Eqt Re 10-K 25 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Feb. 22, 2016	Jun. 30, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	Rice Energy Inc.
Trading Symbol	RICE
Entity Central Index Key	1,588,238
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		136,391,709
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 2,781.3

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash	$ 151,901	$ 256,130
Accounts receivable	154,814	199,900
Receivable from affiliate	0	88
Prepaid expenses and other assets	5,488	3,339
Derivative instruments	186,960	133,034
Total current assets	499,163	592,491
Gas collateral account	4,077	3,995
Property, plant and equipment, net	3,243,131	2,461,331
Deferred financing costs, net	30,244	25,103
Goodwill	39,142	334,050
Intangible assets, net	46,159	47,791
Other non-current assets	2,670	0
Derivative instruments	105,945	63,188
Total assets	3,970,531	3,527,949
Current liabilities:
Current portion of long-term debt	0	680
Accounts payable	83,553	152,329
Royalties payable	40,572	37,172
Accrued capital expenditures	79,747	108,290
Leasehold payable	17,338	30,702
Deferred tax liabilities	0	54,688
Other accrued liabilities	79,132	52,814
Total current liabilities	300,342	436,675
Long-term liabilities:
Long-term debt	1,457,222	900,000
Leasehold payable	6,289	4,279
Deferred tax liabilities	271,988	209,218
Derivative instruments	16,344	0
Other long-term liabilities	13,878	12,609
Total liabilities	2,066,063	1,562,781
Stockholders’ equity:
Common stock, $0.01 par value; authorized - 650,000,000 shares; issued and outstanding 136,387,194 shares and 136,280,766 shares, respectively	1,364	1,363
Preferred stock, $0.01 par value; authorized - 50,000,000 shares; none issued	0	0
Additional paid in capital	1,416,523	1,368,001
Accumulated earnings	(137,990)	153,346
Stockholders’ equity before noncontrolling interest	1,279,897	1,522,710
Noncontrolling interests in consolidated subsidiaries	624,571	442,458
Total liabilities and stockholders’ equity	$ 3,970,531	$ 3,527,949

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2015	Dec. 31, 2014
Common Stock
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares authorized	650,000,000	650,000,000
Common stock, shares issued	136,387,194	136,280,766
Common Stock, shares outstanding	136,387,194	136,280,766
Preferred Stock
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	50,000,000	50,000,000
Preferred stock, shares issued	0	0

Consolidated Statements of Oper

Consolidated Statements of Operations $ in Thousands	12 Months Ended
	Dec. 31, 2014USD ($)$ / sharesshares
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales	$ 359,201
Firm transportation sales, net	26,237
Gathering, compression and water services	5,504
Other revenue	0
Total operating revenues	390,942
Operating expenses:
Lease operating	24,971
Gathering, compression and transportation	35,618
Production taxes and impact fees	4,647
Exploration	4,018
Midstream operation and maintenance	4,607
Incentive unit expense	105,961
Restricted unit expense	0
Impairment of gas properties	0
Impairment of goodwill	0
General and administrative (including stock-based compensation expense of $16,528 and $5,553, respectively)	61,570
Depreciation, depletion and amortization	156,270
Acquisition expense	2,339
Amortization of intangible assets	1,156
(Gain) loss from sale of interest in gas properties	0
Other expense	207
Total operating expenses	401,364
Operating loss	(10,422)
Interest expense	(50,191)
Gain on purchase of Marcellus joint venture	203,579
Other income (loss)	893
Gain on derivative instruments	186,477
Amortization of deferred financing costs	(2,495)
Loss on extinguishment of debt	(7,654)
Write-off of deferred financing costs	(6,896)
Equity in (loss) income of joint ventures	(2,656)
(Loss) income before income taxes	310,635
Income tax expense	(91,600)
Net (loss) income	219,035
Less: Net income attributable to noncontrolling interests	(581)
Net (loss) income attributable to Rice Energy Inc.	$ 218,454
Weighted-average number of shares of common stock - basic | shares	128,151,171
Weighted-average number of shares of common stock - diluted | shares	128,225,155
(Loss) earnings per share—basic | $ / shares	$ 1.70
(Loss) earnings per share—diluted | $ / shares	$ 1.70
Pro forma income tax benefit (unaudited)	$ (91,600)
Pro forma net income (unaudited)	$ 218,454
Pro forma earnings per share—basic (unaudited) | $ / shares	$ 1.75
Pro forma earnings per share—diluted (unaudited) | $ / shares	$ 1.75
Pro Forma
Operating expenses:
Income tax expense	$ 5,560
Net (loss) income attributable to Rice Energy Inc.	224,596
Pro forma income tax benefit (unaudited)	5,560
Pro forma net income (unaudited)	$ 224,596

Consolidated Statements of Ope5

Consolidated Statements of Operations (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Income Statement [Abstract]
Stock based compensation expense	$ 16,528	$ 5,553

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities:
Net (loss) income	$ (267,999)	$ 219,035	$ (35,776)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion and amortization	322,784	156,270	32,815
Impairment of gas properties	18,250	0	0
Impairment of goodwill	294,908	0	0
Amortization of deferred finance costs and loss on extinguishment of debt	5,124	10,149	5,230
Amortization of intangibles	1,632	1,156	0
Exploration	3,137	2,211	8,143
Incentive unit expense	36,097	105,961	0
Write-off of deferred financing costs	0	6,896	0
(Gain) loss from sale of interest in gas properties	(953)	0	4,230
Restricted unit expense	0	0	32,906
Stock compensation expense	16,528	5,553	0
Derivative instruments fair value gain	(273,748)	(186,477)	(6,891)
Cash receipts (payments) for settled derivatives	193,908	(18,784)	676
Deferred income tax expense	8,079	87,639	0
Fair value gain on purchase of Marcellus joint venture	0	(203,579)	0
Equity in (income) loss of joint ventures	0	2,656	(19,420)
Changes in operating assets and liabilities:
Decrease (increase) in accounts receivable and receivable from affiliate	45,175	(151,427)	(7,573)
(Increase) decrease in prepaid expenses and other assets	(5,384)	(1,996)	102
(Decrease) increase in accounts payable	(18,439)	4,661	2,273
Increase in accrued liabilities and other	30,488	25,280	9,525
Increase in royalties payable	3,400	19,871	7,432
Net cash provided by operating activities	412,987	85,075	33,672
Cash flows from investing activities:
Capital expenditures for property and equipment	(1,246,274)	(970,274)	(465,387)
Acquisition of Marcellus joint venture, net of cash acquired	0	(82,766)	0
Acquisition of Momentum assets	0	(111,847)	0
Acquisition of Greene County assets	19,054	(329,469)	0
Proceeds from sale of interest in gas properties	10,201	12,891	6,792
Net cash used in investing activities	(1,217,019)	(1,481,465)	(458,595)
Cash flows from financing activities:
Proceeds from borrowings	913,932	1,090,000	435,500
Repayments of debt obligations	(358,619)	(689,873)	(160,760)
Restricted cash for convertible debt	0	8,268	(8,268)
Distributions to the Partnership’s public unitholders	(17,017)	0	0
Debt issuance costs	(10,266)	(24,543)	(12,194)
Common stock issuance	0	0	195,977
Repurchase of common stock	0	0	(2,267)
Proceeds from conversion of warrants	0	1,975	0
Proceeds from issuance of common stock sold in our IPO, net of offering costs	(129)	597,088	0
Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of offering costs	0	196,254	0
Proceeds from issuance of common units sold by RMP, net of offering costs	171,902	441,739	0
Net cash provided by financing activities	699,803	1,620,908	447,988
Net (decrease) increase in cash	(104,229)	224,518	23,065
Cash at the beginning of the year	256,130	31,612	8,547
Cash at the end of the year	151,901	256,130	31,612
Supplemental disclosure of noncash investing and financing activities
Capital expenditures for natural gas properties financed by accounts payable	77,882	144,053	48,615
Capital expenditures for natural gas properties financed by other accrued liabilities	79,747	108,290	16,753
Natural gas properties financed through deferred payment obligations	23,628	34,984	20,281
Application of advances from joint interest owners	$ (6,994)	$ (7,304)	$ (10,415)

Statements of Consolidated Equi

Statements of Consolidated Equity - USD ($) $ in Thousands	Total	IPO	Secondary Public Offering	Common Stock ($0.01 par)	Common Stock ($0.01 par)IPO	Common Stock ($0.01 par)Secondary Public Offering	Additional Paid-In Capital	Additional Paid-In CapitalIPO	Additional Paid-In CapitalSecondary Public Offering	Accumulated (Deficit) Earnings	Stockholders Equity before Non-controlling Interest	Stockholders Equity before Non-controlling InterestIPO	Stockholders Equity before Non-controlling InterestSecondary Public Offering	Non-Controlling Interest	Non-Controlling InterestIPO
Balance at Dec. 31, 2012	$ 138,191			$ 622			$ 166,901			$ (29,332)	$ 138,191
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Capital contributions, net	196,232			258			195,974				196,232
Consolidated net income (loss)	(35,776)									(35,776)	(35,776)
Balance at Dec. 31, 2013	298,647			880			362,875			(65,108)	298,647
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Shares of common stock issued in initial public offering, net of offering costs		$ 593,413	$ 196,254		$ 300	$ 75		$ 593,113	$ 196,179			$ 593,413	$ 196,254
Shares of common stock issued in purchase of Marcellus joint venture	222,000			95			221,905				222,000
Conversion of restricted units into shares of common stock at our IPO		36,306						36,306				36,306
Conversion of convertible debentures into shares of common stock after our IPO	6,605			6			6,599				6,605
Conversion of warrants into shares of common stock after our IPO	1,975			7			1,968				1,975
Shares of common units issued in RMP IPO, net of offering costs		441,739													$ 441,739
Incentive unit compensation	105,961						105,961				105,961
Stock compensation	5,553						5,415				5,415			$ 138
Tax impact of our IPO and corporate reorganization		(162,320)						$ (162,320)				$ (162,320)
Consolidated net income (loss)	219,035									218,454	218,454			581
Balance at Dec. 31, 2014	1,965,168			1,363			1,368,001			153,346	1,522,710			442,458
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Incentive unit compensation	36,097						36,097				36,097
Stock compensation	16,446			1			12,425				12,426			4,020
Distributions to the Partnership’s public unitholders	(17,017)													(17,017)
Offering costs related to the Partnership’s IPO		$ (129)													$ (129)
Shares of common units issued by RMP, net of offering costs	171,902													171,902
Consolidated net income (loss)	(267,999)									(291,336)	(291,336)			23,337
Balance at Dec. 31, 2015	$ 1,904,468			$ 1,364			$ 1,416,523			$ (137,990)	$ 1,279,897			$ 624,571

Statements of Consolidated Equ8

Statements of Consolidated Equity (Parenthetical) - $ / shares	Dec. 31, 2015	Dec. 31, 2014
Statement of Stockholders' Equity [Abstract]
Par Value	$ 0.01	$ 0.01

Summary of Significant Accounti

Summary of Significant Accounting Policies and Related Matters	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Summary of Significant Accounting Policies and Related Matters	Summary of Significant Accounting Policies and Related Matters Organization, Operations and Principles of Consolidation The accompanying consolidated financial statements of Rice Energy Inc. (the “Company,” “we,” “our,” and “us”) have been prepared by the Company’s management in accordance with generally accepted accounting principles in the United States (“GAAP”) for financial information and applicable rules and regulations promulgated under the Exchange Act. The consolidated financial statements of the Company include the accounts of its wholly-owned subsidiaries. Rice Midstream Holdings LLC, a subsidiary of the Company (“Midstream Holdings”) owns a 41% interest in Rice Midstream Partners LP, a subsidiary of the Company, (“the Partnership”). The financial results of the Partnership are consolidated and the remaining 59% interest in the Partnership is reflected as noncontrolling interest in the consolidated financial statements. All intercompany transactions have been eliminated in consolidation. Corporate Reorganization and Initial Public Offering On January 29, 2014, the Company completed its initial public offering (“IPO”) of 50,000,000 shares of $0.01 par value common stock, which included 30,000,000 shares sold by us, 14,000,000 shares sold by NGP Rice Holdings, LLC (“NGP Holdings”), the selling stockholder in the IPO, and 6,000,000 shares sold subject to an option granted to the underwriters by the selling stockholder. The net proceeds of the IPO, based on the public offering price of $21.00 per share, were approximately $992.6 million , which resulted in net proceeds to the Company of $593.6 million after deducting expenses and underwriting discounts and commissions of approximately $36.4 million and the net proceeds to the selling stockholder of approximately $399.0 million after deducting expenses and underwriting discounts of approximately $21.0 million . The Company did not receive any proceeds from the sale of the shares by the selling stockholder. A portion of the net proceeds from the IPO were used to repay all outstanding borrowings under the revolving credit facility of Alpha Shale Resources, LP and its general partner, Alpha Shale Holdings, LLC (collectively, the “Marcellus joint venture”), to make a $100.0 million payment to Foundation PA Coal Company, LLC (“PA Coal”), a wholly-owned indirect subsidiary of Alpha Natural Resources, Inc. (“Alpha Holdings”) in partial consideration for the acquisition of Alpha Holdings’ 50% interest in the Marcellus joint venture (the “Marcellus JV Buy-In”) and to repay all outstanding borrowings under the Senior Secured Revolving Credit Facility (as defined below). The Company used the remainder of the net proceeds from the IPO to fund a portion of its capital expenditure plan. A corporate reorganization occurred concurrently with the completion of the IPO on January 29, 2014. As a part of this corporate reorganization, the Company acquired all of the outstanding membership interests in Rice Energy Appalachia LLC (“Rice Appalachia”) and Rice Drilling B LLC (“Rice Drilling B”) (other than those already held by Rice Appalachia) in exchange for shares of our common stock. The Exploration and Production segment continues to be conducted through Rice Drilling B, now a wholly-owned subsidiary. This reorganization constituted a common control transaction and the accompanying consolidated financial statements are presented as though this reorganization had occurred for the earliest period presented. As of January 29, 2014, upon (a) the completion of the IPO, (b) the issuance of (i) 43,452,550 shares of common stock to NGP Holdings, (ii) 20,300,923 shares of common stock to Rice Energy Holdings LLC (“Rice Holdings”), (iii) 2,356,844 shares of common stock to Daniel J. Rice III, (iv) 20,000,000 shares of common stock to Rice Energy Family Holdings, LP (“Rice Partners”), (v) 160,831 shares of common stock to the persons holding incentive units representing interests in Rice Appalachia and (vi) 1,728,852 shares of common stock to the members of Rice Drilling B (other than Rice Appalachia), each of which were issued by the Company in connection with the closing of the IPO, and (c) the issuance of 9,523,810 shares of common stock to Alpha Holdings in connection with the completion of the Marcellus JV Buy-In, it had 127,523,810 shares of common stock outstanding. Rice Midstream Partners Initial Public Offering On December 22, 2014 , the Partnership completed its initial public offering (the “RMP IPO”) of 28,750,000 common units representing limited partner interests (the “Common Units”), which included 3,750,000 Common Units sold subject to an option granted to the underwriters. The net proceeds of the RMP IPO, based on the public offering price of $16.50 per Common Unit, were approximately $441.7 million , after deducting underwriting discounts, commissions, structuring fees and expenses. See Note 7 for further discussion of the RMP IPO. Rice Midstream Partners Water Assets Acquisition In November 2015, the Partnership entered into a Purchase and Sale Agreement (the “Water Purchase Agreement”) by and between the Partnership and the Company. Pursuant to the terms of the Water Purchase Agreement, the Partnership acquired all of the outstanding limited liability company interests of two wholly-owned indirect subsidiaries of the Company that own and operate our water services business with an effective date as of November 1, 2015 . The acquired business includes the Company’s Pennsylvania and Ohio fresh water distribution systems and related facilities that provide access to fresh water from the Monongahela River, the Ohio River and other regional water sources in Pennsylvania and Ohio (the “Water Assets”). The Company has also granted the Partnership, until December 31, 2025, (i) the exclusive right to develop water treatment facilities in the areas of dedication defined in the Water Services Agreements and (ii) an option to purchase any water treatment facilities acquired by the Company in such areas at our acquisition cost (collectively, the “Option”). The acquisition of the Water Assets by the Partnership is accounted for as a common control transaction. Nature of Business The Company is an independent natural gas and oil company engaged in the acquisition, exploration and development of natural gas, oil and NGL properties in the Appalachian Basin. The Company operates in two business segments, which are managed separately due to their distinct operational differences. The Company’s two reporting segments are as follows: Exploration and Production. This segment is engaged in the acquisition, exploration and development of natural gas, oil and NGLs in the Appalachian Basin. The Exploration and Production segment operates in what the Company believes to be the core of the Marcellus and Utica Shales. Midstream. This segment is engaged in the gathering and compression of natural gas, oil and NGL production of, and in the provision of water services to support the well completion activities of Rice Energy and third-parties. Risks and Uncertainties The prices the Company receives for its natural gas production heavily influences its revenue, operating results profitability, access to capital, future rate of growth and carrying value of our properties. Natural gas is a commodity and, therefore, its prices is subject to wide fluctuation in response to relatively minor changes in supply and demand. Historically, the commodities market has been volatile. The prices the Company receives for its production, and the levels of its production, depend on numerous factors beyond its control. See “Item 1A. Risk Factors” for a further discussion on risks and uncertainties relevant to the Company. Use of Estimates The preparation of consolidated financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the dates of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates and changes in these estimates are recorded when known. Revenue Recognition Sales of natural gas, NGLs and oil are recognized when the products have been delivered to a custody transfer point, persuasive evidence of a sales arrangement exists, the rights and responsibility of ownership pass to the purchaser upon delivery, collection of revenue from the sale is reasonably assured, and the sales price is fixed or determinable. Natural gas is sold by the Company under contracts with the Company’s natural gas marketers. Pricing provisions are generally tied to the Platts Gas Daily market prices. Some transportation costs incurred by the Company are marketed for resale and are not incurred to transport gas produced by the Company’s Exploration and Production segment. These transportation costs are reflected as a deduction from the related firm transportation sales revenue at the time the transportation is provided to the customer. Revenue from the gathering and compression of natural gas and water services is recognized in the month in which the service is provided. Cash The Company maintains cash at financial institutions which may at times exceed federally insured amounts. The Company has no other accounts that are considered cash equivalents. Accounts Receivable Accounts receivable are primarily from the Company’s joint interest partners and natural gas marketers. The Company extends credit to parties in the normal course of business based upon management’s assessment of their creditworthiness. An allowance is provided for those accounts for which collection is estimated as doubtful; uncollectible accounts are written off and charged against the allowance. In estimating the allowance, management considers, among other things, how recently and how frequently payments have been received and the financial position of the party. There was no allowance recorded for any of the periods presented in the consolidated financial statements. Accounts receivable as of December 31, 2015 and 2014 are detailed below. December 31, (in thousands) 2015 2014 Joint interest $ 76,985 $ 125,300 Natural gas sales 71,512 72,206 Other 6,317 2,394 Total accounts receivable $ 154,814 $ 199,900 Noncontrolling Interest Noncontrolling interests represent third-party equity ownership of the Partnership and are presented as a component of equity in the consolidated balance sheets. In the consolidated statements of operations, noncontrolling interest reflects the allocation of earnings to the third-party investors. The Company owns a 41% equity interest in the Partnership and controls the Partnership through its ownership of the general partner. See Note 7 for further discussion of noncontrolling interests related to the Partnership. Property, Plant and Equipment The Company uses the successful efforts method of accounting for oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties are capitalized as unproved properties, whereas costs to drill and equip exploratory wells that result in proved reserves, are capitalized as proved properties. Costs to drill exploratory wells that do not identify proved reserves as well as geological and geophysical costs and costs of carrying and retaining unproved properties are expensed. Long-lived assets to be held and used or disposed of other than by sale are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. When required, impairment losses on assets to be held and used or disposed other than by sale are recognized based on the fair value of the asset. Long-lived assets to be disposed of by sale are reported at the lower of their carrying amount or fair value less selling costs. Capitalized costs of producing oil and gas properties and support equipment directly related to such properties, after considering estimated residual salvage values, are depreciated and depleted by the units of production method. Midstream property and equipment is recorded at cost and is being depreciated over estimated useful lives on a straight-line basis. Gathering pipelines and compressor stations are depreciated over a useful life of 60 years. Water pipelines, pumping stations and impoundment facilities are depreciated over a useful life of 10 to 15 years. Capitalized costs of unproved properties are evaluated at least annually for recoverability on a prospective basis. This evaluation includes consideration of current economic conditions, changes in development plans or business strategy, expected lease expirations and historical experience. If it is determined that it is unlikely for an unproved property to yield proved reserves prior to lease expiration, an impairment of the respective unproved property is recognized in the period in which that determination is made. For the year ended December 31, 2015 , the Company recognized $7.3 million of impairment expense in the consolidated statement of operations, primarily the result of changes in the Company’s development plans and lease expirations. Upon the sale of an entire interest in an unproved property for cash, a gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained unless the proceeds received are in excess of the cost basis which would result in gain on sale. For the years ended December 31, 2015 and 2013 , the Company recorded (gain) loss on sale of unproved properties of $(1.0) million and $4.2 million , respectively. Unproved oil and gas properties had a net book value of $1,050.0 million and $1,015.4 million at December 31, 2015 and 2014 , respectively. The carrying values of the Company’s proved properties are reviewed periodically when events or circumstances indicate that the remaining carrying amount may not be recoverable. Generally, this evaluation is performed on a formation-level basis by comparing estimated undiscounted future cash flows to the carrying value, and including risk-adjusted probable and possible reserves if deemed reasonable. Key assumptions utilized in determining the estimated undiscounted future cash flows are generally consistent with assumptions used in the Company’s budgeting and forecasting processes. If the carrying value of proved properties exceeds the estimated undiscounted future cash flows, they are written down to fair value. Fair value of proved properties is estimated by discounting the estimated future cash flows using discount rates and consideration of expected assumptions that would be used by a market participant. Due to the significant decline in commodity prices in 2015 and 2014, there were indications that the carrying values of certain proved properties may not be fully recoverable when compared to their fair value. The fair value was determined using an income approach based on estimated future production, future commodity prices adjusted for firm transportation and basis differentials, future operating and capital costs, and an assumed discount rate of 13.5% . As the assumptions used to calculate the estimated fair value were significant unobservable inputs, the valuation of the proved properties was considered to be a Level 3 fair value measurement. The Company determined that the carrying value of Upper Devonian proved properties was not fully recoverable and as a result, for the year ended December 31, 2015 , the Company recognized $10.9 million of impairment expense in the consolidated statement of operations to write-down such proved properties to fair value of $7.3 million . For the years ended December 31, 2014 and 2013, the Company did not recognize impairment charges for proved or unproved properties. Interest The Company capitalizes interest on expenditures for significant exploration and development projects while activities are in progress to bring the assets to their intended use. Upon completion of construction of the asset, the associated capitalized interest costs are included within our asset base and depleted accordingly. The following table summarizes the components of the Company’s interest incurred for the years ended December 31, 2015 , 2014 and 2013 : (in thousands) 2015 2014 2013 Interest incurred: Interest expensed $ 87,446 $ 50,191 $ 17,915 Interest capitalized 195 905 8,034 Total incurred $ 87,641 $ 51,096 $ 25,949 Goodwill Goodwill is the cost of an acquisition less the fair value of the net identifiable assets of the acquired business. The Company evaluates goodwill for impairment at least annually during the fourth quarter, or whenever events or changes in circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The Company may first consider qualitative factors to assess whether there are indicators that it is more likely than not that the fair value of a reporting unit may not exceed its carrying amount. To the extent that such indicators exist, the Company would complete the two-step goodwill impairment test. The Company may also perform the two-step goodwill impairment test at its discretion without performing the qualitative assessment. The first step compares the fair value of a reporting unit to its carrying value. If the carrying amount of a reporting unit exceeds its fair value, the second step is required which compares the implied fair value of the goodwill of a reporting unit to its carrying value. If the carrying value of the goodwill of a reporting unit exceeds its implied fair value, the difference is recognized as an impairment charge. See Note 3 for additional information which includes the results of the Company’s annual goodwill impairment test. Intangible Assets Intangible assets are recorded under the acquisition method of accounting at their estimated fair values at the acquisition date. The customer contracts acquired had an initial contract terms of 10 years with five and one year renewal options. Fair value is calculated as the present value of estimated future cash flows using a risk-adjusted discount rate. The Company’s intangible assets are comprised of customer contracts acquired in our April 2014 acquisition of certain gas gathering assets in eastern Washington and Greene Counties, Pennsylvania (the “Momentum Acquisition”). The Company calculates amortization of intangible assets using the straight-line method over the estimated useful life of the intangible assets, or 30 years. Amortization expense recorded in the consolidated statements of operations for the year ended December 31, 2015 was $1.6 million . The estimated annual amortization expense over the next five years is as follows: 2016 - $1.6 million , 2017 - $1.6 million , 2018 - $1.6 million , 2019 - $1.6 million and 2020 - $1.6 million . Intangible assets as of December 31, 2015 and 2014 are detailed below. (in thousands) Intangible Assets Balance, December 31, 2013 $ — Additions 48,947 Accumulated amortization (1,156 ) Balance, December 31, 2014 47,791 Accumulated amortization (1,632 ) Balance, December 31, 2015 $ 46,159 Deferred Financing Costs Deferred financing costs are amortized on a straight-line basis, which approximates the interest method, over the term of the related agreement. Accumulated amortization was $8.6 million and $3.5 million at December 31, 2015 and 2014 respectively. Amortization expense was $5.1 million , $2.5 million , and $5.2 million for the years ended December 31, 2015 , 2014 and 2013 , respectively. Asset Retirement Obligations The Company records the fair value of a legal liability for an asset retirement obligation in the period in which it is incurred. For oil and gas properties, this is the period in which an oil or gas well is acquired or drilled. The Company’s retirement obligations relate to the abandonment of oil and gas producing facilities and include costs to reclaim drilling sites and dismantle and relocate or dispose of gathering systems, wells and related structures. Estimates are based on historical experience in plugging and abandoning wells and estimated remaining lives of those wells based on reserve estimates. When a new liability is recorded, the Company capitalizes the costs of the liability by increasing the carrying amount of the related long-lived asset. The liability is accreted to its present value each period and the capitalized cost is depreciated over the units of production basis. Income Taxes The Company is a corporation under the Internal Revenue Code subject to federal income tax at a statutory rate of 35% of pretax earnings. The Company did not report any income tax benefit or expense for periods prior to the consummation of its IPO in January 2014 because Rice Drilling B, the Company’s accounting predecessor, is a limited liability company that was not and currently is not subject to federal income tax. The reorganization of the Company’s business in connection with the closing of its IPO, such that it is now held by a corporation subject to federal income tax, required the recognition of a deferred tax asset or liability for the initial temporary differences at the time of the IPO. The resulting deferred tax liability of approximately $162.3 million was recorded in equity at the date of the completion of the IPO as it represents a transaction among shareholders. Additionally, the Company has presented pro forma earnings per share (“EPS”) for the year ended December 31, 2014 assuming a statutory rate as disclosed in the accompanying consolidated statements of operations was applied for the full year ended December 31, 2014. The Company follows ASC 740-10-25, which requires the use of a two-step approach for recognizing and measuring tax benefits taken or expected to be taken in a tax return and disclosures regarding uncertainties in income tax positions. Only tax positions that meet the more likely than not recognition threshold are recognized. Based on management’s analysis, the Company did not have any uncertain tax positions as of December 31, 2015 . Income taxes are accounted for under the asset and liability method, which requires recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial statements and tax basis of assets and liabilities using enacted tax rates in effect for the year in which differences are expected to be recovered or settled pursuant to the provisions of ASC 740-Income Taxes. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. The Company will record a valuation allowance if it is deemed more likely than not that all or a portion of its deferred income tax assets will not be realized. In addition, income tax rules and regulations are subject to interpretation and the application of those rules and regulations requires judgment by us and may be challenged by the taxation authorities. Segment Reporting Business segments are components of the Company for which separate financial information is produced internally and are subject to evaluation by the Company’s chief operating decision maker in deciding how to allocate resources. The Company reports its operations in two segments: (i) Exploration and Production and (ii) Midstream, which reflect its lines of business. Business segments are evaluated for their contribution to the Company’s combined results based on operating income. All of the Company’s operating revenues, income from operations and assets are located in the United States. See Note 9 for additional information regarding segment reporting. Reclassifications Certain reclassifications have been made to prior periods’ financial information related to the presentation of gathering, compression and water service revenues and midstream operation and maintenance expenses to conform to the 2015 presentation.

Property, Plant and Equipment

Property, Plant and Equipment	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	Property, Plant and Equipment The Company’s property, plant and equipment are as follows as of December 31, 2015 and 2014. December 31, (in thousands) 2015 2014 Oil and gas producing properties $ 2,870,691 $ 2,181,880 Impairment of gas properties (18,250 ) — Accumulated depreciation (498,467 ) (201,608 ) Oil and gas producing properties, net 2,353,974 1,980,272 Midstream property and equipment 889,776 467,956 Accumulated depreciation (25,662 ) (4,038 ) Midstream property and equipment, net 864,114 463,918 Other property and equipment 34,425 21,376 Accumulated depreciation (9,382 ) (4,235 ) Other property and equipment, net 25,043 17,141 Property, plant and equipment, net $ 3,243,131 $ 2,461,331

Goodwill

Goodwill	12 Months Ended
	Dec. 31, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill	Goodwill The Company evaluates goodwill for impairment at least annually during the fourth quarter, or whenever events or changes in circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying amount. Impairment testing for goodwill is performed at the reporting unit level. The Company identifies its operations within three reporting units: 1) Exploration and Production; 2) Midstream - Gathering; and 3) Midstream - Water (which had not been ascribed goodwill as of December 31, 2015 and 2014). As a result of the acquisition of the remaining 50% interest in Alpha Holdings in our Marcellus joint venture, the Company allocated $294.9 million and $39.1 million of goodwill to the Exploration and Production and Midstream - Gathering reporting units, respectively. In estimating the fair value of the Company’s reporting units as part of step one of the annual goodwill impairment test, the Company used the income approach and the market approach. The Company employed the discounted cash flow method within the income approach which uses significant inputs not observable in the public market (Level 3). Key inputs within the income approach include estimates and assumptions related to future production and throughput volumes, commodity prices, operating costs, capital spending and changes in working capital. The Company employed the guideline public company method within the market approach which considers market multiples derived from market prices of publicly traded stocks of companies engaged in similar lines of business as our reporting units. Estimating the fair value of the reporting units requires considerable judgment and determining fair value is sensitive to changes in assumptions impacting management’s estimates of the future financial results of the reporting units. Although the Company believes the estimates and assumptions used in estimating the fair value of our reporting units are reasonable and appropriate, different assumptions and estimates could materially impact the calculated fair value of the reporting units. Additionally, actual future results could differ from our current estimates and assumptions. The Company elected the option to default immediately to the first step of the annual goodwill impairment test. The results of the first step indicated that the carrying value of the Exploration and Production reporting unit exceeded its fair value. Due to the result of step one of the annual goodwill impairment test for the Exploration and Production reporting unit, the Company performed the second step of the goodwill impairment analysis comparing the implied fair value of the reporting unit’s goodwill to its carrying amount and determined that such goodwill was fully impaired. As a result, the Company recorded an impairment charge of $294.9 million to eliminate the carrying value of goodwill of the Exploration and Production reporting unit at December 31, 2015. Management considered the negative industry and market trends, including the decline in commodity prices and overall market performance of the Company’s peers and the Company, to be the primary reasons of impairment. There were no impairments recorded related to the Midstream - Gathering reporting unit as a result of the annual goodwill impairment test. Goodwill as of December 31, 2015 and 2014 is detailed below. (in thousands) Exploration and Production Midstream - Gathering Balance, December 31, 2013 $ — $ — Additions 294,908 39,142 Balance, December 31, 2014 294,908 39,142 Impairment (294,908 ) — Balance, December 31, 2015 $ — $ 39,142

Long Term Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt Long-term debt consists of the following as of December 31, 2015 and 2014 : December 31, (in thousands) 2015 2014 Long-term Debt Senior Notes Due 2022 (a) $ 900,000 $ 900,000 Senior Notes Due 2023 (b) 397,222 — Senior Secured Revolving Credit Facility (c) — — Midstream Holdings Revolving Credit Facility (d) 17,000 — RMP Revolving Credit Facility (e) 143,000 — Other — 680 Total debt $ 1,457,222 $ 900,680 Less current portion — 680 Long-term debt $ 1,457,222 $ 900,000 6.25% Senior Notes Due 2022 (a) On April 25, 2014 , the Company issued $900.0 million in aggregate principal amount of 6.25% senior notes due 2022 (the “2022 Notes”) in a private placement to eligible purchasers under Rule 144A and Regulation S of the Securities Act of 1933, as amended (the “Securities Act”), which resulted in net proceeds of $882.7 million , after deducting expenses and the initial purchasers’ discounts of approximately $17.3 million . The Company used $301.8 million of the net proceeds to repay and retire the Second Lien Term Loan Facility (defined below) and used the remainder to fund a portion of the Company’s 2014 capital expenditure program. The 2022 Notes will mature on May 1, 2022 , and interest is payable on the 2022 Notes on each May 1 and November 1 . At any time prior to May 1, 2017 , the Company may redeem up to 35% of the 2022 Notes at a redemption price of 106.25% of the principal amount, plus accrued and unpaid interest to the redemption date, with the proceeds of certain equity offerings so long as the redemption occurs within 180 days of completing such equity offering and at least 65% of the aggregate principal amount of the 2022 Notes remains outstanding after such redemption. Prior to May 1, 2017 , the Company may redeem some or all of the notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. Upon the occurrence of a Change of Control (as defined in the indenture governing the 2022 Notes), unless the Company has given notice to redeem the 2022 Notes, the holders of the 2022 Notes will have the right to require the Company to repurchase all or a portion of the 2022 Notes at a price equal to 101% of the aggregate principal amount of the 2022 Notes, plus any accrued and unpaid interest to the date of purchase. On or after May 1, 2017 , the Company may redeem some or all of the 2022 Notes at redemption prices (expressed as percentages of principal amount) equal to 104.688% for the twelve-month period beginning on May 1, 2017, 103.125% for the twelve-month period beginning May 1, 2018, 101.563% for the twelve-month period beginning on May 1, 2019 and 100.000% beginning on May 1, 2020, plus accrued and unpaid interest to the redemption date. 7.25% Senior Notes Due 2023 (b) On March 26, 2015 , the Company issued $400.0 million in aggregate principal amount of 7.25% senior notes due 2023 (the “ 2023 Notes”) in a private placement to eligible purchasers under Rule 144A and Regulation S of the Securities Act, which resulted in net proceeds of $389.3 million , after deducting expenses and the initial purchasers’ discounts of approximately $10.7 million . The Company used the net proceeds for general corporate purposes, including capital expenditures. The original issuance discount of $3.1 million related to the 2023 Notes is recorded as a reduction of the principal amount. For the year ended December 31, 2015 , the Company recorded $0.3 million of amortization of the debt discount as interest expense using the effective interest method and a rate of 7.345% . The 2023 Notes will mature on May 1, 2023 , and interest is payable on the 2023 Notes on each May 1 and November 1 , commencing on November 1, 2015 . At any time prior to May 1, 2018 , the Company may redeem up to 35% of the 2023 Notes at a redemption price of 107.250% of the principal amount, plus accrued and unpaid interest to the redemption date, with the proceeds of certain equity offerings so long as the redemption occurs within 180 days of completing such equity offering and at least 65% of the aggregate principal amount of the 2023 Notes remains outstanding after such redemption. Prior to May 1, 2018 , the Company may redeem some or all of the notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. Upon the occurrence of a Change of Control (as defined in the indenture governing the 2023 Notes), unless the Company has given notice to redeem the 2023 Notes, the holders of the 2023 Notes will have the right to require the Company to repurchase all or a portion of the 2023 Notes at a price equal to 101% of the aggregate principal amount of the 2023 Notes, plus any accrued and unpaid interest to the date of purchase. On or after May 1, 2018 , the Company may redeem some or all of the 2023 Notes at redemption prices (expressed as percentages of principal amount) equal to 105.438% for the twelve-month period beginning on May 1, 2017, 103.625% for the twelve-month period beginning May 1, 2019, 101.813% for the twelve-month period beginning on May 1, 2020 and 100.000% beginning on May 1, 2021, plus accrued and unpaid interest to the redemption date. In connection with the issuance and sale of the 2023 Notes, the Company and the Company’s restricted subsidiaries (the “Guarantors”) entered into a registration rights agreement with the initial purchasers, dated March 26, 2015 . Pursuant to the registration rights agreement, the Company completed an exchange of the 2023 Notes for registered notes that have substantially identical terms at the 2023 Notes. The 2022 Notes and the 2023 Notes (collectively, the “Notes”) are the Company’s senior unsecured obligations, rank equally in right of payment with all of the Company’s existing and future senior debt, and will rank senior in right of payment to all of the Company’s future subordinated debt. The Notes will be effectively subordinated to all of the Company’s existing and future secured debt to the extent of the value of the collateral securing such indebtedness. The Notes are jointly and severally, fully and unconditionally, guaranteed by the Guarantors. The indentures governing the Notes provide that the guarantees of the Notes will be released under certain circumstances, including: • in connection with any sale or other disposition of all or substantially all of the assets of that Guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary (as defined in the indentures governing the Notes) of the Company; • in connection with any sale or other disposition of the capital stock of that Guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary of the Company, such that, immediately after giving effect to such transaction, such Guarantor would no longer constitute a subsidiary of the Company; • if the Company designates any Restricted Subsidiary that is a Guarantor to be an unrestricted subsidiary in accordance with the indentures governing the Notes; • upon legal defeasance or satisfaction and discharge of the indentures governing the Notes; or • if such Guarantor ceases to guarantee any other indebtedness of the Company or a Guarantor under a credit facility, provided no Event of Default (as defined in the indentures governing the Notes) has occurred and is continuing. The indentures governing the Notes restrict the Company’s ability and the ability of its restricted subsidiaries to: (i) incur or guarantee additional debt or issue certain types of preferred stock; (ii) pay dividends on capital stock or redeem, repurchase or retire the Company’s capital stock or subordinated debt; (iii) make certain investments; (iv) incur liens; (v) enter into transactions with affiliates; (vi) merge or consolidate with another company; (vii) transfer and sell assets; and (viii) create unrestricted subsidiaries. These covenants are subject to a number of important exceptions and qualifications. If at any time when the Notes are rated investment grade by both Moody’s Investors Service, Inc. and Standard & Poor’s Ratings Services and no default (as defined in the indentures governing the Notes) has occurred and is continuing, many of such covenants will terminate and the Company and its restricted subsidiaries will cease to be subject to such covenants. The indentures governing the Notes contain customary events of default, including: • default in any payment of interest on any Note when due, continued for 30 days; • default in the payment of principal of or premium, if any, on any Note when due; • failure by the Company to comply with its other obligations under the indentures governing the Notes, in certain cases subject to notice and grace periods; • payment defaults and accelerations with respect to other indebtedness of the Company and its Restricted Subsidiaries (as defined in the indentures governing the Notes) in the aggregate principal amount of $25.0 million or more; • certain events of bankruptcy, insolvency or reorganization of the Company or a Significant Subsidiary (as defined in the indentures governing the Notes) or group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary; • failure by the Company or Restricted Subsidiary to pay certain final judgments aggregating in excess of $25.0 million within 60 days; and • any guarantee of the Notes by a Guarantor ceases to be in full force and effect, is declared null and void in a judicial proceeding or is denied or disaffirmed by its maker. Senior Secured Revolving Credit Facility (c) In April 2013, the Company entered into a Senior Secured Revolving Credit Facility (the “Senior Secured Revolving Credit Facility”) with Wells Fargo Bank, N.A. (“Wells Fargo”), as administrative agent, and a syndicate of lenders. In April 2014, the Company, as borrower, and Rice Drilling B, as predecessor borrower, amended and restated the credit agreement governing the Senior Secured Revolving Credit Facility (the “Amended Credit Agreement”) to, among other things, assign all of the rights and obligations of Rice Drilling B as borrower under the Senior Secured Revolving Credit Facility to the Company. On January 13, 2016, the Company entered into a Seventh Amendment (the “Seventh Amendment”) to the Amended Credit Agreement, which increased the aggregate notional volume limitations for our hedging arrangements contained in the Amended Credit Agreement for the first eighteen months after any commodity swap agreement or secured firm transportation reimbursement agreement is entered into. As of December 31, 2015 , the borrowing base was $750.0 million and the sublimit for letters of credit was $250.0 million . The Company had zero borrowings outstanding and $99.3 million in letters of credit outstanding under the Amended Credit Agreement as of December 31, 2015 , resulting in availability of $650.7 million . The next redetermination of the borrowing base is scheduled for April 2016. The maturity date of the Senior Secured Revolving Credit Facility is January 29, 2019. Eurodollar loans under the Senior Secured Revolving Credit Facility bear interest at a rate per annum equal to LIBOR plus an applicable margin ranging from 150 to 250 basis points, depending on the percentage of borrowing base utilized. Base rate loans bear interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 50 to 150 basis points, depending on the percentage of borrowing base utilized. The Amended Credit Agreement is secured by liens on at least 80% of the proved oil and gas reserves of the Company and its subsidiaries (other than any subsidiary that is designated as an unrestricted subsidiary, including Midstream Holdings and its subsidiaries), as well as significant unproved acreage and substantially all of the personal property of the Company and such restricted subsidiaries, and the Company’s obligations under the Amended Credit Agreement are guaranteed by such restricted subsidiaries. The Amended Credit Agreement contains restrictive covenants that limit the ability of the Company and its restricted subsidiaries to, among other things: • incur additional indebtedness; • sell assets; • make loans to others; • make investments; • enter into mergers; • make or declare dividends; • hedge future production or interest rates; • incur liens; and • engage in certain other transactions without the prior consent of the lenders. The Amended Credit Agreement also requires the Company to maintain certain financial ratios, which are measured at the end of each calendar quarter: • a current ratio, which is the ratio of consolidated current assets (including unused commitments under the Amended Credit Agreement and excluding non-cash derivative assets) to consolidated current liabilities (excluding current maturities under the Amended Credit Agreement and non-cash derivative liabilities), of not less than 1.0 to 1.0 ; and • a minimum interest coverage ratio, which is the ratio of consolidated EBITDAX (as such term is defined in the Amended Credit Agreement) based on the trailing 12 month period to consolidated interest expense, of not less than 2.5 to 1.0 . The Company was in compliance with such covenants and ratios effective as of December 31, 2015 . Midstream Holdings Revolving Credit Facility (d) On December 22, 2014 , Midstream Holdings entered into a revolving credit facility (the “Midstream Holdings Revolving Credit Facility”) with Wells Fargo, as administrative agent, and a syndicate of lenders with a maximum credit amount of $300.0 million and a sublimit for letters of credit of $25.0 million . As of December 31, 2015 , Midstream Holdings had $17.0 million of borrowings outstanding and no letters of credit under this facility. The average daily outstanding balance of the credit facility was approximately $62.0 million and interest was incurred on the facility at a weighted average annual interest rate of 2.5% during 2015 . The credit facility is available to fund working capital requirements and capital expenditures and to purchase assets and matures on December 22, 2019 . Rice Olympus Midstream LLC, Rice West Virginia Midstream LLC and Strike Force Midstream Holdings LLC (“Strike Force Holdings”) are the guarantors of the obligations under the credit facility. Principal amounts borrowed are payable on the maturity date, and interest is payable quarterly for base rate loans and at the end of the applicable interest period for Eurodollar loans. Under the Midstream Holdings Revolving Credit Facility, Midstream Holdings may elect to borrow in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to the applicable LIBOR Rate plus an applicable margin ranging from 225 to 300 basis points, depending on the leverage ratio then in effect. Base rate loans bear interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 125 to 200 basis points, depending on the leverage ratio then in effect. Midstream Holdings also pays a commitment fee based on the undrawn commitment amount ranging from 37.5 to 50 basis points. The Midstream Holdings Revolving Credit Facility is secured by mortgages and other security interests on substantially all of the properties of, and guarantees from, Midstream Holdings and its restricted subsidiaries (which do not include the Partnership, Rice Midstream Management LLC, a Delaware limited liability company and general partner of the Partnership, or the Company and its subsidiaries other than Midstream Holdings). The Midstream Holdings Revolving Credit Facility limits the ability of Midstream Holdings and its restricted subsidiaries to, among other things: • incur or guarantee additional debt; • redeem or repurchase units or make distributions under certain circumstances; • make certain investments and acquisitions; • incur certain liens or permit them to exist; • enter into certain types of transactions with affiliates; • merge or consolidate with another company; and • transfer, sell or otherwise dispose of assets. The Midstream Holdings Revolving Credit Facility also requires Midstream Holdings to maintain the following financial ratios: • an interest coverage ratio, which is the ratio of Rice Midstream Holding’s consolidated EBITDA (as defined within the Midstream Holdings Revolving Credit Facility) to its consolidated current interest expense of at least 2.50 to 1.0 at the end of each fiscal quarter; and • a consolidated total leverage ratio, which is the ratio of consolidated debt to consolidated EBITDA, of not more than 4.25 to 1.0. Midstream Holdings was in compliance with such covenants and ratios effective as of December 31, 2015 . RMP Revolving Credit Facility (e) On December 22, 2014 , Rice Midstream OpCo LLC, a wholly-owned subsidiary of the Partnership (“Rice Midstream OpCo”), entered into a revolving credit facility (the “RMP Revolving Credit Facility”) with Wells Fargo, as administrative agent, and a syndicate of lenders with a maximum credit amount of $450.0 million with an additional $200.0 million of commitments available under an accordion feature, subject to lender approval. The RMP Revolving Credit Facility provides for a letter of credit sublimit of $50.0 million . As of December 31, 2015 , Rice Midstream OpCo had $143.0 million borrowings outstanding and no letters of credit under this facility. The average daily outstanding balance of the credit facility was approximately $46.9 million and interest was incurred on the facility at a weighted average annual interest rate of 2.0% during 2015 . The RMP Revolving Credit Facility is available to fund working capital requirements and capital expenditures, to purchase assets, to pay distributions and repurchase units and for general partnership purposes and matures on December 22, 2019 . The Partnership is the guarantor of the obligations under the credit facility. Principal amounts borrowed are payable on the maturity date, and interest is payable quarterly for base rate loans and at the end of the applicable interest period for Eurodollar loans. Under the RMP Revolving Credit Facility, the Partnership may elect to borrow in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to the applicable LIBOR Rate plus an applicable margin ranging from 175 to 275 basis points, depending on the leverage ratio then in effect. Base rate loans bears interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 75 to 175 basis points, depending on the leverage ratio then in effect. The Partnership also pays a commitment fee based on the undrawn commitment amount ranging from 35 to 50 basis points. The RMP Revolving Credit Facility is secured by mortgages and other security interests on substantially all of the properties of, and guarantees from, the Partnership and its restricted subsidiaries. The RMP Revolving Credit Facility limits the ability of the Partnership and its restricted subsidiaries to, among other things: • incur or guarantee additional debt; • redeem or repurchase units or make distributions under certain circumstances; • make certain investments and acquisitions; • incur certain liens or permit them to exist; • enter into certain types of transactions with affiliates; • merge or consolidate with another company; and • transfer, sell or otherwise dispose of assets. The RMP Revolving Credit Facility also requires the Partnership to maintain the following financial ratios: • an interest coverage ratio, which is the ratio of the Partnership’s consolidated EBITDA (as defined within the RMP Revolving Credit Facility) to its consolidated current interest expense of at least 2.50 to 1.0 at the end of each fiscal quarter; • a consolidated total leverage ratio, which is the ratio of consolidated debt to consolidated EBITDA, of not more than 4.75 to 1.0, and after electing to issue senior unsecured notes, a consolidated total leverage ratio of not more than 5.25 to 1.0, and, in each case, with certain increases in the permitted total leverage ratio following the completion of a material acquisition; and • if the Partnership elects to issue senior unsecured notes, a consolidated senior secured leverage ratio, which is the ratio of consolidated senior secured debt to consolidated EBITDA, of not more than 3.50 to 1.0. The Partnership was in compliance with such covenants and ratios effective as of December 31, 2015 . Expected Aggregate Maturities Expected aggregate maturities of the notes payable as of December 31, 2015 are as follows (in thousands) : Remainder of Year Ending December 31, 2015 $ — Year Ending December 31, 2016 — Year Ending December 31, 2017 — Year Ending December 31, 2018 — Year Ending December 31, 2019 and Beyond 1,457,222 Total $ 1,457,222 Interest paid in cash was $82.1 million , $36.7 million and $27.7 million for the years ended December 31, 2015 , 2014 and 2013 , respectively. See Note 1 for information on capitalized interest.

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments The Company uses derivative commodity instruments that are placed with major financial institutions whose creditworthiness is regularly monitored. Our derivative counterparties share in the Amended Credit Agreement collateral. The Company has entered into various derivative contracts to manage price risk and to achieve more predictable cash flows. As a result of the Company’s hedging activities, the Company may realize prices that are greater or less than the market prices that it would have received otherwise. As of December 31, 2015 , the Company has entered into derivative instruments with various financial institutions, fixing the price it receives for a portion of its natural gas. The Company’s fixed price derivatives primarily include swap and collar contracts that are tied to the commodity prices on NYMEX. As of December 31, 2015, the Company has entered into NYMEX hedging contracts through December 31, 2019 covering a total of approximately 525 Bcf of our projected natural gas production at a weighted average price of $3.27 per MMBtu. Additionally, the Company has entered into basis swap contracts to hedge the difference between the NYMEX index price and various local index prices. The fixed price and basis hedging contracts the Company has entered into through December 31, 2020 at other various sales points cover a total of approximately 408 Bcf. The Company recognizes all derivative instruments as either assets or liabilities at fair value per the Financial Accounting Standards Board (“FASB”) ASC 815. The Company’s derivative commodity instruments have not been designated as hedges for accounting purposes; therefore, all gains and losses are recognized currently in earnings. The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the consolidated balance sheets for the periods presented, all at fair value: As of December 31, 2015 (in thousands) Derivative instruments, recorded in the Consolidated Balance Sheet, gross Derivative instruments subject to master netting arrangements Derivative Instruments, net Derivative assets $ 372,414 $ (79,509 ) $ 292,905 Derivative liabilities $ 21,043 $ (4,200 ) $ 16,843 As of December 31, 2014 (in thousands) Derivative instruments, recorded in the Consolidated Balance Sheet, gross Derivative instruments subject to master netting arrangements Derivative Instruments, net Derivative assets $ 201,775 $ (5,553 ) $ 196,222

Fair Value of Financial Instrum

Fair Value of Financial Instruments	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value of Financial Instruments The Company determines fair value on a recurring basis for its liability related to restricted units and recorded amounts for derivative instruments as these instruments are required to be recorded at fair value for each reporting amount. Certain amounts in the Company’s financial statements were measured at fair value on a nonrecurring basis including discounts associated with long-term debt. Fair value is based on quoted market prices, where available. If quoted market prices are not available, fair value is based upon models that use as inputs market-based parameters, including but not limited to forward curves, discount rates, broker quotes, volatilities, and nonperformance risk. The Company has categorized its fair value measurements 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). The Company’s fair value measurements relating to restricted units are included in Level 3. The Company’s fair value measurements relating to derivative instruments are included in Level 2. Since the adoption of fair value accounting, the Company has not made any changes to its classification of financial instruments in each category. Items included in Level 3 are valued using internal models that use significant unobservable inputs. Items included in Level 2 are valued using management’s best estimate of fair value corroborated by third-party quotes. The following assets and liabilities were measured at fair value on a recurring basis during the period (refer to Note 5 for details relating to derivative instruments): As of December 31, 2015 (in thousands) Fair Value Measurements at Reporting Date Using (in thousands) Carrying Value Total Fair Value Quoted Prices in Significant Other Significant Assets: Derivative instruments, at fair value $ 292,905 $ 292,905 $ — $ 292,905 $ — Total assets $ 292,905 $ 292,905 $ — $ 292,905 $ — Liabilities: Derivative instruments, at fair value $ 16,843 $ 16,843 $ — $ 16,843 $ — Total liabilities $ 16,843 $ 16,843 $ — $ 16,843 $ — As of December 31, 2014 Fair Value Measurements at Reporting Date Using (in thousands) Carrying Value Total Fair Value Quoted Prices in Significant Other Significant Assets: Derivative instruments, at fair value $ 196,222 $ 196,222 $ — $ 196,222 $ — Total assets $ 196,222 $ 196,222 $ — $ 196,222 $ — Fair Value Measurements Using Significant Unobservable Inputs (Level 3) (in thousands) 2015 2014 Balance as of January 1 $ — $ 36,306 Converted to shares of common stock — (36,306 ) Balance as of December 31 $ — $ — The carrying value of cash equivalents approximates fair value due to the short maturity of the instruments. The Company’s non-financial assets, such as property, plant and equipment, goodwill and intangible assets are recorded at fair value upon business combination and are remeasured at fair value only if an impairment charge is recognized. To the extent necessary, the Company applies unobservable inputs and management judgment due to the absence of quoted market prices (Level 3) to the valuation methodologies for these non-financial assets. The estimated fair value and carrying amount of long-term debt as reported on the consolidated balance sheets as of December 31, 2015 and 2014 is shown in the table below (refer to Note 4 for details relating to the debt instruments). The fair value was estimated using Level 2 inputs based on rates reflective of the remaining maturity as well as the Company’s financial position. The carrying value of the revolving credit facilities approximates fair value as of December 31, 2015 . As of December 31, 2015 As of December 31, 2014 Long-Term Debt (in thousands) Carrying Value Fair Value Carrying Value Fair Value Senior Notes Due 2022 $ 900,000 $ 650,250 $ 900,000 $ 839,250 Senior Notes Due 2023 397,222 294,000 — — Midstream Holdings Revolving Credit Facility 17,000 17,000 — — RMP Revolving Credit Facility 143,000 143,000 — — Other — — 680 680 Total $ 1,457,222 $ 1,104,250 $ 900,680 $ 839,930

Rice Midstream Partners LP

Rice Midstream Partners LP	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Rice Midstream Partners LP	Rice Midstream Partners LP On December 22, 2014 , the Partnership, a subsidiary of the Company, completed the RMP IPO of 28,750,000 common units representing limited partner interests in the Partnership, which represented 50% of the Partnership’s outstanding equity. The Company retained a 50% limited partner interest in the Partnership, consisting of 3,623 common units and 28,753,623 subordinated units. In connection with the RMP IPO, the Company contributed to the Partnership 100% of Rice Poseidon Midstream, LLC (“Rice Poseidon”). A wholly-owned subsidiary of the Company serves as the general partner of the Partnership. The Company continues to consolidate the results of the Partnership and records an income tax provision only as to its ownership percentage. The Company records the noncontrolling interest of the public limited partners in its consolidated financial statements for net income of the Partnership attributed to third party unitholders for periods subsequent to the Partnership’s IPO. Net income attributable to noncontrolling interests was $23.3 million and $0.6 million for the years ended December 31, 2015 and 2014, respectively. The Partnership received cash proceeds, net of issuance costs, of approximately $441.7 million upon the closing of the RMP IPO, which increased the noncontrolling interest component of total equity. Approximately $414.4 million of the proceeds were distributed to the Company, $25.0 million was retained by the Partnership to fund certain expansion capital expenditures, approximately $2.0 million was used to pay expenses from the RMP IPO and $2.7 million was used by the Partnership to pay credit facility origination fees associated with the RMP Revolving Credit Facility. On November 4, 2015, the Partnership entered into a Common Unit Purchase Agreement with certain institutional investors to sell 13,409,961 common units in a private placement for gross proceeds of approximately $175.0 million (the “Private Placement”). After deducting underwriting discounts and commissions of $3.1 million , the Partnership received net proceeds of $171.9 million . The Private Placement closed on November 10, 2015. The Partnership used the proceeds of the Private Placement to repay a portion of the borrowings under the Partnership’s revolving credit facility. Following the Private Placement, the Company owned approximately 41% of the outstanding limited partnership interest in the Partnership. On November 12, 2015 , a cash distribution of $0.1935 per common and subordinated unit was paid to the Partnership’s unitholders related to the third quarter of 2015. On January 22, 2016 , the Board of Directors of the Partnership’s general partner declared a cash distribution to the Partnership’s unitholders for the fourth quarter of 2015 of $0.1965 per common and subordinated unit. The cash distribution was paid on February 11, 2016 to unitholders of record at the close of business on February 2, 2016 .

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Acquisitions	Acquisitions Greene County Acquisition In the second quarter of 2015, the Company received $15.8 million from Chesapeake Appalachia, L.L.C. and its partners as a result of the finalization of the purchase price related to our acquisition of 19,000 net acres and 12 developed Marcellus wells in southwestern Greene County, Pennsylvania for approximately $329.5 million . The accounting for this business combination was final in the third quarter of 2015.

Financial Information by Busine

Financial Information by Business Segment	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Financial Information by Business Segment	Financial Information by Business Segment Management has evaluated how the Company is organized and has identified the Exploration and Production segment and the Midstream segment as separate reportable segments. Operating segments are evaluated on their contribution to the Company’s consolidated results based on operating income. Other income and expenses, interest and income taxes are managed on a consolidated basis. The segment accounting policies are the same as those described in Note 1 of these consolidated financial statements. The operating results and assets of the Company’s reportable segments were as follows as of and for the year ended December 31, 2015 : (in thousands) Exploration and Production Midstream Elimination of Intersegment Transactions Consolidated Total Operating revenues: Natural gas, oil and NGL sales $ 446,515 $ — $ — $ 446,515 Firm transportation sales, net 3,450 — — 3,450 Gathering, compression and water services — 141,823 (92,644 ) 49,179 Other revenue 2,997 — — 2,997 Total operating revenues $ 452,962 $ 141,823 $ (92,644 ) $ 502,141 Operating expenses: Lease operating 44,356 — — 44,356 Gathering, compression and transportation 150,015 — (65,308 ) 84,707 Production taxes and fees 7,609 — — 7,609 Exploration 3,137 — — 3,137 Midstream operation and maintenance — 16,988 — 16,988 Incentive unit expense 33,873 2,224 — 36,097 Impairment of gas properties 18,250 — — 18,250 Impairment of goodwill 294,908 — — 294,908 Acquisition costs 108 1,127 — 1,235 General and administrative expenses 78,592 24,446 — 103,038 Depreciation, depletion and amortization 308,194 19,185 (4,595 ) 322,784 Amortization of intangible assets — 1,632 — 1,632 Gain from sale of interest in gas properties (953 ) — — (953 ) Other expense 6,028 492 — 6,520 Total operating expenses $ 944,117 $ 66,094 $ (69,903 ) $ 940,308 Operating (loss) income $ (491,155 ) $ 75,729 $ (22,741 ) $ (438,167 ) Segment assets $ 3,004,226 $ 989,938 $ (23,633 ) $ 3,970,531 Goodwill $ — $ 39,142 $ — $ 39,142 Capital expenditures for segment assets $ 869,134 $ 404,476 $ (27,336 ) $ 1,246,274 The operating results and assets of the Company’s reportable segments were as follows as of and for the year ended December 31, 2014 : (in thousands) Exploration and Production Midstream Elimination of Intersegment Transactions Consolidated Total Operating revenues: Natural gas, oil and NGL sales $ 359,201 $ — $ — $ 359,201 Firm transportation sales, net 26,237 — — 26,237 Gathering, compression and water services — 7,300 (1,796 ) 5,504 Total operating revenues $ 385,438 $ 7,300 $ (1,796 ) $ 390,942 Operating expenses: Lease operating 24,971 — — 24,971 Gathering, compression and transportation 37,414 — (1,796 ) 35,618 Production taxes and fees 4,647 — — 4,647 Exploration 4,018 — — 4,018 Midstream operation and maintenance — 4,607 — 4,607 Incentive unit expense 86,020 19,941 — 105,961 Acquisition costs 820 1,519 — 2,339 General and administrative expenses 46,229 15,341 — 61,570 Depreciation, depletion and amortization 151,900 4,370 — 156,270 Amortization of intangible assets — 1,156 — 1,156 Other expense — 207 — 207 Total operating expenses $ 356,019 $ 47,141 $ (1,796 ) $ 401,364 Operating income (loss) $ 29,419 $ (39,841 ) $ — $ (10,422 ) Segment assets $ 2,935,814 $ 592,135 $ — $ 3,527,949 Goodwill $ 294,908 $ 39,142 $ — $ 334,050 Capital expenditures for segment assets $ 693,129 $ 277,145 $ — $ 970,274 The operating results and assets of the Company’s reportable segments were as follows as of and for the year ended December 31, 2013 : (in thousands) Exploration and Production Midstream Consolidated Total Operating revenues: Natural gas, oil and NGL sales $ 87,847 $ — $ 87,847 Gathering, compression and water services — 83 83 Other revenue 259 498 757 Total operating revenues $ 88,106 $ 581 $ 88,687 Operating expenses: Lease operating 8,309 — 8,309 Gathering, compression and transportation 8,362 — 8,362 Production taxes and fees 1,629 — 1,629 Exploration 9,951 — 9,951 Midstream operation and maintenance — 1,412 1,412 Restricted unit expense 32,906 — 32,906 General and administrative expenses 13,778 3,175 16,953 Depreciation, depletion and amortization 31,467 1,348 32,815 Loss from sale of interest in gas properties 4,230 — 4,230 Total operating expenses $ 110,632 $ 5,935 $ 116,567 Operating loss $ (22,526 ) $ (5,354 ) $ (27,880 ) Segment assets $ 804,992 $ 74,818 $ 879,810 Capital expenditures for segment assets $ 406,179 $ 59,208 $ 465,387

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies On October 14, 2013 , the Company entered into a Development Agreement and Area of Mutual Interest Agreement (collectively, the “Utica Development Agreements”) with Gulfport Energy Corporation (“Gulfport”) covering approximately 50,000 aggregate net acres in the Utica Shale in Belmont County, Ohio. Pursuant to the Utica Development Agreements, the Company had approximately 68.7% participating interest in acreage currently owned or to be acquired by the Company or Gulfport located within Goshen and Smith Townships (the “Northern Contract Area”) and an approximately 48.2% participating interest in acreage currently owned or to be acquired by the Company or Gulfport located within Wayne and Washington Townships (the “Southern Contract Area”), each within Belmont County, Ohio. The remaining participating interests are held by Gulfport. The participating interests of the Company and Gulfport in each of the Northern and Southern Contract Areas approximated the Company’s then-current relative acreage positions in each area. The Utica Development Agreements have terms of ten years and are terminable upon 90 days’ notice by either party; provided that, with respect to interests included within a drilling unit, such interests shall remain subject to the applicable joint operating agreement and the Company and Gulfport shall remain operators of drilling units located in the Northern and Southern Contract Areas, respectively, following such termination. The Company has commitments for gathering and firm transportation under existing contracts with third parties. Future payments under these contracts as of December 31, 2015 totaled $4,797.2 million ( 2016 - $117.2 million , 2017 - $151.4 million , 2018 - $226.9 million , 2019 - $222.5 million , 2020 - $222.3 million and thereafter - $3,856.9 million ). The Company has three horizontal rigs under contract, of which one expires in 2016 and two expire in 2017. The Company also has two tophole drilling rigs under contract, of which one expires in 2016 and one expires in 2018. Future payments under these contracts as of December 31, 2015 totaled $43.4 million ( 2016 - $29.3 million , 2017 - $12.1 million and 2018 - $2.0 million ). Any other rig performing work for the Company is performed on a well-by-well basis and therefore can be released without penalty at the conclusion of drilling on the current well. These types of drilling obligations have not been included in the amounts above. The values above represent the gross amounts that the Company is committed to pay without regard to its proportionate share based on its working interest. The Company is involved in various litigation matters arising in the normal course of business. Management is not aware of any actions that are expected to have a material adverse effect on its financial position or results of operations.

Lease Obligations

Lease Obligations	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Lease Obligations	Lease Obligations The Company leases drilling rights under agreements which expire at various times. The following represents the future minimum lease payments under the agreements as of December 31, 2015 : (in thousands) 2016 $ 17,288 2017 5,286 2018 566 2019 438 2020 and thereafter — Total future minimum lease payments $ 23,578 These lease payments are included as leasehold payable in the accompanying consolidated balance sheets. Additionally, the Company has leased drilling rights under agreements which specify additional payments due in the event that the Company does not meet predetermined criteria within a specified period of time. The Company could be required to pay up to approximately $0.5 million , of which, $0.2 million would be due in 2016 under these agreements.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The Company is subject to certain legal requirements which result in recognition of a liability related to the obligation to incur future plugging and abandonment costs. The Company records a liability for such asset retirement obligations and capitalizes a corresponding amount for asset retirement costs. The liability is estimated using the present value of expected future cash flows, adjusted for inflation and discounted at the Company’s credit adjusted risk-free rate. The current portion of asset retirement obligations are recorded in other accrued liabilities and the long term portion of asset retirement obligations are recorded in other long-term liabilities on the consolidated balance sheets. A reconciliation of the beginning and ending aggregate carrying amount of asset retirement obligations for the years ended December 31, 2015 and 2014 is as follows: (in thousands) Balance at December 31, 2013 $ 2,114 Liabilities incurred 7,171 Liabilities settled (256 ) Accretion expense 513 Balance at December 31, 2014 $ 9,542 Liabilities incurred 5,198 Revisions in estimated cash flows (3,085 ) Liabilities settled (1,131 ) Accretion expense 890 Balance at December 31, 2015 $ 11,414

Stockholders' Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Stockholders' Equity	Stockholders’ Equity On May 12, 2015, the Company and NGP Holdings entered into an Underwriting Agreement with Goldman, Sachs & Co. and Citigroup Global Markets Inc., relating to the offer and sale by NGP Holdings (the “Secondary Offering”) of 6,000,000 shares of common stock at a price to the public of $24.20 per share ( $23.99 per share net of underwriting discounts and commissions). The Secondary Offering closed on May 15, 2015. The Company did not receive any proceeds from the sale of shares of common stock by NGP Holdings. The Company’s Board of Directors did not declare or pay a dividend to holders of Rice Energy common stock for the year ended December 31, 2015 or 2014 .

Incentive Units

Incentive Units	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Incentive Units	Incentive Units In connection with the IPO and the related corporate reorganization, the Rice Appalachia incentive unit holders contributed their Rice Appalachia incentive units to Rice Holdings and NGP Holdings in return for (i) incentive units in such entities that, in the aggregate, were substantially similar to the Rice Appalachia incentive units they previously held and (ii) shares of common stock in the amount of $3.4 million related to the extinguishment of the incentive burden attributable to Mr. Daniel J. Rice III. No payments were made in respect of incentive units prior to the completion of the Company’s IPO. As a result of the IPO, the payment likelihood related to the NGP Holdings and Rice Holdings incentive units was deemed probable, requiring the Company to recognize compensation expense. The compensation expense related to these interests is treated as additional paid in capital from Rice Holdings and NGP Holdings in our financial statements and is not deductible for federal or state income tax purposes. The compensation expense recognized is a non-cash charge, with the settlement obligation resting on NGP Holdings and Rice Holdings, and as such the incentive units are not dilutive to Rice Energy Inc. NGP Holdings The NGP Holdings incentive units are considered a liability-based award and are adjusted to fair market value on a quarterly basis until all payments have been made. The recognized and unrecognized compensation expense related to the NGP Holdings incentive units is sensitive to certain assumptions, including the estimated timing of NGP Holdings’ sale of the Company’s common stock. Based on negative industry and market trends, including the performance of the Company’s stock price, the estimated timing of NGP Holdings’ sale of the Company’s common stock was adjusted as of December 31, 2015 . The change in the estimated requisite service period will be recognized prospectively. Non-cash compensation (income) expense relative to the NGP Holdings incentive units was $(24.3) million and $44.5 million for the year ended December 31, 2015 or 2014 , respectively. As of December 31, 2015 , the estimated unrecognized compensation expense related to the NGP Holdings interests is approximately $12.0 million . In the first quarter of 2014, NGP Holding’s distribution thresholds with regard to certain classes (tiers) of incentive units were satisfied as a result of NGP Holdings’ distribution of net proceeds from its sale of the Company’s common stock in the IPO, and NGP Holdings made cash distributions to its members, including holders of incentive units, in an aggregate amount of $4.4 million . As a result of the Company’s August 2014 Equity Offering, NGP Holdings paid approximately $12.0 million in the third quarter of 2014 to holders of certain classes of incentive units. The sale of the Company’s stock by NGP Holdings in the Secondary Offering triggered a payment to holders of certain classes of incentive units in May 2015, which resulted in approximately $26.7 million expense for the year ended December 31, 2015 . Rice Holdings The Rice Holdings incentive units are considered an equity-based award with the fair value of the award determined at the grant date and amortized over the service period of the award using the straight-line method. Compensation expense relative to the Rice Holdings incentive units was $33.7 million and $41.7 million for the year ended December 31, 2015 and 2014 respectively. The Company will recognize approximately $39.2 million of additional compensation expense over the remaining expected service period related to the Rice Holdings incentive units. In August 2014, the triggering event for the Rice Holdings incentive units was achieved. As a result, in September 2014 and September 2015, Rice Holdings distributed one quarter and one third, respectively, of its then-remaining assets (consisting solely of shares of the Company’s common stock) to its members pursuant to the terms of its limited liability company agreement. In addition, in September 2016 and 2017, Rice Holdings will distribute one half and all, respectively, of its then-remaining assets (consisting solely of shares of the Company’s common stock) to its members pursuant to the terms of its limited liability company agreement. As a result, over time, the shares of the Company’s common stock held by Rice Holdings will be transferred in their entirety to Rice Energy Irrevocable Trust and the incentive unitholders. Total compensation expense relative to the NGP Holdings and Rice Holdings incentive units was $36.1 million and $106.0 million for the year ended December 31, 2015 or 2014 , respectively. Of the total compensation expense recognized for the year ended December 31, 2015 , approximately $12.8 million related to changes in certain service condition assumptions. Three tranches of the incentive units have a time vesting feature. A rollforward of those units from our IPO to December 31, 2015 is included below. Vested Units Balance, January 29, 2014 133,333 Vested During Period 1,667,578 Forfeited During Period (37,140 ) Granted During Period 37,140 Canceled During Period — Vested Units Balance, December 31, 2014 1,800,911 Vested During Period 1,027,288 Forfeited During Period — Granted During Period — Canceled During Period — Vested Units Balance, December 31, 2015 2,828,199 Four tranches of the incentive units do not have a time vesting feature, and their payouts are triggered upon a future payment condition. As such, none of these awards have legally vested as of December 31, 2015 . The fair value of the incentive units was estimated using a Monte Carlo simulation valuation model with the following assumptions: Rice Holdings Valuation Date 1/29/2014 Dividend Yield 0.00 % Expected Volatility 47.00 % Risk-Free Rate 1.11 % Expected Life (Years) 4.0 Rice Holdings Valuation Date 4/14/2014 Dividend Yield 0.00 % Expected Volatility 45.19 % Risk-Free Rate 1.13 % Expected Life (Years) 3.8 Rice Holdings Valuation Date 4/16/2014 Dividend Yield 0.00 % Expected Volatility 44.32 % Risk-Free Rate 1.18 % Expected Life (Years) 3.8 NGP Holdings Valuation Date 12/31/2015 Dividend Yield 0.00 % Expected Volatility 54.57 % Risk-Free Rate 0.96 % Expected Life (Years) 1.75 Stock-Based Compensation During the years ended December 31, 2015 and 2014 , the Company granted stock-based compensation awards to certain non-employee directors and employees under our long-term incentive plan (the “LTIP”). Pursuant to the LTIP, the Company expects the aggregate maximum number of shares of our common stock issued under the LTIP will not exceed 17,500,000 . The awards consisted of restricted stock units, which vest upon the passage of time, and performance units, which vest based upon attainment of specified company performance criteria. Restricted Stock Unit Awards Restricted stock unit awards are valued based upon the price of the Company’s common stock on the grant date and vest over periods from one to three years, with compensation expense being recognized on a straight-line basis over the requisite service period. Compensation expense related to the restricted stock unit awards was $5.7 million and $2.6 million for the years ended December 31, 2015 and 2014 , respectively, and is recorded in general and administrative expenses on the consolidated statements of operations. The following table summarizes the restricted stock unit award activity during the year ended December 31, 2015 and 2014 . Number of shares Weighted average grant date fair value Total unvested, January 1, 2014 — $ — Granted 328,907 28.79 Vested (1,647 ) 30.33 Forfeited (4,601 ) 32.59 Total unvested, December 31, 2014 322,659 28.38 Granted 535,175 19.25 Vested (121,138 ) 27.98 Forfeited (34,027 ) 24.13 Total unvested - December 31, 2015 702,669 $ 21.70 The following table details the scheduled vesting of the outstanding unvested restricted stock unit awards at December 31, 2015 . Vesting Date Number of shares 2016 254,406 2017 266,452 2018 181,811 702,669 Total unrecognized compensation expense expected to be recognized in the future related to the restricted stock unit awards as of December 31, 2015 is $10.0 million . Performance Stock Unit Awards We use a Monte Carlo simulation valuation model to determine the fair value of the performance stock unit awards on the grant date. The compensation expense related to these awards is being recognized on a straight-line basis and the awards will cliff vest over the requisite service period of approximately three years. Compensation expense related to the performance unit stock awards was $6.7 million and $2.8 million for the years ended December 31, 2015 and 2014 , respectively, and is recorded in general and administrative expenses on the consolidated statements of operations. The following table presents information regarding the assumptions used in determining the fair value of the performance stock unit awards granted in 2015 and 2014. 2015 2014 Dividend Yield 0.00 % 0.00 % Expected Volatility 49.69 % 43.73 % Risk-Free Rate 1.00 % 0.70 % Expected Life (Years) 2.89 2.65 Weighted average fair value of performance stock unit awards $ 21.61 $ 38.77 Total unrecognized compensation expense expected to be recognized in the future related to the performance stock unit awards as of December 31, 2015 is $10.8 million . RMP Phantom Unit Awards During the years ended December 31, 2015 and 2014 , the Partnership’s general partner granted phantom unit awards under the Rice Midstream Partners LP 2014 Long Term Incentive Plan (the “RMP LTIP”) to certain non-employee directors of the Partnership and executive officers and employees of Rice Energy. Pursuant to the RMP LTIP, the maximum aggregate number of common units that may be issued pursuant to any and all awards under the RMP LTIP shall not exceed 5,000,000 common units subject to adjustment due to recapitalization or reorganization, or related to forfeitures or the expiration of Awards, as provided under the RMP LTIP. The equity-based awards are valued based upon the price of the Partnership’s common units on the grant date and will cliff vest over the requisite service period from one and a half to two years. The Partnership recorded $4.1 million and $0.1 million of stock compensation expense related to these awards for the years ended December 31, 2015 and 2014 , respectively, and is recorded in general and administrative expenses on the consolidated statements of operations. Total unrecognized compensation expense expected to be recognized over the remaining vesting period as of December 31, 2015 is $3.0 million for these awards. The following table summarizes the activity for the equity-based awards during the year ended December 31, 2015 and 2014 . Number of units Weighted average grant date fair value Total unvested, January 1, 2014 — $ — Granted 434,094 16.50 Vested — — Forfeited — — Total unvested, December 31, 2014 434,094 16.50 Granted 18,196 16.87 Vested (242 ) 16.50 Forfeited (19,420 ) 16.50 Total unvested - December 31, 2015 432,628 $ 16.52 The following table details the scheduled vesting of the unvested equity-based awards at December 31, 2015 . Vesting Date Number of units 2016 432,628 432,628

Stock Compensation

Stock Compensation	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock Compensation	Incentive Units In connection with the IPO and the related corporate reorganization, the Rice Appalachia incentive unit holders contributed their Rice Appalachia incentive units to Rice Holdings and NGP Holdings in return for (i) incentive units in such entities that, in the aggregate, were substantially similar to the Rice Appalachia incentive units they previously held and (ii) shares of common stock in the amount of $3.4 million related to the extinguishment of the incentive burden attributable to Mr. Daniel J. Rice III. No payments were made in respect of incentive units prior to the completion of the Company’s IPO. As a result of the IPO, the payment likelihood related to the NGP Holdings and Rice Holdings incentive units was deemed probable, requiring the Company to recognize compensation expense. The compensation expense related to these interests is treated as additional paid in capital from Rice Holdings and NGP Holdings in our financial statements and is not deductible for federal or state income tax purposes. The compensation expense recognized is a non-cash charge, with the settlement obligation resting on NGP Holdings and Rice Holdings, and as such the incentive units are not dilutive to Rice Energy Inc. NGP Holdings The NGP Holdings incentive units are considered a liability-based award and are adjusted to fair market value on a quarterly basis until all payments have been made. The recognized and unrecognized compensation expense related to the NGP Holdings incentive units is sensitive to certain assumptions, including the estimated timing of NGP Holdings’ sale of the Company’s common stock. Based on negative industry and market trends, including the performance of the Company’s stock price, the estimated timing of NGP Holdings’ sale of the Company’s common stock was adjusted as of December 31, 2015 . The change in the estimated requisite service period will be recognized prospectively. Non-cash compensation (income) expense relative to the NGP Holdings incentive units was $(24.3) million and $44.5 million for the year ended December 31, 2015 or 2014 , respectively. As of December 31, 2015 , the estimated unrecognized compensation expense related to the NGP Holdings interests is approximately $12.0 million . In the first quarter of 2014, NGP Holding’s distribution thresholds with regard to certain classes (tiers) of incentive units were satisfied as a result of NGP Holdings’ distribution of net proceeds from its sale of the Company’s common stock in the IPO, and NGP Holdings made cash distributions to its members, including holders of incentive units, in an aggregate amount of $4.4 million . As a result of the Company’s August 2014 Equity Offering, NGP Holdings paid approximately $12.0 million in the third quarter of 2014 to holders of certain classes of incentive units. The sale of the Company’s stock by NGP Holdings in the Secondary Offering triggered a payment to holders of certain classes of incentive units in May 2015, which resulted in approximately $26.7 million expense for the year ended December 31, 2015 . Rice Holdings The Rice Holdings incentive units are considered an equity-based award with the fair value of the award determined at the grant date and amortized over the service period of the award using the straight-line method. Compensation expense relative to the Rice Holdings incentive units was $33.7 million and $41.7 million for the year ended December 31, 2015 and 2014 respectively. The Company will recognize approximately $39.2 million of additional compensation expense over the remaining expected service period related to the Rice Holdings incentive units. In August 2014, the triggering event for the Rice Holdings incentive units was achieved. As a result, in September 2014 and September 2015, Rice Holdings distributed one quarter and one third, respectively, of its then-remaining assets (consisting solely of shares of the Company’s common stock) to its members pursuant to the terms of its limited liability company agreement. In addition, in September 2016 and 2017, Rice Holdings will distribute one half and all, respectively, of its then-remaining assets (consisting solely of shares of the Company’s common stock) to its members pursuant to the terms of its limited liability company agreement. As a result, over time, the shares of the Company’s common stock held by Rice Holdings will be transferred in their entirety to Rice Energy Irrevocable Trust and the incentive unitholders. Total compensation expense relative to the NGP Holdings and Rice Holdings incentive units was $36.1 million and $106.0 million for the year ended December 31, 2015 or 2014 , respectively. Of the total compensation expense recognized for the year ended December 31, 2015 , approximately $12.8 million related to changes in certain service condition assumptions. Three tranches of the incentive units have a time vesting feature. A rollforward of those units from our IPO to December 31, 2015 is included below. Vested Units Balance, January 29, 2014 133,333 Vested During Period 1,667,578 Forfeited During Period (37,140 ) Granted During Period 37,140 Canceled During Period — Vested Units Balance, December 31, 2014 1,800,911 Vested During Period 1,027,288 Forfeited During Period — Granted During Period — Canceled During Period — Vested Units Balance, December 31, 2015 2,828,199 Four tranches of the incentive units do not have a time vesting feature, and their payouts are triggered upon a future payment condition. As such, none of these awards have legally vested as of December 31, 2015 . The fair value of the incentive units was estimated using a Monte Carlo simulation valuation model with the following assumptions: Rice Holdings Valuation Date 1/29/2014 Dividend Yield 0.00 % Expected Volatility 47.00 % Risk-Free Rate 1.11 % Expected Life (Years) 4.0 Rice Holdings Valuation Date 4/14/2014 Dividend Yield 0.00 % Expected Volatility 45.19 % Risk-Free Rate 1.13 % Expected Life (Years) 3.8 Rice Holdings Valuation Date 4/16/2014 Dividend Yield 0.00 % Expected Volatility 44.32 % Risk-Free Rate 1.18 % Expected Life (Years) 3.8 NGP Holdings Valuation Date 12/31/2015 Dividend Yield 0.00 % Expected Volatility 54.57 % Risk-Free Rate 0.96 % Expected Life (Years) 1.75 Stock-Based Compensation During the years ended December 31, 2015 and 2014 , the Company granted stock-based compensation awards to certain non-employee directors and employees under our long-term incentive plan (the “LTIP”). Pursuant to the LTIP, the Company expects the aggregate maximum number of shares of our common stock issued under the LTIP will not exceed 17,500,000 . The awards consisted of restricted stock units, which vest upon the passage of time, and performance units, which vest based upon attainment of specified company performance criteria. Restricted Stock Unit Awards Restricted stock unit awards are valued based upon the price of the Company’s common stock on the grant date and vest over periods from one to three years, with compensation expense being recognized on a straight-line basis over the requisite service period. Compensation expense related to the restricted stock unit awards was $5.7 million and $2.6 million for the years ended December 31, 2015 and 2014 , respectively, and is recorded in general and administrative expenses on the consolidated statements of operations. The following table summarizes the restricted stock unit award activity during the year ended December 31, 2015 and 2014 . Number of shares Weighted average grant date fair value Total unvested, January 1, 2014 — $ — Granted 328,907 28.79 Vested (1,647 ) 30.33 Forfeited (4,601 ) 32.59 Total unvested, December 31, 2014 322,659 28.38 Granted 535,175 19.25 Vested (121,138 ) 27.98 Forfeited (34,027 ) 24.13 Total unvested - December 31, 2015 702,669 $ 21.70 The following table details the scheduled vesting of the outstanding unvested restricted stock unit awards at December 31, 2015 . Vesting Date Number of shares 2016 254,406 2017 266,452 2018 181,811 702,669 Total unrecognized compensation expense expected to be recognized in the future related to the restricted stock unit awards as of December 31, 2015 is $10.0 million . Performance Stock Unit Awards We use a Monte Carlo simulation valuation model to determine the fair value of the performance stock unit awards on the grant date. The compensation expense related to these awards is being recognized on a straight-line basis and the awards will cliff vest over the requisite service period of approximately three years. Compensation expense related to the performance unit stock awards was $6.7 million and $2.8 million for the years ended December 31, 2015 and 2014 , respectively, and is recorded in general and administrative expenses on the consolidated statements of operations. The following table presents information regarding the assumptions used in determining the fair value of the performance stock unit awards granted in 2015 and 2014. 2015 2014 Dividend Yield 0.00 % 0.00 % Expected Volatility 49.69 % 43.73 % Risk-Free Rate 1.00 % 0.70 % Expected Life (Years) 2.89 2.65 Weighted average fair value of performance stock unit awards $ 21.61 $ 38.77 Total unrecognized compensation expense expected to be recognized in the future related to the performance stock unit awards as of December 31, 2015 is $10.8 million . RMP Phantom Unit Awards During the years ended December 31, 2015 and 2014 , the Partnership’s general partner granted phantom unit awards under the Rice Midstream Partners LP 2014 Long Term Incentive Plan (the “RMP LTIP”) to certain non-employee directors of the Partnership and executive officers and employees of Rice Energy. Pursuant to the RMP LTIP, the maximum aggregate number of common units that may be issued pursuant to any and all awards under the RMP LTIP shall not exceed 5,000,000 common units subject to adjustment due to recapitalization or reorganization, or related to forfeitures or the expiration of Awards, as provided under the RMP LTIP. The equity-based awards are valued based upon the price of the Partnership’s common units on the grant date and will cliff vest over the requisite service period from one and a half to two years. The Partnership recorded $4.1 million and $0.1 million of stock compensation expense related to these awards for the years ended December 31, 2015 and 2014 , respectively, and is recorded in general and administrative expenses on the consolidated statements of operations. Total unrecognized compensation expense expected to be recognized over the remaining vesting period as of December 31, 2015 is $3.0 million for these awards. The following table summarizes the activity for the equity-based awards during the year ended December 31, 2015 and 2014 . Number of units Weighted average grant date fair value Total unvested, January 1, 2014 — $ — Granted 434,094 16.50 Vested — — Forfeited — — Total unvested, December 31, 2014 434,094 16.50 Granted 18,196 16.87 Vested (242 ) 16.50 Forfeited (19,420 ) 16.50 Total unvested - December 31, 2015 432,628 $ 16.52 The following table details the scheduled vesting of the unvested equity-based awards at December 31, 2015 . Vesting Date Number of units 2016 432,628 432,628

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share Basic EPS is computed by dividing net income (loss) by the weighted-average number of shares of common stock outstanding during the period. Diluted earnings per share takes into account the dilutive effect of potential common stock that could be issued by the Company in conjunction with stock awards that have been granted to directors and employees. The following is a calculation of the basic and diluted weighted-average number of shares of common stock outstanding and EPS for the years ended December 31, 2015 , 2014 and 2013 . As indicated in Note 1, our corporate reorganization was considered a transaction amongst entities under common control. Therefore, the weighted average shares used in our EPS calculation assume that the Rice Energy Inc. corporate structure was in place for all periods presented. Year Ended December 31, 2015 2014 2013 Income (loss) (numerator): Net (loss) income attributable to Rice Energy (in thousands) $ (291,336 ) $ 218,454 $ (35,776 ) Weighted-average shares (denominator): Weighted-average number of shares of common stock - basic 136,344,076 128,151,171 80,441,905 Weighted-average number of shares of common stock - diluted 136,344,076 128,225,155 80,441,905 (Loss) earnings per share: Basic $ (2.14 ) $ 1.70 $ (0.44 ) Diluted $ (2.14 ) $ 1.70 $ (0.44 ) For the year ended December 31, 2015 , 133,611 shares attributable to equity awards were not included in the diluted earnings per share calculations as the Company incurred a net loss for the period presented. For the year ended December 31, 2013, 1,671,800 shares attributable to equity awards were not included in the diluted earnings per share calculation as the Company incurred a net loss for the period presented. The impact of the Partnership’s dilutive units did not have a material impact on the Company’s earnings per share calculation at December 31, 2014 .

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes We are a corporation under the Internal Revenue Code subject to federal income tax at a statutory rate of 35% of pretax earnings. We did not report any income tax benefit or expense for periods prior to the consummation of our IPO in January 2014 because Rice Drilling B, our accounting predecessor, is a limited liability company that was not subject to federal income tax. The reorganization of our business in connection with the closing of our IPO, such that it is now held by a corporation subject to federal income tax, required the recognition of a deferred tax asset or liability for the initial temporary differences at the time of our IPO. The resulting deferred tax liability of approximately $162.3 million was recorded in equity at the date of the completion of our IPO as it represents a transaction among shareholders. Additionally, the pro forma EPS for the year ended December 31, 2014 disclosed in the accompanying consolidated statements of operations assumes a statutory tax rate. The components of the income tax provision are as follows: Year Ended December 31, (in thousands) 2015 2014 Current tax expense: Federal $ 4,039 $ 3,961 State — — Total 4,039 3,961 Deferred tax expense: Federal 19,878 68,846 State (11,799 ) 18,793 Total 8,079 87,639 Total income tax expense $ 12,118 $ 91,600 The effective tax rate for the year ended December 31, 2015 differs from the statutory rate due principally to non-deductible incentive unit expense, impairment losses and noncontrolling interest and, for the year ended December 31, 2014 , pre-tax income prior to our IPO. Income tax expense differs from amounts computed at the federal statutory rate of 35% on pre-tax income as follows: Year Ended December 31, (in thousands) 2015 2014 Tax at statutory rate $ (89,560 ) $ 108,722 Permanent tax differences 74 18 State income taxes (7,668 ) 12,216 Partnership earnings (1/1/14 - 1/28/14) — (66,239 ) Noncontrolling partners’ share of RMP earnings (8,168 ) (203 ) Goodwill impairment 103,218 — Incentive unit expense 12,634 37,086 Other, net 1,588 — Income tax expense $ 12,118 $ 91,600 Effective tax rate (4.74 )% 29.49 % The Company recognizes deferred tax liabilities for temporary differences between the financial statement and tax basis of assets and liabilities. The deferred tax liabilities primarily relate to intangible drilling costs, depletion and depreciation. The effect of changes in the tax laws or tax rates is recognized in income in the period such changes are enacted. The following table summarizes the source and tax effects of temporary differences that give rise to the deferred tax assets and deferred tax liabilities at December 31, 2015 and December 31, 2014 . Year Ended December 31, (in thousands) 2015 2014 Deferred income taxes: Total deferred tax assets $ — $ — Total deferred tax liabilities (271,988 ) (263,906 ) Total net deferred tax liabilities (271,988 ) (263,906 ) Principal components of deferred tax assets and liabilities: Drilling and development costs expensed for tax (294,972 ) (189,475 ) Tax depreciation in excess of book depreciation (92,710 ) (24,252 ) Investment in partnerships 57,227 38,077 Incentive compensation 5,576 2,263 Net operating loss carryforwards 153,558 — Hedging loss (109,352 ) (80,663 ) AMT tax credit 7,999 3,961 Other 686 (13,817 ) Total $ (271,988 ) $ (263,906 ) As of December 31, 2015 , the Company had a federal income tax net operating loss (“NOL”) carryforward of approximately $398.5 million and State NOL carryforwards of approximately $293.8 million . The associated deferred tax assets related to these NOL carryforwards was $153.6 million . The NOL carryforwards expire in 2035. The value of these carryforwards depends on the Company’s ability to generate taxable income. The Company is subject to the alternative minimum tax (“AMT”) if the computed AMT liability exceeds the regular tax liability for the year. As a result of certain AMT preference items related to intangible drilling costs, the Company has generated AMT carryforwards. Because AMT taxes paid can be credited against regular tax and have an indefinite carryforward, this item is reflected as a deferred tax asset in the amount of $8.0 million at December 31, 2015 . During the year ended December 31, 2015 , the Company incurred $0.1 million and $0.1 million of interest and penalties, respectively, related to income tax filings recorded in interest expense and general and administrative expenses, respectively, on the consolidated statement of operations. At December 31, 2015 , there is no accrual for interest recorded on the consolidated balance sheet. Based on management’s analysis, the Company did not have any uncertain tax positions as of December 31, 2015 .

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Prior to the completion of the Marcellus JV Buy-In, the Company was reimbursed for costs incurred on behalf of the Company’s Marcellus joint venture. General and administrative expenses incurred by the Company and reimbursed by the Company’s Marcellus joint venture were $0.3 million and $1.6 million for the years ended December 31, 2014 and 2013, respectively. Prior to our IPO, the Company reimbursed Rice Partners for expenses incurred on behalf of the Company. General and administrative expenses incurred by Rice Partners and reimbursed by the Company were $1.8 million and $9.3 million for the years ended December 31, 2014 and 2013, respectively. Prior to the closing of our IPO, the Company terminated its agreement to reimburse Rice Partners for expenses incurred on its behalf. Upon completion of the RMP IPO, the Company entered into a 15 year, fixed fee gas gathering and compression agreement (the “Gas Gathering and Compression Agreement”) with RMP, under which RMP will gather natural gas on RMP’s gathering systems located in Washington County and Greene County, Pennsylvania and provide compression services. Pursuant to the Gas Gathering and Compression Agreement, RMP will charge the Company a gathering fee of $0.30 per Dth and a compression fee of $0.07 per Dth per stage of compression, each subject to annual adjustment for inflation based on the Consumer Price Index. The Gas Gathering and Compression Agreement covers approximately 93,000 gross acres of the Company’s acreage position in the dry gas core of the Marcellus Shale in southwestern Pennsylvania as of December 31, 2015 and any future acreage it acquires within these counties, excluding the first 40.0 MDth/d of Rice Energy’s production from approximately 19,000 gross acres subject to a pre-existing third-party dedication. The revenues and related receivables RMP records pursuant to the Gas Gathering and Compression Agreement are eliminated in consolidation in the accompanying consolidated financial statements. In connection with the closing of the acquisition of the Water Assets on November 4, 2015 , the Partnership entered into Amended and Restated Water Services Agreements (the “Water Services Agreements”) with the Company, whereby the Partnership has agreed to provide certain fluid handling services to the Company, including the exclusive right to provide fresh water for well completions operations in the Marcellus and Utica Shales and to collect and recycle or dispose of flowback and produced water for the Company within areas of dedication in defined service areas in Pennsylvania and Ohio. The initial term of the Water Services Agreements is until December 22, 2029 and from month to month thereafter. Under the agreements, the Company will pay the Partnership (i) a variable fee, based on volumes of water supplied, for freshwater deliveries by pipeline directly to the well site, subject to annual CPI adjustments and (ii) a produced water hauling fee of actual out-of-pocket cost incurred by us, plus a 2% margin.

New Accounting Pronouncements

New Accounting Pronouncements	12 Months Ended
	Dec. 31, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Pronouncements	New Accounting Pronouncements In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”), No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” or ASU 2014-09. The FASB created Topic 606 which supersedes the revenue recognition requirements in Topic 605, “Revenue Recognition,” and most industry-specific guidance throughout the Industry Topics of the Codification. The FASB and International Accounting Standards Board initiated this joint project to clarify the principles for recognizing revenue and to develop a common revenue standard for both U.S. GAAP and International Financial Reporting Standards. ASU 2014-09 will enhance comparability of revenue recognition practices across entities, industries and capital markets compared to existing guidance. ASU 2014-09 explains that the core principle of the standard is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services and defines a five step process to achieve this core principle. The five step process is to (i) identify the contract with a customer; (ii) identify the performance obligations in the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and (v) recognize revenue when or as the entity satisfies a performance obligation. More judgement and estimates may be required within the new revenue recognition process than are required under existing U.S. GAAP. In August 2015, the FASB issued ASU 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date.” The amendments in this update deferred the effective date for implementation of ASU 2014-09 by one year. ASU 2014-09 will now be effective for annual reporting periods beginning after December 15, 2017 and should be applied retrospectively using either a full retrospective approach reflecting the application of the standard in each prior reporting period or a retrospective approach with the cumulative effect of initially adopting the standard recognized at the date of adoption. Early application is permitted only for annual reporting periods beginning after December 15, 2016, including interim reporting periods within that period. The Company has not yet selected a transition method and is currently evaluating the standard and the impact on its consolidated financial statements and footnote disclosures. In February 2015, the FASB issued ASU, 2015-02, “Consolidation (Topic 810): Amendments to the Consolidation Analysis.” ASU 2015-02 affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. ASU 2015-02 is effective for periods beginning after December 15, 2015 with early adoption permitted. The Company will adopt ASU 2015-02 in the first quarter of 2016. The Company does not anticipate adoption of the standard to impact prior conclusions as to whether or not its subsidiaries are consolidated in the consolidated financial statements In April 2015, the FASB issued ASU, 2015-03, “Interest—Imputation of Interest (Subtopic 835-30): Simplification of Debt Issuance Costs.” ASU 2015-03 was issued to simplify the presentation of debt issuance costs by requiring debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability, consistent with debt discounts. ASU 2015-03 is effective for periods beginning after December 15, 2015 with early adoption permitted. In August 2015, the FASB issued ASU 2015-15, “Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements.” ASU 2015-15 clarifies the guidance in ASU 2015-03 regarding presentation and subsequent measurement of debt issuance costs related to line-of-credit arrangements. The SEC staff announced they would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The Company will adopt ASU 2015-03 in the first quarter of 2016. The adoption of ASU 2015-03 will be applied retrospectively and will result in debt issuance costs being presented as a direct deduction from the carrying amount of the related debt liability in the consolidated balance sheets. The Company will also adopt ASU 2015-15 and present debt issuance costs associated with the Company’s revolving credit facilities as assets named deferred financing costs, net in the consolidated balance sheets. In September 2015, the FASB issued ASU, 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments.” ASU 2015-16 requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. ASU 2015-16 is effective for periods beginning after December 15, 2015 with prospective application and early adoption permitted. The Company will adopt ASU 2015-16 in the first quarter of 2016 and will apply the provisions of the standard on an as-needed basis to the extent that a business combination occurs. In November 2015, the FASB issued ASU, 2015-17, “Income Taxes (Topic 740): Balance Sheet Classifications of Deferred Taxes,” to simplify the presentation of deferred income taxes and aligns the presentation of deferred income tax assets and liabilities with International Financial Reporting Standards (IFRS). Under the new standard, both deferred tax liabilities and assets are required to be classified as noncurrent in a classified balance sheet. ASU 2015-17 is effective for fiscal years, and the interim periods within those years, beginning after December 15, 2016. This update may be applied prospectively to all deferred tax liabilities and assets or retrospectively to all periods presented. The Company has prospectively adopted ASU 2015-017 in the fourth quarter of 2015.

Subsequent Event

Subsequent Event	12 Months Ended
	Dec. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	Subsequent Events On January 13, 2016, the Company entered into the Seventh Amendment to the Amended Credit Agreement, which increased the aggregate notional volume limitations for our hedging arrangements contained in the Amended Credit Agreement for the first 18 months after any commodity swap agreement or secured firm transportation reimbursement agreement is entered into. On February 1, 2016 , Strike Force Holdings, a wholly-owned subsidiary of the Company and Gulfport Midstream Holdings, LLC (“Gulfport Midstream”) a wholly-owned subsidiary of Gulfport, entered into an Amended and Restated Limited Liability Company Agreement (the “Strike Force LLC Agreement”) of Strike Force Midstream LLC (“Strike Force Midstream”) to engage in the natural gas midstream business in approximately 319,000 acres in Belmont and Monroe Counties, Ohio. Under the terms of the Strike Force LLC Agreement, Strike Force Holdings made an initial contribution to Strike Force Midstream of certain pipelines, facilities and rights of way and cash in the amount of $41.0 million in exchange for a 75% membership interest in Strike Force Midstream. Gulfport Midstream made an initial contribution of a gathering system and related assets in exchange for a 25% membership interest in Strike Force Midstream. On February 17, 2016, Midstream Holdings and Rice Midstream GP Holdings LP, a newly-formed Delaware limited partnership (“GP Holdings”) and subsidiary of Midstream Holdings, entered into a securities purchase agreement (the “Securities Purchase Agreement”) with EIG Energy Fund XVI, L.P., a Delaware limited partnership, EIG Energy Fund XV-E, L.P., a Delaware limited partnership, and EIG Holdings (RICE) Partners, LP, a Delaware limited partnership (collectively, the “Purchasers”), pursuant to which (i) Midstream Holdings agreed to sell 375,000 Series B Units (“Series B Units”) in Midstream Holdings with an aggregate liquidation preference of $375.0 million and (ii) GP Holdings agreed to sell common units (“GP Common Units”) representing an 8.25% limited partner interest in GP Holdings for aggregate consideration of $375.0 million in a private placement (the “Midstream Holdings Investment”) exempt from the registration requirements under the Securities Act. The Midstream Holdings Investment closed on February 22, 2016 (the “Closing Date”). After September 30, 2016 and prior to the eighteen -month anniversary of the Closing Date, upon the satisfaction of certain financial and operational metrics, Midstream Holdings has the right to require the Purchasers to purchase additional Series B Units and GP Common Units on the terms set forth above. Midstream Holdings may require the Purchasers to purchase at least $25.0 million of additional units on up to three occasions, up to a total aggregate amount of $125.0 million . Pursuant to the Securities Purchase Agreement, Midstream Holdings is required to pay the Purchasers a quarterly cash commitment fee of 2.0% per annum on any undrawn amounts of the additional $125.0 million commitment. Midstream Holdings will use $75.0 million of the proceeds to reduce outstanding borrowings under its credit facility and to pay transaction fees and expenses, and the remaining $300.0 million will be distributed to the Company. On February 19, 2016, Midstream Holdings entered into the Second Amendment (the “Second Amendment”) to the Midstream Holdings Revolving Credit Facility. Among other changes, the Second Amendment: (i) permits cash distributions by GP Holdings to the Purchasers, subject to certain limitations; (ii) permits a one-time contribution of common units of RMP from Midstream Holdings to GP Holdings; (iii) amends the definition of “Disqualified Capital Stock” to permit a put right feature in connection with the Midstream Holdings Investment; (iv) amends the definition of “Change in Control” to include any change of control under the documents entered into in connection with the Midstream Holdings Investment; (v) expands cross-default to the documents entered into in connection with the Midstream Holdings Investment; and (vi) excludes proceeds from a scheduled sale of equity interests in GP Holdings to an investor from the mandatory prepayment provision.

Guarantor Financial Information

Guarantor Financial Information	12 Months Ended
	Dec. 31, 2015
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Guarantor Financial Information	Guarantor Financial Information On April 25, 2014 , the Company issued $900.0 million in aggregate principal amount of the 2022 Notes and on March 26, 2015 , the Company issued $400.0 million in aggregate principal amount of the 2023 Notes. The obligations under the Notes are fully and unconditionally guaranteed by the Guarantors, subject to release provisions described in Note 3. The Company’s subsidiaries that constitute its Midstream segment, including the Partnership, are unrestricted subsidiaries under the indentures governing the Notes and consequently are not Guarantors. In accordance with positions established by the SEC, the following shows separate financial information with respect to the Company, the Guarantors and the non-guarantor subsidiaries. The principal elimination entries eliminate investment in subsidiaries and certain intercompany balances and transactions. Balance Sheet as of December 31, 2015 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Assets Current assets: Cash $ 78,474 $ 57,800 $ 15,627 $ — $ 151,901 Accounts receivable 147 140,493 14,174 — 154,814 Receivable from affiliate 27,670 — 4,501 (32,171 ) — Prepaid expenses, deposits and other 4,377 817 294 — 5,488 Derivative instruments 47,262 139,698 — — 186,960 Deferred tax assets — — — — — Total current assets 157,930 338,808 34,596 (32,171 ) 499,163 Gas collateral account — 3,995 82 — 4,077 Investments in subsidiaries 2,378,293 113,268 — (2,491,561 ) — Property, plant and equipment, net 21,442 2,382,878 865,043 (26,232 ) 3,243,131 Deferred financing costs, net 25,329 — 4,915 — 30,244 Goodwill — — 39,142 — 39,142 Intangible assets, net — — 46,159 — 46,159 Other non-current assets 32,590 76,025 — — 108,615 Total assets $ 2,615,584 $ 2,914,974 $ 989,937 $ (2,549,964 ) $ 3,970,531 Liabilities and stockholders’ equity Current liabilities: Accounts payable $ 4,178 $ 48,191 $ 31,184 $ — $ 83,553 Royalties payables — 40,572 — — 40,572 Accrued capital expenditures — 45,240 34,507 — 79,747 Leasehold payables — 17,338 — — 17,338 Other accrued liabilities 36,287 71,649 3,367 (32,171 ) 79,132 Total current liabilities 40,465 222,990 69,058 (32,171 ) 300,342 Long-term liabilities: Long-term debt 1,297,222 — 160,000 — 1,457,222 Leasehold payable — 6,289 — — 6,289 Deferred tax liabilities 47,667 299,741 19,911 (95,331 ) 271,988 Other long-term liabilities 19,432 7,661 3,129 — 30,222 Total liabilities 1,404,786 536,681 252,098 (127,502 ) 2,066,063 Stockholders’ equity before noncontrolling interest 1,210,798 2,378,293 113,268 (2,422,462 ) 1,279,897 Noncontrolling interests in consolidated subsidiaries — — 624,571 — 624,571 Total liabilities and stockholders’ equity $ 2,615,584 $ 2,914,974 $ 989,937 $ (2,549,964 ) $ 3,970,531 Balance Sheet as of December 31, 2014 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Assets Current assets: Cash $ 181,835 $ 41,934 $ 32,361 $ — $ 256,130 Accounts receivable 1,773 196,974 1,153 — 199,900 Receivable from affiliates 634 55 2,198 (2,799 ) 88 Prepaid expenses deposits and other 1,296 1,702 341 — 3,339 Derivative instruments 47,291 85,743 — — 133,034 Total current assets 232,829 326,408 36,053 (2,799 ) 592,491 Gas collateral account — 3,995 — — 3,995 Investments in subsidiaries 2,177,895 86,148 — (2,264,043 ) — Property, plant and equipment, net 10,348 1,986,856 464,127 — 2,461,331 Deferred financing costs, net 20,081 — 5,022 — 25,103 Goodwill — 294,908 39,142 — 334,050 Intangible assets, net — — 47,791 — 47,791 Derivative instruments 8,290 54,898 — — 63,188 Total assets $ 2,449,443 $ 2,753,213 $ 592,135 $ (2,266,842 ) $ 3,527,949 Liabilities and stockholders’ equity Current liabilities: Current portion of long-term debt $ — $ 680 $ — $ — $ 680 Accounts payable 19,231 101,132 31,966 — 152,329 Royalties payables — 37,172 — — 37,172 Accrued capital expenditures 1,515 89,858 16,917 — 108,290 Leasehold payables — 30,702 — — 30,702 Deferred tax liabilities 54,688 39,197 — (39,197 ) 54,688 Other accrued liabilities 26,027 27,502 2,086 (2,801 ) 52,814 Total current liabilities 101,461 326,243 50,969 (41,998 ) 436,675 Long-term liabilities: Long-term debt 900,000 — — — 900,000 Leasehold payable — 4,279 — — 4,279 Deferred tax liabilities 12,497 237,155 10,660 (51,094 ) 209,218 Other long-term liabilities 3,068 7,641 1,900 — 12,609 Total liabilities 1,017,026 575,318 63,529 (93,092 ) 1,562,781 Stockholders’ equity before noncontrolling interest 1,432,417 2,177,895 86,148 (2,173,750 ) 1,522,710 Noncontrolling interest in consolidated subsidiaries — — 442,458 — 442,458 Total liabilities and stockholders’ equity $ 2,449,443 $ 2,753,213 $ 592,135 $ (2,266,842 ) $ 3,527,949 Statement of Operations for the Year Ended December 31, 2015 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Operating revenues: Natural gas, oil and natural gas liquids (NGL) sales $ — $ 446,515 $ — $ — $ 446,515 Firm transportation sales, net — 3,450 — — 3,450 Gathering, compression and water services — — 141,823 (92,644 ) 49,179 Other revenue — 2,997 — — 2,997 Total operating revenues — 452,962 141,823 (92,644 ) 502,141 Operating expenses: Lease operating — 44,356 — — 44,356 Gathering, compression and transportation — 150,015 — (65,308 ) 84,707 Production taxes and impact fees — 7,609 — — 7,609 Exploration — 3,137 — — 3,137 Midstream operation and maintenance — — 16,988 — 16,988 Incentive unit expense — 33,873 2,224 — 36,097 Impairment of gas properties — 18,250 — — 18,250 Impairment of goodwill — 294,908 — — 294,908 General and administrative — 78,592 24,446 — 103,038 Depreciation, depletion and amortization — 304,703 19,185 (1,104 ) 322,784 Acquisition expense 4 103 1,128 — 1,235 Amortization of intangible assets — — 1,632 — 1,632 Gain from sale of interest in gas properties — (953 ) — — (953 ) Other expense — 6,028 492 — 6,520 Total operating expenses 4 940,621 66,095 (66,412 ) 940,308 Operating income (loss) (4 ) (487,659 ) 75,728 (26,232 ) (438,167 ) Interest expense (82,664 ) (166 ) (4,616 ) — (87,446 ) Other income 617 439 52 — 1,108 Gain on derivative instruments 68,247 205,501 — — 273,748 Amortization of deferred financing costs (4,072 ) — (1,052 ) — (5,124 ) Equity in income (loss) of joint ventures and subsidiaries (296,335 ) 10,145 — 286,190 — Income (loss) before income taxes (314,211 ) (271,740 ) 70,112 259,958 (255,881 ) Income tax expense (12,118 ) (25,699 ) (9,295 ) 34,994 (12,118 ) Net income (loss) (326,329 ) (297,439 ) 60,817 294,952 (267,999 ) Less: net income attributable to noncontrolling interests — — (23,337 ) — (23,337 ) Net income (loss) attributable to Rice Energy $ (326,329 ) $ (297,439 ) $ 37,480 $ 294,952 $ (291,336 ) Statement of Operations for the Year Ended December 31, 2014 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Operating revenues: Natural gas, oil and natural gas liquids (NGL) sales $ — $ 359,201 $ — $ — $ 359,201 Firm transportation sales, net — 26,237 — — 26,237 Gathering, compression and water services — — 7,300 (1,796 ) 5,504 Total operating revenues — 385,438 7,300 (1,796 ) 390,942 Operating expenses: Lease operating — 24,971 — — 24,971 Gathering, compression and transportation — 37,180 — (1,562 ) 35,618 Production taxes and impact fees — 4,647 — — 4,647 Exploration — 4,018 — — 4,018 Midstream operation and maintenance — — 4,607 — 4,607 Incentive unit expense — 86,020 19,941 — 105,961 General and administrative — 45,268 16,302 — 61,570 Depreciation, depletion and amortization — 153,282 2,988 — 156,270 Acquisition expense — 820 1,519 — 2,339 Amortization of intangible assets — — 1,156 — 1,156 Other expenses — — 207 — 207 Total operating expenses — 356,206 46,720 (1,562 ) 401,364 Operating income (loss) — 29,232 (39,420 ) (234 ) (10,422 ) Interest expense (27,177 ) (10,130 ) (12,884 ) — (50,191 ) Gain on purchase of Marcellus joint venture — 203,579 — — 203,579 Other income (loss) 247 755 (109 ) — 893 Gain on derivative instruments 55,580 130,897 — — 186,477 Amortization of deferred financing costs (2,006 ) (489 ) — — (2,495 ) Loss on extinguishment of debt — (7,654 ) — — (7,654 ) Write-off of deferred financing costs — (6,896 ) — — (6,896 ) Equity in income (loss) of joint ventures and subsidiaries 193,119 (47,208 ) — (148,567 ) (2,656 ) Income (loss) before income taxes 219,763 292,086 (52,413 ) (148,801 ) 310,635 Income tax expense (91,600 ) (98,731 ) 8,440 90,291 (91,600 ) Net income (loss) 128,163 193,355 (43,973 ) (58,510 ) 219,035 Less: net income attributable to noncontrolling interests — — (581 ) — (581 ) Net income (loss) attributable to Rice Energy $ 128,163 $ 193,355 $ (44,554 ) $ (58,510 ) $ 218,454 Statement of Operations for the Year Ended December 31, 2013 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Operating revenues: Natural gas sales $ — $ 87,847 $ — $ — $ 87,847 Gathering, compression and water services — — 83 — 83 Other revenue — 763 (6 ) — 757 Total operating revenues — 88,610 77 — 88,687 Operating expenses: Lease operating — 8,309 — — 8,309 Gathering, compression and transportation — 8,362 — — 8,362 Production taxes and impact fees — 1,629 — — 1,629 Exploration — 9,951 — — 9,951 Midstream operation and maintenance — — 1,412 — 1,412 Restricted unit expense — 32,906 — — 32,906 General and administrative — 16,636 317 — 16,953 Depreciation, depletion and amortization — 32,421 394 — 32,815 (Gain) loss from sale of interest in gas properties — 4,230 — — 4,230 Total operating expenses — 114,444 2,123 — 116,567 Operating (loss) — (25,834 ) (2,046 ) — (27,880 ) Interest expense — (17,915 ) — — (17,915 ) Other (loss) — (357 ) (83 ) — (440 ) Gain on derivative instruments — 6,891 — — 6,891 Amortization of deferred financing costs — (5,230 ) — — (5,230 ) Loss on extinguishment of debt — (10,622 ) — — (10,622 ) Equity in income of joint ventures and subsidiaries — 17,848 — 1,572 19,420 Net income (loss) $ — $ (35,219 ) $ (2,129 ) $ 1,572 $ (35,776 ) Condensed Statement of Cash Flows for the Year Ended December 31, 2015 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ (59,213 ) $ 413,989 $ 85,547 $ (27,336 ) $ 412,987 Capital expenditures for property and equipment (9,775 ) (859,359 ) (404,476 ) 27,336 (1,246,274 ) Investment in subsidiaries (421,063 ) 11,614 — 409,449 — Acquisition of Greene County assets — 19,054 — — 19,054 Proceeds from sale of interest in gas properties — 10,201 — — 10,201 Net cash used in investing activities (430,838 ) (818,490 ) (404,476 ) 436,785 (1,217,019 ) Proceeds from borrowings 411,932 — 502,000 — 913,932 Repayments of debt obligations (15,922 ) (697 ) (342,000 ) — (358,619 ) Distributions to the Partnership’s public unitholders — — (17,017 ) — (17,017 ) Debt issuance costs (9,320 ) — (946 ) — (10,266 ) Proceeds from issuance of common stock sold in our IPO, net of offering costs — — (129 ) — (129 ) Proceeds from issuance of common units sold by RMP, net of offering costs — — 171,902 — 171,902 Contributions from parent, net — 421,064 (11,615 ) (409,449 ) — Net cash provided by financing activities 386,690 420,367 302,195 (409,449 ) 699,803 Increase (decrease) in cash (103,361 ) 15,866 (16,734 ) — (104,229 ) Cash, beginning of year 181,835 41,934 32,361 — 256,130 Cash, end of year $ 78,474 $ 57,800 $ 15,627 $ — $ 151,901 Condensed Statement of Cash Flows for the Year Ended December 31, 2014 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ 16,139 $ 96,147 $ (27,211 ) $ — $ 85,075 Capital expenditures for property and equipment (8,588 ) (684,541 ) (277,145 ) — (970,274 ) Acquisition of Marcellus joint venture, net of cash acquired — (27,766 ) (55,000 ) — (82,766 ) Acquisition of Momentum assets — (400 ) (111,447 ) — (111,847 ) Acquisition of Greene County assets — (329,469 ) — — (329,469 ) Proceeds from sale of interest in gas properties — 12,891 — — 12,891 Net cash used in investing activities (8,588 ) (1,029,285 ) (443,592 ) — (1,481,465 ) Proceeds from borrowings 900,000 190,000 — — 1,090,000 Repayments of debt obligations — (689,873 ) — — (689,873 ) Restricted cash for convertible debt — 8,268 — — 8,268 Debt issuance costs (19,522 ) — (5,021 ) — (24,543 ) Proceeds from conversion of warrants 1,975 — — — 1,975 Proceeds from issuance of common stock sold in our IPO, net of offering costs 597,088 — — — 597,088 Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of offering costs 196,254 — — — 196,254 Proceeds from issuance of common units sold in RMP IPO, net of offering costs — — 441,739 — 441,739 Contributions from parent, net (1,501,511 ) 1,435,269 66,242 — — Net cash provided by financing activities 174,284 943,664 502,960 — 1,620,908 Increase (decrease) in cash 181,835 10,526 32,157 — 224,518 Cash, beginning of year — 31,408 204 — 31,612 Cash, end of year $ 181,835 $ 41,934 $ 32,361 $ — $ 256,130 Condensed Statement of Cash Flows for the Year Ended December 31, 2013 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ — $ 34,428 $ (756 ) $ — $ 33,672 Capital expenditures for property and equipment — (406,179 ) (59,208 ) — (465,387 ) Proceeds from sale of interest in gas properties — 6,792 — — 6,792 Net cash used in investing activities — (399,387 ) (59,208 ) — (458,595 ) Proceeds from borrowings — 435,500 — — 435,500 Repayments of debt obligations — (160,760 ) — — (160,760 ) Restricted cash for convertible debt — (8,268 ) — — (8,268 ) Debt issuance costs — (12,194 ) — — (12,194 ) Common stock issuance — 135,815 60,162 — 195,977 Repurchase of common stock — (2,267 ) — — (2,267 ) Net cash provided by financing activities — 387,826 60,162 — 447,988 Increase (decrease) in cash — 22,867 198 — 23,065 Cash, beginning of year — 8,541 6 — 8,547 Cash, end of year $ — $ 31,408 $ 204 $ — $ 31,612

Quarterly Financial Information

Quarterly Financial Information	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information (Unaudited)	Quarterly Financial Information (Unaudited) The Company’s quarterly financial information for the years ended December 31, 2015 and 2014 is as follows (in thousands): Year ended December 31, 2015: (1) First quarter Second quarter Third quarter Fourth quarter Total operating revenues $ 109,539 $ 112,894 $ 143,621 $ 136,088 Total operating expenses 140,619 159,065 160,295 480,329 Operating loss (31,080 ) (46,171 ) (16,674 ) (344,241 ) Net income (loss) $ 4,687 $ (63,519 ) $ 65,084 $ (274,251 ) Net income (loss) attributable to Rice Energy $ 152 $ (69,683 ) $ 58,950 $ (280,755 ) Earnings (loss) per share attributable to Rice Energy - basic $ — $ (0.51 ) $ 0.43 $ (2.06 ) Earnings (loss) per share attributable to Rice Energy - diluted $ — $ (0.51 ) $ 0.43 $ (2.06 ) Year ended December 31, 2014: (1) First quarter Second quarter Third quarter Fourth quarter Total operating revenues $ 90,477 $ 91,940 $ 79,128 $ 129,398 Total operating expenses 124,272 67,522 91,453 118,118 Operating income (loss) (33,795 ) 24,418 (12,325 ) 11,280 Net income (loss) $ 129,454 $ (7,917 ) $ (6,861 ) $ 104,360 Net income (loss) attributable to Rice Energy $ 129,454 $ (7,917 ) $ (6,861 ) $ 103,779 Earnings (loss) per share attributable to Rice Energy - basic $ 1.04 $ (0.06 ) $ (0.05 ) $ 0.76 Earnings (loss) per share attributable to Rice Energy - diluted $ 1.03 $ (0.06 ) $ (0.05 ) $ 0.76 (1) The sum of quarterly data in some cases may not equal the yearly total due to rounding.

Supplemental Information on Gas

Supplemental Information on Gas Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Supplemental Information on Gas Producing Activities (Unaudited)	Supplemental Information on Gas-Producing Activities (Unaudited) Capitalized costs relating to gas-producing activities are as follows: As of December 31, (in thousands) 2015 2014 Proved properties $ 1,811,279 $ 1,195,274 Unproved properties 1,071,523 1,003,449 2,882,802 2,198,723 Accumulated depreciation and depletion (501,958 ) (215,905 ) Net capitalized costs $ 2,380,844 $ 1,982,818 Costs incurred for property acquisitions, exploration and development are as follows: For the Years Ended December 31, (in thousands) 2015 2014 2013 Acquisitions: Proved leaseholds $ — $ 439,284 $ — Unproved leaseholds 100,172 233,185 305,000 Development costs 616,836 734,106 184,217 Exploration costs: Geological and geophysical 1,276 4,018 9,951 Results of operations related to natural gas production are as follows: For the Years Ended December 31, (in thousands) 2015 2014 2013 Revenues $ 452,962 $ 385,438 $ 88,106 Production costs 201,980 67,032 18,300 Exploration costs 3,137 4,018 9,951 Depreciation, depletion and amortization 308,194 151,900 31,467 Incentive unit expense 33,873 86,020 — Restricted unit expense — — 32,906 Impairment of gas properties 18,250 — — Impairment of goodwill 294,908 — — Acquisition costs 108 820 — (Gain) loss from sale of interest in gas properties (953 ) — 4,230 Other expense 6,028 — — General and administrative expenses 78,592 46,229 13,778 Income tax expense 6,039 38,871 — Results of operations from producing activities $ (497,194 ) $ (9,452 ) $ (22,526 ) Reserve quantity information is as follows: For the Years Ended December 31, (in MMcfe) 2015 2014 2013 (1) Proved developed and undeveloped reserves: Beginning of year 1,306,571 382,660 304,272 Acquisitions — 282,391 — Extensions and discoveries 869,038 692,239 100,626 Revision of previous estimates (274,249 ) 47,018 757 Production (201,328 ) (97,737 ) (22,995 ) End of year 1,700,032 1,306,571 382,660 Proved developed reserves: End of year 1,014,873 644,149 144,309 Proved undeveloped reserves: End of year 685,159 662,422 238,351 (1) Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014. Acquisitions For the year ended December 31, 2014, the Company added 282,391 MMcfe through its purchase of the remaining 50% interest in the Marcellus joint venture in January 2014 and the Greene County acreage acquisition in August 2014. Amounts presented for the year ended December 31, 2013 exclude amounts attributable to our Marcellus joint venture. Extensions, Discoveries and Other Additions The Company added 869,038 MMcfe through its drilling program in the Marcellus Shale and Utica Shale and also as a result of changes in the Company’s operational plans. The Company added 692,239 MMcfe and 100,626 MMcfe through its drilling program in the Marcellus Shale and Utica Shale in 2015 and in the Marcellus Shale in 2014 and 2013 , respectively. Revision of Previous Estimates In 2015, the Company had net negative revisions of 274,249 MMcfe. Such revisions resulted from approximately 40 proved undeveloped locations that were removed from the Company’s estimate of reserves at December 31, 2014 and reclassified to the probable category due to changes in the Company’s operational plans, partially offset by 56,000 MMcfe of positive revisions to the Company’s proved developed locations from the Company’s estimate of reserves at December 31, 2014. The reserve quantity information is limited to reserves which had been evaluated as of December 31, 2015 . Proved developed reserves represent only those reserves expected to be recovered from existing wells and support equipment. Proved undeveloped reserves are expected to be recovered from new wells after substantial development costs are incurred. Netherland, Sewell & Associates, Inc. reviewed 100% of the total net gas proved reserves attributable to the Company’s interests and the Company’s Marcellus joint venture as of December 31, 2015, 2014 and 2013. The information presented represents estimates of proved natural gas reserves based on evaluations prepared by the independent petroleum engineering firms of Netherland, Sewell & Associates, Inc. in accordance with Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Evaluation Engineers and definitions and guidelines established by the SEC. The Company’s independent reserve engineers were selected for their historical experience and geographic expertise in engineering unconventional resources. Since 1961, Netherland, Sewell & Associates, Inc. has evaluated oil and gas properties and independently certified petroleum reserves quantities in the United States and internationally. Certain information concerning the assumptions used in computing the standardized measure of proved reserves and their inherent limitations are discussed below. The Company believes such information is essential for a proper understanding and assessment of the data presented. Future cash inflows are computed by applying the 12-month unweighted arithmetic average of the first-day-of-the-month price for each month in the period January through, respectively, to the period-end quantities of those reserves. Natural gas prices are held constant throughout the lives of the properties. The assumptions used to compute estimated future net revenues do not necessarily reflect the Company’s expectations of actual revenues or costs, or their present worth. In addition, variations from the expected production rates also could result directly or indirectly from factors outside of the Company’s control, such as unintentional delays in development, changes in prices or regulatory controls. The standardized measure calculation further assumes that all reserves will be disposed of by production. However, if reserves are sold in place, this could affect the amount of cash eventually realized. Future development and production costs are computed by estimating the expenditures to be incurred in developing and producing the proved natural gas reserves at the end of the year, based on period-end costs and assuming continuation of existing economic conditions. An annual discount rate of 10% was used to reflect the timing of the future net cash flows relating to proved natural gas reserves. Information with respect to the Company’s estimated discounted future net cash flows related to its proved natural gas and oil reserves is as follows: As of December 31, (in thousands) 2015 2014 2013 (1) Future cash inflows $ 4,497,738 $ 5,904,380 $ 1,496,294 Future production costs (2,378,541 ) (2,161,926 ) (517,101 ) Future development costs (545,988 ) (610,179 ) (219,879 ) Future income tax expense — (745,022 ) — Future net cash flows 1,573,209 2,387,253 759,314 10% annual discount for estimated timing of cash flows (686,936 ) (1,079,499 ) (342,150 ) Standardized measure of discounted future net cash flows (2) $ 886,273 $ 1,307,754 $ 417,164 (1) Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014. (2) Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income. Therefore, the cumulative effect of future income tax expense for the periods presented was included at December 31, 2015 and 2014. For 2015 , the reserves for the Company were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2015 , adjusted for energy content and a regional price differential. For 2015 , this adjusted natural gas price was $2.65 , the adjusted oil price was $41.72 and the adjusted NGL price was $9.91 . For 2014 , the reserves for the Company were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2014 , adjusted for energy content and a regional price differential. For 2014 , this adjusted natural gas price was $4.52 and the adjusted oil price was $85.70 . For 2013 , the reserves for the Company were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2013 , adjusted for energy content and a regional price differential. For 2013 , this adjusted natural gas price was $3.91 per Mcf. We did not have proved reserves for oil in 2013. The following are the principal sources of changes in the standardized measure of discounted future net cash flows: For the Years Ended December 31, (in thousands) 2015 2014 2013 (1) Balance at beginning of period $ 1,307,754 $ 417,164 $ 102,218 Net change in prices and production costs (949,774 ) 81,558 101,345 Net change in future development costs 4,251 (181,813 ) 29,336 Natural gas and oil net revenues (312,269 ) (291,023 ) (68,135 ) Extensions 370,636 930,534 114,489 Acquisitions — 375,865 (2) — Revisions of previous quantity estimates (274,503 ) 37,435 1,133 Previously estimated development costs incurred 122,532 62,653 66,894 Net change in taxes 436,319 (436,319 ) — Accretion of discount 174,407 70,937 10,230 Changes in timing and other 6,920 240,763 59,654 Balance at end of period $ 886,273 $ 1,307,754 $ 417,164 (1) Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014. (2) Reflects the purchase of the remaining 50% interest in the Marcellus joint venture in January 2014 and the Greene County acreage acquisition in August 2014. (3) Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income. Therefore, the cumulative effect of future income tax expense for the periods presented was included at December 31, 2015 and 2014. The information below presents the supplemental information on gas-producing activities for our 50% investment in our Marcellus joint venture for the year ended December 31, 2013. Costs incurred for property acquisitions, exploration and development related to the Company’s Marcellus joint venture are as follows (represents Rice Drilling B’s proportionate share): (in thousands) For the Year Ended December 31, 2013 Acquisitions: Unproved leaseholds $ — Development costs 46,571 Exploration costs: Geological and geophysical — Total costs incurred $ 46,571 The following table presents the Company’s share of the results of operations related to natural gas production of the Marcellus joint venture (represents Rice Drilling B’s proportionate share): (in thousands) For the Year Ended December 31, 2013 Revenues $ 45,339 Production costs 12,557 Impairment of oil and gas properties — Depreciation, depletion and accretion 12,500 General and administrative expenses 1,557 Results of operations from producing activities $ 18,725 Reserve quantity information is as follows for the Marcellus joint venture (represents Rice Drilling B’s proportionate share): Natural Gas (MMcf) (in thousands) For the Year Ended December 31, 2013 Proved developed and undeveloped reserves: Beginning of year 128,118 Extensions and discoveries 19,812 Revision of previous estimates (26,803 ) Production (11,443 ) End of year 109,684 Proved developed reserves: End of year 52,370 Proved undeveloped reserves: End of year 57,314 Rice Drilling B’s 50% equity interest in the Marcellus joint venture added 19,812 MMcf through its drilling program in the Marcellus Shale in 2013. In 2013, Rice Drilling B’s 50% equity interest in the Marcellus joint venture had net negative revisions of 26,803 MMcf due primarily to performance revisions. Information with respect to the Company’s share of the Marcellus joint venture’s estimated discounted future net cash flows related to its proved natural gas reserves is as follows: (in thousands) As of December 31, 2013 Future cash inflows $ 427,167 Future production costs (132,427 ) Future development costs (46,344 ) Future net cash flows 248,396 10% annual discount for estimated timing of cash flows (102,293 ) Standardized measure of discounted future net cash flows (1) $ 146,103 (1) Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income. For 2013, the reserves for the Marcellus joint venture were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2013, adjusted for energy content and a regional price differential. For 2013, this adjusted gas price was $3.90 per Mcf. The following is for the Marcellus joint venture (represents Rice Drilling B’s proportionate share), the principal sources of changes in the standardized measure of discounted future net cash flows: (in thousands) For the Year Ended December 31, 2013 Balance at beginning of period $ 71,077 Net change in prices and production costs 81,974 Net change in future development costs 2,781 Natural gas net revenues (32,782 ) Extensions 18,950 Revisions of previous quantity estimates (14,752 ) Previously estimated development costs incurred 31,253 Accretion of discount 7,111 Changes in timing and other (19,509 ) Balance at end of period $ 146,103

Summary of Significant Accoun32

Summary of Significant Accounting Policies and Related Matters (Policies)	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Accounting	The accompanying consolidated financial statements of Rice Energy Inc. (the “Company,” “we,” “our,” and “us”) have been prepared by the Company’s management in accordance with generally accepted accounting principles in the United States (“GAAP”) for financial information and applicable rules and regulations promulgated under the Exchange Act.
Organization, Operations, Principles of Consolidation, and Noncontrolling Interest	The consolidated financial statements of the Company include the accounts of its wholly-owned subsidiaries. Rice Midstream Holdings LLC, a subsidiary of the Company (“Midstream Holdings”) owns a 41% interest in Rice Midstream Partners LP, a subsidiary of the Company, (“the Partnership”). The financial results of the Partnership are consolidated and the remaining 59% interest in the Partnership is reflected as noncontrolling interest in the consolidated financial statements. All intercompany transactions have been eliminated in consolidation. Noncontrolling Interest Noncontrolling interests represent third-party equity ownership of the Partnership and are presented as a component of equity in the consolidated balance sheets. In the consolidated statements of operations, noncontrolling interest reflects the allocation of earnings to the third-party investors. The Company owns a 41% equity interest in the Partnership and controls the Partnership through its ownership of the general partner. See Note 7 for further discussion of noncontrolling interests related to the Partnership.
Corporate Reorganization and Initial Public Offering	A corporate reorganization occurred concurrently with the completion of the IPO on January 29, 2014. As a part of this corporate reorganization, the Company acquired all of the outstanding membership interests in Rice Energy Appalachia LLC (“Rice Appalachia”) and Rice Drilling B LLC (“Rice Drilling B”) (other than those already held by Rice Appalachia) in exchange for shares of our common stock. The Exploration and Production segment continues to be conducted through Rice Drilling B, now a wholly-owned subsidiary. This reorganization constituted a common control transaction and the accompanying consolidated financial statements are presented as though this reorganization had occurred for the earliest period presented.
Nature of Business and Segment Reporting	Nature of Business The Company is an independent natural gas and oil company engaged in the acquisition, exploration and development of natural gas, oil and NGL properties in the Appalachian Basin. The Company operates in two business segments, which are managed separately due to their distinct operational differences. The Company’s two reporting segments are as follows: Exploration and Production. This segment is engaged in the acquisition, exploration and development of natural gas, oil and NGLs in the Appalachian Basin. The Exploration and Production segment operates in what the Company believes to be the core of the Marcellus and Utica Shales. Midstream. This segment is engaged in the gathering and compression of natural gas, oil and NGL production of, and in the provision of water services to support the well completion activities of Rice Energy and third-parties. Segment Reporting Business segments are components of the Company for which separate financial information is produced internally and are subject to evaluation by the Company’s chief operating decision maker in deciding how to allocate resources. The Company reports its operations in two segments: (i) Exploration and Production and (ii) Midstream, which reflect its lines of business. Business segments are evaluated for their contribution to the Company’s combined results based on operating income. All of the Company’s operating revenues, income from operations and assets are located in the United States. See Note 9 for additional information regarding segment reporting.
Use of Estimates	Use of Estimates The preparation of consolidated financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the dates of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates and changes in these estimates are recorded when known.
Revenue Recognition	Revenue Recognition Sales of natural gas, NGLs and oil are recognized when the products have been delivered to a custody transfer point, persuasive evidence of a sales arrangement exists, the rights and responsibility of ownership pass to the purchaser upon delivery, collection of revenue from the sale is reasonably assured, and the sales price is fixed or determinable. Natural gas is sold by the Company under contracts with the Company’s natural gas marketers. Pricing provisions are generally tied to the Platts Gas Daily market prices. Some transportation costs incurred by the Company are marketed for resale and are not incurred to transport gas produced by the Company’s Exploration and Production segment. These transportation costs are reflected as a deduction from the related firm transportation sales revenue at the time the transportation is provided to the customer. Revenue from the gathering and compression of natural gas and water services is recognized in the month in which the service is provided.
Cash	Cash The Company maintains cash at financial institutions which may at times exceed federally insured amounts. The Company has no other accounts that are considered cash equivalents.
Accounts Receivable	Accounts Receivable Accounts receivable are primarily from the Company’s joint interest partners and natural gas marketers. The Company extends credit to parties in the normal course of business based upon management’s assessment of their creditworthiness. An allowance is provided for those accounts for which collection is estimated as doubtful; uncollectible accounts are written off and charged against the allowance. In estimating the allowance, management considers, among other things, how recently and how frequently payments have been received and the financial position of the party.
Property, Plant and Equipment	Property, Plant and Equipment The Company uses the successful efforts method of accounting for oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties are capitalized as unproved properties, whereas costs to drill and equip exploratory wells that result in proved reserves, are capitalized as proved properties. Costs to drill exploratory wells that do not identify proved reserves as well as geological and geophysical costs and costs of carrying and retaining unproved properties are expensed. Long-lived assets to be held and used or disposed of other than by sale are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. When required, impairment losses on assets to be held and used or disposed other than by sale are recognized based on the fair value of the asset. Long-lived assets to be disposed of by sale are reported at the lower of their carrying amount or fair value less selling costs. Capitalized costs of producing oil and gas properties and support equipment directly related to such properties, after considering estimated residual salvage values, are depreciated and depleted by the units of production method. Midstream property and equipment is recorded at cost and is being depreciated over estimated useful lives on a straight-line basis. Gathering pipelines and compressor stations are depreciated over a useful life of 60 years. Water pipelines, pumping stations and impoundment facilities are depreciated over a useful life of 10 to 15 years. Capitalized costs of unproved properties are evaluated at least annually for recoverability on a prospective basis. This evaluation includes consideration of current economic conditions, changes in development plans or business strategy, expected lease expirations and historical experience. If it is determined that it is unlikely for an unproved property to yield proved reserves prior to lease expiration, an impairment of the respective unproved property is recognized in the period in which that determination is made. For the year ended December 31, 2015 , the Company recognized $7.3 million of impairment expense in the consolidated statement of operations, primarily the result of changes in the Company’s development plans and lease expirations. Upon the sale of an entire interest in an unproved property for cash, a gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained unless the proceeds received are in excess of the cost basis which would result in gain on sale. For the years ended December 31, 2015 and 2013 , the Company recorded (gain) loss on sale of unproved properties of $(1.0) million and $4.2 million , respectively. Unproved oil and gas properties had a net book value of $1,050.0 million and $1,015.4 million at December 31, 2015 and 2014 , respectively. The carrying values of the Company’s proved properties are reviewed periodically when events or circumstances indicate that the remaining carrying amount may not be recoverable. Generally, this evaluation is performed on a formation-level basis by comparing estimated undiscounted future cash flows to the carrying value, and including risk-adjusted probable and possible reserves if deemed reasonable. Key assumptions utilized in determining the estimated undiscounted future cash flows are generally consistent with assumptions used in the Company’s budgeting and forecasting processes. If the carrying value of proved properties exceeds the estimated undiscounted future cash flows, they are written down to fair value. Fair value of proved properties is estimated by discounting the estimated future cash flows using discount rates and consideration of expected assumptions that would be used by a market participant. Due to the significant decline in commodity prices in 2015 and 2014, there were indications that the carrying values of certain proved properties may not be fully recoverable when compared to their fair value. The fair value was determined using an income approach based on estimated future production, future commodity prices adjusted for firm transportation and basis differentials, future operating and capital costs, and an assumed discount rate of 13.5% . As the assumptions used to calculate the estimated fair value were significant unobservable inputs, the valuation of the proved properties was considered to be a Level 3 fair value measurement. The Company determined that the carrying value of Upper Devonian proved properties was not fully recoverable and as a result, for the year ended December 31, 2015 , the Company recognized $10.9 million of impairment expense in the consolidated statement of operations to write-down such proved properties to fair value of $7.3 million . For the years ended December 31, 2014 and 2013, the Company did not recognize impairment charges for proved or unproved properties.
Interest	Interest The Company capitalizes interest on expenditures for significant exploration and development projects while activities are in progress to bring the assets to their intended use. Upon completion of construction of the asset, the associated capitalized interest costs are included within our asset base and depleted accordingly.
Goodwill	Goodwill Goodwill is the cost of an acquisition less the fair value of the net identifiable assets of the acquired business. The Company evaluates goodwill for impairment at least annually during the fourth quarter, or whenever events or changes in circumstances indicate it is more likely than not that the fair value of a reporting unit is less than its carrying amount. The Company may first consider qualitative factors to assess whether there are indicators that it is more likely than not that the fair value of a reporting unit may not exceed its carrying amount. To the extent that such indicators exist, the Company would complete the two-step goodwill impairment test. The Company may also perform the two-step goodwill impairment test at its discretion without performing the qualitative assessment. The first step compares the fair value of a reporting unit to its carrying value. If the carrying amount of a reporting unit exceeds its fair value, the second step is required which compares the implied fair value of the goodwill of a reporting unit to its carrying value. If the carrying value of the goodwill of a reporting unit exceeds its implied fair value, the difference is recognized as an impairment charge. See Note 3 for additional information which includes the results of the Company’s annual goodwill impairment test.
Intangible Assets	Intangible Assets Intangible assets are recorded under the acquisition method of accounting at their estimated fair values at the acquisition date. The customer contracts acquired had an initial contract terms of 10 years with five and one year renewal options. Fair value is calculated as the present value of estimated future cash flows using a risk-adjusted discount rate. The Company’s intangible assets are comprised of customer contracts acquired in our April 2014 acquisition of certain gas gathering assets in eastern Washington and Greene Counties, Pennsylvania (the “Momentum Acquisition”). The Company calculates amortization of intangible assets using the straight-line method over the estimated useful life of the intangible assets, or 30 years.
Deferred Financing Costs	Deferred Financing Costs Deferred financing costs are amortized on a straight-line basis, which approximates the interest method, over the term of the related agreement.
Asset Retirement Obligations	Asset Retirement Obligations The Company records the fair value of a legal liability for an asset retirement obligation in the period in which it is incurred. For oil and gas properties, this is the period in which an oil or gas well is acquired or drilled. The Company’s retirement obligations relate to the abandonment of oil and gas producing facilities and include costs to reclaim drilling sites and dismantle and relocate or dispose of gathering systems, wells and related structures. Estimates are based on historical experience in plugging and abandoning wells and estimated remaining lives of those wells based on reserve estimates. When a new liability is recorded, the Company capitalizes the costs of the liability by increasing the carrying amount of the related long-lived asset. The liability is accreted to its present value each period and the capitalized cost is depreciated over the units of production basis.
Income Taxes	Income Taxes The Company is a corporation under the Internal Revenue Code subject to federal income tax at a statutory rate of 35% of pretax earnings. The Company did not report any income tax benefit or expense for periods prior to the consummation of its IPO in January 2014 because Rice Drilling B, the Company’s accounting predecessor, is a limited liability company that was not and currently is not subject to federal income tax. The reorganization of the Company’s business in connection with the closing of its IPO, such that it is now held by a corporation subject to federal income tax, required the recognition of a deferred tax asset or liability for the initial temporary differences at the time of the IPO. The resulting deferred tax liability of approximately $162.3 million was recorded in equity at the date of the completion of the IPO as it represents a transaction among shareholders. Additionally, the Company has presented pro forma earnings per share (“EPS”) for the year ended December 31, 2014 assuming a statutory rate as disclosed in the accompanying consolidated statements of operations was applied for the full year ended December 31, 2014. The Company follows ASC 740-10-25, which requires the use of a two-step approach for recognizing and measuring tax benefits taken or expected to be taken in a tax return and disclosures regarding uncertainties in income tax positions. Only tax positions that meet the more likely than not recognition threshold are recognized. Based on management’s analysis, the Company did not have any uncertain tax positions as of December 31, 2015 . Income taxes are accounted for under the asset and liability method, which requires recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial statements and tax basis of assets and liabilities using enacted tax rates in effect for the year in which differences are expected to be recovered or settled pursuant to the provisions of ASC 740-Income Taxes. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date. The Company will record a valuation allowance if it is deemed more likely than not that all or a portion of its deferred income tax assets will not be realized. In addition, income tax rules and regulations are subject to interpretation and the application of those rules and regulations requires judgment by us and may be challenged by the taxation authorities. The effective tax rate for the year ended December 31, 2015 differs from the statutory rate due principally to non-deductible incentive unit expense, impairment losses and noncontrolling interest and, for the year ended December 31, 2014 , pre-tax income prior to our IPO.
Reclassifications	Reclassifications Certain reclassifications have been made to prior periods’ financial information related to the presentation of gathering, compression and water service revenues and midstream operation and maintenance expenses to conform to the 2015 presentation.
New Accounting Pronouncements	New Accounting Pronouncements In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”), No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” or ASU 2014-09. The FASB created Topic 606 which supersedes the revenue recognition requirements in Topic 605, “Revenue Recognition,” and most industry-specific guidance throughout the Industry Topics of the Codification. The FASB and International Accounting Standards Board initiated this joint project to clarify the principles for recognizing revenue and to develop a common revenue standard for both U.S. GAAP and International Financial Reporting Standards. ASU 2014-09 will enhance comparability of revenue recognition practices across entities, industries and capital markets compared to existing guidance. ASU 2014-09 explains that the core principle of the standard is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services and defines a five step process to achieve this core principle. The five step process is to (i) identify the contract with a customer; (ii) identify the performance obligations in the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and (v) recognize revenue when or as the entity satisfies a performance obligation. More judgement and estimates may be required within the new revenue recognition process than are required under existing U.S. GAAP. In August 2015, the FASB issued ASU 2015-14, “Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date.” The amendments in this update deferred the effective date for implementation of ASU 2014-09 by one year. ASU 2014-09 will now be effective for annual reporting periods beginning after December 15, 2017 and should be applied retrospectively using either a full retrospective approach reflecting the application of the standard in each prior reporting period or a retrospective approach with the cumulative effect of initially adopting the standard recognized at the date of adoption. Early application is permitted only for annual reporting periods beginning after December 15, 2016, including interim reporting periods within that period. The Company has not yet selected a transition method and is currently evaluating the standard and the impact on its consolidated financial statements and footnote disclosures. In February 2015, the FASB issued ASU, 2015-02, “Consolidation (Topic 810): Amendments to the Consolidation Analysis.” ASU 2015-02 affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. ASU 2015-02 is effective for periods beginning after December 15, 2015 with early adoption permitted. The Company will adopt ASU 2015-02 in the first quarter of 2016. The Company does not anticipate adoption of the standard to impact prior conclusions as to whether or not its subsidiaries are consolidated in the consolidated financial statements In April 2015, the FASB issued ASU, 2015-03, “Interest—Imputation of Interest (Subtopic 835-30): Simplification of Debt Issuance Costs.” ASU 2015-03 was issued to simplify the presentation of debt issuance costs by requiring debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability, consistent with debt discounts. ASU 2015-03 is effective for periods beginning after December 15, 2015 with early adoption permitted. In August 2015, the FASB issued ASU 2015-15, “Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements.” ASU 2015-15 clarifies the guidance in ASU 2015-03 regarding presentation and subsequent measurement of debt issuance costs related to line-of-credit arrangements. The SEC staff announced they would not object to an entity deferring and presenting debt issuance costs as an asset and subsequently amortizing the deferred debt issuance costs ratably over the term of the line-of-credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. The Company will adopt ASU 2015-03 in the first quarter of 2016. The adoption of ASU 2015-03 will be applied retrospectively and will result in debt issuance costs being presented as a direct deduction from the carrying amount of the related debt liability in the consolidated balance sheets. The Company will also adopt ASU 2015-15 and present debt issuance costs associated with the Company’s revolving credit facilities as assets named deferred financing costs, net in the consolidated balance sheets. In September 2015, the FASB issued ASU, 2015-16, “Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments.” ASU 2015-16 requires that an acquirer recognize adjustments to provisional amounts that are identified during the measurement period in the reporting period in which the adjustment amounts are determined. ASU 2015-16 is effective for periods beginning after December 15, 2015 with prospective application and early adoption permitted. The Company will adopt ASU 2015-16 in the first quarter of 2016 and will apply the provisions of the standard on an as-needed basis to the extent that a business combination occurs. In November 2015, the FASB issued ASU, 2015-17, “Income Taxes (Topic 740): Balance Sheet Classifications of Deferred Taxes,” to simplify the presentation of deferred income taxes and aligns the presentation of deferred income tax assets and liabilities with International Financial Reporting Standards (IFRS). Under the new standard, both deferred tax liabilities and assets are required to be classified as noncurrent in a classified balance sheet. ASU 2015-17 is effective for fiscal years, and the interim periods within those years, beginning after December 15, 2016. This update may be applied prospectively to all deferred tax liabilities and assets or retrospectively to all periods presented. The Company has prospectively adopted ASU 2015-017 in the fourth quarter of 2015.

Summary of Significant Accoun33

Summary of Significant Accounting Policies and Related Matters (Tables)	12 Months Ended
	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Accounts Receivable	Accounts receivable as of December 31, 2015 and 2014 are detailed below. December 31, (in thousands) 2015 2014 Joint interest $ 76,985 $ 125,300 Natural gas sales 71,512 72,206 Other 6,317 2,394 Total accounts receivable $ 154,814 $ 199,900
Schedule of Components of Interest Incurred	The following table summarizes the components of the Company’s interest incurred for the years ended December 31, 2015 , 2014 and 2013 : (in thousands) 2015 2014 2013 Interest incurred: Interest expensed $ 87,446 $ 50,191 $ 17,915 Interest capitalized 195 905 8,034 Total incurred $ 87,641 $ 51,096 $ 25,949
Schedule of Intangible Assets	Intangible assets as of December 31, 2015 and 2014 are detailed below. (in thousands) Intangible Assets Balance, December 31, 2013 $ — Additions 48,947 Accumulated amortization (1,156 ) Balance, December 31, 2014 47,791 Accumulated amortization (1,632 ) Balance, December 31, 2015 $ 46,159

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Property Plant and Equipment	The Company’s property, plant and equipment are as follows as of December 31, 2015 and 2014. December 31, (in thousands) 2015 2014 Oil and gas producing properties $ 2,870,691 $ 2,181,880 Impairment of gas properties (18,250 ) — Accumulated depreciation (498,467 ) (201,608 ) Oil and gas producing properties, net 2,353,974 1,980,272 Midstream property and equipment 889,776 467,956 Accumulated depreciation (25,662 ) (4,038 ) Midstream property and equipment, net 864,114 463,918 Other property and equipment 34,425 21,376 Accumulated depreciation (9,382 ) (4,235 ) Other property and equipment, net 25,043 17,141 Property, plant and equipment, net $ 3,243,131 $ 2,461,331

Goodwill (Tables)

Goodwill (Tables)	12 Months Ended
	Dec. 31, 2015
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Goodwill	Goodwill as of December 31, 2015 and 2014 is detailed below. (in thousands) Exploration and Production Midstream - Gathering Balance, December 31, 2013 $ — $ — Additions 294,908 39,142 Balance, December 31, 2014 294,908 39,142 Impairment (294,908 ) — Balance, December 31, 2015 $ — $ 39,142

Long Term Debt (Tables)

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments	Long-term debt consists of the following as of December 31, 2015 and 2014 : December 31, (in thousands) 2015 2014 Long-term Debt Senior Notes Due 2022 (a) $ 900,000 $ 900,000 Senior Notes Due 2023 (b) 397,222 — Senior Secured Revolving Credit Facility (c) — — Midstream Holdings Revolving Credit Facility (d) 17,000 — RMP Revolving Credit Facility (e) 143,000 — Other — 680 Total debt $ 1,457,222 $ 900,680 Less current portion — 680 Long-term debt $ 1,457,222 $ 900,000 6.25% Senior Notes Due 2022 (a) On April 25, 2014 , the Company issued $900.0 million in aggregate principal amount of 6.25% senior notes due 2022 (the “2022 Notes”) in a private placement to eligible purchasers under Rule 144A and Regulation S of the Securities Act of 1933, as amended (the “Securities Act”), which resulted in net proceeds of $882.7 million , after deducting expenses and the initial purchasers’ discounts of approximately $17.3 million . The Company used $301.8 million of the net proceeds to repay and retire the Second Lien Term Loan Facility (defined below) and used the remainder to fund a portion of the Company’s 2014 capital expenditure program. The 2022 Notes will mature on May 1, 2022 , and interest is payable on the 2022 Notes on each May 1 and November 1 . At any time prior to May 1, 2017 , the Company may redeem up to 35% of the 2022 Notes at a redemption price of 106.25% of the principal amount, plus accrued and unpaid interest to the redemption date, with the proceeds of certain equity offerings so long as the redemption occurs within 180 days of completing such equity offering and at least 65% of the aggregate principal amount of the 2022 Notes remains outstanding after such redemption. Prior to May 1, 2017 , the Company may redeem some or all of the notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. Upon the occurrence of a Change of Control (as defined in the indenture governing the 2022 Notes), unless the Company has given notice to redeem the 2022 Notes, the holders of the 2022 Notes will have the right to require the Company to repurchase all or a portion of the 2022 Notes at a price equal to 101% of the aggregate principal amount of the 2022 Notes, plus any accrued and unpaid interest to the date of purchase. On or after May 1, 2017 , the Company may redeem some or all of the 2022 Notes at redemption prices (expressed as percentages of principal amount) equal to 104.688% for the twelve-month period beginning on May 1, 2017, 103.125% for the twelve-month period beginning May 1, 2018, 101.563% for the twelve-month period beginning on May 1, 2019 and 100.000% beginning on May 1, 2020, plus accrued and unpaid interest to the redemption date. 7.25% Senior Notes Due 2023 (b) On March 26, 2015 , the Company issued $400.0 million in aggregate principal amount of 7.25% senior notes due 2023 (the “ 2023 Notes”) in a private placement to eligible purchasers under Rule 144A and Regulation S of the Securities Act, which resulted in net proceeds of $389.3 million , after deducting expenses and the initial purchasers’ discounts of approximately $10.7 million . The Company used the net proceeds for general corporate purposes, including capital expenditures. The original issuance discount of $3.1 million related to the 2023 Notes is recorded as a reduction of the principal amount. For the year ended December 31, 2015 , the Company recorded $0.3 million of amortization of the debt discount as interest expense using the effective interest method and a rate of 7.345% . The 2023 Notes will mature on May 1, 2023 , and interest is payable on the 2023 Notes on each May 1 and November 1 , commencing on November 1, 2015 . At any time prior to May 1, 2018 , the Company may redeem up to 35% of the 2023 Notes at a redemption price of 107.250% of the principal amount, plus accrued and unpaid interest to the redemption date, with the proceeds of certain equity offerings so long as the redemption occurs within 180 days of completing such equity offering and at least 65% of the aggregate principal amount of the 2023 Notes remains outstanding after such redemption. Prior to May 1, 2018 , the Company may redeem some or all of the notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. Upon the occurrence of a Change of Control (as defined in the indenture governing the 2023 Notes), unless the Company has given notice to redeem the 2023 Notes, the holders of the 2023 Notes will have the right to require the Company to repurchase all or a portion of the 2023 Notes at a price equal to 101% of the aggregate principal amount of the 2023 Notes, plus any accrued and unpaid interest to the date of purchase. On or after May 1, 2018 , the Company may redeem some or all of the 2023 Notes at redemption prices (expressed as percentages of principal amount) equal to 105.438% for the twelve-month period beginning on May 1, 2017, 103.625% for the twelve-month period beginning May 1, 2019, 101.813% for the twelve-month period beginning on May 1, 2020 and 100.000% beginning on May 1, 2021, plus accrued and unpaid interest to the redemption date. In connection with the issuance and sale of the 2023 Notes, the Company and the Company’s restricted subsidiaries (the “Guarantors”) entered into a registration rights agreement with the initial purchasers, dated March 26, 2015 . Pursuant to the registration rights agreement, the Company completed an exchange of the 2023 Notes for registered notes that have substantially identical terms at the 2023 Notes. The 2022 Notes and the 2023 Notes (collectively, the “Notes”) are the Company’s senior unsecured obligations, rank equally in right of payment with all of the Company’s existing and future senior debt, and will rank senior in right of payment to all of the Company’s future subordinated debt. The Notes will be effectively subordinated to all of the Company’s existing and future secured debt to the extent of the value of the collateral securing such indebtedness. The Notes are jointly and severally, fully and unconditionally, guaranteed by the Guarantors. The indentures governing the Notes provide that the guarantees of the Notes will be released under certain circumstances, including: • in connection with any sale or other disposition of all or substantially all of the assets of that Guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary (as defined in the indentures governing the Notes) of the Company; • in connection with any sale or other disposition of the capital stock of that Guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary of the Company, such that, immediately after giving effect to such transaction, such Guarantor would no longer constitute a subsidiary of the Company; • if the Company designates any Restricted Subsidiary that is a Guarantor to be an unrestricted subsidiary in accordance with the indentures governing the Notes; • upon legal defeasance or satisfaction and discharge of the indentures governing the Notes; or • if such Guarantor ceases to guarantee any other indebtedness of the Company or a Guarantor under a credit facility, provided no Event of Default (as defined in the indentures governing the Notes) has occurred and is continuing. The indentures governing the Notes restrict the Company’s ability and the ability of its restricted subsidiaries to: (i) incur or guarantee additional debt or issue certain types of preferred stock; (ii) pay dividends on capital stock or redeem, repurchase or retire the Company’s capital stock or subordinated debt; (iii) make certain investments; (iv) incur liens; (v) enter into transactions with affiliates; (vi) merge or consolidate with another company; (vii) transfer and sell assets; and (viii) create unrestricted subsidiaries. These covenants are subject to a number of important exceptions and qualifications. If at any time when the Notes are rated investment grade by both Moody’s Investors Service, Inc. and Standard & Poor’s Ratings Services and no default (as defined in the indentures governing the Notes) has occurred and is continuing, many of such covenants will terminate and the Company and its restricted subsidiaries will cease to be subject to such covenants. The indentures governing the Notes contain customary events of default, including: • default in any payment of interest on any Note when due, continued for 30 days; • default in the payment of principal of or premium, if any, on any Note when due; • failure by the Company to comply with its other obligations under the indentures governing the Notes, in certain cases subject to notice and grace periods; • payment defaults and accelerations with respect to other indebtedness of the Company and its Restricted Subsidiaries (as defined in the indentures governing the Notes) in the aggregate principal amount of $25.0 million or more; • certain events of bankruptcy, insolvency or reorganization of the Company or a Significant Subsidiary (as defined in the indentures governing the Notes) or group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary; • failure by the Company or Restricted Subsidiary to pay certain final judgments aggregating in excess of $25.0 million within 60 days; and • any guarantee of the Notes by a Guarantor ceases to be in full force and effect, is declared null and void in a judicial proceeding or is denied or disaffirmed by its maker. Senior Secured Revolving Credit Facility (c) In April 2013, the Company entered into a Senior Secured Revolving Credit Facility (the “Senior Secured Revolving Credit Facility”) with Wells Fargo Bank, N.A. (“Wells Fargo”), as administrative agent, and a syndicate of lenders. In April 2014, the Company, as borrower, and Rice Drilling B, as predecessor borrower, amended and restated the credit agreement governing the Senior Secured Revolving Credit Facility (the “Amended Credit Agreement”) to, among other things, assign all of the rights and obligations of Rice Drilling B as borrower under the Senior Secured Revolving Credit Facility to the Company. On January 13, 2016, the Company entered into a Seventh Amendment (the “Seventh Amendment”) to the Amended Credit Agreement, which increased the aggregate notional volume limitations for our hedging arrangements contained in the Amended Credit Agreement for the first eighteen months after any commodity swap agreement or secured firm transportation reimbursement agreement is entered into. As of December 31, 2015 , the borrowing base was $750.0 million and the sublimit for letters of credit was $250.0 million . The Company had zero borrowings outstanding and $99.3 million in letters of credit outstanding under the Amended Credit Agreement as of December 31, 2015 , resulting in availability of $650.7 million . The next redetermination of the borrowing base is scheduled for April 2016. The maturity date of the Senior Secured Revolving Credit Facility is January 29, 2019. Eurodollar loans under the Senior Secured Revolving Credit Facility bear interest at a rate per annum equal to LIBOR plus an applicable margin ranging from 150 to 250 basis points, depending on the percentage of borrowing base utilized. Base rate loans bear interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 50 to 150 basis points, depending on the percentage of borrowing base utilized. The Amended Credit Agreement is secured by liens on at least 80% of the proved oil and gas reserves of the Company and its subsidiaries (other than any subsidiary that is designated as an unrestricted subsidiary, including Midstream Holdings and its subsidiaries), as well as significant unproved acreage and substantially all of the personal property of the Company and such restricted subsidiaries, and the Company’s obligations under the Amended Credit Agreement are guaranteed by such restricted subsidiaries. The Amended Credit Agreement contains restrictive covenants that limit the ability of the Company and its restricted subsidiaries to, among other things: • incur additional indebtedness; • sell assets; • make loans to others; • make investments; • enter into mergers; • make or declare dividends; • hedge future production or interest rates; • incur liens; and • engage in certain other transactions without the prior consent of the lenders. The Amended Credit Agreement also requires the Company to maintain certain financial ratios, which are measured at the end of each calendar quarter: • a current ratio, which is the ratio of consolidated current assets (including unused commitments under the Amended Credit Agreement and excluding non-cash derivative assets) to consolidated current liabilities (excluding current maturities under the Amended Credit Agreement and non-cash derivative liabilities), of not less than 1.0 to 1.0 ; and • a minimum interest coverage ratio, which is the ratio of consolidated EBITDAX (as such term is defined in the Amended Credit Agreement) based on the trailing 12 month period to consolidated interest expense, of not less than 2.5 to 1.0 . The Company was in compliance with such covenants and ratios effective as of December 31, 2015 . Midstream Holdings Revolving Credit Facility (d) On December 22, 2014 , Midstream Holdings entered into a revolving credit facility (the “Midstream Holdings Revolving Credit Facility”) with Wells Fargo, as administrative agent, and a syndicate of lenders with a maximum credit amount of $300.0 million and a sublimit for letters of credit of $25.0 million . As of December 31, 2015 , Midstream Holdings had $17.0 million of borrowings outstanding and no letters of credit under this facility. The average daily outstanding balance of the credit facility was approximately $62.0 million and interest was incurred on the facility at a weighted average annual interest rate of 2.5% during 2015 . The credit facility is available to fund working capital requirements and capital expenditures and to purchase assets and matures on December 22, 2019 . Rice Olympus Midstream LLC, Rice West Virginia Midstream LLC and Strike Force Midstream Holdings LLC (“Strike Force Holdings”) are the guarantors of the obligations under the credit facility. Principal amounts borrowed are payable on the maturity date, and interest is payable quarterly for base rate loans and at the end of the applicable interest period for Eurodollar loans. Under the Midstream Holdings Revolving Credit Facility, Midstream Holdings may elect to borrow in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to the applicable LIBOR Rate plus an applicable margin ranging from 225 to 300 basis points, depending on the leverage ratio then in effect. Base rate loans bear interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 125 to 200 basis points, depending on the leverage ratio then in effect. Midstream Holdings also pays a commitment fee based on the undrawn commitment amount ranging from 37.5 to 50 basis points. The Midstream Holdings Revolving Credit Facility is secured by mortgages and other security interests on substantially all of the properties of, and guarantees from, Midstream Holdings and its restricted subsidiaries (which do not include the Partnership, Rice Midstream Management LLC, a Delaware limited liability company and general partner of the Partnership, or the Company and its subsidiaries other than Midstream Holdings). The Midstream Holdings Revolving Credit Facility limits the ability of Midstream Holdings and its restricted subsidiaries to, among other things: • incur or guarantee additional debt; • redeem or repurchase units or make distributions under certain circumstances; • make certain investments and acquisitions; • incur certain liens or permit them to exist; • enter into certain types of transactions with affiliates; • merge or consolidate with another company; and • transfer, sell or otherwise dispose of assets. The Midstream Holdings Revolving Credit Facility also requires Midstream Holdings to maintain the following financial ratios: • an interest coverage ratio, which is the ratio of Rice Midstream Holding’s consolidated EBITDA (as defined within the Midstream Holdings Revolving Credit Facility) to its consolidated current interest expense of at least 2.50 to 1.0 at the end of each fiscal quarter; and • a consolidated total leverage ratio, which is the ratio of consolidated debt to consolidated EBITDA, of not more than 4.25 to 1.0. Midstream Holdings was in compliance with such covenants and ratios effective as of December 31, 2015 . RMP Revolving Credit Facility (e) On December 22, 2014 , Rice Midstream OpCo LLC, a wholly-owned subsidiary of the Partnership (“Rice Midstream OpCo”), entered into a revolving credit facility (the “RMP Revolving Credit Facility”) with Wells Fargo, as administrative agent, and a syndicate of lenders with a maximum credit amount of $450.0 million with an additional $200.0 million of commitments available under an accordion feature, subject to lender approval. The RMP Revolving Credit Facility provides for a letter of credit sublimit of $50.0 million . As of December 31, 2015 , Rice Midstream OpCo had $143.0 million borrowings outstanding and no letters of credit under this facility. The average daily outstanding balance of the credit facility was approximately $46.9 million and interest was incurred on the facility at a weighted average annual interest rate of 2.0% during 2015 . The RMP Revolving Credit Facility is available to fund working capital requirements and capital expenditures, to purchase assets, to pay distributions and repurchase units and for general partnership purposes and matures on December 22, 2019 . The Partnership is the guarantor of the obligations under the credit facility. Principal amounts borrowed are payable on the maturity date, and interest is payable quarterly for base rate loans and at the end of the applicable interest period for Eurodollar loans. Under the RMP Revolving Credit Facility, the Partnership may elect to borrow in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to the applicable LIBOR Rate plus an applicable margin ranging from 175 to 275 basis points, depending on the leverage ratio then in effect. Base rate loans bears interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 75 to 175 basis points, depending on the leverage ratio then in effect. The Partnership also pays a commitment fee based on the undrawn commitment amount ranging from 35 to 50 basis points. The RMP Revolving Credit Facility is secured by mortgages and other security interests on substantially all of the properties of, and guarantees from, the Partnership and its restricted subsidiaries. The RMP Revolving Credit Facility limits the ability of the Partnership and its restricted subsidiaries to, among other things: • incur or guarantee additional debt; • redeem or repurchase units or make distributions under certain circumstances; • make certain investments and acquisitions; • incur certain liens or permit them to exist; • enter into certain types of transactions with affiliates; • merge or consolidate with another company; and • transfer, sell or otherwise dispose of assets. The RMP Revolving Credit Facility also requires the Partnership to maintain the following financial ratios: • an interest coverage ratio, which is the ratio of the Partnership’s consolidated EBITDA (as defined within the RMP Revolving Credit Facility) to its consolidated current interest expense of at least 2.50 to 1.0 at the end of each fiscal quarter; • a consolidated total leverage ratio, which is the ratio of consolidated debt to consolidated EBITDA, of not more than 4.75 to 1.0, and after electing to issue senior unsecured notes, a consolidated total leverage ratio of not more than 5.25 to 1.0, and, in each case, with certain increases in the permitted total leverage ratio following the completion of a material acquisition; and • if the Partnership elects to issue senior unsecured notes, a consolidated senior secured leverage ratio, which is the ratio of consolidated senior secured debt to consolidated EBITDA, of not more than 3.50 to 1.0. The Partnership was in compliance with such covenants and ratios effective as of December 31, 2015 .
Schedule of Maturities of Long-term Debt	Expected aggregate maturities of the notes payable as of December 31, 2015 are as follows (in thousands) : Remainder of Year Ending December 31, 2015 $ — Year Ending December 31, 2016 — Year Ending December 31, 2017 — Year Ending December 31, 2018 — Year Ending December 31, 2019 and Beyond 1,457,222 Total $ 1,457,222

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Offsetting Assets	The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the consolidated balance sheets for the periods presented, all at fair value: As of December 31, 2015 (in thousands) Derivative instruments, recorded in the Consolidated Balance Sheet, gross Derivative instruments subject to master netting arrangements Derivative Instruments, net Derivative assets $ 372,414 $ (79,509 ) $ 292,905 Derivative liabilities $ 21,043 $ (4,200 ) $ 16,843 As of December 31, 2014 (in thousands) Derivative instruments, recorded in the Consolidated Balance Sheet, gross Derivative instruments subject to master netting arrangements Derivative Instruments, net Derivative assets $ 201,775 $ (5,553 ) $ 196,222
Offsetting Liabilities	The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the consolidated balance sheets for the periods presented, all at fair value: As of December 31, 2015 (in thousands) Derivative instruments, recorded in the Consolidated Balance Sheet, gross Derivative instruments subject to master netting arrangements Derivative Instruments, net Derivative assets $ 372,414 $ (79,509 ) $ 292,905 Derivative liabilities $ 21,043 $ (4,200 ) $ 16,843 As of December 31, 2014 (in thousands) Derivative instruments, recorded in the Consolidated Balance Sheet, gross Derivative instruments subject to master netting arrangements Derivative Instruments, net Derivative assets $ 201,775 $ (5,553 ) $ 196,222

Fair Value of Financial Instr38

Fair Value of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The following assets and liabilities were measured at fair value on a recurring basis during the period (refer to Note 5 for details relating to derivative instruments): As of December 31, 2015 (in thousands) Fair Value Measurements at Reporting Date Using (in thousands) Carrying Value Total Fair Value Quoted Prices in Significant Other Significant Assets: Derivative instruments, at fair value $ 292,905 $ 292,905 $ — $ 292,905 $ — Total assets $ 292,905 $ 292,905 $ — $ 292,905 $ — Liabilities: Derivative instruments, at fair value $ 16,843 $ 16,843 $ — $ 16,843 $ — Total liabilities $ 16,843 $ 16,843 $ — $ 16,843 $ — As of December 31, 2014 Fair Value Measurements at Reporting Date Using (in thousands) Carrying Value Total Fair Value Quoted Prices in Significant Other Significant Assets: Derivative instruments, at fair value $ 196,222 $ 196,222 $ — $ 196,222 $ — Total assets $ 196,222 $ 196,222 $ — $ 196,222 $ —
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation	Fair Value Measurements Using Significant Unobservable Inputs (Level 3) (in thousands) 2015 2014 Balance as of January 1 $ — $ 36,306 Converted to shares of common stock — (36,306 ) Balance as of December 31 $ — $ —
Fair Value, by Balance Sheet Grouping	The estimated fair value and carrying amount of long-term debt as reported on the consolidated balance sheets as of December 31, 2015 and 2014 is shown in the table below (refer to Note 4 for details relating to the debt instruments). The fair value was estimated using Level 2 inputs based on rates reflective of the remaining maturity as well as the Company’s financial position. The carrying value of the revolving credit facilities approximates fair value as of December 31, 2015 . As of December 31, 2015 As of December 31, 2014 Long-Term Debt (in thousands) Carrying Value Fair Value Carrying Value Fair Value Senior Notes Due 2022 $ 900,000 $ 650,250 $ 900,000 $ 839,250 Senior Notes Due 2023 397,222 294,000 — — Midstream Holdings Revolving Credit Facility 17,000 17,000 — — RMP Revolving Credit Facility 143,000 143,000 — — Other — — 680 680 Total $ 1,457,222 $ 1,104,250 $ 900,680 $ 839,930

Financial Information by Busi39

Financial Information by Business Segment (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Reconciliation of Revenue from Segments to Consolidated	The operating results and assets of the Company’s reportable segments were as follows as of and for the year ended December 31, 2015 : (in thousands) Exploration and Production Midstream Elimination of Intersegment Transactions Consolidated Total Operating revenues: Natural gas, oil and NGL sales $ 446,515 $ — $ — $ 446,515 Firm transportation sales, net 3,450 — — 3,450 Gathering, compression and water services — 141,823 (92,644 ) 49,179 Other revenue 2,997 — — 2,997 Total operating revenues $ 452,962 $ 141,823 $ (92,644 ) $ 502,141 Operating expenses: Lease operating 44,356 — — 44,356 Gathering, compression and transportation 150,015 — (65,308 ) 84,707 Production taxes and fees 7,609 — — 7,609 Exploration 3,137 — — 3,137 Midstream operation and maintenance — 16,988 — 16,988 Incentive unit expense 33,873 2,224 — 36,097 Impairment of gas properties 18,250 — — 18,250 Impairment of goodwill 294,908 — — 294,908 Acquisition costs 108 1,127 — 1,235 General and administrative expenses 78,592 24,446 — 103,038 Depreciation, depletion and amortization 308,194 19,185 (4,595 ) 322,784 Amortization of intangible assets — 1,632 — 1,632 Gain from sale of interest in gas properties (953 ) — — (953 ) Other expense 6,028 492 — 6,520 Total operating expenses $ 944,117 $ 66,094 $ (69,903 ) $ 940,308 Operating (loss) income $ (491,155 ) $ 75,729 $ (22,741 ) $ (438,167 ) Segment assets $ 3,004,226 $ 989,938 $ (23,633 ) $ 3,970,531 Goodwill $ — $ 39,142 $ — $ 39,142 Capital expenditures for segment assets $ 869,134 $ 404,476 $ (27,336 ) $ 1,246,274 The operating results and assets of the Company’s reportable segments were as follows as of and for the year ended December 31, 2014 : (in thousands) Exploration and Production Midstream Elimination of Intersegment Transactions Consolidated Total Operating revenues: Natural gas, oil and NGL sales $ 359,201 $ — $ — $ 359,201 Firm transportation sales, net 26,237 — — 26,237 Gathering, compression and water services — 7,300 (1,796 ) 5,504 Total operating revenues $ 385,438 $ 7,300 $ (1,796 ) $ 390,942 Operating expenses: Lease operating 24,971 — — 24,971 Gathering, compression and transportation 37,414 — (1,796 ) 35,618 Production taxes and fees 4,647 — — 4,647 Exploration 4,018 — — 4,018 Midstream operation and maintenance — 4,607 — 4,607 Incentive unit expense 86,020 19,941 — 105,961 Acquisition costs 820 1,519 — 2,339 General and administrative expenses 46,229 15,341 — 61,570 Depreciation, depletion and amortization 151,900 4,370 — 156,270 Amortization of intangible assets — 1,156 — 1,156 Other expense — 207 — 207 Total operating expenses $ 356,019 $ 47,141 $ (1,796 ) $ 401,364 Operating income (loss) $ 29,419 $ (39,841 ) $ — $ (10,422 ) Segment assets $ 2,935,814 $ 592,135 $ — $ 3,527,949 Goodwill $ 294,908 $ 39,142 $ — $ 334,050 Capital expenditures for segment assets $ 693,129 $ 277,145 $ — $ 970,274 The operating results and assets of the Company’s reportable segments were as follows as of and for the year ended December 31, 2013 : (in thousands) Exploration and Production Midstream Consolidated Total Operating revenues: Natural gas, oil and NGL sales $ 87,847 $ — $ 87,847 Gathering, compression and water services — 83 83 Other revenue 259 498 757 Total operating revenues $ 88,106 $ 581 $ 88,687 Operating expenses: Lease operating 8,309 — 8,309 Gathering, compression and transportation 8,362 — 8,362 Production taxes and fees 1,629 — 1,629 Exploration 9,951 — 9,951 Midstream operation and maintenance — 1,412 1,412 Restricted unit expense 32,906 — 32,906 General and administrative expenses 13,778 3,175 16,953 Depreciation, depletion and amortization 31,467 1,348 32,815 Loss from sale of interest in gas properties 4,230 — 4,230 Total operating expenses $ 110,632 $ 5,935 $ 116,567 Operating loss $ (22,526 ) $ (5,354 ) $ (27,880 ) Segment assets $ 804,992 $ 74,818 $ 879,810 Capital expenditures for segment assets $ 406,179 $ 59,208 $ 465,387

Lease Obligations (Tables)

Lease Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Schedule of Future Minimum Rental Payments for Capital Leases	The following represents the future minimum lease payments under the agreements as of December 31, 2015 : (in thousands) 2016 $ 17,288 2017 5,286 2018 566 2019 438 2020 and thereafter — Total future minimum lease payments $ 23,578

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	A reconciliation of the beginning and ending aggregate carrying amount of asset retirement obligations for the years ended December 31, 2015 and 2014 is as follows: (in thousands) Balance at December 31, 2013 $ 2,114 Liabilities incurred 7,171 Liabilities settled (256 ) Accretion expense 513 Balance at December 31, 2014 $ 9,542 Liabilities incurred 5,198 Revisions in estimated cash flows (3,085 ) Liabilities settled (1,131 ) Accretion expense 890 Balance at December 31, 2015 $ 11,414

Incentive Units (Tables)

Incentive Units (Tables)	12 Months Ended
	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule of Share-based Payment Award, Incentive Units, Valuation Assumptions	The fair value of the incentive units was estimated using a Monte Carlo simulation valuation model with the following assumptions: Rice Holdings Valuation Date 1/29/2014 Dividend Yield 0.00 % Expected Volatility 47.00 % Risk-Free Rate 1.11 % Expected Life (Years) 4.0 Rice Holdings Valuation Date 4/14/2014 Dividend Yield 0.00 % Expected Volatility 45.19 % Risk-Free Rate 1.13 % Expected Life (Years) 3.8 Rice Holdings Valuation Date 4/16/2014 Dividend Yield 0.00 % Expected Volatility 44.32 % Risk-Free Rate 1.18 % Expected Life (Years) 3.8 NGP Holdings Valuation Date 12/31/2015 Dividend Yield 0.00 % Expected Volatility 54.57 % Risk-Free Rate 0.96 % Expected Life (Years) 1.75
Incentive Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule of Deferred Compensation Arrangement with Individual, Share-based Payments	Three tranches of the incentive units have a time vesting feature. A rollforward of those units from our IPO to December 31, 2015 is included below. Vested Units Balance, January 29, 2014 133,333 Vested During Period 1,667,578 Forfeited During Period (37,140 ) Granted During Period 37,140 Canceled During Period — Vested Units Balance, December 31, 2014 1,800,911 Vested During Period 1,027,288 Forfeited During Period — Granted During Period — Canceled During Period — Vested Units Balance, December 31, 2015 2,828,199

Stock Compensation (Tables)

Stock Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Restricted stock unit award activity and unvested awards	The following table summarizes the restricted stock unit award activity during the year ended December 31, 2015 and 2014 . Number of shares Weighted average grant date fair value Total unvested, January 1, 2014 — $ — Granted 328,907 28.79 Vested (1,647 ) 30.33 Forfeited (4,601 ) 32.59 Total unvested, December 31, 2014 322,659 28.38 Granted 535,175 19.25 Vested (121,138 ) 27.98 Forfeited (34,027 ) 24.13 Total unvested - December 31, 2015 702,669 $ 21.70 The following table details the scheduled vesting of the outstanding unvested restricted stock unit awards at December 31, 2015 . Vesting Date Number of shares 2016 254,406 2017 266,452 2018 181,811 702,669
Schedule of Share-based Payment Award, Performance Stock Awards, Valuation Assumptions	The following table presents information regarding the assumptions used in determining the fair value of the performance stock unit awards granted in 2015 and 2014. 2015 2014 Dividend Yield 0.00 % 0.00 % Expected Volatility 49.69 % 43.73 % Risk-Free Rate 1.00 % 0.70 % Expected Life (Years) 2.89 2.65 Weighted average fair value of performance stock unit awards $ 21.61 $ 38.77
Schedule of Share-based Compensation, Phantom Share Units (PSUs) Activity	The following table summarizes the activity for the equity-based awards during the year ended December 31, 2015 and 2014 . Number of units Weighted average grant date fair value Total unvested, January 1, 2014 — $ — Granted 434,094 16.50 Vested — — Forfeited — — Total unvested, December 31, 2014 434,094 16.50 Granted 18,196 16.87 Vested (242 ) 16.50 Forfeited (19,420 ) 16.50 Total unvested - December 31, 2015 432,628 $ 16.52
Nonvested Phantom Share Units Activity	The following table details the scheduled vesting of the unvested equity-based awards at December 31, 2015 . Vesting Date Number of units 2016 432,628 432,628

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The following is a calculation of the basic and diluted weighted-average number of shares of common stock outstanding and EPS for the years ended December 31, 2015 , 2014 and 2013 . As indicated in Note 1, our corporate reorganization was considered a transaction amongst entities under common control. Therefore, the weighted average shares used in our EPS calculation assume that the Rice Energy Inc. corporate structure was in place for all periods presented. Year Ended December 31, 2015 2014 2013 Income (loss) (numerator): Net (loss) income attributable to Rice Energy (in thousands) $ (291,336 ) $ 218,454 $ (35,776 ) Weighted-average shares (denominator): Weighted-average number of shares of common stock - basic 136,344,076 128,151,171 80,441,905 Weighted-average number of shares of common stock - diluted 136,344,076 128,225,155 80,441,905 (Loss) earnings per share: Basic $ (2.14 ) $ 1.70 $ (0.44 ) Diluted $ (2.14 ) $ 1.70 $ (0.44 )

Income Taxes Income Taxes (Tabl

Income Taxes Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	The components of the income tax provision are as follows: Year Ended December 31, (in thousands) 2015 2014 Current tax expense: Federal $ 4,039 $ 3,961 State — — Total 4,039 3,961 Deferred tax expense: Federal 19,878 68,846 State (11,799 ) 18,793 Total 8,079 87,639 Total income tax expense $ 12,118 $ 91,600
Schedule of Effective Income Tax Rate Reconciliation	Income tax expense differs from amounts computed at the federal statutory rate of 35% on pre-tax income as follows: Year Ended December 31, (in thousands) 2015 2014 Tax at statutory rate $ (89,560 ) $ 108,722 Permanent tax differences 74 18 State income taxes (7,668 ) 12,216 Partnership earnings (1/1/14 - 1/28/14) — (66,239 ) Noncontrolling partners’ share of RMP earnings (8,168 ) (203 ) Goodwill impairment 103,218 — Incentive unit expense 12,634 37,086 Other, net 1,588 — Income tax expense $ 12,118 $ 91,600 Effective tax rate (4.74 )% 29.49 %
Schedule of Deferred Tax Assets and Liabilities	The following table summarizes the source and tax effects of temporary differences that give rise to the deferred tax assets and deferred tax liabilities at December 31, 2015 and December 31, 2014 . Year Ended December 31, (in thousands) 2015 2014 Deferred income taxes: Total deferred tax assets $ — $ — Total deferred tax liabilities (271,988 ) (263,906 ) Total net deferred tax liabilities (271,988 ) (263,906 ) Principal components of deferred tax assets and liabilities: Drilling and development costs expensed for tax (294,972 ) (189,475 ) Tax depreciation in excess of book depreciation (92,710 ) (24,252 ) Investment in partnerships 57,227 38,077 Incentive compensation 5,576 2,263 Net operating loss carryforwards 153,558 — Hedging loss (109,352 ) (80,663 ) AMT tax credit 7,999 3,961 Other 686 (13,817 ) Total $ (271,988 ) $ (263,906 )

Guarantor Financial Informati46

Guarantor Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Balance Sheet	Balance Sheet as of December 31, 2015 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Assets Current assets: Cash $ 78,474 $ 57,800 $ 15,627 $ — $ 151,901 Accounts receivable 147 140,493 14,174 — 154,814 Receivable from affiliate 27,670 — 4,501 (32,171 ) — Prepaid expenses, deposits and other 4,377 817 294 — 5,488 Derivative instruments 47,262 139,698 — — 186,960 Deferred tax assets — — — — — Total current assets 157,930 338,808 34,596 (32,171 ) 499,163 Gas collateral account — 3,995 82 — 4,077 Investments in subsidiaries 2,378,293 113,268 — (2,491,561 ) — Property, plant and equipment, net 21,442 2,382,878 865,043 (26,232 ) 3,243,131 Deferred financing costs, net 25,329 — 4,915 — 30,244 Goodwill — — 39,142 — 39,142 Intangible assets, net — — 46,159 — 46,159 Other non-current assets 32,590 76,025 — — 108,615 Total assets $ 2,615,584 $ 2,914,974 $ 989,937 $ (2,549,964 ) $ 3,970,531 Liabilities and stockholders’ equity Current liabilities: Accounts payable $ 4,178 $ 48,191 $ 31,184 $ — $ 83,553 Royalties payables — 40,572 — — 40,572 Accrued capital expenditures — 45,240 34,507 — 79,747 Leasehold payables — 17,338 — — 17,338 Other accrued liabilities 36,287 71,649 3,367 (32,171 ) 79,132 Total current liabilities 40,465 222,990 69,058 (32,171 ) 300,342 Long-term liabilities: Long-term debt 1,297,222 — 160,000 — 1,457,222 Leasehold payable — 6,289 — — 6,289 Deferred tax liabilities 47,667 299,741 19,911 (95,331 ) 271,988 Other long-term liabilities 19,432 7,661 3,129 — 30,222 Total liabilities 1,404,786 536,681 252,098 (127,502 ) 2,066,063 Stockholders’ equity before noncontrolling interest 1,210,798 2,378,293 113,268 (2,422,462 ) 1,279,897 Noncontrolling interests in consolidated subsidiaries — — 624,571 — 624,571 Total liabilities and stockholders’ equity $ 2,615,584 $ 2,914,974 $ 989,937 $ (2,549,964 ) $ 3,970,531 Balance Sheet as of December 31, 2014 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Assets Current assets: Cash $ 181,835 $ 41,934 $ 32,361 $ — $ 256,130 Accounts receivable 1,773 196,974 1,153 — 199,900 Receivable from affiliates 634 55 2,198 (2,799 ) 88 Prepaid expenses deposits and other 1,296 1,702 341 — 3,339 Derivative instruments 47,291 85,743 — — 133,034 Total current assets 232,829 326,408 36,053 (2,799 ) 592,491 Gas collateral account — 3,995 — — 3,995 Investments in subsidiaries 2,177,895 86,148 — (2,264,043 ) — Property, plant and equipment, net 10,348 1,986,856 464,127 — 2,461,331 Deferred financing costs, net 20,081 — 5,022 — 25,103 Goodwill — 294,908 39,142 — 334,050 Intangible assets, net — — 47,791 — 47,791 Derivative instruments 8,290 54,898 — — 63,188 Total assets $ 2,449,443 $ 2,753,213 $ 592,135 $ (2,266,842 ) $ 3,527,949 Liabilities and stockholders’ equity Current liabilities: Current portion of long-term debt $ — $ 680 $ — $ — $ 680 Accounts payable 19,231 101,132 31,966 — 152,329 Royalties payables — 37,172 — — 37,172 Accrued capital expenditures 1,515 89,858 16,917 — 108,290 Leasehold payables — 30,702 — — 30,702 Deferred tax liabilities 54,688 39,197 — (39,197 ) 54,688 Other accrued liabilities 26,027 27,502 2,086 (2,801 ) 52,814 Total current liabilities 101,461 326,243 50,969 (41,998 ) 436,675 Long-term liabilities: Long-term debt 900,000 — — — 900,000 Leasehold payable — 4,279 — — 4,279 Deferred tax liabilities 12,497 237,155 10,660 (51,094 ) 209,218 Other long-term liabilities 3,068 7,641 1,900 — 12,609 Total liabilities 1,017,026 575,318 63,529 (93,092 ) 1,562,781 Stockholders’ equity before noncontrolling interest 1,432,417 2,177,895 86,148 (2,173,750 ) 1,522,710 Noncontrolling interest in consolidated subsidiaries — — 442,458 — 442,458 Total liabilities and stockholders’ equity $ 2,449,443 $ 2,753,213 $ 592,135 $ (2,266,842 ) $ 3,527,949
Condensed Statement of Operations	Statement of Operations for the Year Ended December 31, 2015 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Operating revenues: Natural gas, oil and natural gas liquids (NGL) sales $ — $ 446,515 $ — $ — $ 446,515 Firm transportation sales, net — 3,450 — — 3,450 Gathering, compression and water services — — 141,823 (92,644 ) 49,179 Other revenue — 2,997 — — 2,997 Total operating revenues — 452,962 141,823 (92,644 ) 502,141 Operating expenses: Lease operating — 44,356 — — 44,356 Gathering, compression and transportation — 150,015 — (65,308 ) 84,707 Production taxes and impact fees — 7,609 — — 7,609 Exploration — 3,137 — — 3,137 Midstream operation and maintenance — — 16,988 — 16,988 Incentive unit expense — 33,873 2,224 — 36,097 Impairment of gas properties — 18,250 — — 18,250 Impairment of goodwill — 294,908 — — 294,908 General and administrative — 78,592 24,446 — 103,038 Depreciation, depletion and amortization — 304,703 19,185 (1,104 ) 322,784 Acquisition expense 4 103 1,128 — 1,235 Amortization of intangible assets — — 1,632 — 1,632 Gain from sale of interest in gas properties — (953 ) — — (953 ) Other expense — 6,028 492 — 6,520 Total operating expenses 4 940,621 66,095 (66,412 ) 940,308 Operating income (loss) (4 ) (487,659 ) 75,728 (26,232 ) (438,167 ) Interest expense (82,664 ) (166 ) (4,616 ) — (87,446 ) Other income 617 439 52 — 1,108 Gain on derivative instruments 68,247 205,501 — — 273,748 Amortization of deferred financing costs (4,072 ) — (1,052 ) — (5,124 ) Equity in income (loss) of joint ventures and subsidiaries (296,335 ) 10,145 — 286,190 — Income (loss) before income taxes (314,211 ) (271,740 ) 70,112 259,958 (255,881 ) Income tax expense (12,118 ) (25,699 ) (9,295 ) 34,994 (12,118 ) Net income (loss) (326,329 ) (297,439 ) 60,817 294,952 (267,999 ) Less: net income attributable to noncontrolling interests — — (23,337 ) — (23,337 ) Net income (loss) attributable to Rice Energy $ (326,329 ) $ (297,439 ) $ 37,480 $ 294,952 $ (291,336 ) Statement of Operations for the Year Ended December 31, 2014 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Operating revenues: Natural gas, oil and natural gas liquids (NGL) sales $ — $ 359,201 $ — $ — $ 359,201 Firm transportation sales, net — 26,237 — — 26,237 Gathering, compression and water services — — 7,300 (1,796 ) 5,504 Total operating revenues — 385,438 7,300 (1,796 ) 390,942 Operating expenses: Lease operating — 24,971 — — 24,971 Gathering, compression and transportation — 37,180 — (1,562 ) 35,618 Production taxes and impact fees — 4,647 — — 4,647 Exploration — 4,018 — — 4,018 Midstream operation and maintenance — — 4,607 — 4,607 Incentive unit expense — 86,020 19,941 — 105,961 General and administrative — 45,268 16,302 — 61,570 Depreciation, depletion and amortization — 153,282 2,988 — 156,270 Acquisition expense — 820 1,519 — 2,339 Amortization of intangible assets — — 1,156 — 1,156 Other expenses — — 207 — 207 Total operating expenses — 356,206 46,720 (1,562 ) 401,364 Operating income (loss) — 29,232 (39,420 ) (234 ) (10,422 ) Interest expense (27,177 ) (10,130 ) (12,884 ) — (50,191 ) Gain on purchase of Marcellus joint venture — 203,579 — — 203,579 Other income (loss) 247 755 (109 ) — 893 Gain on derivative instruments 55,580 130,897 — — 186,477 Amortization of deferred financing costs (2,006 ) (489 ) — — (2,495 ) Loss on extinguishment of debt — (7,654 ) — — (7,654 ) Write-off of deferred financing costs — (6,896 ) — — (6,896 ) Equity in income (loss) of joint ventures and subsidiaries 193,119 (47,208 ) — (148,567 ) (2,656 ) Income (loss) before income taxes 219,763 292,086 (52,413 ) (148,801 ) 310,635 Income tax expense (91,600 ) (98,731 ) 8,440 90,291 (91,600 ) Net income (loss) 128,163 193,355 (43,973 ) (58,510 ) 219,035 Less: net income attributable to noncontrolling interests — — (581 ) — (581 ) Net income (loss) attributable to Rice Energy $ 128,163 $ 193,355 $ (44,554 ) $ (58,510 ) $ 218,454 Statement of Operations for the Year Ended December 31, 2013 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Operating revenues: Natural gas sales $ — $ 87,847 $ — $ — $ 87,847 Gathering, compression and water services — — 83 — 83 Other revenue — 763 (6 ) — 757 Total operating revenues — 88,610 77 — 88,687 Operating expenses: Lease operating — 8,309 — — 8,309 Gathering, compression and transportation — 8,362 — — 8,362 Production taxes and impact fees — 1,629 — — 1,629 Exploration — 9,951 — — 9,951 Midstream operation and maintenance — — 1,412 — 1,412 Restricted unit expense — 32,906 — — 32,906 General and administrative — 16,636 317 — 16,953 Depreciation, depletion and amortization — 32,421 394 — 32,815 (Gain) loss from sale of interest in gas properties — 4,230 — — 4,230 Total operating expenses — 114,444 2,123 — 116,567 Operating (loss) — (25,834 ) (2,046 ) — (27,880 ) Interest expense — (17,915 ) — — (17,915 ) Other (loss) — (357 ) (83 ) — (440 ) Gain on derivative instruments — 6,891 — — 6,891 Amortization of deferred financing costs — (5,230 ) — — (5,230 ) Loss on extinguishment of debt — (10,622 ) — — (10,622 ) Equity in income of joint ventures and subsidiaries — 17,848 — 1,572 19,420 Net income (loss) $ — $ (35,219 ) $ (2,129 ) $ 1,572 $ (35,776 ) Condensed Statement of Cash Flows for the Year Ended December 31, 2015 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ (59,213 ) $ 413,989 $ 85,547 $ (27,336 ) $ 412,987 Capital expenditures for property and equipment (9,775 ) (859,359 ) (404,476 ) 27,336 (1,246,274 ) Investment in subsidiaries (421,063 ) 11,614 — 409,449 — Acquisition of Greene County assets — 19,054 — — 19,054 Proceeds from sale of interest in gas properties — 10,201 — — 10,201 Net cash used in investing activities (430,838 ) (818,490 ) (404,476 ) 436,785 (1,217,019 ) Proceeds from borrowings 411,932 — 502,000 — 913,932 Repayments of debt obligations (15,922 ) (697 ) (342,000 ) — (358,619 ) Distributions to the Partnership’s public unitholders — — (17,017 ) — (17,017 ) Debt issuance costs (9,320 ) — (946 ) — (10,266 ) Proceeds from issuance of common stock sold in our IPO, net of offering costs — — (129 ) — (129 ) Proceeds from issuance of common units sold by RMP, net of offering costs — — 171,902 — 171,902 Contributions from parent, net — 421,064 (11,615 ) (409,449 ) — Net cash provided by financing activities 386,690 420,367 302,195 (409,449 ) 699,803 Increase (decrease) in cash (103,361 ) 15,866 (16,734 ) — (104,229 ) Cash, beginning of year 181,835 41,934 32,361 — 256,130 Cash, end of year $ 78,474 $ 57,800 $ 15,627 $ — $ 151,901
Condensed Statement of Cash Flows	Condensed Statement of Cash Flows for the Year Ended December 31, 2015 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ (59,213 ) $ 413,989 $ 85,547 $ (27,336 ) $ 412,987 Capital expenditures for property and equipment (9,775 ) (859,359 ) (404,476 ) 27,336 (1,246,274 ) Investment in subsidiaries (421,063 ) 11,614 — 409,449 — Acquisition of Greene County assets — 19,054 — — 19,054 Proceeds from sale of interest in gas properties — 10,201 — — 10,201 Net cash used in investing activities (430,838 ) (818,490 ) (404,476 ) 436,785 (1,217,019 ) Proceeds from borrowings 411,932 — 502,000 — 913,932 Repayments of debt obligations (15,922 ) (697 ) (342,000 ) — (358,619 ) Distributions to the Partnership’s public unitholders — — (17,017 ) — (17,017 ) Debt issuance costs (9,320 ) — (946 ) — (10,266 ) Proceeds from issuance of common stock sold in our IPO, net of offering costs — — (129 ) — (129 ) Proceeds from issuance of common units sold by RMP, net of offering costs — — 171,902 — 171,902 Contributions from parent, net — 421,064 (11,615 ) (409,449 ) — Net cash provided by financing activities 386,690 420,367 302,195 (409,449 ) 699,803 Increase (decrease) in cash (103,361 ) 15,866 (16,734 ) — (104,229 ) Cash, beginning of year 181,835 41,934 32,361 — 256,130 Cash, end of year $ 78,474 $ 57,800 $ 15,627 $ — $ 151,901 Condensed Statement of Cash Flows for the Year Ended December 31, 2014 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ 16,139 $ 96,147 $ (27,211 ) $ — $ 85,075 Capital expenditures for property and equipment (8,588 ) (684,541 ) (277,145 ) — (970,274 ) Acquisition of Marcellus joint venture, net of cash acquired — (27,766 ) (55,000 ) — (82,766 ) Acquisition of Momentum assets — (400 ) (111,447 ) — (111,847 ) Acquisition of Greene County assets — (329,469 ) — — (329,469 ) Proceeds from sale of interest in gas properties — 12,891 — — 12,891 Net cash used in investing activities (8,588 ) (1,029,285 ) (443,592 ) — (1,481,465 ) Proceeds from borrowings 900,000 190,000 — — 1,090,000 Repayments of debt obligations — (689,873 ) — — (689,873 ) Restricted cash for convertible debt — 8,268 — — 8,268 Debt issuance costs (19,522 ) — (5,021 ) — (24,543 ) Proceeds from conversion of warrants 1,975 — — — 1,975 Proceeds from issuance of common stock sold in our IPO, net of offering costs 597,088 — — — 597,088 Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of offering costs 196,254 — — — 196,254 Proceeds from issuance of common units sold in RMP IPO, net of offering costs — — 441,739 — 441,739 Contributions from parent, net (1,501,511 ) 1,435,269 66,242 — — Net cash provided by financing activities 174,284 943,664 502,960 — 1,620,908 Increase (decrease) in cash 181,835 10,526 32,157 — 224,518 Cash, beginning of year — 31,408 204 — 31,612 Cash, end of year $ 181,835 $ 41,934 $ 32,361 $ — $ 256,130 Condensed Statement of Cash Flows for the Year Ended December 31, 2013 (in thousands) Parent Guarantors Non-Guarantors Eliminations Consolidated Net cash provided by (used in) operating activities $ — $ 34,428 $ (756 ) $ — $ 33,672 Capital expenditures for property and equipment — (406,179 ) (59,208 ) — (465,387 ) Proceeds from sale of interest in gas properties — 6,792 — — 6,792 Net cash used in investing activities — (399,387 ) (59,208 ) — (458,595 ) Proceeds from borrowings — 435,500 — — 435,500 Repayments of debt obligations — (160,760 ) — — (160,760 ) Restricted cash for convertible debt — (8,268 ) — — (8,268 ) Debt issuance costs — (12,194 ) — — (12,194 ) Common stock issuance — 135,815 60,162 — 195,977 Repurchase of common stock — (2,267 ) — — (2,267 ) Net cash provided by financing activities — 387,826 60,162 — 447,988 Increase (decrease) in cash — 22,867 198 — 23,065 Cash, beginning of year — 8,541 6 — 8,547 Cash, end of year $ — $ 31,408 $ 204 $ — $ 31,612

Quarterly Financial Informati47

Quarterly Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information	The Company’s quarterly financial information for the years ended December 31, 2015 and 2014 is as follows (in thousands): Year ended December 31, 2015: (1) First quarter Second quarter Third quarter Fourth quarter Total operating revenues $ 109,539 $ 112,894 $ 143,621 $ 136,088 Total operating expenses 140,619 159,065 160,295 480,329 Operating loss (31,080 ) (46,171 ) (16,674 ) (344,241 ) Net income (loss) $ 4,687 $ (63,519 ) $ 65,084 $ (274,251 ) Net income (loss) attributable to Rice Energy $ 152 $ (69,683 ) $ 58,950 $ (280,755 ) Earnings (loss) per share attributable to Rice Energy - basic $ — $ (0.51 ) $ 0.43 $ (2.06 ) Earnings (loss) per share attributable to Rice Energy - diluted $ — $ (0.51 ) $ 0.43 $ (2.06 ) Year ended December 31, 2014: (1) First quarter Second quarter Third quarter Fourth quarter Total operating revenues $ 90,477 $ 91,940 $ 79,128 $ 129,398 Total operating expenses 124,272 67,522 91,453 118,118 Operating income (loss) (33,795 ) 24,418 (12,325 ) 11,280 Net income (loss) $ 129,454 $ (7,917 ) $ (6,861 ) $ 104,360 Net income (loss) attributable to Rice Energy $ 129,454 $ (7,917 ) $ (6,861 ) $ 103,779 Earnings (loss) per share attributable to Rice Energy - basic $ 1.04 $ (0.06 ) $ (0.05 ) $ 0.76 Earnings (loss) per share attributable to Rice Energy - diluted $ 1.03 $ (0.06 ) $ (0.05 ) $ 0.76 (1) The sum of quarterly data in some cases may not equal the yearly total due to rounding.

Supplemental Information on G48

Supplemental Information on Gas Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Reserve Quantities [Line Items]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure	Capitalized costs relating to gas-producing activities are as follows: As of December 31, (in thousands) 2015 2014 Proved properties $ 1,811,279 $ 1,195,274 Unproved properties 1,071,523 1,003,449 2,882,802 2,198,723 Accumulated depreciation and depletion (501,958 ) (215,905 ) Net capitalized costs $ 2,380,844 $ 1,982,818
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure	Costs incurred for property acquisitions, exploration and development are as follows: For the Years Ended December 31, (in thousands) 2015 2014 2013 Acquisitions: Proved leaseholds $ — $ 439,284 $ — Unproved leaseholds 100,172 233,185 305,000 Development costs 616,836 734,106 184,217 Exploration costs: Geological and geophysical 1,276 4,018 9,951
Results of Operations for Oil and Gas Producing Activities Disclosure	Results of operations related to natural gas production are as follows: For the Years Ended December 31, (in thousands) 2015 2014 2013 Revenues $ 452,962 $ 385,438 $ 88,106 Production costs 201,980 67,032 18,300 Exploration costs 3,137 4,018 9,951 Depreciation, depletion and amortization 308,194 151,900 31,467 Incentive unit expense 33,873 86,020 — Restricted unit expense — — 32,906 Impairment of gas properties 18,250 — — Impairment of goodwill 294,908 — — Acquisition costs 108 820 — (Gain) loss from sale of interest in gas properties (953 ) — 4,230 Other expense 6,028 — — General and administrative expenses 78,592 46,229 13,778 Income tax expense 6,039 38,871 — Results of operations from producing activities $ (497,194 ) $ (9,452 ) $ (22,526 )
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities	Reserve quantity information is as follows: For the Years Ended December 31, (in MMcfe) 2015 2014 2013 (1) Proved developed and undeveloped reserves: Beginning of year 1,306,571 382,660 304,272 Acquisitions — 282,391 — Extensions and discoveries 869,038 692,239 100,626 Revision of previous estimates (274,249 ) 47,018 757 Production (201,328 ) (97,737 ) (22,995 ) End of year 1,700,032 1,306,571 382,660 Proved developed reserves: End of year 1,014,873 644,149 144,309 Proved undeveloped reserves: End of year 685,159 662,422 238,351 (1) Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014.
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure	Information with respect to the Company’s estimated discounted future net cash flows related to its proved natural gas and oil reserves is as follows: As of December 31, (in thousands) 2015 2014 2013 (1) Future cash inflows $ 4,497,738 $ 5,904,380 $ 1,496,294 Future production costs (2,378,541 ) (2,161,926 ) (517,101 ) Future development costs (545,988 ) (610,179 ) (219,879 ) Future income tax expense — (745,022 ) — Future net cash flows 1,573,209 2,387,253 759,314 10% annual discount for estimated timing of cash flows (686,936 ) (1,079,499 ) (342,150 ) Standardized measure of discounted future net cash flows (2) $ 886,273 $ 1,307,754 $ 417,164 (1) Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014. (2) Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income. Therefore, the cumulative effect of future income tax expense for the periods presented was included at December 31, 2015 and 2014.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows	The following are the principal sources of changes in the standardized measure of discounted future net cash flows: For the Years Ended December 31, (in thousands) 2015 2014 2013 (1) Balance at beginning of period $ 1,307,754 $ 417,164 $ 102,218 Net change in prices and production costs (949,774 ) 81,558 101,345 Net change in future development costs 4,251 (181,813 ) 29,336 Natural gas and oil net revenues (312,269 ) (291,023 ) (68,135 ) Extensions 370,636 930,534 114,489 Acquisitions — 375,865 (2) — Revisions of previous quantity estimates (274,503 ) 37,435 1,133 Previously estimated development costs incurred 122,532 62,653 66,894 Net change in taxes 436,319 (436,319 ) — Accretion of discount 174,407 70,937 10,230 Changes in timing and other 6,920 240,763 59,654 Balance at end of period $ 886,273 $ 1,307,754 $ 417,164 (1) Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014. (2) Reflects the purchase of the remaining 50% interest in the Marcellus joint venture in January 2014 and the Greene County acreage acquisition in August 2014. (3) Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income. Therefore, the cumulative effect of future income tax expense for the periods presented was included at December 31, 2015 and 2014.
Marcellus Joint Venture
Reserve Quantities [Line Items]
Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure	Costs incurred for property acquisitions, exploration and development related to the Company’s Marcellus joint venture are as follows (represents Rice Drilling B’s proportionate share): (in thousands) For the Year Ended December 31, 2013 Acquisitions: Unproved leaseholds $ — Development costs 46,571 Exploration costs: Geological and geophysical — Total costs incurred $ 46,571
Results of Operations for Oil and Gas Producing Activities Disclosure	The following table presents the Company’s share of the results of operations related to natural gas production of the Marcellus joint venture (represents Rice Drilling B’s proportionate share): (in thousands) For the Year Ended December 31, 2013 Revenues $ 45,339 Production costs 12,557 Impairment of oil and gas properties — Depreciation, depletion and accretion 12,500 General and administrative expenses 1,557 Results of operations from producing activities $ 18,725
Schedule of Proved Developed and Undeveloped Oil and Gas Reserve Quantities	Reserve quantity information is as follows for the Marcellus joint venture (represents Rice Drilling B’s proportionate share): Natural Gas (MMcf) (in thousands) For the Year Ended December 31, 2013 Proved developed and undeveloped reserves: Beginning of year 128,118 Extensions and discoveries 19,812 Revision of previous estimates (26,803 ) Production (11,443 ) End of year 109,684 Proved developed reserves: End of year 52,370 Proved undeveloped reserves: End of year 57,314
Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves Disclosure	Information with respect to the Company’s share of the Marcellus joint venture’s estimated discounted future net cash flows related to its proved natural gas reserves is as follows: (in thousands) As of December 31, 2013 Future cash inflows $ 427,167 Future production costs (132,427 ) Future development costs (46,344 ) Future net cash flows 248,396 10% annual discount for estimated timing of cash flows (102,293 ) Standardized measure of discounted future net cash flows (1) $ 146,103 (1) Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income.
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows	The following is for the Marcellus joint venture (represents Rice Drilling B’s proportionate share), the principal sources of changes in the standardized measure of discounted future net cash flows: (in thousands) For the Year Ended December 31, 2013 Balance at beginning of period $ 71,077 Net change in prices and production costs 81,974 Net change in future development costs 2,781 Natural gas net revenues (32,782 ) Extensions 18,950 Revisions of previous quantity estimates (14,752 ) Previously estimated development costs incurred 31,253 Accretion of discount 7,111 Changes in timing and other (19,509 ) Balance at end of period $ 146,103

Summary of Significant Accoun49

Summary of Significant Accounting Policies and Related Matters (Narrative) (Details) $ / shares in Units, $ in Thousands	Dec. 22, 2014USD ($)$ / sharesshares	Jan. 29, 2014USD ($)$ / sharesshares	Nov. 30, 2015subsidiary	Dec. 31, 2015USD ($)segmentbusiness_segment$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares	Dec. 31, 2013USD ($)
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO | shares		50,000,000
Par Value | $ / shares				$ 0.01	$ 0.01
Shares of common stock issued in initial public offering, net of offering costs		$ 992,600
Proceeds from issuance of common stock sold in our IPO, net of offering costs				$ (129)	$ 597,088	$ 0
Shares of common stock outstanding | shares				136,387,194	136,280,766
Number of reporting segments | business_segment				2
Impairment expense on oil and gas properties				$ 18,250	$ 0	0
(Gain) loss from sale of interest in gas properties				953	0	(4,230)
Unproved properties				1,050,000	1,015,400
Amortization of intangibles				1,632	1,156	0
Accumulated amortization for deferred financing costs				8,600	3,500
Amortization of deferred financing costs				$ 5,124	$ 2,495	$ 5,230
Federal income tax statutory rate				35.00%
Number of segments | segment				2
Unproved Oil and Gas Properties
Subsidiary, Sale of Stock [Line Items]
Impairment expense on oil and gas properties				$ 7,300
Proved Oil and Gas Properties | Significant Unobservable Inputs (Level 3) | Income Approach Valuation Technique
Subsidiary, Sale of Stock [Line Items]
Assumed discount rate percentage				13.50%
Proved Oil and Gas Properties | Upper Devonian Proved Properties | Significant Unobservable Inputs (Level 3) | Income Approach Valuation Technique
Subsidiary, Sale of Stock [Line Items]
Impairment expense on oil and gas properties				$ 10,900
Write down on proved properties				$ 7,300
Gathering pipelines and compressor stations
Subsidiary, Sale of Stock [Line Items]
Estimated useful life				60 years
Water pipelines, pumping stations, and impoundment facilities | Minimum
Subsidiary, Sale of Stock [Line Items]
Estimated useful life				10 years
Water pipelines, pumping stations, and impoundment facilities | Maximum
Subsidiary, Sale of Stock [Line Items]
Estimated useful life				15 years
Marcellus Joint Venture
Subsidiary, Sale of Stock [Line Items]
Cash paid for acquisitions		$ 100,000
Interest in Marcellus joint venture acquired		50.00%			50.00%	50.00%
Number of shares issued in initial public offering | shares		9,523,810
Marcellus Joint Venture | Customer Lists
Subsidiary, Sale of Stock [Line Items]
Amortization of intangibles				$ 1,632	$ 1,156
Momentum Acquisition | Customer Lists
Subsidiary, Sale of Stock [Line Items]
Period of initial contract terms				10 years
Amortization period for customer contracts				30 years
Amortization of intangibles				$ 1,600
2,016				1,600
2,017				1,600
2,018				1,600
2,019				1,600
2,020				$ 1,600
Momentum Acquisition | Minimum | Customer Lists
Subsidiary, Sale of Stock [Line Items]
Period of renewal options				1 year
Momentum Acquisition | Maximum | Customer Lists
Subsidiary, Sale of Stock [Line Items]
Period of renewal options				5 years
IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO | shares		30,000,000
Par Value | $ / shares		$ 0.01
Public offering price per share | $ / shares		$ 21
Proceeds from issuance of common stock sold in our IPO, net of offering costs		$ 593,600
Underwriting discounts and commissions		$ 36,400
Shares of common stock outstanding | shares		127,523,810
Tax impact of our IPO and corporate reorganization					$ (162,320)
IPO | Deferred Tax Liability Recorded In Equity
Subsidiary, Sale of Stock [Line Items]
Tax impact of our IPO and corporate reorganization		$ 162,300
Over-Allotment Option
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO | shares		6,000,000
Mr. Daniel J. Rice III | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares issued in initial public offering | shares		2,356,844
Rice Partners | PA and OH Water Disposition
Subsidiary, Sale of Stock [Line Items]
Number of subsidiaries acquired by RMP | subsidiary			2
Rice Partners | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares issued in initial public offering | shares		20,000,000
Incentive Unitholders | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares issued in initial public offering | shares		160,831
Rice Drilling B | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares issued in initial public offering | shares		1,728,852
Selling Stockholder | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO | shares		14,000,000
Shares of common stock issued in initial public offering, net of offering costs		$ 399,000
Underwriting discounts and commissions		$ 21,000
NGP Holdings | NGP Holdings | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares issued in initial public offering | shares		43,452,550
Rice Holdings | Rice Holdings | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares issued in initial public offering | shares		20,300,923
Rice Midstream Partners LP
Subsidiary, Sale of Stock [Line Items]
Ownership interest percentage in Rice Midstream Partners LP	50.00%			41.00%
Rice Midstream Holdings LLC ownership percentage in Rice Midstream Partners LP	50.00%			59.00%
Rice Midstream Partners LP | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO | shares	28,750,000
Public offering price per share | $ / shares	$ 16.50
Proceeds from issuance of common stock sold in our IPO, net of offering costs	$ 441,700
Rice Midstream Partners LP | Over-Allotment Option
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO | shares	3,750,000

Summary of Significant Accoun50

Summary of Significant Accounting Policies and Related Matters (Schedule of Accounts Receivable) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Product Information [Line Items]
Accounts receivable	$ 154,814	$ 199,900
Joint interest
Product Information [Line Items]
Accounts receivable	76,985	125,300
Natural gas sales
Product Information [Line Items]
Accounts receivable	71,512	72,206
Other
Product Information [Line Items]
Accounts receivable	$ 6,317	$ 2,394

Summary of Significant Accoun51

Summary of Significant Accounting Policies and Related Matters (Schedule of Interest Incurred) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Interest incurred:
Interest expensed	$ 87,446	$ 50,191	$ 17,915
Interest capitalized	195	905	8,034
Total incurred	$ 87,641	$ 51,096	$ 25,949

Summary of Significant Accoun52

Summary of Significant Accounting Policies and Related Matters (Schedule of Goodwill and Intangible Assets) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Finite-lived Intangible Assets [Roll Forward]
Accumulated amortization	$ (1,632)	$ (1,156)	$ 0
Marcellus Joint Venture | Customer Lists
Finite-lived Intangible Assets [Roll Forward]
Beginning balance	47,791	0
Additions		48,947
Accumulated amortization	(1,632)	(1,156)
Ending balance	$ 46,159	$ 47,791	$ 0

Property, Plant and Equipment53

Property, Plant and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Property, plant and equipment, net	$ 3,243,131	$ 2,461,331
Oil and gas producing properties
Property, Plant and Equipment [Line Items]
Oil and gas producing properties and Midstream property and equipment	2,870,691	2,181,880
Impairment of gas properties	(18,250)	0
Accumulated depreciation	(498,467)	(201,608)
Oil and gas producing properties and Midstream property and equipment, net	2,353,974	1,980,272
Midstream property and equipment
Property, Plant and Equipment [Line Items]
Oil and gas producing properties and Midstream property and equipment	889,776	467,956
Accumulated depreciation	(25,662)	(4,038)
Oil and gas producing properties and Midstream property and equipment, net	864,114	463,918
Other property and equipment
Property, Plant and Equipment [Line Items]
Property and equipment	34,425	21,376
Accumulated depreciation	(9,382)	(4,235)
Property, plant and equipment, net	$ 25,043	$ 17,141

Goodwill (Narrative) (Details)

Goodwill (Narrative) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)reporting_unit	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Jan. 29, 2014USD ($)
Business Combination Segment Allocation [Line Items]
Number of reporting units | reporting_unit	3
Goodwill	$ 39,142	$ 334,050
Impairment	(294,908)	0	$ 0
Exploration and Production
Business Combination Segment Allocation [Line Items]
Goodwill	0	294,908	0
Impairment	(294,908)
Midstream
Business Combination Segment Allocation [Line Items]
Goodwill	39,142	$ 39,142	$ 0
Impairment	$ 0
Marcellus Joint Venture
Business Combination Segment Allocation [Line Items]
Interest in Marcellus joint venture acquired		50.00%	50.00%	50.00%
Marcellus Joint Venture | Exploration and Production
Business Combination Segment Allocation [Line Items]
Goodwill				$ 294,900
Marcellus Joint Venture | Midstream
Business Combination Segment Allocation [Line Items]
Goodwill				$ 39,100

Goodwill (Schedule of Goodwill

Goodwill (Schedule of Goodwill Assets) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Goodwill [Roll Forward]
Beginning balance	$ 334,050
Impairment	(294,908)	$ 0	$ 0
Ending balance	39,142	334,050
Exploration and Production
Goodwill [Roll Forward]
Beginning balance	294,908	0
Additions		294,908
Impairment	(294,908)
Ending balance	0	294,908	0
Midstream
Goodwill [Roll Forward]
Beginning balance	39,142	0
Additions		39,142
Impairment	0
Ending balance	$ 39,142	$ 39,142	$ 0

Long Term Debt (Schedule of Lon

Long Term Debt (Schedule of Long-term Debt) (Details) - USD ($) $ in Thousands		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Total debt		$ 1,457,222	$ 900,680
Current portion of long-term debt		0	680
Long-term debt		1,457,222	900,000
Senior Notes | Senior Notes Due 2022
Debt Instrument [Line Items]
Total debt	[1]	900,000	900,000
Senior Notes | Senior Notes Due 2023
Debt Instrument [Line Items]
Total debt	[2]	397,222	0
Other
Debt Instrument [Line Items]
Total debt		0	680
Revolving Credit Facility | Senior Secured Revolving Credit Facility
Debt Instrument [Line Items]
Total debt	[3]	0	0
Revolving Credit Facility | Midstream Holdings Revolving Credit Facility
Debt Instrument [Line Items]
Total debt	[4]	17,000	0
Revolving Credit Facility | RMP Revolving Credit Facility
Debt Instrument [Line Items]
Total debt	[5]	$ 143,000	$ 0
[1]	6.25% Senior Notes Due 2022 (a)On April 25, 2014, the Company issued $900.0 million in aggregate principal amount of 6.25% senior notes due 2022 (the “2022 Notes”) in a private placement to eligible purchasers under Rule 144A and Regulation S of the Securities Act of 1933, as amended (the “Securities Act”), which resulted in net proceeds of $882.7 million, after deducting expenses and the initial purchasers’ discounts of approximately $17.3 million. The Company used $301.8 million of the net proceeds to repay and retire the Second Lien Term Loan Facility (defined below) and used the remainder to fund a portion of the Company’s 2014 capital expenditure program. The 2022 Notes will mature on May 1, 2022, and interest is payable on the 2022 Notes on each May 1 and November 1. At any time prior to May 1, 2017, the Company may redeem up to 35% of the 2022 Notes at a redemption price of 106.25% of the principal amount, plus accrued and unpaid interest to the redemption date, with the proceeds of certain equity offerings so long as the redemption occurs within 180 days of completing such equity offering and at least 65% of the aggregate principal amount of the 2022 Notes remains outstanding after such redemption. Prior to May 1, 2017, the Company may redeem some or all of the notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. Upon the occurrence of a Change of Control (as defined in the indenture governing the 2022 Notes), unless the Company has given notice to redeem the 2022 Notes, the holders of the 2022 Notes will have the right to require the Company to repurchase all or a portion of the 2022 Notes at a price equal to 101% of the aggregate principal amount of the 2022 Notes, plus any accrued and unpaid interest to the date of purchase. On or after May 1, 2017, the Company may redeem some or all of the 2022 Notes at redemption prices (expressed as percentages of principal amount) equal to 104.688% for the twelve-month period beginning on May 1, 2017, 103.125% for the twelve-month period beginning May 1, 2018, 101.563% for the twelve-month period beginning on May 1, 2019 and 100.000% beginning on May 1, 2020, plus accrued and unpaid interest to the redemption date.
[2]	7.25% Senior Notes Due 2023 (b)On March 26, 2015, the Company issued $400.0 million in aggregate principal amount of 7.25% senior notes due 2023 (the “2023 Notes”) in a private placement to eligible purchasers under Rule 144A and Regulation S of the Securities Act, which resulted in net proceeds of $389.3 million, after deducting expenses and the initial purchasers’ discounts of approximately $10.7 million. The Company used the net proceeds for general corporate purposes, including capital expenditures. The original issuance discount of $3.1 million related to the 2023 Notes is recorded as a reduction of the principal amount. For the year ended December 31, 2015, the Company recorded $0.3 million of amortization of the debt discount as interest expense using the effective interest method and a rate of 7.345%. The 2023 Notes will mature on May 1, 2023, and interest is payable on the 2023 Notes on each May 1 and November 1, commencing on November 1, 2015. At any time prior to May 1, 2018, the Company may redeem up to 35% of the 2023 Notes at a redemption price of 107.250% of the principal amount, plus accrued and unpaid interest to the redemption date, with the proceeds of certain equity offerings so long as the redemption occurs within 180 days of completing such equity offering and at least 65% of the aggregate principal amount of the 2023 Notes remains outstanding after such redemption. Prior to May 1, 2018, the Company may redeem some or all of the notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest to the redemption date. Upon the occurrence of a Change of Control (as defined in the indenture governing the 2023 Notes), unless the Company has given notice to redeem the 2023 Notes, the holders of the 2023 Notes will have the right to require the Company to repurchase all or a portion of the 2023 Notes at a price equal to 101% of the aggregate principal amount of the 2023 Notes, plus any accrued and unpaid interest to the date of purchase. On or after May 1, 2018, the Company may redeem some or all of the 2023 Notes at redemption prices (expressed as percentages of principal amount) equal to 105.438% for the twelve-month period beginning on May 1, 2017, 103.625% for the twelve-month period beginning May 1, 2019, 101.813% for the twelve-month period beginning on May 1, 2020 and 100.000% beginning on May 1, 2021, plus accrued and unpaid interest to the redemption date.In connection with the issuance and sale of the 2023 Notes, the Company and the Company’s restricted subsidiaries (the “Guarantors”) entered into a registration rights agreement with the initial purchasers, dated March 26, 2015. Pursuant to the registration rights agreement, the Company completed an exchange of the 2023 Notes for registered notes that have substantially identical terms at the 2023 Notes.The 2022 Notes and the 2023 Notes (collectively, the “Notes”) are the Company’s senior unsecured obligations, rank equally in right of payment with all of the Company’s existing and future senior debt, and will rank senior in right of payment to all of the Company’s future subordinated debt. The Notes will be effectively subordinated to all of the Company’s existing and future secured debt to the extent of the value of the collateral securing such indebtedness.The Notes are jointly and severally, fully and unconditionally, guaranteed by the Guarantors. The indentures governing the Notes provide that the guarantees of the Notes will be released under certain circumstances, including: •in connection with any sale or other disposition of all or substantially all of the assets of that Guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary (as defined in the indentures governing the Notes) of the Company;•in connection with any sale or other disposition of the capital stock of that Guarantor (including by way of merger or consolidation) to a person that is not (either before or after giving effect to such transaction) the Company or a Restricted Subsidiary of the Company, such that, immediately after giving effect to such transaction, such Guarantor would no longer constitute a subsidiary of the Company;•if the Company designates any Restricted Subsidiary that is a Guarantor to be an unrestricted subsidiary in accordance with the indentures governing the Notes;•upon legal defeasance or satisfaction and discharge of the indentures governing the Notes; or•if such Guarantor ceases to guarantee any other indebtedness of the Company or a Guarantor under a credit facility, provided no Event of Default (as defined in the indentures governing the Notes) has occurred and is continuing.The indentures governing the Notes restrict the Company’s ability and the ability of its restricted subsidiaries to: (i) incur or guarantee additional debt or issue certain types of preferred stock; (ii) pay dividends on capital stock or redeem, repurchase or retire the Company’s capital stock or subordinated debt; (iii) make certain investments; (iv) incur liens; (v) enter into transactions with affiliates; (vi) merge or consolidate with another company; (vii) transfer and sell assets; and (viii) create unrestricted subsidiaries. These covenants are subject to a number of important exceptions and qualifications. If at any time when the Notes are rated investment grade by both Moody’s Investors Service, Inc. and Standard & Poor’s Ratings Services and no default (as defined in the indentures governing the Notes) has occurred and is continuing, many of such covenants will terminate and the Company and its restricted subsidiaries will cease to be subject to such covenants.The indentures governing the Notes contain customary events of default, including:•default in any payment of interest on any Note when due, continued for 30 days;•default in the payment of principal of or premium, if any, on any Note when due;•failure by the Company to comply with its other obligations under the indentures governing the Notes, in certain cases subject to notice and grace periods;•payment defaults and accelerations with respect to other indebtedness of the Company and its Restricted Subsidiaries (as defined in the indentures governing the Notes) in the aggregate principal amount of $25.0 million or more;•certain events of bankruptcy, insolvency or reorganization of the Company or a Significant Subsidiary (as defined in the indentures governing the Notes) or group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary;•failure by the Company or Restricted Subsidiary to pay certain final judgments aggregating in excess of $25.0 million within 60 days; and•any guarantee of the Notes by a Guarantor ceases to be in full force and effect, is declared null and void in a judicial proceeding or is denied or disaffirmed by its maker.
[3]	Senior Secured Revolving Credit Facility (c)In April 2013, the Company entered into a Senior Secured Revolving Credit Facility (the “Senior Secured Revolving Credit Facility”) with Wells Fargo Bank, N.A. (“Wells Fargo”), as administrative agent, and a syndicate of lenders. In April 2014, the Company, as borrower, and Rice Drilling B, as predecessor borrower, amended and restated the credit agreement governing the Senior Secured Revolving Credit Facility (the “Amended Credit Agreement”) to, among other things, assign all of the rights and obligations of Rice Drilling B as borrower under the Senior Secured Revolving Credit Facility to the Company. On January 13, 2016, the Company entered into a Seventh Amendment (the “Seventh Amendment”) to the Amended Credit Agreement, which increased the aggregate notional volume limitations for our hedging arrangements contained in the Amended Credit Agreement for the first eighteen months after any commodity swap agreement or secured firm transportation reimbursement agreement is entered into.As of December 31, 2015, the borrowing base was $750.0 million and the sublimit for letters of credit was $250.0 million. The Company had zero borrowings outstanding and $99.3 million in letters of credit outstanding under the Amended Credit Agreement as of December 31, 2015, resulting in availability of $650.7 million. The next redetermination of the borrowing base is scheduled for April 2016. The maturity date of the Senior Secured Revolving Credit Facility is January 29, 2019.Eurodollar loans under the Senior Secured Revolving Credit Facility bear interest at a rate per annum equal to LIBOR plus an applicable margin ranging from 150 to 250 basis points, depending on the percentage of borrowing base utilized. Base rate loans bear interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 50 to 150 basis points, depending on the percentage of borrowing base utilized. The Amended Credit Agreement is secured by liens on at least 80% of the proved oil and gas reserves of the Company and its subsidiaries (other than any subsidiary that is designated as an unrestricted subsidiary, including Midstream Holdings and its subsidiaries), as well as significant unproved acreage and substantially all of the personal property of the Company and such restricted subsidiaries, and the Company’s obligations under the Amended Credit Agreement are guaranteed by such restricted subsidiaries. The Amended Credit Agreement contains restrictive covenants that limit the ability of the Company and its restricted subsidiaries to, among other things:•incur additional indebtedness;•sell assets;•make loans to others;•make investments;•enter into mergers;•make or declare dividends;•hedge future production or interest rates;•incur liens; and•engage in certain other transactions without the prior consent of the lenders.The Amended Credit Agreement also requires the Company to maintain certain financial ratios, which are measured at the end of each calendar quarter:•a current ratio, which is the ratio of consolidated current assets (including unused commitments under the Amended Credit Agreement and excluding non-cash derivative assets) to consolidated current liabilities (excluding current maturities under the Amended Credit Agreement and non-cash derivative liabilities), of not less than 1.0 to 1.0; and •a minimum interest coverage ratio, which is the ratio of consolidated EBITDAX (as such term is defined in the Amended Credit Agreement) based on the trailing 12 month period to consolidated interest expense, of not less than 2.5 to 1.0. The Company was in compliance with such covenants and ratios effective as of December 31, 2015.
[4]	Midstream Holdings Revolving Credit Facility (d)On December 22, 2014, Midstream Holdings entered into a revolving credit facility (the “Midstream Holdings Revolving Credit Facility”) with Wells Fargo, as administrative agent, and a syndicate of lenders with a maximum credit amount of $300.0 million and a sublimit for letters of credit of $25.0 million. As of December 31, 2015, Midstream Holdings had $17.0 million of borrowings outstanding and no letters of credit under this facility. The average daily outstanding balance of the credit facility was approximately $62.0 million and interest was incurred on the facility at a weighted average annual interest rate of 2.5% during 2015. The credit facility is available to fund working capital requirements and capital expenditures and to purchase assets and matures on December 22, 2019. Rice Olympus Midstream LLC, Rice West Virginia Midstream LLC and Strike Force Midstream Holdings LLC (“Strike Force Holdings”) are the guarantors of the obligations under the credit facility.Principal amounts borrowed are payable on the maturity date, and interest is payable quarterly for base rate loans and at the end of the applicable interest period for Eurodollar loans. Under the Midstream Holdings Revolving Credit Facility, Midstream Holdings may elect to borrow in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to the applicable LIBOR Rate plus an applicable margin ranging from 225 to 300 basis points, depending on the leverage ratio then in effect. Base rate loans bear interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 125 to 200 basis points, depending on the leverage ratio then in effect. Midstream Holdings also pays a commitment fee based on the undrawn commitment amount ranging from 37.5 to 50 basis points. The Midstream Holdings Revolving Credit Facility is secured by mortgages and other security interests on substantially all of the properties of, and guarantees from, Midstream Holdings and its restricted subsidiaries (which do not include the Partnership, Rice Midstream Management LLC, a Delaware limited liability company and general partner of the Partnership, or the Company and its subsidiaries other than Midstream Holdings). The Midstream Holdings Revolving Credit Facility limits the ability of Midstream Holdings and its restricted subsidiaries to, among other things: •incur or guarantee additional debt; •redeem or repurchase units or make distributions under certain circumstances; •make certain investments and acquisitions; •incur certain liens or permit them to exist; •enter into certain types of transactions with affiliates; •merge or consolidate with another company; and •transfer, sell or otherwise dispose of assets. The Midstream Holdings Revolving Credit Facility also requires Midstream Holdings to maintain the following financial ratios: •an interest coverage ratio, which is the ratio of Rice Midstream Holding’s consolidated EBITDA (as defined within the Midstream Holdings Revolving Credit Facility) to its consolidated current interest expense of at least 2.50 to 1.0 at the end of each fiscal quarter; and•a consolidated total leverage ratio, which is the ratio of consolidated debt to consolidated EBITDA, of not more than 4.25 to 1.0. Midstream Holdings was in compliance with such covenants and ratios effective as of December 31, 2015.
[5]	RMP Revolving Credit Facility (e)On December 22, 2014, Rice Midstream OpCo LLC, a wholly-owned subsidiary of the Partnership (“Rice Midstream OpCo”), entered into a revolving credit facility (the “RMP Revolving Credit Facility”) with Wells Fargo, as administrative agent, and a syndicate of lenders with a maximum credit amount of $450.0 million with an additional $200.0 million of commitments available under an accordion feature, subject to lender approval. The RMP Revolving Credit Facility provides for a letter of credit sublimit of $50.0 million. As of December 31, 2015, Rice Midstream OpCo had $143.0 million borrowings outstanding and no letters of credit under this facility. The average daily outstanding balance of the credit facility was approximately $46.9 million and interest was incurred on the facility at a weighted average annual interest rate of 2.0% during 2015. The RMP Revolving Credit Facility is available to fund working capital requirements and capital expenditures, to purchase assets, to pay distributions and repurchase units and for general partnership purposes and matures on December 22, 2019. The Partnership is the guarantor of the obligations under the credit facility.Principal amounts borrowed are payable on the maturity date, and interest is payable quarterly for base rate loans and at the end of the applicable interest period for Eurodollar loans. Under the RMP Revolving Credit Facility, the Partnership may elect to borrow in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to the applicable LIBOR Rate plus an applicable margin ranging from 175 to 275 basis points, depending on the leverage ratio then in effect. Base rate loans bears interest at a rate per annum equal to the greatest of (i) the agent bank’s reference rate, (ii) the federal funds effective rate plus 50 basis points and (iii) the rate for one month Eurodollar loans plus 100 basis points, plus an applicable margin ranging from 75 to 175 basis points, depending on the leverage ratio then in effect. The Partnership also pays a commitment fee based on the undrawn commitment amount ranging from 35 to 50 basis points. The RMP Revolving Credit Facility is secured by mortgages and other security interests on substantially all of the properties of, and guarantees from, the Partnership and its restricted subsidiaries. The RMP Revolving Credit Facility limits the ability of the Partnership and its restricted subsidiaries to, among other things: •incur or guarantee additional debt; •redeem or repurchase units or make distributions under certain circumstances; •make certain investments and acquisitions; •incur certain liens or permit them to exist; •enter into certain types of transactions with affiliates; •merge or consolidate with another company; and •transfer, sell or otherwise dispose of assets. The RMP Revolving Credit Facility also requires the Partnership to maintain the following financial ratios: •an interest coverage ratio, which is the ratio of the Partnership’s consolidated EBITDA (as defined within the RMP Revolving Credit Facility) to its consolidated current interest expense of at least 2.50 to 1.0 at the end of each fiscal quarter;•a consolidated total leverage ratio, which is the ratio of consolidated debt to consolidated EBITDA, of not more than 4.75 to 1.0, and after electing to issue senior unsecured notes, a consolidated total leverage ratio of not more than 5.25 to 1.0, and, in each case, with certain increases in the permitted total leverage ratio following the completion of a material acquisition; and•if the Partnership elects to issue senior unsecured notes, a consolidated senior secured leverage ratio, which is the ratio of consolidated senior secured debt to consolidated EBITDA, of not more than 3.50 to 1.0. The Partnership was in compliance with such covenants and ratios effective as of December 31, 2015.

Long Term Debt (6.25% Senior No

Long Term Debt (6.25% Senior Notes Due 2022) (Details) - USD ($) $ in Thousands	Apr. 25, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Proceeds from borrowings		$ 913,932	$ 1,090,000	$ 435,500
Underwriting discounts and commissions		10,266	24,543	12,194
Repayments of debt obligations		$ 358,619	$ 689,873	$ 160,760
Senior Notes | Senior Notes Due 2022
Debt Instrument [Line Items]
Interest rate	6.25%
Aggregate principal amounts of debt offered	$ 900,000
Proceeds from borrowings	882,700
Underwriting discounts and commissions	17,300
Repayments of debt obligations	$ 301,800
Prior to May 1, 2017 | Senior Notes | Senior Notes Due 2022
Debt Instrument [Line Items]
Percentage of principal amount, plus accrued and unpaid interest with proceeds of certain equity offerings	106.25%
Redemption period after completing equity offering	180 days
Percentage of aggregate principal amount of Notes outstanding after redemption (at least)	65.00%
Percentage of principal amount redeemed (up to)	100.00%
Percentage that may be redeemed upon change in control	101.00%
Prior to May 1, 2017 | Senior Notes | Senior Notes Due 2022 | Maximum
Debt Instrument [Line Items]
Percentage of redemption price of principal amount plus applicable make-whole premium and accrued and unpaid interest	35.00%
On or after May 1, 2017 | Senior Notes | Senior Notes Due 2022
Debt Instrument [Line Items]
Percentage of principal amount redeemed (up to)	104.688%
12 month period beginning May 1, 2018 | Senior Notes | Senior Notes Due 2022
Debt Instrument [Line Items]
Percentage of principal amount redeemed (up to)	103.125%
12 month period beginning on May 1, 2019 | Senior Notes | Senior Notes Due 2022
Debt Instrument [Line Items]
Percentage of principal amount redeemed (up to)	101.563%
12 month period beginning on May 1, 2020 | Senior Notes | Senior Notes Due 2022
Debt Instrument [Line Items]
Percentage of principal amount redeemed (up to)	100.00%

Long Term Debt (7.25% Senior No

Long Term Debt (7.25% Senior Notes Due 2023) (Details) - USD ($)	Mar. 26, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Proceeds from borrowings		$ 913,932,000	$ 1,090,000,000	$ 435,500,000
Underwriting discounts and commissions		10,266,000	$ 24,543,000	$ 12,194,000
Senior Notes
Debt Instrument [Line Items]
Period for default of interest payment	30 days
Debt covenant requirement, required payment defaults and accelerations for aggregate principal amounts in default (or more)	$ 25,000,000
Debt covenant requirement, failure to pay certain final judgments aggregate amount (in excess of)	$ 25,000,000
Debt covenant requirement, period for failure to pay final judgments	60 days
Senior Notes | Senior Notes Due 2023
Debt Instrument [Line Items]
Interest rate	7.25%
Aggregate principal amounts of debt offered	$ 400,000,000
Proceeds from borrowings	389,300,000
Underwriting discounts and commissions	10,700,000
Amount of discount	$ 3,100,000
Amortization of debt discount		$ 300,000
Effective interest rate (percentage)	7.345%
Senior Notes | Senior Notes Due 2023 | Prior to May 1, 2018
Debt Instrument [Line Items]
Percentage of principal amount, plus accrued and unpaid interest with proceeds of certain equity offerings	107.25%
Redemption period after completing equity offering	180 days
Percentage of aggregate principal amount of Notes outstanding after redemption (at least)	65.00%
Percentage of principal amount redeemed (up to)	100.00%
Percentage that may be redeemed upon change in control	101.00%
Senior Notes | Senior Notes Due 2023 | Prior to May 1, 2018 | Maximum
Debt Instrument [Line Items]
Percentage of redemption price of principal amount	35.00%
Senior Notes | Senior Notes Due 2023 | On or after May 1, 2018
Debt Instrument [Line Items]
Percentage of principal amount redeemed (up to)	105.438%
Senior Notes | Senior Notes Due 2023 | 12 month period beginning May 1, 2019
Debt Instrument [Line Items]
Percentage of principal amount redeemed (up to)	103.625%
Senior Notes | Senior Notes Due 2023 | 12 month period beginning May 1, 2020
Debt Instrument [Line Items]
Percentage of principal amount redeemed (up to)	101.813%
Senior Notes | Senior Notes Due 2023 | 12 month period beginning May 1, 2021
Debt Instrument [Line Items]
Percentage of principal amount redeemed (up to)	100.00%

Long Term Debt (Senior Secured

Long Term Debt (Senior Secured Revolving Credit Facility) (Details) - Senior Secured Revolving Credit Facility - Wells Fargo	Jan. 13, 2016	Jan. 29, 2014	Dec. 31, 2015USD ($)	Apr. 25, 2014
Revolving Credit Facility
Line of Credit Facility [Line Items]
Borrowing base after amendment			$ 750,000,000
Borrowings outstanding			0
Availability under revolving credit facility			650,700,000
Current ratio (not less than)				1
Minimum interest coverage ratio (not less than)				2.5
Revolving Credit Facility | Minimum
Line of Credit Facility [Line Items]
Percentage lien on proved oil and gas reserves				80.00%
Revolving Credit Facility | LIBOR | Minimum
Line of Credit Facility [Line Items]
Interest rate spread (percentage)		1.50%
Revolving Credit Facility | LIBOR | Maximum
Line of Credit Facility [Line Items]
Interest rate spread (percentage)		2.50%
Revolving Credit Facility | Federal Funds Rate
Line of Credit Facility [Line Items]
Interest rate spread (percentage)		0.50%
Revolving Credit Facility | Eurodollar
Line of Credit Facility [Line Items]
Interest rate spread (percentage)		1.00%
Revolving Credit Facility | Base Rate | Minimum
Line of Credit Facility [Line Items]
Interest rate spread (percentage)		0.50%
Revolving Credit Facility | Base Rate | Maximum
Line of Credit Facility [Line Items]
Interest rate spread (percentage)		1.50%
Letters of Credit
Line of Credit Facility [Line Items]
Borrowing base after amendment			250,000,000
Borrowings outstanding			$ 99,300,000
Subsequent Event | Revolving Credit Facility
Line of Credit Facility [Line Items]
Period after any commodity swap agreement or secured firm transportation reimbursement agreement	18 months

Long Term Debt (Midstream Holdi

Long Term Debt (Midstream Holdings Revolving Credit Facility) (Details) - Midstream Holdings Revolving Credit Facility - Wells Fargo	Dec. 22, 2014USD ($)	Dec. 31, 2015USD ($)
Revolving Credit Facility
Debt Instrument [Line Items]
Maximum credit amount	$ 300,000,000
Borrowings outstanding		$ 17,000,000
Average daily balance of credit facility		$ 62,000,000
Weighted average annual interest rate percentage		2.50%
Interest coverage ratio (at least)	2.50
Consolidated total leverage ratio (not more than)	4.25
Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Commitment fee (percentage)	0.375%
Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Commitment fee (percentage)	0.50%
Revolving Credit Facility | LIBOR | Minimum
Debt Instrument [Line Items]
Interest rate spread (percentage)	2.25%
Revolving Credit Facility | LIBOR | Maximum
Debt Instrument [Line Items]
Interest rate spread (percentage)	3.00%
Revolving Credit Facility | Federal Funds Rate
Debt Instrument [Line Items]
Interest rate spread (percentage)	0.50%
Revolving Credit Facility | Eurodollar
Debt Instrument [Line Items]
Interest rate spread (percentage)	1.00%
Revolving Credit Facility | Base Rate | Minimum
Debt Instrument [Line Items]
Interest rate spread (percentage)	1.25%
Revolving Credit Facility | Base Rate | Maximum
Debt Instrument [Line Items]
Interest rate spread (percentage)	2.00%
Letters of Credit
Debt Instrument [Line Items]
Maximum credit amount	$ 25,000,000
Borrowings outstanding		$ 0

Long Term Debt (RMP Revolving C

Long Term Debt (RMP Revolving Credit Facility) (Details) - RMP Revolving Credit Facility - Wells Fargo	Dec. 22, 2014USD ($)	Dec. 31, 2015USD ($)
Revolving Credit Facility
Debt Instrument [Line Items]
Maximum credit amount	$ 450,000,000
Additional commitments available under accordion feature	$ 200,000,000
Borrowings outstanding		$ 143,000,000
Interest coverage ratio (at least)	2.50
Consolidated total leverage ratio (not more than)	4.75
Consolidated leverage ratio including senior unsecured notes (not more than)	5.25
Consolidated senior secured leverage ratio (not more than)	3.50
Revolving Credit Facility | Minimum
Debt Instrument [Line Items]
Commitment fee (percentage)	0.35%
Revolving Credit Facility | Maximum
Debt Instrument [Line Items]
Commitment fee (percentage)	0.50%
Revolving Credit Facility | LIBOR | Minimum
Debt Instrument [Line Items]
Interest rate spread (percentage)	1.75%
Revolving Credit Facility | LIBOR | Maximum
Debt Instrument [Line Items]
Interest rate spread (percentage)	2.75%
Revolving Credit Facility | Federal Funds Rate
Debt Instrument [Line Items]
Interest rate spread (percentage)	0.50%
Revolving Credit Facility | Eurodollar
Debt Instrument [Line Items]
Interest rate spread (percentage)	1.00%
Revolving Credit Facility | Base Rate | Minimum
Debt Instrument [Line Items]
Interest rate spread (percentage)	0.75%
Revolving Credit Facility | Base Rate | Maximum
Debt Instrument [Line Items]
Interest rate spread (percentage)	1.75%
Letters of Credit
Debt Instrument [Line Items]
Maximum credit amount	$ 50,000,000
Borrowings outstanding		0
Average daily balance of credit facility		$ 46,900,000
Weighted average annual interest rate percentage		2.00%

Long Term Debt (Schedule of Exp

Long Term Debt (Schedule of Expected Maturities of Notes Payable) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Debt Disclosure [Abstract]
Remainder of Year Ending December 31, 2015	$ 0
Year Ending December 31, 2016	0
Year Ending December 31, 2017	0
Year Ending December 31, 2018	0
Year Ending December 31, 2019 and Beyond	1,457,222
Total debt	1,457,222	$ 900,680
Interest paid in cash	$ 82,100	$ 36,700	$ 27,700

Derivative Instruments (Narrati

Derivative Instruments (Narrative) (Details) - Not Designated as Hedging Instrument MMcf in Thousands	12 Months Ended
	Dec. 31, 2015$ / MMBTUMMcf
NYMEX, Swap and Collar Contracts, Natural Gas, Through December 31, 2019
Derivative [Line Items]
Projected natural gas production (Bcf)	525
Weighted average price, per MMBtu | $ / MMBTU	3.27
NYMEX, Fixed Price and Basis Contracts, Natural Gas, Through December 31, 2020
Derivative [Line Items]
Projected natural gas production (Bcf)	408

Derivative Instruments (Schedul

Derivative Instruments (Schedule of Offsetting Assets and Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative instruments, recorded in the Consolidated Balance Sheet, gross, Derivative assets	$ 372,414	$ 201,775
Derivative instruments subject to master netting arrangements, Derivative assets	(79,509)	(5,553)
Derivative Instruments, net, Derivative assets	292,905	$ 196,222
Derivative instruments, recorded in the Consolidated Balance Sheet, gross, Derivative liabilities	21,043
Derivative instruments subject to master netting arrangements, Derivative liabilities	(4,200)
Derivative Instruments, net, Derivative liabilities	$ 16,843

Fair Value of Financial Instr65

Fair Value of Financial Instruments (Schedule of Assets and Liabilities Measured at Fair Value) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Assets:
Derivative instruments, at fair value	$ 292,905	$ 196,222
Liabilities:
Derivative instruments, at fair value	16,843
Fair Value, Measurements, Recurring
Assets:
Derivative instruments, at fair value	292,905	196,222
Total assets	292,905	196,222
Liabilities:
Derivative instruments, at fair value	16,843
Total liabilities	16,843
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivative instruments, at fair value	0	0
Total assets	0	0
Liabilities:
Derivative instruments, at fair value	0
Total liabilities	0
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2)
Assets:
Derivative instruments, at fair value	292,905	196,222
Total assets	292,905	196,222
Liabilities:
Derivative instruments, at fair value	16,843
Total liabilities	16,843
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3)
Assets:
Derivative instruments, at fair value	0	0
Total assets	0	0
Liabilities:
Derivative instruments, at fair value	0
Total liabilities	0
Carrying Value | Fair Value, Measurements, Recurring
Assets:
Derivative instruments, at fair value	292,905	196,222
Total assets	292,905	$ 196,222
Liabilities:
Derivative instruments, at fair value	16,843
Total liabilities	$ 16,843

Fair Value of Financial Instr66

Fair Value of Financial Instruments (Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation) (Details) - Restricted Units - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance as of the beginning of the period	$ 0	$ 36,306
Converted to shares of common stock	0	(36,306)
Balance as of the end of the period	$ 0	$ 0

Fair Value of Financial Instr67

Fair Value of Financial Instruments (Schedule of the Estimated Fair Value and Carrying Amount of Long-term Debt) (Details) - Significant Other Observable Inputs (Level 2) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Carrying Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other	$ 0	$ 680
Total fair value	1,457,222	900,680
Carrying Value | Senior Notes Due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes Due 2022	900,000	900,000
Carrying Value | Senior Notes Due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes Due 2023	397,222	0
Carrying Value | Midstream Holdings Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Midstream Holdings Revolving Credit Facility	17,000	0
Carrying Value | RMP Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
RMP Revolving Credit Facility	143,000	0
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Other	0	680
Total fair value	1,104,250	839,930
Fair Value | Senior Notes Due 2022
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes Due 2022	650,250	839,250
Fair Value | Senior Notes Due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes Due 2023	294,000	0
Fair Value | Midstream Holdings Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Midstream Holdings Revolving Credit Facility	17,000	0
Fair Value | RMP Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
RMP Revolving Credit Facility	$ 143,000	$ 0

Rice Midstream Partners LP (Det

Rice Midstream Partners LP (Details) - USD ($) $ / shares in Units, $ in Thousands	Jan. 22, 2016	Nov. 12, 2015	Nov. 10, 2015	Dec. 22, 2014	Jan. 29, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO					50,000,000
Net income attributable to noncontrolling interests						$ (23,337)	$ (581)	$ 0
Proceeds from issuance of common stock sold in our IPO, net of offering costs						(129)	597,088	0
Proceeds distributed to the company						$ 17,017	$ 0	$ 0
IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO					30,000,000
Proceeds from issuance of common stock sold in our IPO, net of offering costs					$ 593,600
Underwriting discounts and commissions					$ 36,400
Rice Midstream Partners LP
Subsidiary, Sale of Stock [Line Items]
Rice Midstream Holdings LLC ownership percentage in Rice Midstream Partners LP				50.00%		59.00%
Ownership interest percentage in Rice Midstream Partners LP				50.00%		41.00%
Cash distribution paid per unit		$ 0.1935
Rice Midstream Partners LP | Subsequent Event
Subsidiary, Sale of Stock [Line Items]
Cash distribution declared to Partnership's unitholders	$ 0.1965
Rice Midstream Partners LP | IPO
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO				28,750,000
Percentage of partnership contributed				100.00%
Proceeds from issuance of common stock sold in our IPO, net of offering costs				$ 441,700
Proceeds distributed to the company				414,400
Proceeds retained by the Partnership				25,000
Proceeds used to pay expenses from the IPO				2,000
Origination fees				$ 2,700
Rice Midstream Partners LP | IPO | Common Units
Subsidiary, Sale of Stock [Line Items]
Common units and subordinated units retained				3,623
Rice Midstream Partners LP | IPO | Subordinated Units
Subsidiary, Sale of Stock [Line Items]
Common units and subordinated units retained				28,753,623
Rice Midstream Partners LP | Private Placement
Subsidiary, Sale of Stock [Line Items]
Number of common units sold in private placement			13,409,961
Gross proceeds under Common Unit Purchase Agreement			$ 175,000
Underwriting discounts and commissions			3,100
Net proceeds received			$ 171,900

Acquisitions (Narrative) (Detai

Acquisitions (Narrative) (Details) - Greene County Acquisition - Greene County, Pennsylvania a in Thousands, $ in Millions	Jul. 07, 2014USD ($)aWell	Jun. 30, 2015USD ($)
Business Acquisition [Line Items]
Amount received for purchase price revision		$ 15.8
Net acres acquired | a	19
Number of developed wells acquired | Well	12
Purchase price	$ 329.5

Financial Information by Busi70

Financial Information by Business Segment (Details) - USD ($) $ in Thousands	3 Months Ended																12 Months Ended
	Dec. 31, 2015		Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014		Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	$ 446,515	$ 359,201	$ 87,847
Firm transportation sales, net																	3,450	26,237
Gathering, compression and water services																	49,179	5,504	83
Other revenue																	2,997	0	757
Total operating revenues	$ 136,088	[1]	$ 143,621		$ 112,894		$ 109,539		$ 129,398	[1]	$ 79,128		$ 91,940		$ 90,477		502,141	390,942	88,687
Operating expenses:
Lease operating																	44,356	24,971	8,309
Gathering, compression and transportation																	84,707	35,618	8,362
Production taxes and impact fees																	7,609	4,647	1,629
Exploration																	3,137	4,018	9,951
Midstream operation and maintenance																	16,988	4,607	1,412
Incentive unit expense																	36,097	105,961	0
Impairment of gas properties																	18,250	0	0
Impairment of goodwill																	294,908	0	0
Acquisition expense																	1,235	2,339	0
General and administrative expenses																	103,038	61,570	16,953
Depreciation, depletion and amortization																	322,784	156,270	32,815
Amortization of intangible assets																	1,632	1,156	0
(Gain) loss from sale of interest in gas properties																	(953)	0	4,230
Restricted unit expense																	0	0	32,906
Other expense																	6,520	207	0
Total operating expenses	480,329	[1]	160,295		159,065		140,619		118,118	[1]	91,453		67,522		124,272		940,308	401,364	116,567
Operating loss	(344,241)	[1]	$ (16,674)		$ (46,171)		$ (31,080)		11,280	[1]	$ (12,325)		$ 24,418		$ (33,795)		(438,167)	(10,422)	(27,880)
Segment assets	3,970,531								3,527,949								3,970,531	3,527,949	879,810
Goodwill	39,142								334,050								39,142	334,050
Capital expenditures for segment assets																	1,246,274	970,274	465,387
Exploration and Production
Operating expenses:
Impairment of goodwill																	294,908
Goodwill	0								294,908								0	294,908	0
Midstream
Operating expenses:
Impairment of goodwill																	0
Goodwill	39,142								39,142								39,142	39,142	0
Operating Segments | Exploration and Production
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	446,515	359,201	87,847
Firm transportation sales, net																	3,450	26,237
Gathering, compression and water services																	0	0	0
Other revenue																	2,997		259
Total operating revenues																	452,962	385,438	88,106
Operating expenses:
Lease operating																	44,356	24,971	8,309
Gathering, compression and transportation																	150,015	37,414	8,362
Production taxes and impact fees																	7,609	4,647	1,629
Exploration																	3,137	4,018	9,951
Midstream operation and maintenance																	0	0	0
Incentive unit expense																	33,873	86,020
Impairment of gas properties																	18,250
Impairment of goodwill																	294,908
Acquisition expense																	108	820
General and administrative expenses																	78,592	46,229	13,778
Depreciation, depletion and amortization																	308,194	151,900	31,467
Amortization of intangible assets																	0	0
(Gain) loss from sale of interest in gas properties																	(953)		4,230
Restricted unit expense																			32,906
Other expense																	6,028	0
Total operating expenses																	944,117	356,019	110,632
Operating loss																	(491,155)	29,419	(22,526)
Segment assets	3,004,226								2,935,814								3,004,226	2,935,814	804,992
Goodwill	0								294,908								0	294,908
Capital expenditures for segment assets																	869,134	693,129	406,179
Operating Segments | Midstream
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	0	0	0
Firm transportation sales, net																	0	0
Gathering, compression and water services																	141,823	7,300	83
Other revenue																	0		498
Total operating revenues																	141,823	7,300	581
Operating expenses:
Lease operating																	0	0	0
Gathering, compression and transportation																	0	0	0
Production taxes and impact fees																	0	0	0
Exploration																	0	0	0
Midstream operation and maintenance																	16,988	4,607	1,412
Incentive unit expense																	2,224	19,941
Impairment of gas properties																	0
Impairment of goodwill																	0
Acquisition expense																	1,127	1,519
General and administrative expenses																	24,446	15,341	3,175
Depreciation, depletion and amortization																	19,185	4,370	1,348
Amortization of intangible assets																	1,632	1,156
(Gain) loss from sale of interest in gas properties																	0		0
Restricted unit expense																			0
Other expense																	492	207
Total operating expenses																	66,094	47,141	5,935
Operating loss																	75,729	(39,841)	(5,354)
Segment assets	989,938								592,135								989,938	592,135	74,818
Goodwill	39,142								39,142								39,142	39,142
Capital expenditures for segment assets																	404,476	277,145	$ 59,208
Elimination of Intersegment Transactions
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	0	0
Firm transportation sales, net																	0	0
Gathering, compression and water services																	(92,644)	(1,796)
Other revenue																	0
Total operating revenues																	(92,644)	(1,796)
Operating expenses:
Lease operating																	0	0
Gathering, compression and transportation																	(65,308)	(1,796)
Production taxes and impact fees																	0	0
Exploration																	0	0
Midstream operation and maintenance																	0	0
Incentive unit expense																	0	0
Impairment of gas properties																	0
Impairment of goodwill																	0
Acquisition expense																	0	0
General and administrative expenses																	0	0
Depreciation, depletion and amortization																	(4,595)	0
Amortization of intangible assets																	0	0
(Gain) loss from sale of interest in gas properties																	0
Other expense																	0	0
Total operating expenses																	(69,903)	(1,796)
Operating loss																	(22,741)	0
Segment assets	(23,633)								0								(23,633)	0
Goodwill	$ 0								$ 0								0	0
Capital expenditures for segment assets																	$ (27,336)	$ 0
[1]	The sum of quarterly data in some cases may not equal the yearly total due to rounding.

Commitments and Contingencies (

Commitments and Contingencies (Details) a in Thousands, $ in Millions	Oct. 14, 2013a	Dec. 31, 2015USD ($)Drilling_Rig
Other Commitments [Line Items]
Total future payments for drilling rigs under contract | $		$ 43.4
Future payments for drilling rigs under contract, 2016 | $		29.3
Future payments for drilling rigs under contract, 2017 | $		12.1
Future payments for drilling rigs under contract, 2018 | $		$ 2
Horizontal Drilling Rigs
Other Commitments [Line Items]
Number of drilling rigs under contract		3
Number of drilling rigs under contract that expire in 2016		1
Number of drilling rigs under contract that expire in 2017		2
Tophole Drilling Rigs
Other Commitments [Line Items]
Number of drilling rigs under contract		2
Number of drilling rigs under contract that expire in 2016		1
Number of drilling rigs under contract that expire in 2018		1
Utica Development Agreements
Other Commitments [Line Items]
Net acres | a	50
Utica Development Agreements, terms	10 years
Period of notice prior to termination	90 days
Utica Development Agreements | Goshen and Smith Townships in Belmont County, Ohio
Other Commitments [Line Items]
Participating interest in acreage (percentage)	68.70%
Utica Development Agreements | Wayne and Washington Townships in Belmont County, Ohio
Other Commitments [Line Items]
Participating interest in acreage (percentage)	48.20%

Commitments and Contingencies72

Commitments and Contingencies (Commitment for Gathering and Firm Transportation) (Details) - Gathering and Firm Transportation $ in Millions	Dec. 31, 2015USD ($)
Other Commitments [Line Items]
Future payments under contracts	$ 4,797.2
Commitment for gathering and firm transportation, 2016	117.2
Commitment for gathering and firm transportation, 2017	151.4
Commitment for gathering and firm transportation, 2018	226.9
Commitment for gathering and firm transportation, 2019	222.5
Commitment for gathering and firm transportation, 2020	222.3
Commitment for gathering and firm transportation, Thereafter	$ 3,856.9

Lease Obligations (Details)

Lease Obligations (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Capital Leased Assets [Line Items]
2,016		$ 17,288
2,017		5,286
2,018		566
2,019		438
2020 and thereafter		0
Total future minimum lease payments		23,578
Leased drilling rights
Capital Leased Assets [Line Items]
Required payments under lease agreements (up to $0.9 million)		$ 500
Leased drilling rights | Scenario, Forecast
Capital Leased Assets [Line Items]
Required payments under lease agreements (up to $0.9 million)	$ 200

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Balance	$ 9,542	$ 2,114
Liabilities incurred	5,198	7,171
Revisions in estimated cash flows	(3,085)
Liabilities settled	(1,131)	(256)
Accretion expense	890	513
Balance	$ 11,414	$ 9,542

Stockholders' Equity (Details)

Stockholders' Equity (Details) - Secondary Public Offering - NGP Holdings - NGP Holdings	May. 12, 2015$ / sharesshares
Class of Stock [Line Items]
Shares of common stock relating to offer and sale by NGP Holdings, Inc | shares	6,000,000
Price per share of sale of common stock	$ 24.20
Price per share of sale of common stock, net of underwriting discounts and commissions	$ 23.99

Incentive Units (Narrative) (De

Incentive Units (Narrative) (Details) $ in Thousands	Jan. 29, 2014USD ($)	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2014	Aug. 31, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2014shares	Dec. 31, 2015USD ($)Trancheshares	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-cash compensation (income) expense									$ 36,097	$ 105,961	$ 0
Incentive Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-cash compensation (income) expense									36,100	106,000
Compensation expense related to changes in certain service condition assumptions									$ 12,800
Incentive Units | Time Vesting Feature
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of tranches with time vest feature | Tranche									3
Awards legally vested | shares								1,667,578	1,027,288
Incentive Units | Future Payment Condition Vesting Feature
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of tranches without time vest feature | Tranche									4
Awards legally vested | shares									0
Incentive Units | NGP Holdings | NGP Holdings
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-cash compensation (income) expense									$ (24,300)	44,500
Unrecognized compensation cost									12,000
Incentive Units | Rice Holdings | Rice Holdings
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-cash compensation (income) expense									33,700	$ 41,700
Unrecognized compensation cost									39,200
Distribution percentage to members				33.33333%	25.00%
Incentive Units | Rice Holdings | Rice Holdings | Scenario, Forecast
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Distribution percentage to members		100.00%	50.00%
Incentive Units | IPO | Incentive Unitholders
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Value of shares of common stock issued in connection with IPO and corporate reorganization	$ 3,400
Incentive Units | IPO | NGP Holdings | NGP Holdings
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Cash distributions to members							$ 4,400
Incentive Units | Secondary Public Offering | NGP Holdings | NGP Holdings
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-cash compensation (income) expense									$ 26,700
Cash distributions to members						$ 12,000

Incentive Units (Roll Forward o

Incentive Units (Roll Forward of Incentive Units) (Details) - Incentive Units - Time Vesting Feature - shares	11 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2015
Number of shares
Vested Units Beginning Balance	133,333	1,800,911
Vested During Period	1,667,578	1,027,288
Forfeited During Period	(37,140)	0
Granted During Period	37,140	0
Canceled During Period	0	0
Vested Units Ending Balance	1,800,911	2,828,199

Incentive Units (Fair Value of

Incentive Units (Fair Value of Incentive Units) (Details) - Incentive Units - Future Payment Condition Vesting Feature	Dec. 31, 2015	Apr. 16, 2014	Apr. 14, 2014	Jan. 29, 2014
Rice Holdings | Rice Holdings | 1/29/2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend Yield				0.00%
Expected Volatility				47.00%
Risk-Free Rate				1.11%
Expected Life (Years)				4 years
Rice Holdings | Rice Holdings | 4/14/2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend Yield			0.00%
Expected Volatility			45.19%
Risk-Free Rate			1.13%
Expected Life (Years)			3 years 9 months 18 days
Rice Holdings | Rice Holdings | 4/16/2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend Yield		0.00%
Expected Volatility		44.32%
Risk-Free Rate		1.18%
Expected Life (Years)		3 years 9 months 15 days
NGP Holdings | NGP Holdings | 12/31/2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend Yield	0.00%
Expected Volatility	54.57%
Risk-Free Rate	0.96%
Expected Life (Years)	1 year 9 months

Stock Compensation (Restricted

Stock Compensation (Restricted Stock Unit Awards) (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense				$ 16,528	$ 5,553
Restricted Units
Number of shares
Total unvested, December 31, 2014			702,669	322,659	0
Granted				535,175	328,907
Vested				(121,138)	(1,647)
Forfeited				(34,027)	(4,601)
Total unvested - December 31, 2015				702,669	322,659
Weighted average grant date fair value
Total unvested, December 31, 2014			$ 21.70	$ 28.38	$ 0
Granted				19.25	28.79
Vested				27.98	30.33
Forfeited				24.13	32.59
Total unvested - December 31, 2015				$ 21.70	$ 28.38
Total unrecognized compensation expense				$ 10,000
Restricted Units | Scenario, Forecast
Number of shares
Vested	(181,811)	(266,452)	(254,406)
Restricted Units | General and Administrative Expense
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense				$ 5,700	$ 2,600
Restricted Units | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period				1 year
Restricted Units | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period				3 years
LTIP
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Aggregate maximum number of shares of common stock under LTIP				17,500,000

Stock Compensation (Performance

Stock Compensation (Performance Stock Awards) (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 16,528	$ 5,553
Performance Shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years
Dividend Yield	0.00%	0.00%
Expected Volatility	49.69%	43.73%
Risk-Free Rate	1.00%	0.70%
Expected Life (Years)	2 years 10 months 21 days	2 years 7 months 24 days
Weighted average fair value of performance stock unit awards	$ 21.61	$ 38.77
Total unrecognized compensation expense	$ 10,800
Performance Shares | General and Administrative Expense
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense	$ 6,700	$ 2,800

Stock Compensation (RMP Phantom

Stock Compensation (RMP Phantom Unit Awards) (Details) - USD ($) $ / shares in Units, $ in Thousands	Dec. 22, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 16,528	$ 5,553
Rice Midstream Partners LP 2014 Long Term Incentive Plan | Phantom Share Units (PSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of units available to be granted	5,000,000
Total unrecognized compensation expense			$ 3,000
Number of shares
Total unvested, December 31, 2014		432,628	434,094	0
Granted			18,196	434,094
Vested			(242)	0
Forfeited			(19,420)	0
Total unvested - December 31, 2015			432,628	434,094
Weighted average grant date fair value
Total unvested, December 31, 2014		$ 16.52	$ 16.50	$ 0
Granted			16.87	16.50
Vested			16.50	0
Forfeited			16.50	0
Total unvested - December 31, 2015			$ 16.52	$ 16.50
Rice Midstream Partners LP 2014 Long Term Incentive Plan | Phantom Share Units (PSUs) | Scenario, Forecast
Number of shares
Vested		(432,628)
Rice Midstream Partners LP 2014 Long Term Incentive Plan | Phantom Share Units (PSUs) | General and Administrative Expense
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense			$ 4,100	$ 100
Rice Midstream Partners LP 2014 Long Term Incentive Plan | Phantom Share Units (PSUs) | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	1 year 6 months
Rice Midstream Partners LP 2014 Long Term Incentive Plan | Phantom Share Units (PSUs) | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	2 years

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended																12 Months Ended
	Dec. 31, 2015	[1]	Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014	[1]	Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Earnings Per Share [Abstract]
Net income (loss)	$ (280,755)		$ 58,950		$ (69,683)		$ 152		$ 103,779		$ (6,861)		$ (7,917)		$ 129,454		$ (291,336)	$ 218,454	$ (35,776)
Weighted-average shares (denominator):
Weighted-average number of shares of common stock - basic																	136,344,076	128,151,171	80,441,905
Weighted-average number of shares of common stock - diluted																	136,344,076	128,225,155	80,441,905
(Loss) earnings per share:
(Loss) earnings per share—basic	$ (2.06)		$ 0.43		$ (0.51)		$ 0		$ 0.76		$ (0.05)		$ (0.06)		$ 1.04		$ (2.14)	$ 1.70	$ (0.44)
(Loss) earnings per share—diluted	$ (2.06)		$ 0.43		$ (0.51)		$ 0		$ 0.76		$ (0.05)		$ (0.06)		$ 1.03		$ (2.14)	$ 1.70	$ (0.44)
Number of shares not considered dilutive																	133,611		1,671,800
[1]	The sum of quarterly data in some cases may not equal the yearly total due to rounding.

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($)	Jan. 29, 2014	Dec. 31, 2015	Dec. 31, 2014
Income Taxes [Line Items]
Federal income tax statutory rate		35.00%
Deferred tax assets related to NOL carryforwards		$ 153,600,000
AMT tax credit		7,999,000	$ 3,961,000
Accrual for interest related to income tax filings		0
Interest Expense
Income Taxes [Line Items]
Interest incurred related to income tax filings		100,000
General and Administrative Expense
Income Taxes [Line Items]
Penalties incurred related to income tax filings		100,000
Federal | IRS
Income Taxes [Line Items]
Income tax net operating loss (NOL) carryforward		398,500,000
Federal | IRS | Intangible drilling costs
Income Taxes [Line Items]
AMT tax credit		8,000,000
State
Income Taxes [Line Items]
Income tax net operating loss (NOL) carryforward		$ 293,800,000
IPO
Income Taxes [Line Items]
Deferred tax liability recorded in equity			$ (162,320,000)
IPO | Deferred Tax Liability Recorded In Equity
Income Taxes [Line Items]
Deferred tax liability recorded in equity	$ 162,300,000

Income Taxes (Schedule of Compo

Income Taxes (Schedule of Components of Income Tax Provision) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current tax expense:
Federal	$ 4,039	$ 3,961
State	0	0
Total	4,039	3,961
Deferred tax expense:
Federal	19,878	68,846
State	(11,799)	18,793
Total	8,079	87,639	$ 0
Income tax expense	$ 12,118	$ 91,600	$ 0

Income Taxes (Schedule of Effec

Income Taxes (Schedule of Effective Income Tax Rate) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Tax at statutory rate	$ (89,560)	$ 108,722
Permanent tax differences	74	18
State income taxes	(7,668)	12,216
Partnership earnings (1/1/14 - 1/28/14)	0	(66,239)
Noncontrolling partners’ share of RMP earnings	(8,168)	(203)
Goodwill impairment	103,218	0
Incentive unit expense	12,634	37,086
Other, net	1,588	0
Income tax expense	$ 12,118	$ 91,600	$ 0
Effective tax rate	(4.74%)	29.49%

Income Taxes (Schedule of Com86

Income Taxes (Schedule of Components of Deferred Tax Assets and Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Deferred income taxes:
Total deferred tax assets	$ 0	$ 0
Total deferred tax liabilities	(271,988)	(263,906)
Total net deferred tax liabilities	(271,988)	(263,906)
Principal components of deferred tax assets and liabilities:
Drilling and development costs expensed for tax	(294,972)	(189,475)
Tax depreciation in excess of book depreciation	(92,710)	(24,252)
Investment in partnerships	57,227	38,077
Incentive compensation	5,576	2,263
Net operating loss carryforwards	153,558	0
Hedging loss	(109,352)	(80,663)
AMT tax credit	7,999	3,961
Other	686	(13,817)
Total net deferred tax liabilities	$ (271,988)	$ (263,906)

Related Party Transactions (Det

Related Party Transactions (Details) a in Thousands, MMBTU in Thousands, $ in Millions	Nov. 04, 2015	Dec. 22, 2014a$ / MMBTU	Dec. 31, 2015MMBTU	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Gas Gathering and Compression Agreement
Related Party Transaction [Line Items]
Duration of fixed fee gas gathering and compression agreement		15 years
Gross acres covered | a		93
Gas Gathering and Compression Agreement, Gathering Fee | Gas Gathering and Compression Agreement
Related Party Transaction [Line Items]
Gathering fee (per Dth) | $ / MMBTU		0.30
Gas Gathering and Compression Agreement, Compression Fee | Gas Gathering and Compression Agreement
Related Party Transaction [Line Items]
Gathering fee (per Dth) | $ / MMBTU		0.07
Gross Acres subject to Pre-existing Third Party Dedication
Related Party Transaction [Line Items]
Gross acres covered | a		19
Production from acres subject to pre-existing third-party dedication (Mdth/d) | MMBTU			40
Rice Partners | Reimbursements to Rice Partners for Expenses Incurred on behalf of the Company
Related Party Transaction [Line Items]
General and administrative expenses incurred | $				$ 1.8	$ 9.3
Rice Partners | PA and OH Water Disposition
Related Party Transaction [Line Items]
Fixed margin percentage under Water Services Agreements	2.00%
Marcellus Joint Venture | Marcellus Joint Venture | Reimbursement for Costs Incurred on behalf of Marcellus Joint Venture
Related Party Transaction [Line Items]
General and administrative expenses incurred | $				$ 0.3	$ 1.6

Subsequent Event (Narrative) (D

Subsequent Event (Narrative) (Details) a in Thousands	Feb. 22, 2016USD ($)occasionshares	Feb. 01, 2016USD ($)a	Jan. 13, 2016	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Subsequent Event [Line Items]
Aggregate consideration				$ 171,902,000
Remaining proceeds to be distributed to the company				$ 171,902,000	$ 441,739,000	$ 0
Subsequent Event | Strike Force Midstream LLC | Strike Force Midstream LLC
Subsequent Event [Line Items]
Initial contribution		$ 41,000,000
Membership interest percentage		75.00%
Subsequent Event | Strike Force Midstream LLC | Strike Force Midstream LLC | Belmont and Monroe Counties, Ohio | Natural Gas
Subsequent Event [Line Items]
Number of acres for natural gas midstream business | a		319
Subsequent Event | Gulfport Midstream | Strike Force Midstream LLC
Subsequent Event [Line Items]
Membership interest percentage		25.00%
Subsequent Event | Midstream Holdings
Subsequent Event [Line Items]
Number of occasions | occasion	3
Subsequent Event | Midstream Holdings | Minimum
Subsequent Event [Line Items]
Amount required to purchase under securities purchase agreement	$ 25,000,000
Subsequent Event | Midstream Holdings | Maximum
Subsequent Event [Line Items]
Amount required to purchase under securities purchase agreement	$ 125,000,000
Subsequent Event | Midstream Holdings | Private Placement
Subsequent Event [Line Items]
Period after closing date	18 months
Commitment fee percentage	2.00%
Reduction in outstanding borrowings under credit facility	$ 75,000,000
Remaining proceeds to be distributed to the company	$ 300,000,000
Subsequent Event | Midstream Holdings | Midstream Holdings | Series B Units
Subsequent Event [Line Items]
Number of Series B Units | shares	375,000
Subsequent Event | Midstream Holdings | Midstream Holdings | Private Placement | Series B Units
Subsequent Event [Line Items]
Aggregate liquidation preference	$ 375,000,000
Subsequent Event | GP Holdings | GP Holdings | Common Units
Subsequent Event [Line Items]
Aggregate consideration	$ 375,000,000
Subsequent Event | GP Holdings | GP Holdings | Private Placement | Common Units
Subsequent Event [Line Items]
Limited partner interest percentage	8.25%
Subsequent Event | Revolving Credit Facility | Senior Secured Revolving Credit Facility | Wells Fargo
Subsequent Event [Line Items]
Period after any commodity swap agreement or secured firm transportation reimbursement agreement			18 months

Guarantor Financial Informati89

Guarantor Financial Information (Narrative) (Details) - Senior Notes - USD ($) $ in Millions	Mar. 26, 2015	Apr. 25, 2014
Senior Notes Due 2022
Condensed Financial Statements, Captions [Line Items]
Aggregate principal amounts of debt offered		$ 900
Senior Notes Due 2023
Condensed Financial Statements, Captions [Line Items]
Aggregate principal amounts of debt offered	$ 400

Guarantor Financial Informati90

Guarantor Financial Information (Condensed Balance Sheets) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current assets:
Cash	$ 151,901	$ 256,130	$ 31,612	$ 8,547
Accounts receivable	154,814	199,900
Receivable from affiliate	0	88
Prepaid expenses and other assets	5,488	3,339
Derivative instruments	186,960	133,034
Deferred tax assets	0
Total current assets	499,163	592,491
Gas collateral account	4,077	3,995
Investments in subsidiaries	0	0
Property, plant and equipment, net	3,243,131	2,461,331
Deferred financing costs, net	30,244	25,103
Goodwill	39,142	334,050
Intangible assets, net	46,159	47,791
Other non-current assets	108,615
Derivative instruments	105,945	63,188
Total assets	3,970,531	3,527,949	879,810
Current liabilities:
Current portion of long-term debt	0	680
Accounts payable	83,553	152,329
Royalties payable	40,572	37,172
Accrued capital expenditures	79,747	108,290
Leasehold payable	17,338	30,702
Deferred tax liabilities	0	54,688
Other accrued liabilities	79,132	52,814
Total current liabilities	300,342	436,675
Long-term liabilities:
Long-term debt	1,457,222	900,000
Leasehold payable	6,289	4,279
Deferred tax liabilities	271,988	209,218
Other long-term liabilities	13,878	12,609
Other long-term liabilities	30,222
Total liabilities	2,066,063	1,562,781
Stockholders’ equity before noncontrolling interest	1,279,897	1,522,710
Noncontrolling interests in consolidated subsidiaries	624,571	442,458
Total liabilities and stockholders’ equity	3,970,531	3,527,949
Reportable Legal Entities | Parent
Current assets:
Cash	78,474	181,835	0	0
Accounts receivable	147	1,773
Receivable from affiliate	27,670	634
Prepaid expenses and other assets	4,377	1,296
Derivative instruments	47,262	47,291
Deferred tax assets	0
Total current assets	157,930	232,829
Gas collateral account	0	0
Investments in subsidiaries	2,378,293	2,177,895
Property, plant and equipment, net	21,442	10,348
Deferred financing costs, net	25,329	20,081
Goodwill	0	0
Intangible assets, net	0	0
Other non-current assets	32,590
Derivative instruments		8,290
Total assets	2,615,584	2,449,443
Current liabilities:
Current portion of long-term debt		0
Accounts payable	4,178	19,231
Royalties payable	0	0
Accrued capital expenditures	0	1,515
Leasehold payable	0	0
Deferred tax liabilities		54,688
Other accrued liabilities	36,287	26,027
Total current liabilities	40,465	101,461
Long-term liabilities:
Long-term debt	1,297,222	900,000
Leasehold payable	0	0
Deferred tax liabilities	47,667	12,497
Other long-term liabilities		3,068
Other long-term liabilities	19,432
Total liabilities	1,404,786	1,017,026
Stockholders’ equity before noncontrolling interest	1,210,798	1,432,417
Noncontrolling interests in consolidated subsidiaries	0	0
Total liabilities and stockholders’ equity	2,615,584	2,449,443
Reportable Legal Entities | Guarantors
Current assets:
Cash	57,800	41,934	31,408	8,541
Accounts receivable	140,493	196,974
Receivable from affiliate	0	55
Prepaid expenses and other assets	817	1,702
Derivative instruments	139,698	85,743
Deferred tax assets	0
Total current assets	338,808	326,408
Gas collateral account	3,995	3,995
Investments in subsidiaries	113,268	86,148
Property, plant and equipment, net	2,382,878	1,986,856
Deferred financing costs, net	0	0
Goodwill	0	294,908
Intangible assets, net	0	0
Other non-current assets	76,025
Derivative instruments		54,898
Total assets	2,914,974	2,753,213
Current liabilities:
Current portion of long-term debt		680
Accounts payable	48,191	101,132
Royalties payable	40,572	37,172
Accrued capital expenditures	45,240	89,858
Leasehold payable	17,338	30,702
Deferred tax liabilities		39,197
Other accrued liabilities	71,649	27,502
Total current liabilities	222,990	326,243
Long-term liabilities:
Long-term debt	0	0
Leasehold payable	6,289	4,279
Deferred tax liabilities	299,741	237,155
Other long-term liabilities		7,641
Other long-term liabilities	7,661
Total liabilities	536,681	575,318
Stockholders’ equity before noncontrolling interest	2,378,293	2,177,895
Noncontrolling interests in consolidated subsidiaries	0	0
Total liabilities and stockholders’ equity	2,914,974	2,753,213
Reportable Legal Entities | Non-Guarantors
Current assets:
Cash	15,627	32,361	204	6
Accounts receivable	14,174	1,153
Receivable from affiliate	4,501	2,198
Prepaid expenses and other assets	294	341
Derivative instruments	0	0
Deferred tax assets	0
Total current assets	34,596	36,053
Gas collateral account	82	0
Investments in subsidiaries	0	0
Property, plant and equipment, net	865,043	464,127
Deferred financing costs, net	4,915	5,022
Goodwill	39,142	39,142
Intangible assets, net	46,159	47,791
Other non-current assets	0
Derivative instruments		0
Total assets	989,937	592,135
Current liabilities:
Current portion of long-term debt		0
Accounts payable	31,184	31,966
Royalties payable	0	0
Accrued capital expenditures	34,507	16,917
Leasehold payable	0	0
Deferred tax liabilities		0
Other accrued liabilities	3,367	2,086
Total current liabilities	69,058	50,969
Long-term liabilities:
Long-term debt	160,000	0
Leasehold payable	0	0
Deferred tax liabilities	19,911	10,660
Other long-term liabilities		1,900
Other long-term liabilities	3,129
Total liabilities	252,098	63,529
Stockholders’ equity before noncontrolling interest	113,268	86,148
Noncontrolling interests in consolidated subsidiaries	624,571	442,458
Total liabilities and stockholders’ equity	989,937	592,135
Eliminations
Current assets:
Cash	0	0	$ 0	$ 0
Accounts receivable	0	0
Receivable from affiliate	(32,171)	(2,799)
Prepaid expenses and other assets	0	0
Derivative instruments	0	0
Deferred tax assets	0
Total current assets	(32,171)	(2,799)
Gas collateral account	0	0
Investments in subsidiaries	(2,491,561)	(2,264,043)
Property, plant and equipment, net	(26,232)	0
Deferred financing costs, net	0	0
Goodwill	0	0
Intangible assets, net	0	0
Other non-current assets	0
Derivative instruments		0
Total assets	(2,549,964)	(2,266,842)
Current liabilities:
Current portion of long-term debt		0
Accounts payable	0	0
Royalties payable	0	0
Accrued capital expenditures	0	0
Leasehold payable	0	0
Deferred tax liabilities		(39,197)
Other accrued liabilities	(32,171)	(2,801)
Total current liabilities	(32,171)	(41,998)
Long-term liabilities:
Long-term debt	0	0
Leasehold payable	0	0
Deferred tax liabilities	(95,331)	(51,094)
Other long-term liabilities		0
Other long-term liabilities	0
Total liabilities	(127,502)	(93,092)
Stockholders’ equity before noncontrolling interest	(2,422,462)	(2,173,750)
Noncontrolling interests in consolidated subsidiaries	0	0
Total liabilities and stockholders’ equity	$ (2,549,964)	$ (2,266,842)

Guarantor Financial Informati91

Guarantor Financial Information (Condensed Statement of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended																12 Months Ended
	Dec. 31, 2015	[1]	Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014	[1]	Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	$ 446,515	$ 359,201	$ 87,847
Firm transportation sales, net																	3,450	26,237	0
Gathering, compression and water services																	49,179	5,504	83
Other revenue																	2,997	0	757
Total operating revenues	$ 136,088		$ 143,621		$ 112,894		$ 109,539		$ 129,398		$ 79,128		$ 91,940		$ 90,477		502,141	390,942	88,687
Operating expenses:
Lease operating																	44,356	24,971	8,309
Gathering, compression and transportation																	84,707	35,618	8,362
Production taxes and impact fees																	7,609	4,647	1,629
Exploration																	3,137	4,018	9,951
Midstream operation and maintenance																	16,988	4,607	1,412
Incentive unit expense																	36,097	105,961	0
Impairment of gas properties																	18,250	0	0
Impairment of goodwill																	294,908	0	0
Restricted unit expense																	0	0	32,906
General and administrative expenses																	103,038	61,570	16,953
Depreciation, depletion and amortization																	322,784	156,270	32,815
Acquisition expense																	1,235	2,339	0
Amortization of intangible assets																	1,632	1,156	0
(Gain) loss from sale of interest in gas properties																	(953)	0	4,230
Other expense																	6,520	207	0
Total operating expenses	480,329		160,295		159,065		140,619		118,118		91,453		67,522		124,272		940,308	401,364	116,567
Operating loss	(344,241)		(16,674)		(46,171)		(31,080)		11,280		(12,325)		24,418		(33,795)		(438,167)	(10,422)	(27,880)
Interest expense																	(87,446)	(50,191)	(17,915)
Gain on purchase of Marcellus joint venture																	0	203,579	0
Other income (loss)																	1,108	893	(440)
Gain on derivative instruments																	273,748	186,477	6,891
Amortization of deferred financing costs																	(5,124)	(2,495)	(5,230)
Loss on extinguishment of debt																	0	(7,654)	(10,622)
Write-off of deferred financing costs																	0	(6,896)	0
Equity in income (loss) of joint ventures and subsidiaries																	0	(2,656)	19,420
(Loss) income before income taxes																	(255,881)	310,635	(35,776)
Income tax expense																	(12,118)	(91,600)	0
Net (loss) income	(274,251)		65,084		(63,519)		4,687		104,360		(6,861)		(7,917)		129,454		(267,999)	219,035	(35,776)
Less: Net income attributable to noncontrolling interests																	(23,337)	(581)	0
Net (loss) income attributable to Rice Energy Inc.	$ (280,755)		$ 58,950		$ (69,683)		$ 152		$ 103,779		$ (6,861)		$ (7,917)		$ 129,454		(291,336)	218,454	(35,776)
Reportable Legal Entities | Parent
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	0	0	0
Firm transportation sales, net																	0	0
Gathering, compression and water services																	0	0	0
Other revenue																	0		0
Total operating revenues																	0	0	0
Operating expenses:
Lease operating																	0	0	0
Gathering, compression and transportation																	0	0	0
Production taxes and impact fees																	0	0	0
Exploration																	0	0	0
Midstream operation and maintenance																	0	0	0
Incentive unit expense																	0	0
Impairment of gas properties																	0
Impairment of goodwill																	0
Restricted unit expense																			0
General and administrative expenses																	0	0	0
Depreciation, depletion and amortization																	0	0	0
Acquisition expense																	4	0
Amortization of intangible assets																	0	0
(Gain) loss from sale of interest in gas properties																	0		0
Other expense																	0	0
Total operating expenses																	4	0	0
Operating loss																	(4)	0	0
Interest expense																	(82,664)	(27,177)	0
Gain on purchase of Marcellus joint venture																		0
Other income (loss)																	617	247	0
Gain on derivative instruments																	68,247	55,580	0
Amortization of deferred financing costs																	(4,072)	(2,006)	0
Loss on extinguishment of debt																		0	0
Write-off of deferred financing costs																		0
Equity in income (loss) of joint ventures and subsidiaries																	(296,335)	193,119	0
(Loss) income before income taxes																	(314,211)	219,763	0
Income tax expense																	(12,118)	(91,600)
Net (loss) income																	(326,329)	128,163
Less: Net income attributable to noncontrolling interests																	0	0
Net (loss) income attributable to Rice Energy Inc.																	(326,329)	128,163
Reportable Legal Entities | Guarantors
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	446,515	359,201	87,847
Firm transportation sales, net																	3,450	26,237
Gathering, compression and water services																	0	0	0
Other revenue																	2,997		763
Total operating revenues																	452,962	385,438	88,610
Operating expenses:
Lease operating																	44,356	24,971	8,309
Gathering, compression and transportation																	150,015	37,180	8,362
Production taxes and impact fees																	7,609	4,647	1,629
Exploration																	3,137	4,018	9,951
Midstream operation and maintenance																	0	0	0
Incentive unit expense																	33,873	86,020
Impairment of gas properties																	18,250
Impairment of goodwill																	294,908
Restricted unit expense																			32,906
General and administrative expenses																	78,592	45,268	16,636
Depreciation, depletion and amortization																	304,703	153,282	32,421
Acquisition expense																	103	820
Amortization of intangible assets																	0	0
(Gain) loss from sale of interest in gas properties																	(953)		4,230
Other expense																	6,028	0
Total operating expenses																	940,621	356,206	114,444
Operating loss																	(487,659)	29,232	(25,834)
Interest expense																	(166)	(10,130)	(17,915)
Gain on purchase of Marcellus joint venture																		203,579
Other income (loss)																	439	755	(357)
Gain on derivative instruments																	205,501	130,897	6,891
Amortization of deferred financing costs																	0	(489)	(5,230)
Loss on extinguishment of debt																		(7,654)	(10,622)
Write-off of deferred financing costs																		(6,896)
Equity in income (loss) of joint ventures and subsidiaries																	10,145	(47,208)	17,848
(Loss) income before income taxes																	(271,740)	292,086	(35,219)
Income tax expense																	(25,699)	(98,731)
Net (loss) income																	(297,439)	193,355
Less: Net income attributable to noncontrolling interests																	0	0
Net (loss) income attributable to Rice Energy Inc.																	(297,439)	193,355
Reportable Legal Entities | Non-Guarantors
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	0	0	0
Firm transportation sales, net																	0	0
Gathering, compression and water services																	141,823	7,300	83
Other revenue																	0		(6)
Total operating revenues																	141,823	7,300	77
Operating expenses:
Lease operating																	0	0	0
Gathering, compression and transportation																	0	0	0
Production taxes and impact fees																	0	0	0
Exploration																	0	0	0
Midstream operation and maintenance																	16,988	4,607	1,412
Incentive unit expense																	2,224	19,941
Impairment of gas properties																	0
Impairment of goodwill																	0
Restricted unit expense																			0
General and administrative expenses																	24,446	16,302	317
Depreciation, depletion and amortization																	19,185	2,988	394
Acquisition expense																	1,128	1,519
Amortization of intangible assets																	1,632	1,156
(Gain) loss from sale of interest in gas properties																	0		0
Other expense																	492	207
Total operating expenses																	66,095	46,720	2,123
Operating loss																	75,728	(39,420)	(2,046)
Interest expense																	(4,616)	(12,884)	0
Gain on purchase of Marcellus joint venture																		0
Other income (loss)																	52	(109)	(83)
Gain on derivative instruments																	0	0	0
Amortization of deferred financing costs																	(1,052)	0	0
Loss on extinguishment of debt																		0	0
Write-off of deferred financing costs																		0
Equity in income (loss) of joint ventures and subsidiaries																	0	0	0
(Loss) income before income taxes																	70,112	(52,413)	(2,129)
Income tax expense																	(9,295)	8,440
Net (loss) income																	60,817	(43,973)
Less: Net income attributable to noncontrolling interests																	(23,337)	(581)
Net (loss) income attributable to Rice Energy Inc.																	37,480	(44,554)
Eliminations
Operating revenues:
Natural gas, oil and natural gas liquids (NGL) sales																	0	0	0
Firm transportation sales, net																	0	0
Gathering, compression and water services																	(92,644)	(1,796)	0
Other revenue																	0		0
Total operating revenues																	(92,644)	(1,796)	0
Operating expenses:
Lease operating																	0	0	0
Gathering, compression and transportation																	(65,308)	(1,562)	0
Production taxes and impact fees																	0	0	0
Exploration																	0	0	0
Midstream operation and maintenance																	0	0	0
Incentive unit expense																	0	0
Impairment of gas properties																	0
Impairment of goodwill																	0
Restricted unit expense																			0
General and administrative expenses																	0	0	0
Depreciation, depletion and amortization																	(1,104)	0	0
Acquisition expense																	0	0
Amortization of intangible assets																	0	0
(Gain) loss from sale of interest in gas properties																	0		0
Other expense																	0	0
Total operating expenses																	(66,412)	(1,562)	0
Operating loss																	(26,232)	(234)	0
Interest expense																	0	0	0
Gain on purchase of Marcellus joint venture																		0
Other income (loss)																	0	0	0
Gain on derivative instruments																	0	0	0
Amortization of deferred financing costs																	0	0	0
Loss on extinguishment of debt																		0	0
Write-off of deferred financing costs																		0
Equity in income (loss) of joint ventures and subsidiaries																	286,190	(148,567)	1,572
(Loss) income before income taxes																	259,958	(148,801)	$ 1,572
Income tax expense																	34,994	90,291
Net (loss) income																	294,952	(58,510)
Less: Net income attributable to noncontrolling interests																	0	0
Net (loss) income attributable to Rice Energy Inc.																	$ 294,952	$ (58,510)
[1]	The sum of quarterly data in some cases may not equal the yearly total due to rounding.

Guarantor Financial Informati92

Guarantor Financial Information (Condensed Statement of Cash Flows) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	$ 412,987	$ 85,075	$ 33,672
Cash flows from investing activities:
Capital expenditures for property and equipment	(1,246,274)	(970,274)	(465,387)
Investment in subsidiaries	0
Acquisition of Greene County assets	19,054	(329,469)	0
Acquisition of Marcellus joint venture, net of cash acquired	0	(82,766)	0
Acquisition of Momentum assets	0	(111,847)	0
Proceeds from sale of interest in gas properties	10,201	12,891	6,792
Net cash used in investing activities	(1,217,019)	(1,481,465)	(458,595)
Cash flows from financing activities:
Proceeds from borrowings	913,932	1,090,000	435,500
Repayments of debt obligations	(358,619)	(689,873)	(160,760)
Distributions to the Partnership’s public unitholders	(17,017)	0	0
Restricted cash for convertible debt	0	8,268	(8,268)
Debt issuance costs	(10,266)	(24,543)	(12,194)
Proceeds from conversion of warrants	0	1,975	0
Proceeds from issuance of common stock sold in our IPO, net of offering costs	(129)	597,088	0
Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of offering costs	0	196,254	0
Proceeds from issuance of common units sold by RMP, net of offering costs	171,902	441,739	0
Contributions from parent, net	0	0
Common stock issuance	0	0	195,977
Repurchase of common stock	0	0	(2,267)
Net cash provided by financing activities	699,803	1,620,908	447,988
Net (decrease) increase in cash	(104,229)	224,518	23,065
Cash at the beginning of the year	256,130	31,612	8,547
Cash at the end of the year	151,901	256,130	31,612
Reportable Legal Entities | Parent
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	(59,213)	16,139	0
Cash flows from investing activities:
Capital expenditures for property and equipment	(9,775)	(8,588)	0
Investment in subsidiaries	(421,063)
Acquisition of Greene County assets	0	0
Acquisition of Marcellus joint venture, net of cash acquired		0
Acquisition of Momentum assets		0
Proceeds from sale of interest in gas properties	0	0	0
Net cash used in investing activities	(430,838)	(8,588)	0
Cash flows from financing activities:
Proceeds from borrowings	411,932	900,000	0
Repayments of debt obligations	(15,922)	0	0
Distributions to the Partnership’s public unitholders	0
Restricted cash for convertible debt		0	0
Debt issuance costs	(9,320)	(19,522)	0
Proceeds from conversion of warrants		1,975
Proceeds from issuance of common stock sold in our IPO, net of offering costs	0	597,088
Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of offering costs		196,254
Proceeds from issuance of common units sold by RMP, net of offering costs	0	0
Contributions from parent, net	0	(1,501,511)
Common stock issuance			0
Repurchase of common stock			0
Net cash provided by financing activities	386,690	174,284	0
Net (decrease) increase in cash	(103,361)	181,835	0
Cash at the beginning of the year	181,835	0	0
Cash at the end of the year	78,474	181,835	0
Reportable Legal Entities | Guarantors
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	413,989	96,147	34,428
Cash flows from investing activities:
Capital expenditures for property and equipment	(859,359)	(684,541)	(406,179)
Investment in subsidiaries	11,614
Acquisition of Greene County assets	19,054	(329,469)
Acquisition of Marcellus joint venture, net of cash acquired		(27,766)
Acquisition of Momentum assets		(400)
Proceeds from sale of interest in gas properties	10,201	12,891	6,792
Net cash used in investing activities	(818,490)	(1,029,285)	(399,387)
Cash flows from financing activities:
Proceeds from borrowings	0	190,000	435,500
Repayments of debt obligations	(697)	(689,873)	(160,760)
Distributions to the Partnership’s public unitholders	0
Restricted cash for convertible debt		8,268	(8,268)
Debt issuance costs	0	0	(12,194)
Proceeds from conversion of warrants		0
Proceeds from issuance of common stock sold in our IPO, net of offering costs	0	0
Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of offering costs		0
Proceeds from issuance of common units sold by RMP, net of offering costs	0	0
Contributions from parent, net	421,064	1,435,269
Common stock issuance			135,815
Repurchase of common stock			(2,267)
Net cash provided by financing activities	420,367	943,664	387,826
Net (decrease) increase in cash	15,866	10,526	22,867
Cash at the beginning of the year	41,934	31,408	8,541
Cash at the end of the year	57,800	41,934	31,408
Reportable Legal Entities | Non-Guarantors
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	85,547	(27,211)	(756)
Cash flows from investing activities:
Capital expenditures for property and equipment	(404,476)	(277,145)	(59,208)
Investment in subsidiaries	0
Acquisition of Greene County assets	0	0
Acquisition of Marcellus joint venture, net of cash acquired		(55,000)
Acquisition of Momentum assets		(111,447)
Proceeds from sale of interest in gas properties	0	0	0
Net cash used in investing activities	(404,476)	(443,592)	(59,208)
Cash flows from financing activities:
Proceeds from borrowings	502,000	0	0
Repayments of debt obligations	(342,000)	0	0
Distributions to the Partnership’s public unitholders	(17,017)
Restricted cash for convertible debt		0	0
Debt issuance costs	(946)	(5,021)	0
Proceeds from conversion of warrants		0
Proceeds from issuance of common stock sold in our IPO, net of offering costs	(129)	0
Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of offering costs		0
Proceeds from issuance of common units sold by RMP, net of offering costs	171,902	441,739
Contributions from parent, net	(11,615)	66,242
Common stock issuance			60,162
Repurchase of common stock			0
Net cash provided by financing activities	302,195	502,960	60,162
Net (decrease) increase in cash	(16,734)	32,157	198
Cash at the beginning of the year	32,361	204	6
Cash at the end of the year	15,627	32,361	204
Eliminations
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by (used in) operating activities	(27,336)	0	0
Cash flows from investing activities:
Capital expenditures for property and equipment	27,336	0	0
Investment in subsidiaries	409,449
Acquisition of Greene County assets	0	0
Acquisition of Marcellus joint venture, net of cash acquired		0
Acquisition of Momentum assets		0
Proceeds from sale of interest in gas properties	0	0	0
Net cash used in investing activities	436,785	0	0
Cash flows from financing activities:
Proceeds from borrowings	0	0	0
Repayments of debt obligations	0	0	0
Distributions to the Partnership’s public unitholders	0
Restricted cash for convertible debt		0	0
Debt issuance costs	0	0	0
Proceeds from conversion of warrants		0
Proceeds from issuance of common stock sold in our IPO, net of offering costs	0	0
Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of offering costs		0
Proceeds from issuance of common units sold by RMP, net of offering costs	0	0
Contributions from parent, net	(409,449)	0
Common stock issuance			0
Repurchase of common stock			0
Net cash provided by financing activities	(409,449)	0	0
Net (decrease) increase in cash	0	0	0
Cash at the beginning of the year	0	0	0
Cash at the end of the year	$ 0	$ 0	$ 0

Quarterly Financial Informati93

Quarterly Financial Information (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended																12 Months Ended
	Dec. 31, 2015	[1]	Sep. 30, 2015	[1]	Jun. 30, 2015	[1]	Mar. 31, 2015	[1]	Dec. 31, 2014	[1]	Sep. 30, 2014	[1]	Jun. 30, 2014	[1]	Mar. 31, 2014	[1]	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]
Total operating revenues	$ 136,088		$ 143,621		$ 112,894		$ 109,539		$ 129,398		$ 79,128		$ 91,940		$ 90,477		$ 502,141	$ 390,942	$ 88,687
Total operating expenses	480,329		160,295		159,065		140,619		118,118		91,453		67,522		124,272		940,308	401,364	116,567
Operating loss	(344,241)		(16,674)		(46,171)		(31,080)		11,280		(12,325)		24,418		(33,795)		(438,167)	(10,422)	(27,880)
Net (loss) income	(274,251)		65,084		(63,519)		4,687		104,360		(6,861)		(7,917)		129,454		(267,999)	219,035	(35,776)
Net (loss) income attributable to Rice Energy Inc.	$ (280,755)		$ 58,950		$ (69,683)		$ 152		$ 103,779		$ (6,861)		$ (7,917)		$ 129,454		$ (291,336)	$ 218,454	$ (35,776)
(Loss) earnings per share—basic	$ (2.06)		$ 0.43		$ (0.51)		$ 0		$ 0.76		$ (0.05)		$ (0.06)		$ 1.04		$ (2.14)	$ 1.70	$ (0.44)
(Loss) earnings per share—diluted	$ (2.06)		$ 0.43		$ (0.51)		$ 0		$ 0.76		$ (0.05)		$ (0.06)		$ 1.03		$ (2.14)	$ 1.70	$ (0.44)
[1]	The sum of quarterly data in some cases may not equal the yearly total due to rounding.

Supplemental Information on G94

Supplemental Information on Gas Producing Activities (Unaudited) (Capitalized Costs Relating to Gas Producing Activities) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Extractive Industries [Abstract]
Proved properties	$ 1,811,279	$ 1,195,274
Unproved properties	1,071,523	1,003,449
Gross capitalized costs	2,882,802	2,198,723
Accumulated depreciation and depletion	(501,958)	(215,905)
Net capitalized costs	$ 2,380,844	$ 1,982,818

Supplemental Information on G95

Supplemental Information on Gas Producing Activities (Unaudited) (Costs Incurred for Property Acquisitions, Exploration and Development) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Acquisitions:
Proved leaseholds	$ 0	$ 439,284	$ 0
Unproved leaseholds	100,172	233,185	305,000
Development costs	616,836	734,106	184,217
Exploration costs:
Geological and geophysical	$ 1,276	$ 4,018	9,951
Marcellus Joint Venture
Acquisitions:
Unproved leaseholds			0
Development costs			46,571
Exploration costs:
Geological and geophysical			0
Total costs incurred			$ 46,571

Supplemental Information on G96

Supplemental Information on Gas Producing Activities (Unaudited) (Results of Operations Related to Natural Gas Production) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Revenues	$ 452,962	$ 385,438	$ 88,106
Production costs	201,980	67,032	18,300
Exploration costs	3,137	4,018	9,951
Depreciation, depletion and amortization	308,194	151,900	31,467
Incentive unit expense	33,873	86,020	0
Restricted unit expense	0	0	32,906
Impairment of oil and gas properties	18,250	0	0
Impairment of goodwill	294,908	0	0
Acquisition costs	108	820	0
(Gain) loss from sale of interest in gas properties	(953)	0	4,230
Other expense	6,028	0	0
General and administrative expenses	78,592	46,229	13,778
Income tax expense	6,039	38,871	0
Results of operations from producing activities	$ (497,194)	$ (9,452)	(22,526)
Marcellus Joint Venture
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]
Revenues			45,339
Production costs			12,557
Depreciation, depletion and amortization			12,500
Impairment of oil and gas properties			0
General and administrative expenses			1,557
Results of operations from producing activities			$ 18,725

Supplemental Information on G97

Supplemental Information on Gas Producing Activities (Unaudited) (Reserve Quantity Information) (Details) Mcfe in Thousands	12 Months Ended
	Dec. 31, 2015Mcfe	Dec. 31, 2014McfeMMcf		Dec. 31, 2013McfeMMcf		Dec. 31, 2012McfeMMcf		Jan. 29, 2014
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Beginning of year	1,306,571	382,660	[1]	304,272	[1]
Acquisitions	0	282,391				0	[1]
Extensions and discoveries	869,038	692,239				100,626	[1]
Revision of previous estimates	(274,249)	47,018				757	[1]
Production	(201,328)	(97,737)				(22,995)	[1]
End of year	1,700,032	1,306,571		382,660	[1]	304,272	[1]
Proved Developed Reserves [Abstract]
Proved developed reserves:	1,014,873	644,149		144,309	[1]
Proved Undeveloped Reserves [Abstract]
Proved undeveloped reserves:	685,159	662,422		238,351	[1]
Marcellus Joint Venture
Proved Developed and Undeveloped Reserves [Abstract]
Beginning of year | MMcf		109,684		128,118
Extensions and discoveries | MMcf				19,812
Revision of previous estimates | MMcf				(26,803)
Production | MMcf				(11,443)
End of year | MMcf				109,684		128,118
Proved Developed Reserves [Abstract]
Proved developed reserves: | MMcf				52,370
Proved Undeveloped Reserves [Abstract]
Proved undeveloped reserves: | MMcf				57,314
Equity investment ownership percentage				50.00%
Marcellus Joint Venture
Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]
Acquisitions	282,391
Proved Undeveloped Reserves [Abstract]
Interest in Marcellus joint venture acquired		50.00%		50.00%				50.00%
[1]	Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014.

Supplemental Information on G98

Supplemental Information on Gas Producing Activities (Unaudited) (Narrative) (Details) Mcfe in Thousands	12 Months Ended
	Dec. 31, 2015Mcfelocation$ / Mcf	Dec. 31, 2014Mcfe$ / Mcf	Dec. 31, 2013Mcfe$ / McfMMcf	Dec. 31, 2012Mcfe	[1]	Jan. 29, 2014
Gas and Oil Acreage [Line Items]
Acquisitions	0	282,391		0
Extensions and discoveries	869,038	692,239		100,626
Revision of previous estimates	(274,249)	47,018		757
Proved undeveloped reserve locations | location	40
Positive revisions	56,000
Percentage of total net gas proved reserves reviewed by Netherland, Sewell and Associates	100.00%	100.00%	100.00%
Marcellus Joint Venture
Gas and Oil Acreage [Line Items]
Equity investment ownership percentage			50.00%
Added reserves | MMcf			19,812
Net negative revisions of previous estimates | MMcf			26,803
Gas
Gas and Oil Acreage [Line Items]
Adjusted price | $ / Mcf	2.65	4.52	3.91
Gas | Marcellus Joint Venture
Gas and Oil Acreage [Line Items]
Adjusted price | $ / Mcf			3.90
Oil
Gas and Oil Acreage [Line Items]
Adjusted price | $ / Mcf	41.72	85.70
NGL
Gas and Oil Acreage [Line Items]
Adjusted price | $ / Mcf	9.91
Marcellus Shale and Utica Shale
Gas and Oil Acreage [Line Items]
Extensions and discoveries	869,038
Marcellus Shale
Gas and Oil Acreage [Line Items]
Extensions and discoveries		692,239	100,626
Marcellus Joint Venture
Gas and Oil Acreage [Line Items]
Acquisitions	282,391
Interest in Marcellus joint venture acquired		50.00%	50.00%			50.00%
[1]	Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014.

Supplemental Information on G99

Supplemental Information on Gas Producing Activities (Unaudited) (Standardized Measure of Discounted Future Cash Flows Relating to Proved Reserves) (Details) - USD ($) $ in Thousands	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows	$ 4,497,738		$ 5,904,380		$ 1,496,294	[1]
Future production costs	(2,378,541)		(2,161,926)		(517,101)	[1]
Future development costs	(545,988)		(610,179)		(219,879)	[1]
Future income tax expense	0		(745,022)		0	[1]
Future net cash flows	1,573,209		2,387,253		759,314	[1]
10% annual discount for estimated timing of cash flows	(686,936)		(1,079,499)		(342,150)	[1]
Standardized measure of discounted future net cash flows	$ 886,273	[2]	$ 1,307,754	[2]	417,164	[1],[2],[3]	$ 102,218	[3]
Marcellus Joint Venture
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]
Future cash inflows					427,167
Future production costs					(132,427)
Future development costs					(46,344)
Future net cash flows					248,396
10% annual discount for estimated timing of cash flows					(102,293)
Standardized measure of discounted future net cash flows					$ 146,103	[4]	$ 71,077
Equity investment ownership percentage					50.00%
[1]	Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014.
[2]	Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income. Therefore, the cumulative effect of future income tax expense for the periods presented was included at December 31, 2015 and 2014.
[3]	Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014.
[4]	Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income.

Supplemental Information on 100

Supplemental Information on Gas Producing Activities (Unaudited) (Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows) (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013		Jan. 29, 2014
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Balance at beginning of period		$ 1,307,754	[1]	$ 417,164	[1],[2],[3]	$ 102,218	[2]
Net change in prices and production costs		(949,774)		81,558		101,345	[2]
Net change in future development costs		4,251		(181,813)		29,336	[2]
Natural gas and oil net revenues		(312,269)		(291,023)		(68,135)	[2]
Extensions		370,636		930,534		114,489	[2]
Acquisitions		0		375,865	[4]	0	[2]
Revisions of previous quantity estimates		(274,503)		37,435		1,133	[2]
Previously estimated development costs incurred		122,532		62,653		66,894	[2]
Net change in taxes		436,319		(436,319)		0	[2]
Accretion of discount		174,407		70,937		10,230	[2]
Changes in timing and other		6,920		240,763		59,654	[2]
Balance at end of period	[1]	$ 886,273		1,307,754		417,164	[2],[3]
Marcellus Joint Venture
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Balance at beginning of period				$ 146,103	[5]	71,077
Net change in prices and production costs						81,974
Net change in future development costs						2,781
Natural gas and oil net revenues						(32,782)
Extensions						18,950
Revisions of previous quantity estimates						(14,752)
Previously estimated development costs incurred						31,253
Accretion of discount						7,111
Changes in timing and other						(19,509)
Balance at end of period	[5]					$ 146,103
Marcellus Joint Venture
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Interest in Marcellus joint venture acquired				50.00%		50.00%		50.00%
[1]	Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income. Therefore, the cumulative effect of future income tax expense for the periods presented was included at December 31, 2015 and 2014.
[2]	Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014.
[3]	Reflects the balances for Rice Drilling B. Amounts presented in the table exclude amounts attributable to our Marcellus joint venture for periods prior to the completion of our IPO in January 2014.
[4]	Reflects the purchase of the remaining 50% interest in the Marcellus joint venture in January 2014 and the Greene County acreage acquisition in August 2014.
[5]	Does not include the effects of income taxes on future revenues at December 31, 2013 because that period reflects the result of Rice Drilling B, our accounting predecessor, which was and currently is a limited liability company not subject to entity-level taxation. Accordingly, no provision for federal or state corporate income taxes has been provided because taxable income was passed through to Rice Drilling B’s equity holders. However, in connection with the closing of our IPO, as a result of the corporate reorganization, the Company became the sole member of Rice Drilling B. The Company is a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income.