liability of $4.8 million . On May 1, 2018, pursuant to the Purchase and Sale Agreement dated April 25, 2018, by and among EQM, EQM Gathering, Gulfport Energy Corporation (Gulfport) and an affiliate of Gulfport, EQM Gathering acquired the remaining 25% limited liability company interest in Strike Force Midstream not owned by Strike Force Holdings for $175 million (the Gulfport Transaction). As a result, EQM has owned 100% of Strike Force Midstream since May 1, 2018. On May 22, 2018, pursuant to an Incentive Distribution Rights Purchase and Sale agreement dated April 25, 2018, by and among the Company, Rice Midstream GP Holdings (Rice Midstream GP Holdings), a wholly owned subsidiary of the Company that owned the RMP IDRs, and EQGP, EQGP acquired all of the issued and outstanding RMP IDRs in exchange for 36,293,766 EQGP common units (the RMP IDR Purchase). As a result of the RMP IDR Purchase, EQT's percentage ownership of the outstanding EQGP common units increased from approximately 90.1% to approximately 91.3% . In connection with the RMP IDR Purchase, the Company recorded a $35.1 million loss to additional paid-in-capital, an increase in noncontrolling interest in consolidated subsidiary of $46.1 million and a decrease to deferred tax liability of $11.0 million . On April 25, 2018, EQM entered into an Agreement and Plan of Merger (the Midstream Merger Agreement) with RMP, Rice Midstream Management LLC, the general partner of RMP (the RMP General Partner), EQT Midstream Services, LLC, the general partner of EQM (the EQM General Partner), EQM Acquisition Sub, LLC, a wholly owned subsidiary of EQM (Merger Sub), EQM GP Acquisition Sub, LLC, a wholly owned subsidiary of EQM (GP Merger Sub), and, solely for certain limited purposes set forth therein, the Company. Pursuant to the Midstream Merger Agreement, on July 23, 2018, Merger Sub and GP Merger Sub merged with and into RMP and the RMP General Partner, respectively, with RMP and the RMP General Partner surviving as wholly owned subsidiaries of EQM (the Midstream Mergers). Pursuant to the Midstream Merger Agreement, each RMP common unit issued and outstanding immediately prior to the effective time of the Midstream Mergers was converted into the right to receive 0.3319 EQM common units (the Midstream Mergers Consideration), the issued and outstanding RMP IDRs were canceled and each outstanding award of phantom units in respect of RMP common units fully vested and converted into the right to receive the Midstream Mergers Consideration, less applicable tax withholding, in respect of each RMP common unit subject thereto. The aggregate Midstream Mergers Consideration consisted of approximately 34 million EQM common units. As a result of the Midstream Mergers, RMP's common units are no longer publicly traded. Also in connection with the completion of the Midstream Mergers, on July 23, 2018, EQM repaid approximately $260 million of borrowings outstanding under the Credit Agreement, dated as of December 22, 2014, by and among RMP, as parent guarantor, Rice Midstream OpCo LLC, a wholly owned subsidiary of RMP (RMP OpCo), as borrower, Wells Fargo Bank, N.A., as administrative agent, and the lenders and other parties from time to time party thereto (the RMP Credit Agreement), and the RMP Credit Agreement was terminated. On April 25, 2018, EQM entered a $2.5 billion unsecured multi-draw 364-day term loan facility with a syndicate of lenders (the EQM Term Loan Facility). The EQM Term Loan Facility was used to fund the cash consideration for the Drop-Down Transaction, to repay borrowings under EQM’s $1 billion credit facility, and for other general partnership purposes. During the second quarter of 2018, the balance outstanding under the EQM Term Loan Facility was repaid, and the EQM Term Loan Facility was terminated on June 25, 2018 in connection with EQM's issuance of the EQM 2018 Senior Notes (described in the following section). As a result of the termination of the EQM Term Loan Facility, EQM expensed $3 million of deferred issuance costs. From April 25, 2018 through June 25, 2018, the maximum amount of EQM's outstanding borrowings under the EQM Term Loan Facility at any time was $1,825 million and the average daily balance was approximately $1,231 million . EQM incurred interest at a weighted average annual interest rate of approximately 3.3% for the period from April 25, 2018 through June 25, 2018. During the second quarter of 2018, EQM issued 4.75% senior notes due July 15, 2023 in the aggregate principal amount of $1.1 billion , 5.50% senior notes due July 15, 2028 in the aggregate principal amount of $850 million and 6.50% senior notes due July 15, 2048 in the aggregate principal amount of $550 million (collectively, the EQM 2018 Senior Notes). The offering of the EQM 2018 Senior Notes resulted in net proceeds of approximately $2,465.8 million , inclusive of a discount of $11.8 million and estimated debt issuance costs of $22.4 million . The net proceeds were used to repay the balance outstanding under the EQM Term Loan Facility and the RMP Credit Agreement and the remainder is expected to be used for general partnership purposes. The EQM 2018 Senior Notes were issued pursuant to new supplemental indentures to EQM's existing indenture dated August 1, 2014. The EQM 2018 Senior Notes contain covenants that limit EQM's ability to, among other things, incur certain liens securing indebtedness, engage in certain sale and leaseback transactions, and enter into certain consolidations, mergers, conveyances, transfers or leases of all of substantially all of EQM's assets. As a result of the Midstream Mergers, on July 23, 2018, an indirect wholly owned subsidiary of the Company received 9,554,530 EQM common units as Midstream Mergers Consideration. Acquisitions On February 1, 2017, the Company acquired approximately 14,000 net Marcellus acres located in Marion, Monongalia and Wetzel Counties of West Virginia from a third-party. On February 27, 2017, the Company acquired approximately 85,000 net Marcellus acres, including drilling rights on approximately 44,000 net Utica acres and current natural gas production of approximately 110 MMcfe per day, from Stone Energy Corporation. The acquired acres are primarily located in Wetzel, Marshall, Tyler and Marion Counties of West Virginia. The acquired assets also included 174 Marcellus wells, 120 of which were producing at the time of the acquisition, and 20 miles of gathering pipeline. During the first half of 2017, the Company paid net cash of $736.0 million and assumed liabilities estimated at $11.9 million as of June 30, 2017. Furthermore, the Company paid $75.2 million and recorded a deduction of $2.2 million of non-cash capital expenditures as a result of post-closing adjustments on 2016 acquisitions in the second quarter 2017. Fair Value Measurement As these acquisitions qualified as business combinations under GAAP, the fair value of the acquired assets was determined using a market approach for the undeveloped acreage and a discounted cash flow model under the income approach for the wells. Significant unobservable inputs used in the analysis included the determination of estimated developed reserves and forward pricing estimates. As a result, valuation of the acquired assets was a Level 3 fair value measurement.

Divestitures

Divestitures	6 Months Ended
	Jun. 30, 2018
Property, Plant and Equipment [Abstract]
Divestitures	Divestitures On June 19, 2018, the Company sold its non-core Permian Basin assets located in Texas for net proceeds of $60.2 million , subject to final purchase price adjustments (the Permian Divestiture). The assets sold in the Permian Divestiture included approximately 970 productive wells with current net production of approximately 20 MMcfe per day, approximately 350 miles of low-pressure gathering lines and 26 compressors. The Company also agreed to sell approximately 2.5 million non-core, net acres in the Huron Play located in Southern Appalachia for $575 million , subject to purchase price adjustments (the Huron Divestiture). The assets in the Huron Divestiture include approximately 12,000 productive wells with current net production of approximately 200 MMcfe per day, approximately 6,400 miles of low-pressure gathering lines and 59 compressor stations. The Company will retain the deep drilling rights across the divested acreage. Upon the execution of the definitive agreement governing the Huron Divestiture on June 28, 2018, the Company received an initial deposit of $57.5 million which is recorded within other current liabilities on the Condensed Consolidated Balance Sheet. The following table presents amounts included in the Company’s Condensed Consolidated Balance Sheet that are classified as held for sale as of June 30, 2018 related to the Huron Divestiture. Classification June 30, 2018 December 31, 2017 (Thousands) Assets: Property, plant and equipment, net $ 719,584 $ — Liabilities: Other current liabilities 4,763 — Other liabilities and credits 190,541 — The Huron Divestiture closed on July 18, 2018. During the first quarter of 2018 , the Company recorded an impairment of $2.3 billion associated with the production and related midstream assets in the Huron and Permian Plays. The impairment of these properties and related pipeline assets recorded during the first quarter of 2018 was due to the carrying value of the assets exceeding the undiscounted cash flows which were expected to result from the continued use and potential disposition of the underlying assets as well as management’s determination that it no longer intended to develop the unproved properties. The first quarter of 2018 impairment reduced these assets to their estimated fair value at that time of approximately $1 billion . The fair value of the impaired assets, as determined at March 31, 2018, was based on significant inputs that were not observable in the market and as such are considered to be Level 3 fair value measurements. See Note K for a description of the fair value hierarchy and Note 1 included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 for our policy on impairment of proved and unproved properties. Key assumptions included in the calculation of the fair value of the impaired assets as of March 31, 2018 included (i) reserves, including risk adjustments for probable and possible reserves; (ii) future commodity prices; (iii) to the extent available, market based indicators of fair value including estimated proceeds which could be realized upon a potential disposition; (iv) production rates based on the Company's experience with similar properties in which it operates; (v) estimated future operating and development costs; and (vi) a market-based weighted average cost of capital. In connection with the Permian Divestiture and the Huron Divestiture, the Company recorded an additional impairment/loss on sale of long-lived assets of $118.1 million during the second quarter of 2018 to write down the carrying value of the disposal groups to the estimated amounts to be received upon the closing of the transactions. As a result of the Huron Divestiture, the Company expects to record an additional impairment/loss on sale of long-lived assets of up to $275 million during the third quarter of 2018 associated with certain capacity contracts that the Company will no longer have existing production to satisfy and does not plan to utilize in the future.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2018
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events In July 2018, the Company’s Board of Directors approved a share repurchase authorization to repurchase shares of the Company’s outstanding common stock for an aggregate purchase price of not more than $500 million . Pursuant to the share repurchase authorization, the Company may repurchase shares from time to time in open market or in privately negotiated transactions. The share repurchase authorization does not obligate the Company to acquire any specific number of shares, has no pre-established end date and may be discontinued by the Company at any time. The Company has not repurchased any shares under this authorization since its inception.

Recently Issued Accounting Stan

Recently Issued Accounting Standards	6 Months Ended
	Jun. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recently Issued Accounting Standards	Recently Issued Accounting Standards In May 2014, the Financial Accounting Standards Board (FASB) issued ASU No. 2014-09, Revenue from Contracts with Customers . The standard requires an entity to recognize revenue in a manner that depicts the transfer of goods or services to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Company adopted this standard on January 1, 2018 using the modified retrospective method of adoption. Adoption of the ASU did not require an adjustment to the opening balance of equity. The Company does not expect the standard to have a significant effect on its results of operations, liquidity or financial position in 2018. The Company implemented processes and controls to ensure new contracts are reviewed for the appropriate accounting treatment and to generate the disclosures required under the new standard in the first quarter of 2018. For the disclosures required by this ASU, see Note F . In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities . The standard primarily affects accounting for equity investments, financial liabilities under the fair value option and the presentation and disclosure requirements for financial instruments, and eliminates the cost method of accounting for equity investments. The Company adopted this standard in the first quarter of 2018 which resulted in a cumulative effect adjustment of $4.1 million on the Statement of Condensed Consolidated Equity. In February 2016, the FASB issued ASU No. 2016-02, Leases . The standard requires an entity to record assets and obligations for contracts currently recognized as operating leases. Lessees and lessors must apply a modified retrospective transition approach. The ASU will be effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period, with early adoption permitted. The Company has performed a high-level identification of agreements covered by this standard, is currently evaluating processes and internal controls and is in the process of implementing a third-party supported lease accounting information system to facilitate the accounting and financial reporting requirements. In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments-Credit Losses: Measurement of Credit Losses on Financial Instruments . This ASU amends guidance on reporting credit losses for assets held at amortized cost basis and available for sale debt securities. For assets held at amortized cost basis, this ASU eliminates the probable initial recognition threshold in current GAAP and, instead, requires an entity to reflect its current estimate of all expected credit losses. The amendments affect loans, debt securities, trade receivables, net investments in leases, off balance sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope that have the contractual right to receive cash. The ASU will be effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period. The Company is currently evaluating the effect this standard will have on its financial statements and related disclosures. In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows: Restricted Cash. This ASU requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning of period and end of period total amounts shown on the statement of cash flows. The Company adopted this standard in the first quarter of 2018. The Company had $75 million restricted cash at December 31, 2016. In accordance with ASU 2016-18, restricted cash is included in the beginning of period cash balance and excluded from investing activities on the Statements of Condensed Consolidated Cash Flows for the six months ended June 30, 2017 . The Company had no restricted cash on the Condensed Consolidated Balance Sheet from March 31, 2017 through the current period. In January 2017, the FASB issued ASU No. 2017-01, Business Combinations: Clarifying the Definition of a Business . This ASU clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be recorded as acquisitions (or disposals) of assets or businesses. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. In January 2017, the FASB issued ASU No. 2017-04, Simplifying the Test of Goodwill Impairment . This ASU simplifies the quantitative goodwill impairment test requirements by eliminating the requirement to calculate the implied fair value of goodwill (Step 2 of the current goodwill impairment test). Instead, a company would record an impairment charge based on the excess of a reporting unit’s carrying value over its fair value (measured in Step 1 of the current goodwill impairment test). Entities will apply the standard’s provisions prospectively. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. In March 2017, the FASB issued ASU No. 2017-07, Compensation - Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost . This ASU provides additional guidance on the presentation of net benefit cost in the income statement and on the components eligible for capitalization in assets. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. In May 2017, the FASB issued ASU No. 2017-09, Compensation - Stock Compensation: Scope of Modification Accounting . This ASU provides guidance regarding which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. This ASU will be applied prospectively to awards modified on or after the adoption date. In February 2018, the FASB issued ASU No. 2018-02, Income Statement—Reporting Comprehensive Income: Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. This ASU allows companies to reclassify stranded tax effects resulting from the Tax Reform Legislation from accumulated other comprehensive income to retained earnings. The ASU is effective for fiscal years beginning after December 15, 2018 and early adoption is permitted. The reclassification permitted under this ASU should be applied either in the period of adoption or retrospectively to each period (or periods) in which the effect of the change in the U.S. federal corporate income tax rate in the Tax Reform Legislation is recognized. The Company is currently evaluating the effect this standard will have on its financial statements and related disclosures.

Recently Issued Accounting St30

Recently Issued Accounting Standards (Policies)	6 Months Ended
	Jun. 30, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recently Issued Accounting Standards	In May 2014, the Financial Accounting Standards Board (FASB) issued ASU No. 2014-09, Revenue from Contracts with Customers . The standard requires an entity to recognize revenue in a manner that depicts the transfer of goods or services to customers at an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. The Company adopted this standard on January 1, 2018 using the modified retrospective method of adoption. Adoption of the ASU did not require an adjustment to the opening balance of equity. The Company does not expect the standard to have a significant effect on its results of operations, liquidity or financial position in 2018. The Company implemented processes and controls to ensure new contracts are reviewed for the appropriate accounting treatment and to generate the disclosures required under the new standard in the first quarter of 2018. For the disclosures required by this ASU, see Note F . In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments-Overall: Recognition and Measurement of Financial Assets and Financial Liabilities . The standard primarily affects accounting for equity investments, financial liabilities under the fair value option and the presentation and disclosure requirements for financial instruments, and eliminates the cost method of accounting for equity investments. The Company adopted this standard in the first quarter of 2018 which resulted in a cumulative effect adjustment of $4.1 million on the Statement of Condensed Consolidated Equity. In February 2016, the FASB issued ASU No. 2016-02, Leases . The standard requires an entity to record assets and obligations for contracts currently recognized as operating leases. Lessees and lessors must apply a modified retrospective transition approach. The ASU will be effective for annual reporting periods beginning after December 15, 2018, including interim periods within that reporting period, with early adoption permitted. The Company has performed a high-level identification of agreements covered by this standard, is currently evaluating processes and internal controls and is in the process of implementing a third-party supported lease accounting information system to facilitate the accounting and financial reporting requirements. In June 2016, the FASB issued ASU No. 2016-13, Financial Instruments-Credit Losses: Measurement of Credit Losses on Financial Instruments . This ASU amends guidance on reporting credit losses for assets held at amortized cost basis and available for sale debt securities. For assets held at amortized cost basis, this ASU eliminates the probable initial recognition threshold in current GAAP and, instead, requires an entity to reflect its current estimate of all expected credit losses. The amendments affect loans, debt securities, trade receivables, net investments in leases, off balance sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope that have the contractual right to receive cash. The ASU will be effective for annual reporting periods beginning after December 15, 2019, including interim periods within that reporting period. The Company is currently evaluating the effect this standard will have on its financial statements and related disclosures. In November 2016, the FASB issued ASU No. 2016-18, Statement of Cash Flows: Restricted Cash. This ASU requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Therefore, amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning of period and end of period total amounts shown on the statement of cash flows. The Company adopted this standard in the first quarter of 2018. The Company had $75 million restricted cash at December 31, 2016. In accordance with ASU 2016-18, restricted cash is included in the beginning of period cash balance and excluded from investing activities on the Statements of Condensed Consolidated Cash Flows for the six months ended June 30, 2017 . The Company had no restricted cash on the Condensed Consolidated Balance Sheet from March 31, 2017 through the current period. In January 2017, the FASB issued ASU No. 2017-01, Business Combinations: Clarifying the Definition of a Business . This ASU clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be recorded as acquisitions (or disposals) of assets or businesses. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. In January 2017, the FASB issued ASU No. 2017-04, Simplifying the Test of Goodwill Impairment . This ASU simplifies the quantitative goodwill impairment test requirements by eliminating the requirement to calculate the implied fair value of goodwill (Step 2 of the current goodwill impairment test). Instead, a company would record an impairment charge based on the excess of a reporting unit’s carrying value over its fair value (measured in Step 1 of the current goodwill impairment test). Entities will apply the standard’s provisions prospectively. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. In March 2017, the FASB issued ASU No. 2017-07, Compensation - Retirement Benefits: Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost . This ASU provides additional guidance on the presentation of net benefit cost in the income statement and on the components eligible for capitalization in assets. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. In May 2017, the FASB issued ASU No. 2017-09, Compensation - Stock Compensation: Scope of Modification Accounting . This ASU provides guidance regarding which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting. The Company adopted this standard in the first quarter of 2018 with no significant effect on its financial statements or related disclosures. This ASU will be applied prospectively to awards modified on or after the adoption date. In February 2018, the FASB issued ASU No. 2018-02, Income Statement—Reporting Comprehensive Income: Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income. This ASU allows companies to reclassify stranded tax effects resulting from the Tax Reform Legislation from accumulated other comprehensive income to retained earnings. The ASU is effective for fiscal years beginning after December 15, 2018 and early adoption is permitted. The reclassification permitted under this ASU should be applied either in the period of adoption or retrospectively to each period (or periods) in which the effect of the change in the U.S. federal corporate income tax rate in the Tax Reform Legislation is recognized. The Company is currently evaluating the effect this standard will have on its financial statements and related disclosures.

Financial Statements Financial

Financial Statements Financial Statements (Tables)	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Business Acquisition, Pro Forma Information	The following unaudited pro forma combined financial information presents the Company’s results as though the Rice Merger had been completed at January 1, 2017. The pro forma combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the Rice Merger taken place on January 1, 2017; furthermore, the financial information is not intended to be a projection of future results. (in thousands, except per share data) (unaudited) Three Months Ended June 30, 2017 Six Months Ended June 30, 2017 Pro forma operating revenues $ 1,183,044 $ 2,449,427 Pro forma net income $ 246,313 $ 482,383 Pro forma net income attributable to noncontrolling interests $ (111,108 ) $ (220,193 ) Pro forma net income attributable to EQT $ 135,205 $ 262,190 Pro forma income per share (basic) $ 0.51 $ 0.99 Pro forma income per share (diluted) $ 0.51 $ 0.99

Revenue from Contracts with C32

Revenue from Contracts with Customers (Tables)	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	The table below provides disaggregated information regarding the Company’s revenues, presented consistently with the Company’s segment reporting. Certain contracts that provide for the release of capacity that is not used to transport the Company’s produced volumes were deemed to be outside the scope of Revenue from Contracts with Customers. The cost of, and recoveries on, that capacity are reported within pipeline and net marketing services at EQT Production. Derivative contracts are also outside the scope of Revenue from Contracts with Customers. Three Months Ended June 30, 2018 Revenues from contracts with customers Other sources of revenue Total (Thousands) Natural gas sales $ 855,924 $ — $ 855,924 NGLs sales 125,657 — 125,657 Oil sales 9,784 — 9,784 Sales of natural gas, oil and NGLs $ 991,365 $ — $ 991,365 Pipeline and net marketing services at EQT Production $ 9,391 $ 3,789 $ 13,180 EQM Gathering: Firm reservation fee revenues 111,702 — 111,702 Volumetric based fee revenues: Usage fees under firm contracts 9,956 — 9,956 Usage fees under interruptible contracts 58,958 — 58,958 EQM Transmission: Firm reservation fee revenues 82,222 — 82,222 Volumetric based fee revenues: Usage fees under firm contracts 4,828 — 4,828 Usage fees under interruptible contracts 2,095 — 2,095 RMP Gathering: Gathering revenues 52,966 — 52,966 Compression revenues 9,315 — 9,315 Water services at RMP Water 42,655 — 42,655 Intersegment eliminations (270,674 ) — (270,674 ) Pipeline, water and net marketing services $ 113,414 $ 3,789 $ 117,203 Loss on derivatives not designated as hedges $ — $ (53,897 ) $ (53,897 ) Total operating revenues $ 1,104,779 $ (50,108 ) $ 1,054,671 Six Months Ended June 30, 2018 Revenues from contracts with customers Other sources of revenue Total (Thousands) Natural gas sales $ 1,945,684 $ — $ 1,945,684 NGLs sales 251,125 — 251,125 Oil sales 20,930 — 20,930 Sales of natural gas, oil and NGLs $ 2,217,739 $ — $ 2,217,739 Pipeline and net marketing services at EQT Production $ 11,668 $ 24,582 $ 36,250 EQM Gathering: Firm reservation fee revenues 221,635 — 221,635 Volumetric based fee revenues: Usage fees under firm contracts 22,064 — 22,064 Usage fees under interruptible contracts 116,545 — 116,545 EQM Transmission: Firm reservation fee revenues 179,997 — 179,997 Volumetric based fee revenues: Usage fees under firm contracts 8,650 — 8,650 Usage fees under interruptible contracts 7,432 — 7,432 RMP Gathering: Gathering revenues 105,696 — 105,696 Compression revenues 18,086 — 18,086 Water services at RMP Water 65,618 — 65,618 Intersegment eliminations (520,153 ) — (520,153 ) Pipeline, water and net marketing services $ 237,238 $ 24,582 $ 261,820 Gain on derivatives not designated as hedges $ — $ 8,695 $ 8,695 Total operating revenues $ 2,454,977 $ 33,277 $ 2,488,254
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	The following table includes the transaction price allocated to the Company's remaining performance obligations on all contracts with fixed consideration. The table excludes all contracts that qualified for the exception to the relative standalone selling price method. Gathering firm reservation fees and transmission and storage firm reservation fees include amounts related to affiliate contracts. 2018 (a) 2019 2020 2021 2022 Thereafter Total (Thousands) Natural gas sales $ 36,865 $ 24,841 $ 1,275 $ — $ — $ — $ 62,981 Gathering firm reservation fees $ 227,675 $ 476,730 $ 552,308 $ 562,307 $ 561,019 $ 2,841,280 $ 5,221,319 Gathering revenues supported by MVCs $ — $ 65,700 $ 71,370 $ 71,175 $ 71,175 $ 136,875 $ 416,295 Transmission and storage firm reservation fees $ 179,786 $ 347,061 $ 347,261 $ 341,769 $ 338,010 $ 2,602,572 $ 4,156,459 (a) July 1 through December 31.

Consolidated Variable Interes33

Consolidated Variable Interest Entities (Tables)	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of amounts included in balance sheets, consolidated operations and cash flows of EQGP and EQM	The following table presents amounts included in the Company's Condensed Consolidated Balance Sheets that were for the use or obligation of EQGP or EQM as of June 30, 2018 and December 31, 2017 . Classification June 30, 2018 December 31, 2017 (Thousands) Assets: Cash and cash equivalents $ 684,456 $ 2,857 Accounts receivable 47,587 28,804 Prepaid expenses and other 9,556 8,470 Property, plant and equipment, net 3,922,144 2,804,059 Goodwill 37,954 — Intangible assets, net 596,887 — Other assets 1,028,418 483,004 Liabilities: Accounts payable $ 84,969 $ 47,042 Other current liabilities 484,884 133,531 Credit facility borrowings — 180,000 Senior Notes 3,453,975 987,352 Other liabilities and credits 21,442 20,273 The following table summarizes EQGP's Statements of Consolidated Operations and Cash Flows for the three and six months ended June 30, 2018 and 2017 , inclusive of affiliate amounts. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Operating revenues $ 269,761 $ 198,966 $ 556,323 $ 402,392 Operating expenses 89,419 58,463 166,875 117,988 Other expenses 8,777 1,949 9,768 3,862 Net income $ 171,565 $ 138,554 $ 379,680 $ 280,542 Net cash provided by operating activities $ 219,297 $ 158,886 $ 440,071 $ 319,655 Net cash used in investing activities (1,422,852 ) (125,612 ) (1,676,669 ) (207,299 ) Net cash provided by (used in) financing activities 1,852,799 (63,255 ) 1,876,692 (160,022 ) The following table presents amounts included in the Company’s Condensed Consolidated Balance Sheets that are for the use or obligation of RMP as of June 30, 2018 and December 31, 2017 . Classification June 30, 2018 December 31, 2017 (Thousands) Assets: Cash and cash equivalents $ 17,339 $ 10,538 Accounts receivable 9,016 12,246 Prepaid expenses and other 541 1,327 Property, plant and equipment, net 1,479,671 1,431,802 Goodwill 1,346,918 1,346,918 Other assets 8,871 — Liabilities: Accounts payable $ 30,966 $ 24,634 Other current liabilities 2,338 4,200 Credit facility borrowings 260,000 286,000 Other liabilities and credits 9,572 9,360 The following table summarizes RMP’s Statements of Consolidated Operations and Cash Flows for the three and six months ended June 30, 2018 and 2017 , inclusive of affiliate amounts. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Operating revenues $ 104,936 $ — $ 189,400 $ — Operating expenses 41,341 — 70,340 — Other expenses 2,382 — 4,330 — Net income $ 61,213 $ — $ 114,730 $ — Net cash provided by operating activities $ 118,725 $ — $ 181,261 $ — Net cash used in investing activities (47,358 ) — (80,070 ) — Net cash used in financing activities (100,546 ) — (94,390 ) —

Financial Information by Busi34

Financial Information by Business Segment (Tables)	6 Months Ended
	Jun. 30, 2018
Segment Reporting [Abstract]
Schedule of company's operating revenues, income from operations and assets	Three Months Ended June 30, 2018 EQT Production EQM Gathering EQM Transmission RMP RMP Intersegment Eliminations EQT Corporation Revenues: (Thousands) Sales of natural gas, oil and NGLs $ 991,365 $ — $ — $ — $ — $ — $ 991,365 Pipeline, water and net marketing services 13,180 180,616 89,145 62,281 42,655 (270,674 ) 117,203 Loss on derivatives not designated as hedges (53,897 ) — — — — — (53,897 ) Total operating revenues $ 950,648 $ 180,616 $ 89,145 $ 62,281 $ 42,655 $ (270,674 ) $ 1,054,671 Three Months Ended June 30, 2017 EQT Production EQM Gathering EQM Transmission Intersegment Eliminations EQT Corporation Revenues: (Thousands) Sales of natural gas, oil and NGLs $ 576,714 $ — $ — $ — $ 576,714 Pipeline and net marketing services 8,061 112,145 84,670 (139,174 ) 65,702 Gain on derivatives not designated as hedges 46,326 — — — 46,326 Total operating revenues $ 631,101 $ 112,145 $ 84,670 $ (139,174 ) $ 688,742 Six Months Ended June 30, 2018 EQT Production EQM Gathering EQM Transmission RMP Gathering RMP Water Intersegment Eliminations EQT Corporation Revenues: (Thousands) Sales of natural gas, oil and NGLs $ 2,217,739 $ — $ — $ — $ — $ — $ 2,217,739 Pipeline and net marketing services 36,250 360,244 196,079 123,782 65,618 (520,153 ) 261,820 Gain on derivatives not designated as hedges 8,695 — — — — — 8,695 Total operating revenues $ 2,262,684 $ 360,244 $ 196,079 $ 123,782 $ 65,618 $ (520,153 ) $ 2,488,254 Six Months Ended June 30, 2017 EQT Production EQM Gathering EQM Transmission Intersegment Eliminations EQT Corporation Revenues: (Thousands) Sales of natural gas, oil and NGLs $ 1,250,179 $ — $ — $ — $ 1,250,179 Pipeline and net marketing services 22,516 214,474 182,413 (273,739 ) 145,664 Gain on derivatives not designated as hedges 187,068 — — — 187,068 Total operating revenues $ 1,459,763 $ 214,474 $ 182,413 $ (273,739 ) $ 1,582,911 Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Operating income (loss): EQT Production (a) $ (79,846 ) $ 52,884 $ (2,005,645 ) $ 310,433 EQM Gathering 121,631 83,425 252,513 157,129 EQM Transmission 60,642 57,863 140,093 129,467 RMP Gathering 39,614 — 83,709 — RMP Water 23,981 — 35,351 — Unallocated expenses and intersegment eliminations (b) (66,053 ) (4,045 ) (129,568 ) (15,926 ) Total operating income (loss) $ 99,969 $ 190,127 $ (1,623,547 ) $ 581,103 (a) Impairment of long-lived assets of $0.1 billion is included in EQT Production operating income for the three months ended June 30, 2018 and $2.4 billion for the six months ended June 30, 2018 . See Note Q . (b) Unallocated expenses consist of compensation expense and administrative costs, including transaction costs of $19.7 million for the three months ended June 30, 2018 and $54.5 million for the six months ended June 30, 2018 . Intersegment eliminations include the profit on water services that are provided to EQT Production and capitalized as part of development costs of $24.9 million for the three months ended June 30, 2018 and $47.5 million for the six months ended June 30, 2018 .
Reconciliation of operating income to income from continuing operations	Reconciliation of operating income (loss) to net income (loss): Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Total operating income (loss) $ 99,969 $ 190,127 $ (1,623,547 ) $ 581,103 Other income 11,752 6,305 21,337 9,354 Interest expense 77,004 44,078 147,017 86,733 Income tax (benefit) expense (101,629 ) 29,709 (440,594 ) 130,374 Net income (loss) $ 136,346 $ 122,645 $ (1,308,633 ) $ 373,350
Schedule of segment assets	June 30, 2018 December 31, 2017 (Thousands) Segment assets: EQT Production $ 19,393,931 $ 21,015,132 EQM Gathering 3,151,655 2,961,099 EQM Transmission 2,486,059 1,923,427 RMP Gathering 2,800,534 2,720,305 RMP Water 165,476 185,079 Total operating segments 27,997,655 28,805,042 Headquarters assets, including cash and short-term investments 965,573 717,562 Total assets $ 28,963,228 $ 29,522,604
Schedule of depreciation, depletion and amortization and expenditures for segment assets	Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (Thousands) Depreciation and depletion: (c) EQT Production $ 374,782 $ 219,211 $ 770,635 $ 430,308 EQM Gathering 15,646 9,555 30,590 18,415 EQM Transmission 12,430 11,845 24,871 23,532 RMP Gathering 8,236 — 16,360 — RMP Water 5,798 — 11,569 — Other 780 206 1,540 480 Total $ 417,672 $ 240,817 $ 855,565 $ 472,735 Expenditures for segment assets: (d) EQT Production (e) $ 739,183 $ 455,721 $ 1,369,941 $ 1,401,179 EQM Gathering 139,099 53,708 252,297 102,546 EQM Transmission 27,962 29,978 46,891 51,367 RMP Gathering 47,358 — 68,298 — RMP Water 7,002 — 9,377 — Other and intersegment eliminations (f) (21,889 ) 2,967 (43,112 ) 4,595 Total $ 938,715 $ 542,374 $ 1,703,692 $ 1,559,687 (c) Excludes amortization of intangible assets. (d) Includes the capitalized portion of non-cash stock-based compensation costs, non-cash acquisitions and the impact of capital accruals. The impact of accrued capital expenditures includes the reversal of the prior period accrual as well as the current period estimate, both of which are non-cash items. The net impact of these non-cash items was $(34.3) million and $37.4 million for the three months ended June 30, 2018 and 2017 , respectively, and $6.6 million and $58.4 million for the six months ended June 30, 2018 and 2017 , respectively. These non-cash items are excluded from capital expenditures on the Statements of Condensed Consolidated Cash Flows. Expenditures for segment assets does not include consideration for the Rice Merger. (e) Expenditures for segment assets in the EQT Production segment included $41.3 million and $47.0 million for fill-ins and bolt-ons associated with legacy EQT acreage for the three months ended June 30, 2018 and 2017 , respectively, and $78.1 million and $89.7 million for fill-ins and bolt-ons associated with legacy EQT acreage for the six months ended June 30, 2018 and 2017 , respectively. The three and six months ended June 30, 2017 included $141.7 million and $811.2 million of cash capital expenditures, respectively, and $9.7 million of non-cash capital expenditures for the six months ended June 30, 2017 , for the acquisitions discussed in Note P . (f) Intersegment eliminations include profit on water services that are provided to EQT Production and capitalized as part of development costs.

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of impact of netting agreements and margin deposits on gross derivative assets	The table below reflects the impact of netting agreements and margin deposits on gross derivative assets and liabilities as of June 30, 2018 and December 31, 2017 . As of June 30, 2018 Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross Derivative instruments subject to master netting agreements Margin deposits remitted to counterparties Derivative instruments, net (Thousands) Asset derivatives: Derivative instruments, at fair value $ 270,288 $ (94,320 ) $ (3,105 ) $ 172,863 Liability derivatives: Derivative instruments, at fair value $ 146,061 $ (94,320 ) $ — $ 51,741 As of December 31, 2017 Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross Derivative instruments subject to master netting agreements Margin deposits remitted to counterparties Derivative instruments, net (Thousands) Asset derivatives: Derivative instruments, at fair value $ 241,952 $ (86,856 ) $ — $ 155,096 Liability derivatives: Derivative instruments, at fair value $ 139,089 $ (86,856 ) $ — $ 52,233
Schedule of impact of netting agreements and margin deposits on gross derivative liabilities	The table below reflects the impact of netting agreements and margin deposits on gross derivative assets and liabilities as of June 30, 2018 and December 31, 2017 . As of June 30, 2018 Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross Derivative instruments subject to master netting agreements Margin deposits remitted to counterparties Derivative instruments, net (Thousands) Asset derivatives: Derivative instruments, at fair value $ 270,288 $ (94,320 ) $ (3,105 ) $ 172,863 Liability derivatives: Derivative instruments, at fair value $ 146,061 $ (94,320 ) $ — $ 51,741 As of December 31, 2017 Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross Derivative instruments subject to master netting agreements Margin deposits remitted to counterparties Derivative instruments, net (Thousands) Asset derivatives: Derivative instruments, at fair value $ 241,952 $ (86,856 ) $ — $ 155,096 Liability derivatives: Derivative instruments, at fair value $ 139,089 $ (86,856 ) $ — $ 52,233

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Schedule of assets and liabilities measured at fair value on a recurring basis	The following assets and liabilities were measured at fair value on a recurring basis during the applicable period: Fair value measurements at reporting date using Description As of June 30, 2018 Quoted prices in active markets for identical assets (Level 1) Significant other observable inputs (Level 2) Significant unobservable inputs (Level 3) (Thousands) Assets Derivative instruments, at fair value $ 270,288 $ — $ 270,288 $ — Liabilities Derivative instruments, at fair value $ 146,061 $ — $ 146,061 $ — Fair value measurements at reporting date using Description As of December 31, 2017 Quoted prices in active markets for identical assets (Level 1) Significant other observable inputs (Level 2) Significant unobservable inputs (Level 3) (Thousands) Assets Derivative instruments, at fair value $ 241,952 $ — $ 241,952 $ — Liabilities Derivative instruments, at fair value $ 139,089 $ — $ 139,089 $ —

Changes in Accumulated Other 37

Changes in Accumulated Other Comprehensive Income by Component (Tables)	6 Months Ended
	Jun. 30, 2018
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Schedule of the changes in accumulated OCI by component	The following tables explain the changes in accumulated other comprehensive income (OCI) by component during the applicable period: Three Months Ended June 30, 2018 Natural gas cash flow hedges, net of tax Interest rate cash flow hedges, net of tax Other post- retirement benefit liability adjustment, net of tax Accumulated OCI, net of tax (Thousands) Accumulated OCI (loss), net of tax, as of April 1, 2018 $ 4,338 $ (511 ) $ (6,442 ) $ (2,615 ) (Gains) losses reclassified from accumulated OCI, net of tax (466 ) (a) 36 (a) 86 (b) (344 ) Accumulated OCI (loss), net of tax, as of June 30, 2018 $ 3,872 $ (475 ) $ (6,356 ) $ (2,959 ) Three Months Ended June 30, 2017 Natural gas cash Interest rate Other post- Accumulated (Thousands) Accumulated OCI (loss), net of tax, as of April 1, 2017 $ 8,719 $ (663 ) $ (6,790 ) $ 1,266 (Gains) losses reclassified from accumulated OCI, net of tax (1,672 ) (a) 36 (a) 77 (b) (1,559 ) Accumulated OCI (loss), net of tax, as of June 30, 2017 $ 7,047 $ (627 ) $ (6,713 ) $ (293 ) Six Months Ended June 30, 2018 Natural gas cash flow hedges, net of tax Interest rate cash flow hedges, net of tax Other post- retirement benefit liability adjustment, net of tax Accumulated OCI, net of tax (Thousands) Accumulated OCI (loss), net of tax, as of January 1, 2018 $ 4,625 $ (555 ) $ (6,528 ) $ (2,458 ) (Gains) losses reclassified from accumulated OCI, net of tax (753 ) (a) 80 (a) 172 (b) (501 ) Accumulated OCI (loss), net of tax, as of June 30, 2018 $ 3,872 $ (475 ) $ (6,356 ) $ (2,959 ) Six Months Ended June 30, 2017 Natural gas cash flow hedges, net of tax Interest rate cash flow hedges, net of tax Pension and other post- retirement benefits liability adjustment, net of tax Accumulated OCI, net of tax (Thousands) Accumulated OCI (loss), net of tax, as of January 1, 2017 $ 9,607 $ (699 ) $ (6,866 ) $ 2,042 (Gains) losses reclassified from accumulated OCI, net of tax (2,560 ) (a) 72 (a) 153 (b) (2,335 ) Accumulated OCI (loss), net of tax, as of June 30, 2017 $ 7,047 $ (627 ) $ (6,713 ) $ (293 ) (a) (Gains) losses reclassified from accumulated OCI, net of tax related to natural gas cash flow hedges were reclassified into operating revenues. Losses from accumulated OCI, net of tax related to interest rate cash flow hedges were reclassified into interest expense. (b) The accumulated OCI reclassification is attributable to the net actuarial loss and net prior service cost related to the Company’s post-retirement benefit plans. See Note 1 to the Consolidated Financial Statements in the Company’s Annual Report on Form 10-K for the year ended December 31, 2017 for additional information.

Divestitures Divestitures (Tabl

Divestitures Divestitures (Tables)	6 Months Ended
	Jun. 30, 2018
Discontinued Operations and Disposal Groups [Abstract]
Disposal Groups Classified as Held for Sale	The following table presents amounts included in the Company’s Condensed Consolidated Balance Sheet that are classified as held for sale as of June 30, 2018 related to the Huron Divestiture. Classification June 30, 2018 December 31, 2017 (Thousands) Assets: Property, plant and equipment, net $ 719,584 $ — Liabilities: Other current liabilities 4,763 — Other liabilities and credits 190,541 —

Financial Statements Financia39

Financial Statements Financial Statements (Details) - Rice Merger Agreement - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended	6 Months Ended
	Jun. 30, 2017	Jun. 30, 2017
Business Acquisition [Line Items]
Pro forma operating revenues	$ 1,183,044	$ 2,449,427
Pro forma net income	246,313	482,383
Pro forma net income attributable to noncontrolling interests	(111,108)	(220,193)
Pro forma net income attributable to EQT	$ 135,205	$ 262,190
Pro forma income per share (basic) (in dollars per share)	$ 0.51	$ 0.99
Pro forma income per share (diluted) (in dollars per share)	$ 0.51	$ 0.99

Midstream Streamlining Transa40

Midstream Streamlining Transactions and Financing - Additional Information (Details)	Jul. 23, 2018USD ($)shares	May 22, 2018USD ($)shares	May 01, 2018USD ($)	Jun. 25, 2018USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Sep. 30, 2018USD ($)	May 21, 2018	Apr. 25, 2018USD ($)
Business Acquisition [Line Items]
Payments to acquire businesses, gross							$ 0	$ 811,207,000
Noncontrolling interest, decrease							$ 175,000,000
Strike Force Midstream Holdings | Strike Force Midstream LLC
Business Acquisition [Line Items]
General partner interest							75.00%
EQM | Senior Notes Due 2023 | Senior Notes
Business Acquisition [Line Items]
Interest rate, stated percentage					4.75%		4.75%
Face amount					$ 1,100,000,000		$ 1,100,000,000
EQM | Senior Notes Due 2028 | Senior Notes
Business Acquisition [Line Items]
Interest rate, stated percentage					5.50%		5.50%
Face amount					$ 850,000,000		$ 850,000,000
EQM | Senior Notes Due 2048 | Senior Notes
Business Acquisition [Line Items]
Interest rate, stated percentage					6.50%		6.50%
Face amount					$ 550,000,000		$ 550,000,000
EQM | The Notes | Senior Notes
Business Acquisition [Line Items]
Proceeds from debt					2,465,800,000
Unamortized discount					11,800,000		11,800,000
Debt issuance costs, gross					22,400,000		22,400,000
EQM | EQM Term Loan Facility
Business Acquisition [Line Items]
Line of credit facility, maximum borrowing capacity											$ 2,500,000,000
Debt issuance costs, net							3,000,000
Maximum amount of outstanding short-term loans at any time during the period				$ 1,825,000,000
Average daily balance of short-term loans outstanding during the period				$ 1,231,000,000
Debt, weighted average interest rate				3.30%
EQM | Revolving credit facility
Business Acquisition [Line Items]
Line of credit facility, maximum borrowing capacity					1,000,000,000		1,000,000,000
Maximum amount of outstanding short-term loans at any time during the period					338,000,000	$ 0	420,000,000	$ 0
Average daily balance of short-term loans outstanding during the period					$ 122,000,000		$ 211,000,000
EQM | Strike Force Midstream LLC
Business Acquisition [Line Items]
Ownership percentage by parent			25.00%		100.00%		100.00%
Drop-Down Transactions
Business Acquisition [Line Items]
Equity interests issued and issuable (in shares)		$ 5,889,282
Payments to acquire businesses, gross		1,150,000,000
Additional paid in capital, increase		15,500,000
Noncontrolling interest, decrease		20,300,000
Deferred tax liabilities, increase		4,800,000
Gulfport Transaction | EQM
Business Acquisition [Line Items]
Payments to acquire businesses and interest in affiliates			$ 175,000,000
IDR Transaction
Business Acquisition [Line Items]
Additional paid in capital, increase		(35,100,000)
Deferred tax liabilities, increase		(11,000,000)
Increase from business combination		$ 46,100,000
IDR Transaction | EQGP
Business Acquisition [Line Items]
Ownership percentage by parent		91.30%								90.10%
IDR Transaction | EQGP
Business Acquisition [Line Items]
Equity interest issued or issuable, number of shares (in shares) | shares		36,293,766
Midstream Mergers | EQM | Subsequent Event
Business Acquisition [Line Items]
Equity interest issued or issuable, number of shares (in shares) | shares	34,000,000
Repayments of debt	$ 260,000,000
Midstream Mergers | Rice Midstream Partners, LP | Subsequent Event
Business Acquisition [Line Items]
Common share conversion ratio	0.3319
Scenario, Forecast | SpinCo
Business Acquisition [Line Items]
Distribution rate of common stock									80.10%
Scenario, Forecast | EQM | Revolving credit facility
Business Acquisition [Line Items]
Line of credit facility, maximum borrowing capacity									$ 2,000,000,000
Indirect Wholly Owned Subsidiary | Midstream Mergers | EQM | Subsequent Event
Business Acquisition [Line Items]
Equity interest issued or issuable, number of shares (in shares) | shares	9,554,530

EQT GP Holdings, LP (Details)

EQT GP Holdings, LP (Details) - USD ($) $ / shares in Units, $ in Millions	Aug. 23, 2018	Jul. 24, 2018	May 22, 2018	Jun. 30, 2018
General Partner Common
Class of Stock [Line Items]
Incentive distribution rights distributed in respect of each common unit and general partner unit (in dollars per share)				$ 0.5250
Affiliated Entity | Limited Partner Common
Class of Stock [Line Items]
Number of common units (in shares)				276,008,766
EQGP
Class of Stock [Line Items]
Percentage of all incremental cash distributed (up to)				48.00%
EQGP | Subsequent Event
Class of Stock [Line Items]
Cash distribution declared (in dollars per share)		$ 0.306
Cash distribution declared		$ 92.6
EQGP | General Partner
Class of Stock [Line Items]
General partner interest				1.60%
EQGP | Affiliated Entity | Limited Partner Common
Class of Stock [Line Items]
Number of common units (in shares)				21,811,643
EQGP | Affiliated Entity | General Partner
Class of Stock [Line Items]
Number of general partner units (in shares)				1,443,015
IDR Transaction | EQGP
Class of Stock [Line Items]
Equity interest issued or issuable, number of shares (in shares)			36,293,766
EQGP | Affiliated Entity | Limited Partner Common
Class of Stock [Line Items]
Limited partner interest				91.30%
EQM | EQGP | Affiliated Entity | Limited Partner Common
Class of Stock [Line Items]
Limited partner interest				24.80%
Scenario, Forecast | EQGP
Class of Stock [Line Items]
Distribution Made to Limited Partner, Cash Distributions Paid	$ 84.5

EQT Midstream Partners, LP (Det

EQT Midstream Partners, LP (Details) - USD ($) $ / shares in Units, $ in Millions	Jul. 26, 2018	Jul. 24, 2018	Jun. 30, 2018
EQT Corporation | EQM
Subsidiary or equity method investee
Limited partner interest			6.70%
EQM
Subsidiary or equity method investee
Cash distribution declared			$ 16.8
EQM | Subsequent Event
Subsidiary or equity method investee
Distribution made to limited partner and general partner, cash distributions declared	$ 94.3
Cash distribution declared	23.8
Distribution made to general partner, cash distributions declared	2.4
Cash distribution declared related to IDRs	$ 68.1
General Partner | EQM
Subsidiary or equity method investee
Common unit, outstanding (in shares)			5,889,282
General Partner | EQM | Subsequent Event
Subsidiary or equity method investee
Cash distribution declared (in dollars per share)		$ 1.090

Rice Midstream Partners LP Ri43

Rice Midstream Partners LP Rice Midstream Partners LP (Details)	Nov. 13, 2017
Rice Midstream Partners, LP | EQT Corporation
Subsidiary of Limited Liability Company or Limited Partnership [Line Items]
Limited partner interest	28.10%

Revenue from Contracts with C44

Revenue from Contracts with Customers - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Contract with customer, asset, net	$ 441,100		$ 441,100
Revenues from contracts with customers	1,104,779		2,454,977
(Loss) gain on derivatives not designated as hedges	(53,897)	$ 46,326	8,695	$ 187,068
Other sources of revenue	(50,108)		33,277
Total operating revenues	1,054,671	688,742	$ 2,488,254	1,582,911
Gathering, Transmission, and Storage Services
Disaggregation of Revenue [Line Items]
Number of days in which payment is required			21 days
Natural Gas Sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	855,924		$ 1,945,684
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	855,924		1,945,684
NGLs Sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	125,657		251,125
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	125,657		251,125
Oil Sales
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9,784		20,930
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	9,784		$ 20,930
Natural Gas, Oil, and NGLs Sales
Disaggregation of Revenue [Line Items]
Number of days in which payment is required			25 days
Revenues from contracts with customers	991,365		$ 2,217,739
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	991,365		$ 2,217,739
Water Services
Disaggregation of Revenue [Line Items]
Number of days in which payment is required			21 days
Pipeline, Water and Net Marketing Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	113,414		$ 237,238
Other sources of revenue, excluding gain (loss) on derivatives	3,789		24,582
Total, excluding gain (loss) on derivatives	117,203		261,820
Intersegment Eliminations
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(270,674)		(520,153)
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	(270,674)		(520,153)
(Loss) gain on derivatives not designated as hedges	0	0	0	0
Total operating revenues	(270,674)	$ (139,174)	(520,153)	$ (273,739)
EQT Production | Pipeline and Net Marketing Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9,391		11,668
Other sources of revenue, excluding gain (loss) on derivatives	3,789		24,582
Total, excluding gain (loss) on derivatives	13,180		36,250
EQM Gathering | Firm Reservation Fee Revenue
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	111,702		221,635
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	111,702		221,635
EQM Gathering | Usage Fees Under Firm Contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9,956		22,064
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	9,956		22,064
EQM Gathering | Usage Fees Under Interruptible Contract
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	58,958		116,545
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	58,958		116,545
EQM Transmission | Firm Reservation Fee Revenue
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	82,222		179,997
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	82,222		179,997
EQM Transmission | Usage Fees Under Firm Contracts
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,828		8,650
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	4,828		8,650
EQM Transmission | Usage Fees Under Interruptible Contract
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,095		7,432
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	2,095		7,432
RMP Gathering | Gathering Revenues
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	52,966		105,696
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	52,966		105,696
RMP Gathering | Compression Revenues
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	9,315		18,086
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	9,315		18,086
RMP Water | Water Services
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	42,655		65,618
Other sources of revenue, excluding gain (loss) on derivatives	0		0
Total, excluding gain (loss) on derivatives	$ 42,655		$ 65,618
Minimum
Disaggregation of Revenue [Line Items]
Contract term					8 years
Maximum
Disaggregation of Revenue [Line Items]
Contract term					15 years

Revenue from Contracts with C45

Revenue from Contracts with Customers - Remaining Performance Obligations (Details) $ in Thousands	Jun. 30, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01 | Natural Gas Sales
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 36,865
Remaining performance obligation, expected timing of satisfaction, period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01 | Gathering Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 227,675
Remaining performance obligation, expected timing of satisfaction, period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01 | Gathering Revenues
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01 | Transmission and Storage Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 179,786
Remaining performance obligation, expected timing of satisfaction, period	6 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Natural Gas Sales
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 24,841
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Gathering Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 476,730
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Gathering Revenues
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 65,700
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Transmission and Storage Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 347,061
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Natural Gas Sales
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 1,275
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Gathering Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 552,308
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Gathering Revenues
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 71,370
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Transmission and Storage Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 347,261
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Natural Gas Sales
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Gathering Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 562,307
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Gathering Revenues
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 71,175
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Transmission and Storage Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 341,769
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Natural Gas Sales
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Gathering Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 561,019
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Gathering Revenues
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 71,175
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Transmission and Storage Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 338,010
Remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Natural Gas Sales
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Remaining performance obligation, expected timing of satisfaction, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Gathering Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,841,280
Remaining performance obligation, expected timing of satisfaction, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Gathering Revenues
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 136,875
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Transmission and Storage Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,602,572
Remaining performance obligation, expected timing of satisfaction, period
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Natural Gas Sales
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 62,981
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Gathering Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	5,221,319
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Gathering Revenues
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	416,295
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Transmission and Storage Firm Reservation Fees
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 4,156,459

Investment in Nonconsolidated46

Investment in Nonconsolidated Entity (Details) $ in Millions	1 Months Ended				6 Months Ended
	Sep. 30, 2018USD ($)	Jul. 31, 2018USD ($)	May 31, 2018USD ($)	Apr. 30, 2018USD ($)	Jun. 30, 2018USD ($)mi	Dec. 31, 2020mi
Schedule of Equity Method Investments [Line Items]
Percent interest to require approval					66.67%
Issuance of performance guarantee					$ 91
Variable Interest Entity, Not Primary Beneficiary | MVP Joint Venture
Schedule of Equity Method Investments [Line Items]
Maximum financial statement exposure					$ 1,094
MVP Joint Venture
Schedule of Equity Method Investments [Line Items]
Capital call notice			$ 445.9
MVP Joint Venture | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Capital call notice paid	$ 252.5
MVP Joint Venture | Subsequent Event
Schedule of Equity Method Investments [Line Items]
Capital call notice paid		$ 193.4
MVP Joint Venture | EQM
Schedule of Equity Method Investments [Line Items]
Ownership percentage					45.50%
Mountain Valley Pipeline
Schedule of Equity Method Investments [Line Items]
Natural gas interstate pipeline (in miles) | mi					300
Mountain Valley Pipeline | Minimum
Schedule of Equity Method Investments [Line Items]
Estimated project cost				$ 3,500
Mountain Valley Pipeline | Maximum
Schedule of Equity Method Investments [Line Items]
Estimated project cost				3,700
MVP Southgate Project | Minimum
Schedule of Equity Method Investments [Line Items]
Estimated project cost				350
MVP Southgate Project | Maximum
Schedule of Equity Method Investments [Line Items]
Estimated project cost				$ 500
MVP Southgate Project | Scenario, Forecast
Schedule of Equity Method Investments [Line Items]
Natural gas interstate pipeline (in miles) | mi						70
MVP Southgate Project | MVP Joint Venture | EQM | Scenario, Forecast | Minimum
Schedule of Equity Method Investments [Line Items]
Ownership percentage						33.00%
MVP Southgate Project | MVP Joint Venture | EQM | Scenario, Forecast | Maximum
Schedule of Equity Method Investments [Line Items]
Ownership percentage						48.00%

Consolidated Variable Interes47

Consolidated Variable Interest Entities - Balance Sheets (Details) - Variable Interest Entity, Primary Beneficiary - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
EQGP and EQM | Cash and cash equivalents
Variable Interest Entity [Line Items]
Assets	$ 684,456	$ 2,857
EQGP and EQM | Accounts receivable
Variable Interest Entity [Line Items]
Assets	47,587	28,804
EQGP and EQM | Prepaid expenses and other
Variable Interest Entity [Line Items]
Assets	9,556	8,470
EQGP and EQM | Property, plant and equipment, net
Variable Interest Entity [Line Items]
Assets	3,922,144	2,804,059
EQGP and EQM | Goodwill
Variable Interest Entity [Line Items]
Assets	37,954	0
EQGP and EQM | Intangible assets, net
Variable Interest Entity [Line Items]
Assets	596,887	0
EQGP and EQM | Other assets
Variable Interest Entity [Line Items]
Assets	1,028,418	483,004
EQGP and EQM | Accounts payable
Variable Interest Entity [Line Items]
Liabilities	84,969	47,042
EQGP and EQM | Other current liabilities
Variable Interest Entity [Line Items]
Liabilities	484,884	133,531
EQGP and EQM | Credit facility borrowings
Variable Interest Entity [Line Items]
Liabilities	0	180,000
EQGP and EQM | Senior Notes
Variable Interest Entity [Line Items]
Liabilities	3,453,975	987,352
EQGP and EQM | Other liabilities and credits
Variable Interest Entity [Line Items]
Liabilities	21,442	20,273
RMP | Cash and cash equivalents
Variable Interest Entity [Line Items]
Assets	17,339	10,538
RMP | Accounts receivable
Variable Interest Entity [Line Items]
Assets	9,016	12,246
RMP | Prepaid expenses and other
Variable Interest Entity [Line Items]
Assets	541	1,327
RMP | Property, plant and equipment, net
Variable Interest Entity [Line Items]
Assets	1,479,671	1,431,802
RMP | Goodwill
Variable Interest Entity [Line Items]
Assets	1,346,918	1,346,918
RMP | Other assets
Variable Interest Entity [Line Items]
Assets	8,871	0
RMP | Accounts payable
Variable Interest Entity [Line Items]
Liabilities	30,966	24,634
RMP | Other current liabilities
Variable Interest Entity [Line Items]
Liabilities	2,338	4,200
RMP | Credit facility borrowings
Variable Interest Entity [Line Items]
Liabilities	260,000	286,000
RMP | Other liabilities and credits
Variable Interest Entity [Line Items]
Liabilities	$ 9,572	$ 9,360

Consolidated Variable Interes48

Consolidated Variable Interest Entities - Statements of Operations and Cash Flows (Details) - Variable Interest Entity, Primary Beneficiary - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
EQGP
Variable Interest Entity [Line Items]
Operating revenues	$ 269,761	$ 198,966	$ 556,323	$ 402,392
Operating expenses	89,419	58,463	166,875	117,988
Other (income) expenses	8,777	1,949	9,768	3,862
Net income	171,565	138,554	379,680	280,542
Net cash provided by operating activities	219,297	158,886	440,071	319,655
Net cash used in investing activities	(1,422,852)	(125,612)	(1,676,669)	(207,299)
Net cash provided by (used in) financing activities	1,852,799	(63,255)	1,876,692	(160,022)
RMP
Variable Interest Entity [Line Items]
Operating revenues	104,936	0	189,400	0
Operating expenses	41,341	0	70,340	0
Other (income) expenses	2,382	0	4,330	0
Net income	61,213	0	114,730	0
Net cash provided by operating activities	118,725	0	181,261	0
Net cash used in investing activities	(47,358)	0	(80,070)	0
Net cash provided by (used in) financing activities	$ (100,546)	$ 0	$ (94,390)	$ 0

Financial Information by Busi49

Financial Information by Business Segment - Schedule of Revenue from External Customers and Operating Income (Details) $ in Thousands	Nov. 12, 2017segment	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)segment	Jun. 30, 2017USD ($)	Dec. 31, 2017USD ($)	Nov. 13, 2017USD ($)
Operating segments information
Number of reportable segments | segment	3			5
Goodwill		$ 1,998,726		$ 1,998,726		$ 1,998,726
Revenues:
Sales of natural gas, oil and NGLs		1,104,779		2,454,977
(Loss) gain on derivatives not designated as hedges		(53,897)	$ 46,326	8,695	$ 187,068
Total operating revenues		1,054,671	688,742	2,488,254	1,582,911
Reconciliation of operating (loss) income to net (loss) income:
Total operating income (loss)		99,969	190,127	(1,623,547)	581,103
Other income		11,752	6,305	21,337	9,354
Interest expense		77,004	44,078	147,017	86,733
Income tax (benefit) expense		(101,629)	29,709	(440,594)	130,374
Net income (loss)		136,346	122,645	(1,308,633)	373,350
Transaction costs		25,959	4,238	61,670	4,238
Sales of natural gas, oil and NGLs
Revenues:
Sales of natural gas, oil and NGLs		991,365	576,714	2,217,739	1,250,179
Pipeline, water and net marketing services
Revenues:
Pipeline, water and net marketing services		117,203	65,702	261,820	145,664
EQT Production
Reconciliation of operating (loss) income to net (loss) income:
Impairment of long-lived assets		100,000		2,400,000
Operating Segments | EQT Production
Revenues:
(Loss) gain on derivatives not designated as hedges		(53,897)	46,326	8,695	187,068
Total operating revenues		950,648	631,101	2,262,684	1,459,763
Reconciliation of operating (loss) income to net (loss) income:
Total operating income (loss)		(79,846)	52,884	(2,005,645)	310,433
Operating Segments | EQT Production | Sales of natural gas, oil and NGLs
Revenues:
Sales of natural gas, oil and NGLs		991,365	576,714	2,217,739	1,250,179
Operating Segments | EQT Production | Pipeline, water and net marketing services
Revenues:
Pipeline, water and net marketing services		13,180	8,061	36,250	22,516
Operating Segments | EQM Gathering
Revenues:
(Loss) gain on derivatives not designated as hedges		0	0	0	0
Total operating revenues		180,616	112,145	360,244	214,474
Reconciliation of operating (loss) income to net (loss) income:
Total operating income (loss)		121,631	83,425	252,513	157,129
Operating Segments | EQM Gathering | Sales of natural gas, oil and NGLs
Revenues:
Sales of natural gas, oil and NGLs		0	0	0	0
Operating Segments | EQM Gathering | Pipeline, water and net marketing services
Revenues:
Pipeline, water and net marketing services		180,616	112,145	360,244	214,474
Operating Segments | EQM Transmission
Revenues:
(Loss) gain on derivatives not designated as hedges		0	0	0	0
Total operating revenues		89,145	84,670	196,079	182,413
Reconciliation of operating (loss) income to net (loss) income:
Total operating income (loss)		60,642	57,863	140,093	129,467
Operating Segments | EQM Transmission | Sales of natural gas, oil and NGLs
Revenues:
Sales of natural gas, oil and NGLs		0	0	0	0
Operating Segments | EQM Transmission | Pipeline, water and net marketing services
Revenues:
Pipeline, water and net marketing services		89,145	84,670	196,079	182,413
Operating Segments | RMP Gathering
Revenues:
(Loss) gain on derivatives not designated as hedges		0		0
Total operating revenues		62,281		123,782
Reconciliation of operating (loss) income to net (loss) income:
Total operating income (loss)		39,614	0	83,709	0
Operating Segments | RMP Gathering | Sales of natural gas, oil and NGLs
Revenues:
Sales of natural gas, oil and NGLs		0		0
Operating Segments | RMP Gathering | Pipeline, water and net marketing services
Revenues:
Pipeline, water and net marketing services		62,281		123,782
Operating Segments | RMP Water
Revenues:
(Loss) gain on derivatives not designated as hedges		0		0
Total operating revenues		42,655		65,618
Reconciliation of operating (loss) income to net (loss) income:
Total operating income (loss)		23,981	0	35,351	0
Operating Segments | RMP Water | Sales of natural gas, oil and NGLs
Revenues:
Sales of natural gas, oil and NGLs		0		0
Operating Segments | RMP Water | Pipeline, water and net marketing services
Revenues:
Pipeline, water and net marketing services		42,655		65,618
Intersegment Eliminations
Revenues:
Sales of natural gas, oil and NGLs		(270,674)		(520,153)
(Loss) gain on derivatives not designated as hedges		0	0	0	0
Total operating revenues		(270,674)	(139,174)	(520,153)	(273,739)
Intersegment Eliminations | Sales of natural gas, oil and NGLs
Revenues:
Sales of natural gas, oil and NGLs		0	0	0	0
Intersegment Eliminations | Pipeline, water and net marketing services
Revenues:
Pipeline, water and net marketing services		(270,674)	(139,174)	(520,153)	(273,739)
Unallocated Expenses
Reconciliation of operating (loss) income to net (loss) income:
Total operating income (loss)		(66,053)	$ (4,045)	(129,568)	$ (15,926)
Transaction costs		19,700		54,500
Income (loss) included in development costs		$ 24,900		$ 47,500
Previously Reported | Rice Merger Agreement
Operating segments information
Goodwill							$ 78,400

Financial Information by Busi50

Financial Information by Business Segment - Schedule of Segment Assets (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Segment assets:
Total assets	$ 28,963,228	$ 29,522,604
Operating Segments
Segment assets:
Total assets	27,997,655	28,805,042
Operating Segments | EQT Production
Segment assets:
Total assets	19,393,931	21,015,132
Operating Segments | EQM Gathering
Segment assets:
Total assets	3,151,655	2,961,099
Operating Segments | EQM Transmission
Segment assets:
Total assets	2,486,059	1,923,427
Operating Segments | RMP Gathering
Segment assets:
Total assets	2,800,534	2,720,305
Operating Segments | RMP Water
Segment assets:
Total assets	165,476	185,079
Headquarters assets, including cash and short-term investments
Segment assets:
Total assets	$ 965,573	$ 717,562

Financial Information by Busi51

Financial Information by Business Segment - Schedule of Depreciation, Amortization, and Expenditures (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Depreciation and depletion:
Depreciation and depletion	$ 417,672	$ 240,817	$ 855,565	$ 472,735
Expenditures for segment assets:
Expenditures for segment assets	938,715	542,374	1,703,692	1,559,687
Payments to acquire businesses, gross			0	811,207
Operating Segments | EQT Production
Depreciation and depletion:
Depreciation and depletion	374,782	219,211	770,635	430,308
Expenditures for segment assets:
Expenditures for segment assets	739,183	455,721	1,369,941	1,401,179
Accrual (reversal) of capital expenditures	(34,300)	37,400	6,600	58,400
Payments to acquire businesses, gross		141,700		811,200
Capital expenditures incurred but not yet paid				9,700
Operating Segments | EQT Production | Fill-ins and Bolt-ons
Expenditures for segment assets:
Expenditures for segment assets	41,300	47,000	78,100	89,700
Operating Segments | EQM Gathering
Depreciation and depletion:
Depreciation and depletion	15,646	9,555	30,590	18,415
Expenditures for segment assets:
Expenditures for segment assets	139,099	53,708	252,297	102,546
Operating Segments | EQM Transmission
Depreciation and depletion:
Depreciation and depletion	12,430	11,845	24,871	23,532
Expenditures for segment assets:
Expenditures for segment assets	27,962	29,978	46,891	51,367
Operating Segments | RMP Gathering
Depreciation and depletion:
Depreciation and depletion	8,236	0	16,360	0
Expenditures for segment assets:
Expenditures for segment assets	47,358	0	68,298	0
Operating Segments | RMP Water
Depreciation and depletion:
Depreciation and depletion	5,798	0	11,569	0
Expenditures for segment assets:
Expenditures for segment assets	7,002	0	9,377	0
Other
Depreciation and depletion:
Depreciation and depletion	780	206	1,540	480
Expenditures for segment assets:
Expenditures for segment assets	$ (21,889)	$ 2,967	$ (43,112)	$ 4,595

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details)	6 Months Ended	12 Months Ended
	Jun. 30, 2018USD ($)BcfMBbls	Dec. 31, 2017BcfMBbls
Derivative Instruments, Gain (Loss) [Line Items]
Maximum additional collateral as percentage of derivative liability	100.00%
Aggregate fair value of derivative instruments with credit-risk related contingencies	$ 70,700,000
Collateral posted	$ 0
Natural Gas Liquid Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative instruments (in Bcf, Mbbls) | MBbls	1,012	1,460
Cash flow hedging | Commodity derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Volume of derivative instruments (in Bcf, Mbbls) | Bcf	2,874	2,148

Derivative Instruments - Impact

Derivative Instruments - Impact of Netting Agreements and Margin Deposits (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Asset derivatives:
Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross	$ 270,288	$ 241,952
Liability derivatives:
Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross	146,061	139,089
Commodity derivatives
Asset derivatives:
Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross	270,288	241,952
Derivative instruments subject to master netting agreements	(94,320)	(86,856)
Margin deposits remitted to counterparties	(3,105)	0
Derivative instruments, net	172,863	155,096
Liability derivatives:
Derivative instruments, recorded in the Condensed Consolidated Balance Sheet, gross	146,061	139,089
Derivative instruments subject to master netting agreements	(94,320)	(86,856)
Margin deposits remitted to counterparties	0	0
Derivative instruments, net	$ 51,741	$ 52,233

Fair Value Measurements - Deriv

Fair Value Measurements - Derivative Instrument Assets and Liabilities Measured at Fair Value (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Assets
Derivative instruments, at fair value	$ 270,288	$ 241,952
Fair value on a recurring basis | Quoted prices in active markets for identical assets (Level 1)
Assets
Derivative instruments, at fair value	0	0
Liabilities
Derivative instruments, at fair value	0	0
Fair value on a recurring basis | Significant other observable inputs (Level 2)
Assets
Derivative instruments, at fair value	270,288	241,952
Liabilities
Derivative instruments, at fair value	146,061	139,089
Fair value on a recurring basis | Significant unobservable inputs (Level 3)
Assets
Derivative instruments, at fair value	0	0
Liabilities
Derivative instruments, at fair value	0	0
Fair value on a recurring basis | Fair value
Assets
Derivative instruments, at fair value	270,288	241,952
Liabilities
Derivative instruments, at fair value	$ 146,061	$ 139,089

Fair Value Measurements - Narra

Fair Value Measurements - Narrative (Details) - USD ($) $ in Billions	Jun. 30, 2018	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Estimated fair value of long-term debt	$ 8.1	$ 5.7

Income Taxes (Details)

Income Taxes (Details)	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Income Tax Disclosure [Abstract]
Effective tax rate	25.20%	25.90%

Revolving Credit Facilities (De

Revolving Credit Facilities (Details) - Revolving credit facility - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Sep. 30, 2018	Dec. 31, 2017
EQM
Line of Credit Facility
Line of credit facility, maximum borrowing capacity	$ 1,000,000,000		$ 1,000,000,000
Amount of borrowings	0	$ 0	0	$ 0		$ 180,000,000
Letters of credit outstanding under revolving credit facility	0	0	0	0		0
Maximum amount of outstanding short-term loans at any time during the period	338,000,000	0	420,000,000	0
Average daily balance of short-term loans outstanding during the period	$ 122,000,000		$ 211,000,000
Weighted average interest rates of average daily balance of short-term loans	3.40%		3.20%
EQM | Scenario, Forecast
Line of Credit Facility
Line of credit facility, maximum borrowing capacity					$ 2,000,000,000
EQT 2.5 Billion Facility
Line of Credit Facility
Line of credit facility, maximum borrowing capacity	$ 2,500,000,000		$ 2,500,000,000
Amount of borrowings	200,000,000	0	200,000,000	0		1,300,000,000
Letters of credit outstanding under revolving credit facility	0	0	0	0		159,400,000
Maximum amount of outstanding short-term loans at any time during the period	1,500,000,000	$ 0	1,600,000,000	$ 0
Average daily balance of short-term loans outstanding during the period	$ 900,000,000		$ 1,200,000,000
Weighted average interest rates of average daily balance of short-term loans	3.40%		3.20%
RMP $850 Million Facility
Line of Credit Facility
Amount of borrowings	$ 260,000,000		$ 260,000,000			286,000,000
Letters of credit outstanding under revolving credit facility	1,000,000		1,000,000			$ 1,000,000
Maximum amount of outstanding short-term loans at any time during the period			375,000,000
Average daily balance of short-term loans outstanding during the period	$ 305,000,000		$ 306,000,000
Weighted average interest rates of average daily balance of short-term loans	3.90%		3.80%

Earnings Per Share (Details)

Earnings Per Share (Details) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Earnings Per Share [Abstract]
Potentially dilutive securities included in calculation of diluted EPS (in shares)	123,973	120,228		204,430
Options to purchase common stock excluded from potentially dilutive securities (in shares)	1,201,900	713,800	1,283,753	473,700

Changes in Accumulated Other 59

Changes in Accumulated Other Comprehensive Income by Component (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax
Beginning Balance			$ 18,414,613	$ 9,119,247
(Gains) losses reclassified from accumulated OCI, net of tax	$ (344)	$ (1,559)	(501)	(2,335)
Ending Balance	16,702,619	9,377,570	16,702,619	9,377,570
Cash flow hedge, net of tax | Natural gas cash flow hedges, net of tax
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax
Beginning Balance	4,338	8,719	4,625	9,607
(Gains) losses reclassified from accumulated OCI, net of tax	(466)	(1,672)	(753)	(2,560)
Ending Balance	3,872	7,047	3,872	7,047
Cash flow hedge, net of tax | Interest rate cash flow hedges, net of tax
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax
Beginning Balance	(511)	(663)	(555)	(699)
(Gains) losses reclassified from accumulated OCI, net of tax	36	36	80	72
Ending Balance	(475)	(627)	(475)	(627)
Other post- retirement benefit liability adjustment, net of tax
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax
Beginning Balance	(6,442)	(6,790)	(6,528)	(6,866)
(Gains) losses reclassified from accumulated OCI, net of tax	86	77	172	153
Ending Balance	(6,356)	(6,713)	(6,356)	(6,713)
Accumulated OCI, net of tax
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax
Beginning Balance	(2,615)	1,266	(2,458)	2,042
Ending Balance	$ (2,959)	$ (293)	$ (2,959)	$ (293)

Acquisitions (Details)

Acquisitions (Details) a in Thousands, Mcfe in Thousands, $ in Thousands	Feb. 27, 2017aMcfewellmi	Feb. 01, 2017a	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)
Business Acquisition [Line Items]
Payments to acquire businesses, gross			$ 0	$ 811,207
Bankruptcy Auction
Business Acquisition [Line Items]
Area of property acquired (in acres) | a	85
Number of acres with drilling rights (in acres) | a	44
Production of well (in Mcfe) | Mcfe	110
Number of wells acquired | well	174
Number of producing wells acquired | well	120
Number of miles of pipeline acquired | mi	20
2017 Acquisitions
Business Acquisition [Line Items]
Payments to acquire businesses, gross				736,000
Assumed liabilities				11,900
2016 Acquisitions
Business Acquisition [Line Items]
Payments to acquire businesses, gross				75,200
Adjustment to PP&E				$ 2,200
Marion, Monongalia, and Wetzel Counties
Business Acquisition [Line Items]
Area of property acquired (in acres) | a		14

Divestitures - Additional Infor

Divestitures - Additional Information (Details) $ in Thousands, a in Millions	Jul. 18, 2018USD ($)MMcfemiwellacompressor_station	Jun. 19, 2018USD ($)MMcfemiwellcompressor_station	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of productive assets		$ 60,200
Number of wells sold | well		970
Reduction in sales volume | MMcfe		20
Number of miles of gathering lines sold | mi		350
Number of compressors sold | compressor_station		26
Impairment of long-lived assets					$ 2,300,000
Oil and gas asset					$ 1,000,000
Gain (loss) on disposal and impairment				$ (118,114)		$ 0	$ (2,447,159)	$ 0
Scenario, Forecast
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment of long-lived assets			$ (275,000)
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Subsequent Event
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale of productive assets	$ 575,000
Number of wells sold | well	12,000
Reduction in sales volume | MMcfe	200
Number of miles of gathering lines sold | mi	6,400
Number of compressors sold | compressor_station	59
Number of acres sold | a	2.5
Deposit received	$ 57,500

Divestitures - Assets and Liabi

Divestitures - Assets and Liabilities in Disposal (Details) - Discontinued Operations, Held-for-sale - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Assets:
Property, plant and equipment, net	$ 719,584	$ 0
Liabilities:
Other current liabilities	4,763	0
Other liabilities and credits	$ 190,541	$ 0

Subsequent Event (Details)

Subsequent Event (Details)	Jul. 31, 2018USD ($)
Subsequent Event
Subsequent Event [Line Items]
Authorized repurchase amount	$ 500,000,000

Recently Issued Accounting St64

Recently Issued Accounting Standards Recently Issued Accounting Standards (Details) - USD ($)		Mar. 31, 2018	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2016
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Change in accounting principle	[1]		$ 4,113,000
Restricted cash				$ 0	$ 75,000,000
Accounting Standards Update 2016-01
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Change in accounting principle		$ 4,100,000
[1]	Related to adoption of ASU No. 2016-01. See Notes K and S for additional information.