8-K

Derivative Instruments and Hedging Activities Disclosure [Abstract]

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.

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

12 Months Ended

Dec. 31, 2015

Debt Disclosure [Abstract]

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)

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)


•	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;

•


•	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 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)


•	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)

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)

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

12 Months Ended

Dec. 31, 2015

Derivative Instruments

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.



	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 Instruments

12 Months Ended

Dec. 31, 2015

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

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 Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
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 Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
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	$	—	$	—



	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	12 Months Ended
Rice Midstream Partners LP	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	12 Months Ended
Acquisitions	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 Business Segment

12 Months Ended

Dec. 31, 2015

Segment Reporting [Abstract]

Financial Information by Business Segment

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			Rice Midstream Holdings		Rice Midstream Partners		Elimination of Intersegment Transactions			Consolidated Total
Operating revenues	$	452,962		$	27,364	$	114,459	$	(92,644	)	$	502,141
Operating expenses	944,117			13,671		52,423		(69,903		)	940,308
Operating (loss) income	$	(491,155	)	$	13,693	$	62,036	$	(22,741	)	$	(438,167	)

Segment assets	$	3,004,226		$	300,148	$	689,790	$	(23,633	)	$	3,970,531
Goodwill	$	—		$	—	$	39,142	$	—		$	39,142
Depreciation, depletion and amortization	$	308,194		$	2,786	$	16,399	$	(4,595	)	$	322,784
Capital expenditures for segment assets	$	869,134		$	156,013	$	248,463	$	(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		Rice Midstream Holdings			Rice Midstream Partners			Elimination of Intersegment Transactions			Consolidated Total
Operating revenues	$	385,438	$	852		$	6,448		$	(1,796	)	$	390,942
Operating expenses	356,019		10,126			37,015			(1,796		)	401,364
Operating income (loss)	$	29,419	$	(9,274	)	$	(30,567	)	$	—		$	(10,422	)

Segment assets	$	2,935,814	$	149,044		$	443,091		$	—		$	3,527,949
Goodwill	$	294,908	$	—		$	39,142		$	—		$	334,050
Depreciation, depletion and amortization	$	151,900	$	205		$	4,165		$	—		$	156,270
Capital expenditures for segment assets	$	693,129	$	107,319		$	169,826		$	—		$	970,274

The operating results and assets of the Company’s reportable segments were as follows for the year ended December 31, 2013:



(in thousands)	Exploration and Production			Rice Midstream Holdings			Rice Midstream Partners			Elimination of Intersegment Transactions			Consolidated Total
Operating revenues	$	88,604		$	—		$	498		$	(415	)	$	88,687
Operating expenses	111,047			229			5,706			(415		)	116,567
Operating loss	$	(22,443	)	$	(229	)	$	(5,208	)	$	—		$	(27,880	)

Depreciation, depletion and amortization	$	31,467		$	158		$	1,190		$	—		$	32,815
Capital expenditures for segment assets	$	406,179		$	14,964		$	44,244		$	—		$	465,387

Commitments and Contingencies	12 Months Ended
Commitments and Contingencies	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

12 Months Ended

Dec. 31, 2015

Leases [Abstract]

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.

Asset Retirement Obligations

12 Months Ended

Dec. 31, 2015

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

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	12 Months Ended
Stockholders' Equity	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

12 Months Ended

Dec. 31, 2015

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Incentive Units

NGP Holdings

Rice Holdings

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



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

Restricted Stock Unit Awards



	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



	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

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-Based Compensation

12 Months Ended

Dec. 31, 2015

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Stock-Based Compensation

Incentive Units

NGP Holdings

Rice Holdings

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



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

Restricted Stock Unit Awards



	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



	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

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

12 Months Ended

Dec. 31, 2015

Earnings Per Share [Abstract]

Earnings Per Share



	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	)

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

12 Months Ended

Dec. 31, 2015

Income Tax Disclosure [Abstract]

Income Taxes



	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

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		%



	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	)

Based on management’s analysis, the Company did not have any uncertain tax positions as of December 31, 2015.

Related Party Transactions	12 Months Ended
Related Party Transactions	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	12 Months Ended
New Accounting Pronouncements	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	12 Months Ended
Subsequent Event	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. On April 12, 2016, the Company announced that it has entered into a stalking horse asset purchase agreement (“asset purchase agreement”) to acquire Marcellus and Utica Assets in central Greene County, Pennsylvania from Alpha Natural Resources Inc. (“Alpha”) for $200.0 million (the “Alpha Acquisition”). Pursuant to the terms of the asset purchase agreement, the Company will acquire leasehold interest in approximately 27,400 net undeveloped Marcellus acres, plus an additional 3,200 gross acres owned in fee that are currently leased to the Company and generating royalty cash flow. In addition, the aforementioned acreage includes the rights to the deep Utica on 23,500 net acres. Alpha is conducting the sale of the assets pursuant to Section 363 of the United States Bankruptcy Code. The proposed asset purchase agreement constitutes a “stalking horse bid” in accordance with the bidding procedures approved by the bankruptcy court. Although the Company’s stalking horse bid was approved by the bankruptcy court, Alpha may still be required to hold an auction for these assets before the Company can consummate the acquisition. Consummation of the acquisition would be subject to the Company being selected as the successful bidder in any such auction and bankruptcy court approval. On April 15, 2016, the Company issued and completed a public offering (the “April 2016 Equity Offering”) of an aggregate of 29,858,891 shares of common stock at $16.35 per share, which included 20,000,000 shares sold by the Company and 9,858,891 shares sold by NGP Holdings. On April 21, 2016, NGP Holdings sold an additional 4,478,834 shares of common stock pursuant to the exercise of the underwriters option to purchase additional shares. After deducting underwriting discounts and commissions of $15.0 million and transaction costs, the Company received net proceeds of $311.7 million. The Company received no proceeds from the sale of shares by NGP Holdings. The Company intends to use a portion of the net proceeds from this offering to finance the Alpha Acquisition and the remainder for general corporate purposes. If the Alpha Acquisition is not consummated, the Company intends to use the net proceeds for general corporate purposes, which may include funding a portion of its 2017 capital budget.

Guarantor Financial Information

12 Months Ended

Dec. 31, 2015

Condensed Financial Information of Parent Company Only Disclosure [Abstract]

Guarantor Financial Information



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 (Unaudited)

12 Months Ended

Dec. 31, 2015

Quarterly Financial Information Disclosure [Abstract]

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 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

Extensions, Discoveries and Other Additions

Revision of Previous Estimates

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.

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)

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)

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

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)



(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 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 three business segments, which are managed separately due to their distinct operational differences. The Company’s three 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. Rice Midstream Holdings. This segment is engaged in the gathering and compression of natural gas, oil and NGL production of Rice Energy and third parties in Belmont and Monroe counties, Ohio. Rice Midstream Partners. This segment is engaged in the gathering and compression of natural gas, oil and NGL production of Rice Energy and third parties in Washington and Greene counties, Pennsylvania, and in the provision of water services of Rice Energy and third parties in Washington and Greene counties, Pennsylvania and Belmont County, Ohio to support well completion activities. 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 three segments: (i) the Exploration and Production segment (ii) the RMH segment and (iii) the RMP segment. Operating 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 as of December 31, 2015. As discussed in Note 9, and effective with the Company’s change in operating segments, the Company’s reporting units for purposes of our annual goodwill impairment evaluation will be (i) Exploration and Production; (ii) Ohio Gathering and Compression; (iii) Pennsylvania Gathering and Compression; and (iv) Water Services for future periods.
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 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 (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)

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)

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)

7.25% Senior Notes Due 2023 (b)


•	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;

•


•	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 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)


•	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)

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)

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)

12 Months Ended

Dec. 31, 2015

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Offsetting Assets



	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



	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 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 Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
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 Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
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



	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 Business Segment (Tables)

12 Months Ended

Dec. 31, 2015

Segment Reporting [Abstract]

Operating Results and Assets of Reportable Segments

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			Rice Midstream Holdings		Rice Midstream Partners		Elimination of Intersegment Transactions			Consolidated Total
Operating revenues	$	452,962		$	27,364	$	114,459	$	(92,644	)	$	502,141
Operating expenses	944,117			13,671		52,423		(69,903		)	940,308
Operating (loss) income	$	(491,155	)	$	13,693	$	62,036	$	(22,741	)	$	(438,167	)

Segment assets	$	3,004,226		$	300,148	$	689,790	$	(23,633	)	$	3,970,531
Goodwill	$	—		$	—	$	39,142	$	—		$	39,142
Depreciation, depletion and amortization	$	308,194		$	2,786	$	16,399	$	(4,595	)	$	322,784
Capital expenditures for segment assets	$	869,134		$	156,013	$	248,463	$	(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		Rice Midstream Holdings			Rice Midstream Partners			Elimination of Intersegment Transactions			Consolidated Total
Operating revenues	$	385,438	$	852		$	6,448		$	(1,796	)	$	390,942
Operating expenses	356,019		10,126			37,015			(1,796		)	401,364
Operating income (loss)	$	29,419	$	(9,274	)	$	(30,567	)	$	—		$	(10,422	)

Segment assets	$	2,935,814	$	149,044		$	443,091		$	—		$	3,527,949
Goodwill	$	294,908	$	—		$	39,142		$	—		$	334,050
Depreciation, depletion and amortization	$	151,900	$	205		$	4,165		$	—		$	156,270
Capital expenditures for segment assets	$	693,129	$	107,319		$	169,826		$	—		$	970,274

The operating results and assets of the Company’s reportable segments were as follows for the year ended December 31, 2013:



(in thousands)	Exploration and Production			Rice Midstream Holdings			Rice Midstream Partners			Elimination of Intersegment Transactions			Consolidated Total
Operating revenues	$	88,604		$	—		$	498		$	(415	)	$	88,687
Operating expenses	111,047			229			5,706			(415		)	116,567
Operating loss	$	(22,443	)	$	(229	)	$	(5,208	)	$	—		$	(27,880	)

Depreciation, depletion and amortization	$	31,467		$	158		$	1,190		$	—		$	32,815
Capital expenditures for segment assets	$	406,179		$	14,964		$	44,244		$	—		$	465,387

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 (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)

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-Based 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)

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 (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 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



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 (Unaudited) (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 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)

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)

Cost Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Disclosure

Reserve Quantities [Line Items]

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)

Schedule of Changes in 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 Accounting Policies and Related Matters (Narrative) (Details) $ / shares in Units, $ in Thousands			1 Months Ended	12 Months Ended
	Dec. 22, 2014 USD ($) $ / shares shares	Jan. 29, 2014 USD ($) $ / shares shares	Nov. 30, 2015 subsidiary	Dec. 31, 2015 USD ($) segment business_segment $ / shares shares	Dec. 31, 2014 USD ($) $ / shares shares	Dec. 31, 2013 USD ($)
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO \| shares		50,000,000
Common stock, 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				3
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				3
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
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
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
2016				1,600
2017				1,600
2018				1,600
2019				1,600
2020				$ 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
Common stock, par value \| $ / shares		$ 0.01
Public offering price per share \| $ / shares		$ 21.00
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
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
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

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 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 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 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) $ in Thousands	12 Months Ended
Goodwill (Narrative) (Details) $ in Thousands	Dec. 31, 2015 USD ($) reporting_unit	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)	Jan. 29, 2014 USD ($)
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)
RMP
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 \| RMP
Business Combination Segment Allocation [Line Items]
Goodwill				$ 39,100

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
RMP
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 Long-term Debt) (Details) - USD ($)
$ in Thousands

Dec. 31, 2015

Dec. 31, 2014

Current portion of long-term debt

$ 1,457,222

$ 900,680

680

Long-term debt

1,457,222

900,000

Senior Notes | Senior Notes Due 2022

Senior Notes | Senior Notes Due 2023

^[1]

900,000

^[2]

397,222

Other

Revolving Credit Facility | Senior Secured Revolving Credit Facility

680

Revolving Credit Facility | Midstream Holdings Revolving Credit Facility

^[3]

Revolving Credit Facility | RMP Revolving Credit Facility

^[4]

17,000

^[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 Notes Due 2022) (Details) - USD ($) $ in Thousands		12 Months Ended
	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 Notes Due 2023) (Details) - USD ($)		12 Months Ended
	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 Revolving Credit Facility) (Details) - Senior Secured Revolving Credit Facility - Wells Fargo		1 Months Ended
	Jan. 13, 2016	Apr. 30, 2013	Dec. 31, 2015 USD ($)	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 Holdings Revolving Credit Facility) (Details) - Midstream Holdings Revolving Credit Facility - Wells Fargo		12 Months Ended
	Dec. 22, 2014 USD ($)	Dec. 31, 2015 USD ($)
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 Credit Facility) (Details) - RMP Revolving Credit Facility - Wells Fargo		12 Months Ended
	Dec. 22, 2014 USD ($)	Dec. 31, 2015 USD ($)
Revolving Credit Facility
Debt Instrument [Line Items]
Maximum credit amount	$ 450,000,000
Additional commitments available under accordion feature	$ 200,000,000.0
Borrowings outstanding		$ 143,000,000
Average daily balance of credit facility		$ 46,900,000
Weighted average annual interest rate percentage		2.00%
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

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 (Narrative) (Details) - Not Designated as Hedging Instrument MMcf in Thousands	12 Months Ended
	Dec. 31, 2015 $ / MMBTU MMcf
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 (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 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 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 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	900,000	900,000
Carrying Value \| Senior Notes Due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes	397,222	0
Carrying Value \| Midstream Holdings Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Revolving Credit Facility	17,000	0
Carrying Value \| RMP Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
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	650,250	839,250
Fair Value \| Senior Notes Due 2023
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Senior Notes	294,000	0
Fair Value \| Midstream Holdings Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Revolving Credit Facility	17,000	0
Fair Value \| RMP Revolving Credit Facility
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Revolving Credit Facility	$ 143,000	$ 0

Rice Midstream Partners LP (Details) - USD ($) $ / shares in Units, $ in Thousands							12 Months Ended
	Apr. 15, 2016	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
Subsequent Event
Subsidiary, Sale of Stock [Line Items]
Number of shares sold with the completion of the IPO	29,858,891
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) (Details) - Greene County Acquisition - Greene County, Pennsylvania a in Thousands, $ in Millions		3 Months Ended
	Jul. 07, 2014 USD ($) a Well	Jun. 30, 2015 USD ($)
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 Business Segment (Details)
$ in Thousands

3 Months Ended

12 Months Ended

Dec. 31, 2015

USD ($)

Sep. 30, 2015

USD ($)

^[1]

Jun. 30, 2015

USD ($)

^[1]

Mar. 31, 2015

USD ($)

^[1]

Dec. 31, 2014

USD ($)

Sep. 30, 2014

USD ($)

^[1]

Jun. 30, 2014

USD ($)

^[1]

Mar. 31, 2014

USD ($)

^[1]

Dec. 31, 2015

USD ($)

business_segment

Dec. 31, 2014

USD ($)

Dec. 31, 2013

USD ($)

Number of reporting segments | business_segment

$ 136,088

^[1]

$ 143,621

$ 112,894

$ 109,539

$ 129,398

^[1]

$ 79,128

$ 91,940

$ 90,477

$ 502,141

$ 390,942

$ 88,687

480,329

^[1]

160,295

159,065

140,619

118,118

^[1]

91,453

67,522

124,272

940,308

401,364

116,567

(344,241)

^[1]

$ (16,674)

$ (46,171)

$ (31,080)

11,280

^[1]

$ (12,325)

$ 24,418

$ (33,795)

(438,167)

(10,422)

(27,880)

3,970,531

3,527,949

3,970,531

3,527,949

39,142

334,050

39,142

334,050

322,784

156,270

32,815

Exploration and Production

1,246,274

970,274

465,387

Operating Segments | Exploration and Production

294,908

452,962

385,438

88,604

944,117

356,019

111,047

(491,155)

29,419

(22,443)

3,004,226

2,935,814

3,004,226

2,935,814

294,908

308,194

151,900

31,467

Operating Segments | Rice Midstream Holdings

869,134

693,129

406,179

27,364

852

13,671

10,126

229

13,693

(9,274)

(229)

300,148

149,044

300,148

149,044

2,786

205

158

Operating Segments | Rice Midstream Partners

156,013

107,319

14,964

114,459

6,448

498

52,423

37,015

5,706

62,036

(30,567)

(5,208)

689,790

443,091

689,790

443,091

39,142

16,399

4,165

1,190

Elimination of Intersegment Transactions

248,463

169,826

44,244

(92,644)

(1,796)

(415)

(69,903)

(1,796)

(415)

(22,741)

(23,633)

$ 0

(4,595)

Net (loss) income attributable to Rice Energy (in thousands)

$ (27,336)

$ 0

[1]	The sum of quarterly data in some cases may not equal the yearly total due to rounding.

Commitments and Contingencies (Details) a in Thousands, $ in Millions	Oct. 14, 2013 a	Dec. 31, 2015 USD ($) 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 \| $		$ 2.0
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 Contingencies (Commitment for Gathering and Firm Transportation) (Details) - Gathering and Firm Transportation $ in Millions	Dec. 31, 2015 USD ($)
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) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Capital Leased Assets [Line Items]
2016		$ 17,288
2017		5,286
2018		566
2019		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 (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) - Secondary Public Offering - NGP Holdings - NGP Holdings	May. 12, 2015 $ / shares shares
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) (Details) $ in Thousands		1 Months Ended					3 Months Ended	11 Months Ended	12 Months Ended
Incentive Units (Narrative) (Details) $ in Thousands	Jan. 29, 2014 USD ($)	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2014	Aug. 31, 2014 USD ($)	Mar. 31, 2014 USD ($)	Dec. 31, 2014 shares	Dec. 31, 2015 USD ($) Tranche shares	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)
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 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) (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-Based 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, beginning balance			702,669	322,659	0
Granted				535,175	328,907
Vested				(121,138)	(1,647)
Forfeited				(34,027)	(4,601)
Total unvested, ending balance				702,669	322,659
Weighted average grant date fair value
Total unvested, beginning balance			$ 21.70	$ 28.38	$ 0.00
Granted				19.25	28.79
Vested				27.98	30.33
Forfeited				24.13	32.59
Total unvested, ending balance				$ 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-Based 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-Based Compensation (RMP Phantom Unit Awards) (Details) - USD ($) $ / shares in Units, $ in Thousands		12 Months Ended
	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, beginning balance		432,628	434,094	0
Granted			18,196	434,094
Vested			(242)	0
Forfeited			(19,420)	0
Total unvested, ending balance			432,628	434,094
Weighted average grant date fair value
Total unvested, beginning balance		$ 16.52	$ 16.50	$ 0.00
Granted			16.87	16.50
Vested			16.50	0.00
Forfeited			16.50	0.00
Total unvested, ending balance			$ 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) - 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]

$ (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)

$ 0.00

$ 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)

$ 0.00

$ 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) (Details) - USD ($)		12 Months Ended
Income Taxes (Narrative) (Details) - USD ($)	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 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 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 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 (Details) a in Thousands, $ in Millions			12 Months Ended
	Nov. 04, 2015	Dec. 22, 2014 a $ / MMBTU	Dec. 31, 2015 MMBTU	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)
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			40,000
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) (Details)								12 Months Ended
Subsequent Event (Narrative) (Details)	Apr. 21, 2016 shares	Apr. 15, 2016 USD ($) $ / shares shares	Apr. 12, 2016 USD ($) a	Feb. 22, 2016 USD ($) occasion shares	Feb. 01, 2016 USD ($) a	Jan. 13, 2016	Jan. 29, 2014 shares	Dec. 31, 2015 USD ($)	Dec. 31, 2014 USD ($)	Dec. 31, 2013 USD ($)
Subsequent Event [Line Items]
Aggregate consideration								$ 171,902,000
Remaining proceeds to be distributed to the company								171,902,000	$ 441,739,000	$ 0
Number of shares issued through public offering \| shares							50,000,000
Common stock issuance								$ 0	$ 0	$ 195,977,000
Subsequent Event
Subsequent Event [Line Items]
Number of shares issued through public offering \| shares		29,858,891
Subsequent Event \| Public Offering
Subsequent Event [Line Items]
Number of shares issued through public offering \| shares		20,000,000
Public offering price per share \| $ / shares		$ 16.35
Underwriting discounts and commissions		$ 15,000,000
Common stock issuance		$ 311,700,000
Subsequent Event \| Alpha Acquisition \| Greene County, Pennsylvania \| Alpha Natural Resources Inc
Subsequent Event [Line Items]
Purchase price			$ 200,000,000
Subsequent Event \| Alpha Acquisition \| Marcellus Acres \| Alpha Natural Resources Inc
Subsequent Event [Line Items]
Net acres \| a			27,400
Gross acres \| a			3,200
Subsequent Event \| Alpha Acquisition \| Utica Acres \| Alpha Natural Resources Inc
Subsequent Event [Line Items]
Net acres \| a			23,500
Subsequent Event \| Strike Force Midstream LLC \| Strike Force Midstream LLC \| Strike Force Holdings, LLC
Subsequent Event [Line Items]
Purchase price					$ 41,000,000
Membership interest percentage					75.00%
Subsequent Event \| Strike Force Midstream LLC \| Strike Force Midstream LLC \| Strike Force Holdings, LLC \| Belmont and Monroe Counties, Ohio \| Natural Gas
Subsequent Event [Line Items]
Number of acres for natural gas midstream business \| a					319,000
Subsequent Event \| Gulfport Midstream \| Strike Force Midstream LLC
Subsequent Event [Line Items]
Membership interest percentage					25.00%
Subsequent Event \| Midstream Holdings \| Private Placement
Subsequent Event [Line Items]
Period after closing date				18 months
Subsequent Event \| Midstream Holdings \| Midstream Holdings \| Private Placement
Subsequent Event [Line Items]
Number of occasions \| occasion				3
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 \| Private Placement \| Minimum
Subsequent Event [Line Items]
Amount required to purchase pursuant to securities purchase agreement				25,000,000
Subsequent Event \| Midstream Holdings \| Midstream Holdings \| Private Placement \| Maximum
Subsequent Event [Line Items]
Amount required to purchase pursuant to securities purchase agreement				$ 125,000,000
Subsequent Event \| Midstream Holdings \| Midstream Holdings \| Private Placement \| Series B Units
Subsequent Event [Line Items]
Number of Series B Units \| shares				375,000
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 \| NGP Holdings \| Selling Stockholder \| Public Offering
Subsequent Event [Line Items]
Number of shares issued through public offering \| shares	4,478,834	9,858,891
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 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		$ 900.0
Senior Notes Due 2023
Condensed Financial Statements, Captions [Line Items]
Aggregate principal amounts of debt offered	$ 400.0

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, deposits and other	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
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, deposits and other	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, deposits and other	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, deposits and other	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, deposits and other	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 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

Natural gas, oil and natural gas liquids (NGL) sales

$ 446,515

$ 359,201

$ 87,847

3,450

26,237

49,179

5,504

2,997

757

$ 136,088

$ 143,621

$ 112,894

$ 109,539

$ 129,398

$ 79,128

$ 91,940

$ 90,477

502,141

390,942

88,687

44,356

24,971

8,309

84,707

35,618

8,362

7,609

4,647

1,629

3,137

4,018

9,951

16,988

4,607

1,412

36,097

105,961

18,250

294,908

32,906

103,038

61,570

16,953

322,784

156,270

32,815

1,235

2,339

(Gain) loss from sale of interest in gas properties

1,632

1,156

(953)

4,230

6,520

207

480,329

160,295

159,065

140,619

118,118

91,453

67,522

124,272

940,308

401,364

116,567

(344,241)

(16,674)

(46,171)

(31,080)

11,280

(12,325)

24,418

(33,795)

(438,167)

(10,422)

(27,880)

(87,446)

(50,191)

(17,915)

203,579

1,108

893

(440)

273,748

186,477

6,891

(5,124)

(2,495)

(5,230)

(7,654)

(10,622)

Equity in income (loss) of joint ventures and subsidiaries

(6,896)

(2,656)

19,420

(255,881)

310,635

(35,776)

(12,118)

(91,600)

Less: Net income attributable to noncontrolling interests

(274,251)

65,084

(63,519)

4,687

104,360

(6,861)

(7,917)

129,454

(267,999)

219,035

(35,776)

(23,337)

(581)

Reportable Legal Entities | Parent

$ (280,755)

$ 58,950

$ (69,683)

$ 152

$ 103,779

$ (6,861)

$ (7,917)

$ 129,454

(291,336)

218,454

(35,776)

Natural gas, oil and natural gas liquids (NGL) sales

(Gain) loss from sale of interest in gas properties

(4)

(82,664)

(27,177)

617

247

68,247

55,580

(4,072)

(2,006)

Equity in income (loss) of joint ventures and subsidiaries

(296,335)

193,119

(314,211)

219,763

(12,118)

(91,600)

Less: Net income attributable to noncontrolling interests

(326,329)

128,163

Reportable Legal Entities | Guarantors

(326,329)

128,163

Natural gas, oil and natural gas liquids (NGL) sales

446,515

359,201

87,847

3,450

26,237

2,997

763

452,962

385,438

88,610

44,356

24,971

8,309

150,015

37,180

8,362

7,609

4,647

1,629

3,137

4,018

9,951

33,873

86,020

18,250

294,908

32,906

78,592

45,268

16,636

304,703

153,282

32,421

103

820

(Gain) loss from sale of interest in gas properties

(953)

4,230

6,028

940,621

356,206

114,444

(487,659)

29,232

(25,834)

(166)

(10,130)

(17,915)

203,579

439

755

(357)

205,501

130,897

6,891

(489)

(5,230)

(7,654)

(10,622)

Equity in income (loss) of joint ventures and subsidiaries

(6,896)

10,145

(47,208)

17,848

(271,740)

292,086

(35,219)

(25,699)

(98,731)

Less: Net income attributable to noncontrolling interests

(297,439)

193,355

Reportable Legal Entities | Non-Guarantors

(297,439)

193,355

Natural gas, oil and natural gas liquids (NGL) sales

141,823

7,300

(6)

141,823

7,300

16,988

4,607

1,412

2,224

19,941

24,446

16,302

317

19,185

2,988

394

1,128

1,519

(Gain) loss from sale of interest in gas properties

1,632

1,156

492

207

66,095

46,720

2,123

75,728

(39,420)

(2,046)

(4,616)

(12,884)

(109)

(83)

(1,052)

Equity in income (loss) of joint ventures and subsidiaries

70,112

(52,413)

(2,129)

(9,295)

8,440

Less: Net income attributable to noncontrolling interests

60,817

(43,973)

(23,337)

(581)

37,480

(44,554)

Eliminations

Natural gas, oil and natural gas liquids (NGL) sales

(92,644)

(1,796)

(92,644)

(1,796)

(65,308)

(1,562)

(1,104)

(Gain) loss from sale of interest in gas properties

(66,412)

(1,562)

(26,232)

(234)

Equity in income (loss) of joint ventures and subsidiaries

286,190

(148,567)

1,572

259,958

(148,801)

$ 1,572

34,994

90,291

Less: Net income attributable to noncontrolling interests

294,952

(58,510)

Quarterly Financial Information Disclosure [Abstract]

$ 294,952

$ (58,510)

[1]	The sum of quarterly data in some cases may not equal the yearly total due to rounding.

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 Information (Unaudited) (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

$ 136,088

$ 143,621

$ 112,894

$ 109,539

$ 129,398

$ 79,128

$ 91,940

$ 90,477

$ 502,141

$ 390,942

$ 88,687

480,329

160,295

159,065

140,619

118,118

91,453

67,522

124,272

940,308

401,364

116,567

(344,241)

(16,674)

(46,171)

(31,080)

11,280

(12,325)

24,418

(33,795)

(438,167)

(10,422)

(27,880)

(274,251)

65,084

(63,519)

4,687

104,360

(6,861)

(7,917)

129,454

(267,999)

219,035

(35,776)

Earnings (loss) per share attributable to Rice Energy - basic

$ (280,755)

$ 58,950

$ (69,683)

$ 152

$ 103,779

$ (6,861)

$ (7,917)

$ 129,454

$ (291,336)

$ 218,454

$ (35,776)

$ (2.06)

$ 0.43

$ (0.51)

$ 0.00

$ 0.76

$ (0.05)

$ (0.06)

$ 1.04

$ (2.14)

$ 1.70

$ (0.44)

Earnings (loss) per share attributable to Rice Energy - diluted

$ (2.06)

$ 0.43

$ (0.51)

$ 0.00

$ 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 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 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 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 Gas Producing Activities (Unaudited) (Reserve Quantity Information) (Details)
Mcfe in Thousands

12 Months Ended

Dec. 31, 2015

Mcfe

Dec. 31, 2014

Mcfe

MMcf

Dec. 31, 2013

Mcfe

MMcf

Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]

Beginning of year

1,306,571

382,660

^[1]

304,272

^[1]

282,391

^[1]

Revision of previous estimates

869,038

692,239

100,626

^[1]

(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]

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]

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

Proved Developed Reserves [Abstract]

Proved developed reserves: | MMcf

52,370

Proved Undeveloped Reserves [Abstract]

Proved undeveloped reserves: | MMcf

57,314

Proved Developed and Undeveloped Reserve (Energy) [Roll Forward]

282,391

[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 Gas Producing Activities (Unaudited) (Narrative) (Details)
Mcfe in Thousands

12 Months Ended

Dec. 31, 2015

Mcfe

location

$ / Mcf

Dec. 31, 2014

Mcfe

$ / Mcf

Dec. 31, 2013

Mcfe

$ / Mcf

MMcf

Jan. 29, 2014

282,391

^[1]

Revision of previous estimates

869,038

692,239

100,626

^[1]

(274,249)

47,018

757

^[1]

Proved undeveloped reserve locations removed from estimate of reserves | location

Positive revisions

56,000

Percentage of total net gas proved reserves reviewed by Netherland, Sewell and Associates

100.00%

Equity investment ownership percentage

50.00%

Added reserves | MMcf

19,812

Net negative revisions of previous estimates | MMcf

26,803

Gas

Gas | Marcellus Joint Venture

2.65

4.52

3.91

3.90

Oil

41.72

85.70

NGL

Marcellus Shale and Utica Shale

9.91

869,038

Marcellus Shale

692,239

100,626

Interest in Marcellus joint venture acquired

282,391

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 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

(745,022)

^[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]

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

[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 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]

Revisions of previous quantity estimates

375,865

^[4]

^[2]

(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)

^[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]

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