Rice Drilling B S-4 3 Dec 14 Registration of securities issued in business combination transactions Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2014
Document And Entity Information [Abstract]	'
Document Type	'S-4
Amendment Flag	'false
Document Period End Date	30-Sep-14
Trading Symbol	'RICE
Entity Registrant Name	'Rice Energy Inc.
Entity Central Index Key	'0001588238
Entity Filer Category	'Non-accelerated Filer

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Sep. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'	'
Cash	$131,978	$31,612	$8,547
Restricted cash	0	8,268	0
Accounts receivable	136,560	31,765	8,557
Receivable from affiliate	222	2,244	11,879
Deposits	760	601	'
Prepaid expenses and other	'	863	321
Prepaid expenses and other	2,374	262	'
Derivative assets	8,546	0	'
Total current assets	280,440	74,752	29,304
Investments in joint ventures	0	49,814	30,976
Gas collateral account	3,995	3,700	5,843
Proved natural gas properties, net	1,023,603	270,523	159,988
Unproved natural gas properties	1,158,483	457,836	111,030
Property and equipment, net	13,637	5,972	2,622
Deferred financing costs, net	20,452	12,292	5,208
Goodwill	338,036	0	'
Intangible assets, net	48,199	0	'
Other non-current assets	386	0	'
Derivative assets	8,555	4,921	0
Total assets	2,895,786	879,810	344,971
Current liabilities:	'	'	'
Current portion of long-term debt	1,006	20,120	8,814
Accounts payable	95,218	51,219	19,793
Royalties payable	28,906	9,393	1,960
Accrued interest	24,219	250	2,004
Accrued capital expenditures	176,087	16,753	2,359
Other accrued liabilities	19,378	8,283	5,585
Leasehold payable	24,940	18,606	3,954
Derivative liabilities	0	965	2,260
Payable to affiliate	0	6,148	2,482
Operated prepayment liability	1,886	1,201	11,553
Total current liabilities	371,640	132,938	60,764
Long-term liabilities:	'	'	'
Long-term debt	900,000	406,822	140,506
Leasehold payable	3,330	1,675	106
Deferred tax liabilities	199,040	0	'
Restricted units	0	36,306	3,400
Other long-term liabilities	9,218	3,422	2,004
Total liabilities	1,483,228	581,163	206,780
Stockholders' equity	1,412,558	298,647	138,191
Total liabilities and stockholders' equity	$2,895,786	$879,810	$344,971

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating revenues:	'	'	'	'	'	'	'
Natural gas, oil and natural gas liquids (NGL) sales	$67,831	$23,526	$246,816	$60,219	$87,847	$26,743	$13,972
Firm transportation sales, net	9,733	0	11,851	0	'	'	'
Other revenue	1,563	163	2,878	580	757	457	0
Total operating revenues	79,127	23,689	261,545	60,799	88,604	27,200	13,972
Operating expenses:	'	'	'	'	'	'	'
Lease operating	4,553	1,777	16,406	5,794	8,309	3,688	1,617
Gathering, compression and transportation	9,597	3,365	25,904	6,951	9,774	3,754	540
Production taxes and impact fees	1,114	522	2,624	1,029	1,629	1,382	0
Exploration	747	338	1,706	1,784	9,951	3,275	660
Incentive unit expense	26,418	0	101,695	0	'	'	'
Restricted unit expense	0	32,381	0	40,087	32,906	0	170
Stock compensation expense	2,058	0	3,274	0	'	'	'
General and administrative	10,458	4,169	36,733	9,952	16,953	7,599	5,208
Depreciation, depletion and amortization	33,853	9,722	91,912	23,215	32,815	14,149	5,981
Acquisition expense	2,246	0	2,246	0	'	'	'
Write-down of abandoned leases	'	'	'	'	0	2,253	109
Amortization of intangible assets	408	0	748	0	'	'	'
Loss (gain) from sale of interest in gas properties	'	'	'	'	4,230	0	-1,478
Total operating expenses	91,452	52,274	283,248	88,812	116,567	36,100	12,807
Operating income (loss)	-12,325	-28,585	-21,703	-28,013	-27,963	-8,900	1,165
Other income (expense):	'	'	'	'	'	'	'
Interest expense	-15,754	-5,943	-38,737	-13,033	-17,915	-3,487	-531
Gain on purchase of Marcellus joint venture	0	0	203,579	0	'	'	'
Other income (expense)	-216	38	180	-408	-357	112	161
Gain (loss) on derivative instruments	36,935	8,050	5,357	16,698	6,891	-1,381	574
Amortization of deferred financing costs	-707	-958	-1,728	-4,760	-5,230	-7,220	-2,675
Loss on extinguishment of debt	-790	-10,622	-3,934	-10,622	-10,622	0	0
Write-off of deferred financing costs	0	0	-6,896	0	'	'	'
Equity in income (loss) of joint ventures	0	4,368	-2,656	19,297	19,420	1,532	370
Total other expense	'	'	'	'	-7,813	-10,444	-2,101
Income (loss) before income taxes	7,143	-33,652	133,462	-20,841	'	'	'
Income tax benefit (expense)	-14,005	0	-18,787	0	'	'	'
Net income (loss)	-6,862	-33,652	114,675	-20,841	-35,776	-19,344	-936
Weighted average number of shares of common stock-basic	132,269,081	88,000,000	125,411,524	77,894,855	80,441,905	57,966,572	39,958,066
Weighted average common shares outstanding;	'	'	'	'	'	'	'
Basic and Diluted	'	'	'	'	80,441,000	57,967,000	39,958,000
Weighted average number of shares of common stock-diluted	132,269,081	88,000,000	125,678,095	77,894,855	80,441,905	57,966,572	39,958,066
Net loss per common share	'	'	'	'	'	'	'
Basic and Diluted	'	'	'	'	($0.44)	($0.33)	($0.02)
Earnings (loss) per share-basic	($0.05)	($0.38)	$0.91	($0.27)	($0.44)	($0.33)	($0.02)
Earnings (loss) per share-diluted	($0.05)	($0.38)	$0.91	($0.27)	($0.44)	($0.33)	($0.02)
Pro Forma	'	'	'	'	'	'	'
Other income (expense):	'	'	'	'	'	'	'
Income tax benefit (expense)	'	'	5,560	'	14,844	'	'
Net income (loss)	'	'	$120,235	'	($20,932)	'	'
Weighted average common shares outstanding;	'	'	'	'	'	'	'
Earnings per share-basic	'	'	$0.96	'	'	'	'
Net loss per common share	'	'	'	'	'	'	'
Basic and Diluted	'	'	'	'	($0.26)	'	'
Earnings per share-diluted	'	'	$0.96	'	'	'	'

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Cash Flows (USD $)	9 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'	'	'
Net income (loss)	$114,675	($20,841)	($35,776)	($19,344)	($936)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:	'	'	'	'	'
Depreciation, depletion and amortization	91,912	23,215	32,815	14,149	5,981
Amortization of deferred financing costs	1,728	4,760	5,230	7,220	2,675
Amortization of intangibles	748	0	'	'	'
Loss (gain) from sale of interest in gas properties	'	'	4,230	0	-1,478
Incentive unit expense	101,695	0	'	'	'
Write-off of deferred financing costs	6,896	0	'	'	'
Loss on extinguishment of debt	3,934	0	'	'	'
Restricted unit expense	0	40,087	32,906	0	170
Stock compensation expense	3,274	0	'	'	'
Write-off of unsuccessful exploratory well costs	'	'	8,143	0	0
Derivative instruments fair value (gain) loss	-5,357	-16,698	-6,891	1,381	-574
Cash payments for settled derivatives	-20,782	-1,053	676	879	574
Deferred income tax expense	18,787	0	'	'	'
Fair value gain on purchase of Marcellus joint venture	-203,579	0	'	'	'
Equity in (income) loss of joint ventures	2,656	-19,297	-19,420	-1,532	-370
Write-down of abandoned leases and other leasehold costs	'	'	0	2,253	109
(Increase) decrease in:	'	'	'	'	'
Accounts receivable	-89,443	-12,398	-17,208	-3,828	-4,310
Receivable from affiliate	2,033	6,897	9,635	-8,403	-76
Gas collateral account	0	4,343	643	-4,137	-207
Prepaid expenses and other	-2,165	-270	-541	-212	73
Cash receipts (payments) for settled derivatives	-20,782	-1,053	676	879	574
Increase (decrease) in:	'	'	'	'	'
Accounts payable	2,845	-133	2,273	-30	-125
Royalties payable	11,605	5,916	7,432	775	1,117
Accrued interest	23,315	-1,324	'	'	'
Other accrued expenses	14,546	5,029	5,859	7,391	746
Payable to affiliate	-9,644	4,258	3,666	424	1,762
Net cash provided by (used in) operating activities	69,679	22,491	33,672	-3,014	5,131
Cash flows from investing activities:	'	'	'	'	'
Capital expenditures for natural gas properties	-634,129	-341,347	-463,128	-109,149	-69,077
Acquisition of Marcellus joint venture, net of cash acquired	-82,766	0	0	-9,957	-15,205
Acquisition of Momentum assets	-111,447	0	'	'	'
Acquisition of Greene County assets	-329,469	0	'	'	'
Capital expenditures for property and equipment	-8,279	-1,278	-2,259	-867	-673
Proceeds from sale of interest in gas properties	11,542	0	6,792	0	5,710
Net cash provided by (used in) investing activities	-1,154,548	-342,625	-458,595	-119,973	-79,245
Cash flows from financing activities:	'	'	'	'	'
Proceeds from borrowings	900,000	321,003	435,500	44,361	82,972
Repayments of debt obligations	-498,983	-159,726	-160,760	-10,152	-7,726
Restricted cash for convertible debt	8,268	-8,268	-8,268	0	0
Debt issuance costs	-19,401	-9,480	-12,194	-1,913	-9,699
Common stock issuance	0	197,987	'	'	'
Repurchase of common stock	0	-2,267	'	'	'
Costs relating to IPO	-1,412	0	'	'	'
Proceeds from conversion of warrants	1,975	0	'	'	'
Proceeds from issuance of common stock sold in IPO, net of underwriting fees	598,500	0	'	'	'
Costs relating to August 2014 Equity Offering	-784	0	'	'	'
Common stock issuance	197,072	0	195,977	96,782	7,900
Repurchase of common stock	'	'	-2,267	-1,133	0
Return of capital	'	'	0	-800	0
Net cash provided by (used in)financing activities	1,185,235	339,249	447,988	127,145	73,447
Net increase (decrease) in cash	100,366	19,115	23,065	4,158	-667
Cash at the beginning of the year	31,612	8,547	8,547	4,389	5,056
Cash at the end of the year	131,978	27,662	31,612	8,547	4,389
Supplemental disclosure of noncash investing and financing activities	'	'	'	'	'
Accretion of debt discount	'	'	2,099	0	0
Gas collateral financed by accounts payable	'	'	0	1,500	0
Capital expenditures for property, office furniture and equipment funded by capital lease borrowings	'	'	1,557	419	0
Application of advances from joint interest owners	'	'	-10,415	0	0
Warrants issued in exchange for services	'	'	0	0	3,294
Conversion of related-party note payable to common stock	'	'	255	11,332	0
Natural Gas Properties | Accounts Payable	'	'	'	'	'
Supplemental disclosure of noncash investing and financing activities	'	'	'	'	'
Capital expenditures	'	'	48,615	18,083	10,529
Natural Gas Properties | Other accrued liabilities	'	'	'	'	'
Supplemental disclosure of noncash investing and financing activities	'	'	'	'	'
Capital expenditures	'	'	16,753	2,359	5,936
Natural Gas Properties | Borrowings	'	'	'	'	'
Supplemental disclosure of noncash investing and financing activities	'	'	'	'	'
Capital expenditures	'	'	0	18,328	1,016
Natural Gas Properties | Deferred payment obligation	'	'	'	'	'
Supplemental disclosure of noncash investing and financing activities	'	'	'	'	'
Capital expenditures	'	'	20,281	3,577	5,314
Natural Gas Properties | Other Liabilities	'	'	'	'	'
Supplemental disclosure of noncash investing and financing activities	'	'	'	'	'
Capital expenditures	'	'	0	8,261	0
Property and equipment | Borrowings	'	'	'	'	'
Supplemental disclosure of noncash investing and financing activities	'	'	'	'	'
Capital expenditures	'	'	$503	$1,270	$0

Statements_of_Condensed_Consol

Statements of Condensed Consolidated Equity (USD $)	Total	IPO	Common Stock ($0.01 par)	Common Stock ($0.01 par)	Additional Paid-In Capital	Additional Paid-In Capital	Accumulated (Deficit) Earnings	Accumulated (Deficit) Earnings
In Thousands, unless otherwise specified				IPO		IPO		IPO
Balance at Dec. 31, 2010	$36,563	'	$392	'	$45,223	'	($9,052)	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'
Capital Contributions, net	7,900	'	14	'	7,886	'	0	'
Issuance of warrants	3,294	'	0	'	3,294	'	0	'
Net income (loss)	-936	'	0	'	0	'	-936	'
Balance at Dec. 31, 2011	46,821	'	406	'	56,403	'	-9,988	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'
Capital Contributions, net	100,182	'	192	'	99,990	'	0	'
Return of Capital	-800	'	-1	'	-799	'	0	'
Conversion of related-party notes payable	11,332	'	25	'	11,307	'	0	'
Net income (loss)	-19,344	'	0	'	0	'	-19,344	'
Balance at Dec. 31, 2012	138,191	'	622	'	166,901	'	-29,332	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'
Capital Contributions, net	197,990	'	258	'	197,732	'	0	'
Net income (loss)	-20,841	'	0	'	0	'	-20,841	'
Balance at Sep. 30, 2013	315,340	'	880	'	364,633	'	-50,173	'
Balance at Dec. 31, 2012	138,191	'	622	'	166,901	'	-29,332	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'
Capital Contributions, net	196,232	'	258	'	195,974	'	0	'
Net income (loss)	-35,776	'	0	'	0	'	-35,776	'
Balance at Dec. 31, 2013	298,647	'	880	'	362,875	'	-65,108	'
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'	'	'	'	'	'	'	'
Shares of common stock issued in purchase of Marcellus joint venture	222,000	'	95	'	221,905	'	0	'
Conversion of restricted units into shares of common stock at IPO	'	36,306	'	0	'	36,306	'	0
Conversion of convertible debentures into shares of common stock after IPO	'	6,605	'	6	'	6,599	'	0
Conversion of warrants into shares of common stock after IPO	'	1,975	'	7	'	1,968	'	0
Shares of common stock issued in August 2014 Equity Offering, net of offering costs	196,288	593,413	75	300	196,213	593,113	0	0
Incentive unit compensation	101,695	'	0	'	101,695	'	0	'
Stock compensation	3,274	'	0	'	3,274	'	0	'
Tax impact of IPO and corporate reorganization	'	-162,320	'	0	'	-162,320	'	0
Net income (loss)	114,675	'	0	'	0	'	114,675	'
Balance at Sep. 30, 2014	$1,412,558	'	$1,363	'	$1,361,628	'	$49,567	'

Statements_of_Condensed_Consol1

Statements of Condensed Consolidated Equity (Parenthetical) (Common Stock ($0.01 par), USD $)	Sep. 30, 2014	Dec. 31, 2013
Common Stock ($0.01 par)	'	'
Common Stock, par value per share	$0.01	$0.01

Basis_of_Presentation

Basis of Presentation	9 Months Ended
	Sep. 30, 2014
Accounting Policies [Abstract]	'
Basis of Presentation	'
	1	Basis of Presentation
	The accompanying unaudited condensed 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 interim financial information and applicable rules and regulations promulgated under the Exchange Act. Accordingly, they do not include all of the information and footnotes required by GAAP for annual financial statements. The unaudited condensed consolidated financial statements included herein contain all adjustments which are, in the opinion of management, necessary to present fairly the Company’s financial position as of September 30, 2014 and its condensed consolidated statements of operations for the three and nine months ended September 30, 2014 and 2013 and of cash flows for the nine months ended September 30, 2014 and 2013. The condensed consolidated statements of operations for the three and nine months ended September 30, 2014 and 2013 are not necessarily indicative of the results to be expected for future periods. A corporate reorganization occurred concurrently with the completion of our IPO on January 29, 2014. As a part of this corporate reorganization, we acquired all of the outstanding membership interests in Rice Appalachia and Rice Drilling B (other than those already held by Rice Appalachia) in exchange for shares of our common stock. Our business 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. These condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes therein for the year ended December 31, 2013, as filed with the Securities and Exchange Commission by the Company in its 2013 Annual Report. Certain prior period financial statement amounts have been reclassified to conform to current period presentation.

LongTerm_Debt

Long-Term Debt

9 Months Ended

12 Months Ended

Sep. 30, 2014

Dec. 31, 2013

Debt Disclosure [Abstract]

'

'

Long-Term Debt

'

'

2

Long-Term Debt

4

Long-Term Debt

Long-term debt consists of the following as of December 31, 2013 and 2012 (in thousands):

Long-term debt consists of the following as of September 30, 2014 and December 31, 2013.

Description

December 31, 2013

December 31, 2012

Long-term Debt

(in thousands)

September 30,

December 31,

Debentures (a)

$

6,890

$

60,000

2014

2013

Wells Fargo Energy Capital Credit Facility (b)

—

70,000

Long-term Debt

Second Lien Term Loan Facility (c)

293,821

—

Senior Notes Due 2022 (a)

$

900,000

$

—

NPI Note (d)

8,028

15,282

Second Lien Term Loan Facility (b)

—

293,821

Senior Secured Revolving Credit Facility (e)

115,000

—

Senior Secured Revolving Credit Facility (c)

—

115,000

Other

3,203

4,038

Debentures (d)

—

6,890

NPI Note

—

8,028

Total debt

$

426,942

$

149,320

Other

1,006

3,203

Less current portion

20,120

8,814

Total debt

$

901,006

$

426,942

Long-term debt

$

406,822

$

140,506

Less current portion

1,006

20,120

Debentures (a)

Long-term debt

$

900,000

$

406,822

In June of 2011, the Company sold $60.0 million of its 12% Senior Subordinated Convertible Debentures due 2014 (“the Debentures”) in a private placement to certain accredited investors as defined in Rule 501 of Regulation D. The Debentures accrue interest at 12% per year payable monthly in arrears by the 15th day of the month and mature on July 31, 2014 (“Maturity Date”). The Debentures are the Company’s unsecured senior obligations and rank equally with all of the Company’s current and future senior unsecured indebtedness.

From July 31, 2013 through August 20, 2013 (“the put redemption period”), any holder of Debentures had the right to cause the Company to repurchase all or any portion of the Debentures owned by such holder at 100% of the portion of the principal amount of the Debentures as to which the right was being exercised, plus a premium of 20%. During the put redemption period, the Company repurchased $53.1 million of outstanding Debentures and paid a put premium of $10.6 million in accordance with the terms of the agreements. The put redemption period expired in the nine months ended September 30, 2013 and the Company recorded the premium of $10.6 million as a loss on extinguishment of debt in the statement of consolidated operations for the year ended December 31, 2013.

At any time after July 31, 2013 until the Maturity Date, the Company has the right to redeem all, but not less than all, of the Debentures on 30 days prior written notice at a redemption price equal to 100% of the principal amount of the Debentures plus a premium of 50%. In connection with the IPO, the convertible debentures and warrants of Rice Drilling B were amended to become convertible or exercisable for an aggregate 1,671,800 shares of common stock of Rice Energy Inc. Through March 10, 2014, approximately $5.0 million of the convertible debentures had been converted into 433,073 shares of Rice Energy Inc. common stock. On February 28, 2014, the Company issued a call notice on the remaining convertible debentures, requiring a response by March 30, 2014. Amounts not converted by the redemption date will receive a cash payment from the Company of 100% of the principal amount plus a premium of 50%, which could result in additional costs of $1.0 million if all remaining convertible debentures are redeemed. As the principal amount of the convertible debentures outstanding has been reduced to less than $5.0 million, the Company is no longer required to maintain restricted cash.

6.25% Senior Notes Due 2022 (a)

In connection with the convertible debt offering, Rice Drilling B granted warrants that were issued on August 15, 2011, to certain of the broker-dealers involved in the private placement. These warrants are considered to be separate instruments issued solely in lieu of cash compensation for services provided by the broker-dealers. Two separate classes of warrants were issued (Normal and Bonus), the sole difference being the exercise price.

The fair value of these warrants at the date of grant was estimated using the Black-Scholes valuation model with the following assumptions:

On April 25, 2014, the Company issued $900.0 million (the “Senior Notes Offering”) in the aggregate principal amount of 6.25% senior notes due 2022 (the “Notes”) in a private placement to eligible purchasers under Rule 144A and Regulation S of 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), with the remainder having been used to fund a portion of the Company’s 2014 capital expenditure program.

Dividend yield

—

%

Expected volatility

72.1

%

The Notes will mature on May 1, 2022, and interest is payable on the 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 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 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 notes (the “Indenture”), unless the Company has given notice to redeem the Notes, the holders of the Notes will have the right to require the Company to repurchase all or a portion of the Notes at a price equal to 101% of the aggregate principal amount of the 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 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.

Risk-free rate

0.96

%

Expected life

5 years

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.

“Normal” warrant

The Company, as the parent company, has no independent assets or operations. The Notes are guaranteed on a senior unsecured basis by the Guarantors (as defined in the Indenture). The guarantees are full and unconditional, subject to customary exceptions pursuant to the Indenture, as discussed below. Other than the Guarantors, Company has no subsidiaries other than minor subsidiaries. In addition, there are no restrictions on the ability of the Company to obtain funds from its subsidiary by dividend or loan. Finally, the Company’s wholly-owned subsidiaries do not have restricted assets that exceed 25% of net assets as of the most recent fiscal year end that may not be transferred to the Company in the form of loans, advances or cash dividends by the subsidiary without the consent of a third party.

Number of warrants issued

1,044

Exercise price

$

10,000

Guarantees of the Notes will be released under certain circumstances, including:

Grant date fair value, per unit

$

2,569

Weighted average contractual life

5 years

•

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 Indenture) of the Company;

“Bonus” warrant

Number of warrants issued

192

Exercise price

$

6,250

•

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;

Grant date fair value, per unit

$

3,184

Weighted average contractual life

5 years

The fair value of $3.3 million of the above warrants were recorded as a deferred financing cost during the year ended December 31, 2011, and were amortized over the term of the Debentures. Subsequent to December 31, 2013, two warrants had been exercised in exchange for 1,728 shares of Rice Energy Inc. common stock. If all warrants are exercised approximately 1.1 million shares of Rice Energy Inc. common stock would be issued.

•

if the Company designates any Restricted Subsidiary that is a Guarantor to be an unrestricted subsidiary in accordance with the Indenture;

Wells Fargo Energy Capital Credit Facility (b)

In November of 2012, the Company amended and restated its then existing credit facility with Wells Fargo. In connection with the amendment and restatement, a lender was added to the new facility. The amendment and restatement was accounted for as a modification of the debt, resulting in $0.2 million of third-party costs associated with the amendment and restatement being expensed. The Wells Fargo Energy Capital Credit Facility (“Wells Fargo Energy Capital Credit Facility”) was subject to a maximum borrowing base equal to $200.0 million, as determined unanimously by Wells Fargo Energy Capital, in accordance with customary lending practices. This loan was repaid using proceeds from the Second Lien Term Loan Facility during the second quarter of 2013.

Second Lien Term Loan Facility (c)

•

upon legal defeasance or satisfaction and discharge of the Indenture; or

On April 25, 2013, the Company entered into a Second Lien Term Loan Facility (“Second Lien Term Loan Facility”) with Barclays Bank PLC, as administrative agent, and a syndicate of lenders in an aggregate principal amount of $300.0 million. The Company estimated the discount on issuance of this instrument based upon an estimate of market rates at the inception of the instrument and recorded a discount of $4.5 million. The discount is being amortized over the life of the note using an effective interest rate of 0.284% using the effective yield method. As of December 31, 2013, the Company had a balance of $293.8 million relating to the Second Lien Term Loan Facility, this includes borrowings outstanding of $297.7 million less a discount of $3.9 million. The Second Lien Term Loan Facility matures October 25, 2018. Approximately $7.3 million in fees were capitalized in connection with the Second Lien Term Loan Facility.

Principal amounts borrowed under the Second Lien Term Loan Facility are payable in an amount equal to 0.25% of the initial principal amount at the end of each quarter with the remainder payable on the maturity date. Interest is payable in arrears at the end of each quarter and on the maturity date. The Company has the choice to borrow in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to LIBOR plus 725 basis points. Base rate loans bear interest at a rate per annum equal to the greatest of (i) 2.25%, (ii) the agent bank’s reference rate, (iii) the federal funds effective rate plus 50 basis points and (iv) the rate for one month Eurodollar loans plus 100 basis points, plus 625 basis points. The Company may prepay the borrowings under the Second Lien Term Loan Facility at any time, provided that any prepayments of principal amounts during the first year following the closing date are subject to a 2% premium and any prepayments of principal during the second year following the closing date are subject to 1% premium. The interest rate was 8.5% as of December 31, 2013.

•

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 Indenture) has occurred and is continuing.

The Second Lien Term Loan Facility is secured by liens on substantially all of the Company’s properties that are subordinated to the liens securing the revolving credit facility and guarantees from the Company’s subsidiaries other than any subsidiary that have been designated as an unrestricted subsidiary. The Second Lien Term Loan Facility contains restrictive covenants that may limit the Company’s ability to, among other things:

The Indenture restricts the Company’s ability and the ability of certain of its 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 our 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 Indenture) has occurred and is continuing, many of such covenants will terminate and the Company and its subsidiaries will cease to be subject to such covenants.

•

incur additional indebtedness;

The Indenture contains customary events of default, including:

•

sell assets;

•

withdraw funds from specified restricted account;

•

default in any payment of interest on any Note when due, continued for 30 days;

•

make loans to others;

•

default in the payment of principal of or premium, if any, on any Note when due;

•

make investments;

•

enter into mergers;

•

failure by the Company to comply with its other obligations under the Indenture, in certain cases subject to notice and grace periods;

•

make or declare dividends;

•

payment defaults and accelerations with respect to other indebtedness of the Company and its Restricted Subsidiaries (as defined in the Indenture) in the aggregate principal amount of $25.0 million or more;

•

hedge future production or interest rates;

•

incur liens; and

•

certain events of bankruptcy, insolvency or reorganization of the Company or a Significant Subsidiary (as defined in the Indenture) or group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary;

•

engage in certain other transactions without the prior consent of the lenders.

The Second Lien Term Loan Facility also requires the Company to maintain an asset coverage ratio, which is the ratio of the present value of oil and gas reserves (discounted at 10% per annum) to the sum of all secured debt (including any debt incurred by the Company’s Marcellus joint venture under its credit facility or any replacement or refinancing of its credit facility) of not less than 1.5 to 1.0.

•

failure by the Company or Restricted Subsidiary to pay certain final judgments aggregating in excess of $25.0 million within 60 days; and

The Company was in compliance with such covenants and ratios as of December 31, 2013.

NPI Note (d)

In November of 2012, in connection with the amendment of the Wells Fargo Credit Facility, the Company repurchased the NPI it had previously assigned to Wells Fargo for $26.5 million, of which $9.5 million was paid at the closing of the Wells Fargo Energy Capital Credit Facility and $17.0 million was financed by a note to Wells Fargo. The Company accounted for this as the acquisition of a mineral right and therefore capitalized this amount in proved properties and will amortize using the units of production method. There is no stated interest rate associated with this note and as a result, this note was considered to have below market financing rates. The Company estimated the discount on issuance of this instrument based upon an estimate of market rates at the inception of the instrument and recorded a discount of $2.0 million. The discount is being amortized over the life of the note using an effective interest rate of 12.10% using the effective yield method. As part of the use of proceeds from the Second Lien Term Loan Facility, the Company repaid $8.5 million of this note during the second quarter of 2013. A final payment of $8.5 million is due to be repaid in June of 2014.

•

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 (e)

In connection with the issuance and sale of the Notes, the Company and certain of the Company’s subsidiaries (the “Guarantors”) entered into a registration rights agreement with the Initial Purchasers, dated April 25, 2014. Pursuant to the registration rights agreement, the Company and the Guarantors have agreed to file a registration statement with the Securities and Exchange Commission so that holders of the Notes can exchange the Notes for registered notes that have substantially identical terms as the Notes. In addition, the Company and the Guarantors have agreed to exchange the guarantee related to the Notes for a registered guarantee having substantially the same terms as the original guarantee. The Company and the Guarantors will use commercially reasonable efforts to cause the exchange to be completed within 365 days after the issuance of the Notes. The Company and the Guarantors are required to pay additional interest if they fail to comply with their obligations to register the Notes within the specified time periods.

On April 25, 2013, the Company entered into a revolving credit facility with Wells Fargo Bank, N.A., as administrative agent, and a syndicate of lenders with a maximum credit amount of $500.0 million and a sublimit for letters of credit of $10.0 million. As of December 31, 2013, the sublimit for the letters of credit was $100.0 million. The amount available to be borrowed under the revolving credit facility is subject to a borrowing base that is redetermined semiannually as of each January 1 and July 1 and depends on the volumes of our proved oil and gas reserves and estimated cash flows from these reserves and our commodity hedge positions. The next redetermination is scheduled to occur in April 2014. As of December 31 2013, the borrowing base was $200.0 million. As of December 31, 2013, we had $115.0 million in borrowings and approximately $22.5 million in letters of credit outstanding under our revolving credit facility. The revolving credit facility matures April 25, 2018.

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. The Company has a choice of borrowing in Eurodollars or at the base rate. Eurodollar loans bear interest at a rate per annum equal to LIBOR plus an applicable margin ranging from 175 to 275 basis points, depending on the percentage of our 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 75 to 175 basis points, depending on the percentage of our borrowing base utilized. The Company may repay any amounts borrowed prior to the maturity date without any premium or penalty other than customary LIBOR breakage costs. The weighted average interest rate was 2.39% as of December 31, 2013.

Second Lien Term Loan Facility (b)

The credit facility is secured by liens on substantially all of the properties of the Company and guarantees from its subsidiaries other than any subsidiary that we have designated as an unrestricted subsidiary. The credit facility contains restrictive covenants that may limit our ability to, among other things:

On April 25, 2013, Rice Drilling B entered into a Second Lien Term Loan Facility (“Second Lien Term Loan Facility”) with Barclays Bank PLC, as administrative agent, and a syndicate of lenders in an aggregate principal amount of $300.0 million. Rice Drilling B estimated the discount on issuance of this instrument based upon an estimate of market rates at the inception of the instrument and recorded a discount of $4.5 million. The discount was being amortized over the life of the note using an effective interest rate of 0.284%. Approximately $7.4 million in fees were capitalized in connection with the Second Lien Term Loan Facility.

•

incur additional indebtedness;

On April 25, 2014, the Company used a portion of the net proceeds from the Senior Notes Offering to repay and retire the Second Lien Term Loan Facility in the amount of $301.8 million. The payment was comprised of repayment of the principal balance of $297.0 million, a pre-payment penalty of $0.8 million and accrued but unpaid interest of $1.8 million. The prepayment penalty is presented as loss on extinguishment of debt in the condensed consolidated statements of operations for the nine months ended September 30, 2014. The pre-payment also resulted in a debt extinguishment and subsequent write-off of the unamortized deferred finance costs of $6.9 million presented in the condensed consolidated statements of operations for the nine months ended September 30, 2014.

•

sell assets;

•

make loans to others;

Senior Secured Revolving Credit Facility (c)

•

make investments;

On April 25, 2013, Rice Drilling B entered into a Senior Secured Revolving Credit Facility (“Senior Secured Revolving Credit Facility”) with Wells Fargo Bank, N.A., as administrative agent, and a syndicate of lenders with a maximum credit amount of $500.0 million and a sublimit for letters of credit of $10.0 million. Concurrently with the closing of the IPO, on January 29, 2014, Rice Drilling B amended its Senior Secured Revolving Credit Facility to, among other things, allow for the corporate reorganization that was completed simultaneously with the closing of the IPO, add the Company as a guarantor, increase the maximum commitment amount to $1.5 billion and lower the interest rate on amounts borrowed under the Senior Secured Revolving Credit Facility. The Company used a portion of the net proceeds of the IPO to repay $115.0 million of borrowings under the Senior Secured Revolving Credit Facility. After giving effect to the amendment, the borrowing base under the Senior Secured Revolving Credit Facility was increased to $350.0 million as a result of the Marcellus JV Buy-In.

•

enter into mergers;

In April 2014, concurrently with the Senior Notes Offering, the Company, as borrower, and Rice Drilling B, as predecessor borrower, amended and restated its Senior Secured Revolving Credit Facility (“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. Furthermore, the Amended Credit Agreement (i) allowed for the issuance of the Notes described below and (ii) provided that the Company did not incur an immediate reduction in the borrowing base under the Senior Secured Revolving Credit Facility as a result of the issuance of the Notes. As such, the borrowing base under the Amended Credit Agreement immediately following the issuance of the Notes remained at $350.0 million. The Amended Credit Agreement also extended the maturity date of the Senior Secured Revolving Credit Facility from April 25, 2018 to January 29, 2019. The amount available to be borrowed under the Amended Credit Agreement is subject to a semi-annual borrowing base redetermination that depends on, among other factors, the volumes of the Company’s proved oil and gas reserves. A redetermination occurred in May 2014, which increased the borrowing base to $385.0 million. As of September 30, 2014, the borrowing base was $385.0 million and the sublimit for letters of credit was $100.0 million. The Company had zero borrowings outstanding and $66.8 million in letters of credit outstanding under its Amended Credit Agreement as of September 30, 2014, resulting in availability of $318.2 million. In October 2014, a subsequent redetermination occurred which increased the borrowing base to $550.0 million. The next redetermination is scheduled for April 2015 based on the redetermination criteria as of January 1, 2015.

•

make or declare dividends;

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.

•

hedge future production or interest rates;

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), as well as significant unproved acreage and substantially all of the personal property of the Company and such restricted subsidiaries, and the Amended Credit Agreement is 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 liens; and

•

engage in certain other transactions without the prior consent of the lenders.

•

incur additional indebtedness;

The credit facility also requires the Company to maintain the following three financial ratios, which are measured at the end of each calendar quarter:

•

a current ratio, which is the ratio of the Company’s consolidated current assets (includes unused commitment under the credit facility and excludes derivative assets) to its consolidated current liabilities, of not less than 0.75 to 1.0 as of March 31, 2013 and 1.0 to 1.0 at the end of each fiscal quarter thereafter;

•

sell assets;

•

a minimum interest coverage ratio, which is the ratio of consolidated EBITDAX based on the trailing twelve month period to consolidated interest expense, of not less than 2.5 to 1.0; and

•

make loans to others;

•

an asset coverage ratio, which is the ratio of the present value of the Company’s oil and gas reserves (discounted at 10% per annum) to the sum of all our secured debt (including 50% of any debt incurred by the Company’s Marcellus joint venture under its credit facility or any replacement or refinancing of its credit facility) of not less than 1.5 to 1.0 so long as any debt is outstanding under the term loan facility.

The Company was in compliance with such covenants and ratios as of December 31, 2013.

Concurrently with the closing of Rice Energy’s IPO, the Company amended its revolving credit facility to, among other things, increase the maximum commitment amount to $1.5 billion and lower the interest rate owed on amounts borrowed under the revolving credit facility. After giving effect to the amendment, the borrowing base under the credit facility was increased to $350 million as a result of the Marcellus JV Buy-In. Eurodollar loans under the amended 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 Company will be subject to the same financial ratios and substantively the same restricted covenants as under the revolving credit facility prior to such amendment. The amended revolving credit facility will mature upon the earlier of the date that is five years following the closing of the amendment and the date that is 180 days prior to the maturity of the second lien term loan facility, if any amounts are outstanding under that facility as of such date.

•

make investments;

Expected aggregate maturities of notes payable subsequent to December 31, 2013, are as follows (in thousands):

•

enter into mergers;

2014

$

20,120

2015

3,058

2016

2,277

•

make or declare dividends;

2017

2,173

2018

399,314

•

hedge future production or interest rates;

Total

$

426,942

Interest paid in cash was $27.7 million and $10.2 million for years ended December 31, 2013 and 2012, respectively. See Note 1 for information on capitalized interest.

•

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 September 30, 2014.

Debentures (d)

In June of 2011, Rice Drilling B sold $60.0 million of its 12% Senior Subordinated Convertible Debentures due 2014 (the “Debentures”) in a private placement to certain accredited investors as defined in Rule 501 of Regulation D. The Debentures accrued interest at 12% per year payable monthly in arrears by the 15th day of the month and had a scheduled maturity date of July 31, 2014 (“Maturity Date”). The Debentures were Rice Drilling B’s unsecured senior obligations and ranked equally with all of Rice Drilling B’s then-current and future senior unsecured indebtedness.

From July 31, 2013 through August 20, 2013 (the “put redemption period”), any holder of Debentures had the right to cause Rice Drilling B to repurchase all or any portion of the Debentures owned by such holder at 100% of the portion of the principal amount of the Debentures as to which the right was being exercised, plus a premium of 20%. During the put redemption period, Rice Drilling B repurchased $53.1 million of outstanding Debentures and paid a put premium of $10.6 million in accordance with the terms of the agreements.

At any time after July 31, 2013 until the Maturity Date, Rice Drilling B had the right to redeem all, but not less than all, of the Debentures on 30 days prior written notice at a redemption price equal to 100% of the principal amount of the Debentures plus a premium of 50%. In connection with the IPO, the Debentures and warrants of Rice Drilling B were amended to become convertible or exercisable for shares of common stock of the Company. On February 28, 2014, Rice Drilling B issued a redemption notice on the remaining Debentures, which set a redemption date of March 28, 2014. Prior to the redemption date, $6.6 million of the Debentures were converted into 570,945 shares of the Company’s common stock. The remaining principal balance of $0.3 million that was not converted will be paid upon request from holders of the remaining Debentures. The premium of $0.1 million was recorded to expense in the nine months ended September 30, 2014. As of September 30, 2014, the remaining principal balance was $0.2 million.

In connection with the convertible debenture offering, Rice Drilling B granted warrants that were issued on August 15, 2011 to certain of the broker-dealers involved in the private placement. These warrants are considered to be separate instruments issued solely in lieu of cash compensation for services provided by the broker-dealers. Two separate classes of warrants were issued with the sole difference being the exercise price. At September 30, 2014, 90 warrants remain exercisable at a weighted average price of $11.57 per share of the Company’s common stock. The 90 warrants are exercisable in exchange for up to 77,363 shares. For the three and nine months ended September 30, 2014, warrants were exercised in exchange for 126,240 and 686,006 shares of the Company’s common stock, respectively.

Expected Aggregate Maturities

Expected aggregate maturities of notes payable as of September 30, 2014 are as follows (in thousands):

Remainder of Year Ending December 31, 2014

$

326

Year Ending December 31, 2015

680

Year Ending December 31, 2016

Year Ending December 31, 2017

Year Ending December 31, 2018 and Beyond

900,000

Total

$

901,006

Interest paid in cash was $30 thousand and $8.9 million for the three and nine months ended September 30, 2014, respectively, and $6.5 million and $17.2 million for the three and nine months ended September 30, 2013, respectively.

Derivative_Instruments

Derivative Instruments	9 Months Ended													12 Months Ended
	Sep. 30, 2014													Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'													'
Derivative Instruments	'													'
	3	Derivative Instruments												11	Derivative Instruments
	The Company uses derivative commodity instruments that are placed with major financial institutions whose creditworthiness is regularly monitored. Our derivative counterparties share in the Amended Credit Agreement collateral. The Company’s derivative commodity instruments have not been designated as hedges for accounting purposes; therefore, all gains and losses are recognized in income currently. As of September 30, 2014, the Company has entered into derivative instruments with various financial institutions, fixing the price it receives for a portion of its natural gas through December 1, 2017, as summarized in the following table:													The Company uses derivative commodity instruments that are placed with major financial institutions whose creditworthiness is regularly monitored. Our derivative counterparties share in the Credit Agreement collateral. The Company’s derivative commodity instruments have not been designated as hedges for accounting purposes; therefore, all gains and losses were recognized in income currently. As of December 31, 2013, the Company entered into derivative instruments with Wells Fargo Bank, N.A. and Bank of Montreal fixing the price it receives for natural gas through November 28, 2017, as summarized in the following table:
	Swap Contract Expiration		MMBtu/day		Weighted									Swap Contract Expiration		MMbtu/day			Weighted
					Average Price														Average Price
	Fourth quarter of 2014			173,000	$	4.15								2014			87,219		$	4.112
	2015			166,000	$	4.09								2015			58,781		$	4.153
	2016			214,000	$	4.14								2016			68,326		$	4.233
	2017			60,000	$	4.24								2017			30,000		$	4.343
	Collar Contract Expiration		MMBtu/day		Floor/Ceiling
	Fourth quarter of 2014			10,000	$	3.00/5.80								Collar Contract Expiration		MMbtu/day			Floor/Ceiling
	2015			139,000	$	3.96/4.65								2014			10,000		$	3.000/$5.800
														2015			45,000		$	4.000/$4.500
	Basis Contract Expiration		MMBtu/day		Swap
					($/MMBtu)
	Fourth quarter of 2014			60,000	$	(0.46	)							Basis Contract Expiration		MMbtu/day			Swap
	2015			62,000	$	(0.57	)												($/MMBtu)
	2016			38,000	$	(0.63	)							2014			15,000		$	(0.205	)
														2015			10,000		$	(0.410	)
	Put Contract Expiration		MMBtu/day		Put Premium									The following is a summary of the Company’s derivative instruments, which are recorded in the consolidated balance sheets as of December 31, 2013 and 2012 (in thousands):
					($/MMBtu)
	2014			50,000	$	0.45
																December 31, 2013			December 31, 2012
	The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets for the periods presented, all at fair value:													Current derivative assets		$	2,270		$	46
														Long-term derivative assets			6,030			—
			As of September 30, 2014													$	8,300		$	46
	(in thousands)		Derivative instruments, recorded		Derivative instruments subject to			Derivative Instruments, net
			in the Condensed Consolidated		master netting arrangements									Current derivative liabilities		$	3,235		$	2,306
			Balance Sheet, gross											Long-term derivative liabilities			1,109			—
	Derivative assets		$	39,672	$	(22,571	)	$	17,101
	Derivative liabilities		$	22,571	$	(22,571	)	$	—							$	4,344		$	2,306
														Net current value of derivative liabilities		$	(965	)	$	(2,260	)
			As of December 31, 2013
	(in thousands)		Derivative instruments, recorded		Derivative instruments subject to			Derivative Instruments, net						Net long-term value of derivative assets		$	4,921		$	—
			in the Condensed Consolidated		master netting arrangements
			Balance Sheet, gross
	Derivative assets		$	13,000	$	(4,700	)	$	8,300					The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the consolidated balance sheets for the periods presented, all at fair value (in thousands):
	Derivative liabilities		$	256	$	(4,600	)	$	(4,344	)
	The following table presents the realized and unrealized gains or losses presented as gain or loss on derivatives in the condensed consolidated statements of operations for the periods presented:
																December 31, 2013
														Description		Gross Amounts of			Gross Amounts			Net Amounts of
			Three Months Ended September 30,					Nine Months Ended September 30,								Recognized Assets			Offset on			Assets (Liabilities) on
	(in thousands)		2014		2013			2014			2013								Balance Sheet			Balance Sheet
	Realized gain (loss)		$	171	$	788		$	(20,782	)	$	(1,053	)	Derivative assets		$	13,000		$	(4,700	)	$	8,300
	Unrealized gain		$	36,764	$	7,262		$	26,139		$	17,751		Derivative liabilities		$	256		$	(4,600	)	$	(4,344	)
																December 31, 2012
														Description		Gross Amounts of			Gross Amounts			Net Amounts of
																Recognized Assets			Offset on			Assets (Liabilities) on
																			Balance Sheet			Balance Sheet
														Derivative assets		$	416		$	(370	)	$	46
														Derivative liabilities		$	—		$	(2,306	)	$	(2,306	)
														Both realized and unrealized gains and losses are recorded as a gain or loss on derivatives in the consolidated statement of operations under other income/expense. The Company had an unrealized gain of $6.2 million for the year ended December 31, 2013 and an unrealized loss of $2.3 million for the year ended December 31, 2012. There were no unrealized gains or losses for the year ended December 31, 2011. The Company had realized gains related to contract settlements of $0.7 million, $0.9 million and $0.6 million for the years ended December 31, 2013, 2012 and 2011 respectively.

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	9 Months Ended														12 Months Ended
	Sep. 30, 2014														Dec. 31, 2013
Fair Value Disclosures [Abstract]	'														'
Fair Value of Financial Instruments	'														'
	4	Fair Value of Financial Instruments													5	Fair Value of Financial Instruments
	The Company determines fair value on a recurring basis for its liability related to restricted units and recorded amounts for derivative instruments as these instruments are required to be recorded at fair value for each reporting amount. Certain amounts in the Company’s financial statements were measured at fair value on a nonrecurring basis including discounts associated with long-term debt. Fair value is based on quoted market prices, where available. If quoted market prices are not available, fair value is based upon models that use as inputs market-based parameters, including but not limited to forward curves, discount rates, broker quotes, volatilities, and nonperformance risk.														The Company determines fair value on a recurring basis for its liability related to restricted units and recorded amounts for derivative instruments as these instruments are required to be recorded at fair value for each reporting amount. Certain amounts in the Company’s financial statements are measured at fair value on a nonrecurring basis including discounts associated with long-term debt. Fair value is based on quoted market prices, where available. If quoted market prices are not available, fair value is based upon models that use as inputs market-based parameters, including but not limited to forward curves, discount rates, broker quotes, volatilities, and nonperformance risk.
	The Company has categorized its fair value measurements into a three-level fair value hierarchy, based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The Company’s fair value measurements relating to restricted units are included in Level 3. The Company’s fair value measurements relating to derivative instruments are included in Level 2. Since the adoption of fair value accounting, the Company has not made any changes to its classification of financial instruments in each category.														The Company has categorized its fair value measurements into a three-level fair value hierarchy, based on the priority of the inputs to the valuation technique. The fair value hierarchy gives the highest priority to quoted prices in active markets for identical assets and liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The Company’s fair value measurements relating to restricted units are included in Level 3. The Company’s fair value measurements relating to derivative instruments are included in Level 2. Since the adoption of fair value accounting, the Company has not made any changes to its classification of financial instruments in each category.
	Items included in Level 3 are valued using internal models that use significant unobservable inputs. Items included in Level 2 are valued using management’s best estimate of fair value corroborated by third-party quotes.
															Items included in Level 3 are valued using internal models that use significant unobservable inputs. Items included in Level 2 are valued using management’s best estimate of fair value corroborated by third-party quotes.
	The following assets and liabilities were measured at fair value on a recurring basis during the period (refer to Note 3 for details relating to derivative instruments):														The following liabilities were measured at fair value on a recurring basis during the period (refer to Notes 9 and 11 for details relating to the restricted units and derivative instruments) (in thousands):
			As of September 30, 2014																	Fair Value Measurements at
						Fair Value Measurements at Reporting Date Using														Reporting Date Using
	(in thousands)		Carrying			Total			Quoted Prices		Significant		Significant		Description		December 31,			Quoted Prices in		Significant Other		Significant
			Value			Fair			in Active		Other		Unobservable				2013			Active Markets		Observable		Unobservable
						Value			Markets for		Observable		Inputs							for Identical		Inputs		Inputs (Level 3)
									Identical Assets		Inputs		(Level 3)							Assets		(Level 2)
									(Level 1)		(Level 2)									(Level 1)
	Assets:														Assets:
	Derivative instruments, at fair value		$	17,101		$	17,101		$	—	$	17,101	$	—	Derivative Instruments, at fair value		$	4,921		$	—	$	4,921	$	—
	Total assets		$	17,101		$	17,101		$	—	$	17,101	$	—	Total assets		$	4,921		$	—	$	4,921	$	—
	Liabilities:														Liabilities:
	Derivative instruments, at fair value		$	—		$	—		$	—	$	—	$	—	Restricted units, at fair value		$	36,306		$	—	$	—	$	36,306
															Derivative Instruments, at fair value			965			—		965		—
	Total liabilities		$	—		$	—		$	—	$	—	$	—
															Total liabilities		$	37,271		$	—	$	965	$	36,306
			As of December 31, 2013
						Fair Value Measurements at Reporting Date Using														Fair Value Measurements at
	(in thousands)		Carrying			Total			Quoted Prices		Significant		Significant							Reporting Date Using
			Value			Fair			in Active		Other		Unobservable		Description		December 31,			Quoted Prices in		Significant Other		Significant
						Value			Markets for		Observable		Inputs				2012			Active Markets		Observable		Unobservable
									Identical		Inputs		(Level 3)							for Identical		Inputs		Inputs (Level 3)
									Assets		(Level 2)									Assets		(Level 2)
									(Level 1)											(Level 1)
	Assets:														Liabilities:
	Derivative instruments, at fair value		$	4,921		$	4,921		$	—	$	4,921	$	—	Restricted units, at fair value		$	5,667		$	—	$	—	$	5,667
															Derivative Instruments, at fair value			2,260			—		2,260		—
	Total assets		$	4,921		$	4,921		$	—	$	4,921	$	—
															Total liabilities		$	7,927		$	—	$	2,260	$	5,667
	Liabilities:
	Restricted units, at fair value		$	36,306		$	36,306		$	—	$	—	$	36,306
	Derivative instruments, at fair value			965			965		$	—		965	$	—
																	Fair Value
	Total liabilities		$	37,271		$	37,271		$	—	$	965	$	36,306			Measurements
																	Using
																	Significant
																	Unobservable
			Fair Value Measurements Using														Inputs (Level 3)
			Significant Unobservable Inputs												Balance at December 31, 2011		$	6,800
			(Level 3)												Total gain or losses:
	(in thousands)		2014			2013									Included in earnings			115
	Balance as of January 1,		$	36,306		$	5,667								Transfers in and/or out of Level 3			—
	Total gain or losses:			—			—								Repurchase of restricted units			(1,133	)
	Included in earnings			—			—								Settlement			(115	)
	Transfers in and/or out of Level 3			—			—
	Repurchase of restricted units			—			(2,267	)							Balance at December 31, 2012		$	5,667
	Converted to shares of common stock			(36,306	)		—								Total gain or losses:
															Included in earnings			32,906
	Balance as of September 30,		$	—		$	3,400								Transfers in and/or out of Level 3			—
															Repurchase of restricted units			(2,267	)
	Gains and losses related to restricted units included in earnings for the period are reported in operating expenses in the statements of consolidated operations.														Settlement			—
	The carrying value of cash equivalents approximates fair value due to the short maturity of the instruments.
															Balance at December 31, 2013		$	36,306
	The estimated fair value and carrying amount of long-term debt as reported on the condensed consolidated balance sheets as of September 30, 2014 and December 31, 2013 is shown in the table below (refer to Note 2 for details relating to the borrowing arrangements). The fair value was estimated using Level 2 inputs based on rates reflective of the remaining maturity as well as the Company’s financial position.
															Gains and losses related to restricted units included in earnings for the period are reported in operating expenses in the statements of consolidated operations.
			As of September 30, 2014						As of December 31, 2013						The carrying value of cash equivalents approximates fair value due to the short maturity of the instruments.
			Carrying Value			Fair Value			Carrying Value		Fair Value				The estimated fair value of long-term debt on the consolidated balance sheets at December 31, 2013 and 2012 is shown in the table below (refer to Note 4 for details relating to the borrowing arrangements) (in thousands). The fair value was estimated using Level 3 inputs based on rates reflective of the remaining maturity as well as the Company’s financial position.
	Long-Term Debt (in thousands)
Senior Notes Offering		$	900,000		$	866,864		$	—	$	—
Second Lien Term Loan Facility			—			—			293,821		315,284			Description		2013			2012
Senior Secured Revolving Credit Facility			—			—			115,000		115,000			Long-term debt, at fair value
Debentures			—			—			6,890		12,671			Debentures		$	12,671		$	70,220
NPI Note			—			—			8,028		8,028			Wells Fargo Energy Capital Credit Facility			—			70,000
Other			1,006			1,006			3,203		3,203			Second Lien Term Loan Facility			315,284			—
														NPI Note			8,028			15,282
Total		$	901,006		$	867,870		$	426,942	$	454,186			Senior Secured Revolving Credit Facility			115,000			—
														Other			3,203			4,038
														Total		$	454,186		$	159,540

Acquisitions

Acquisitions	9 Months Ended														12 Months Ended
	Sep. 30, 2014														Dec. 31, 2013
Business Combinations [Abstract]	'														'
Acquisitions	'														'
	5	Acquisitions													14	Acquisitions
	Marcellus JV Buy-In														On December 31, 2012, the Company entered into a transaction to acquire certain producing shallow natural gas wells and unproved properties (the “Shallow-Well Acquisition”). Total firm consideration in the Shallow-Well Acquisition was approximately $10.0 million of which $3.3 million was paid to the seller in January 2013. An additional $1.0 million was paid to the seller as of December 31, 2013, reducing the notes payable. The remaining consideration will be transferred to the seller from 2014 to 2015. In addition to the firm consideration, the seller has the right to participate in the development of the unproved properties and the Company is responsible for funding $3.7 million of these activities. The Company has recorded the $10.0 million purchase price with the offset to proved and unproved properties.
	Prior to the completion of the Marcellus JV Buy-In, the Company accounted for its 50% equity interest in the Marcellus joint venture under the equity method of accounting. Immediately prior to the completion of the Marcellus JV Buy-In, the fair value of the existing equity in the Marcellus joint venture was approximately $250.6 million. The acquisition date fair value of the existing equity investment was based on an income approach. The income approach, considered to be a Level 3 fair value method, calculated the present value of the future cash flows related to the natural gas properties as of the date of the transaction, utilizing a discount rate based upon market participant assumptions, natural gas strip prices as of the date of the transaction, and a decline curve consistent with our geographic peers. As a result of the Marcellus JV Buy-In, the Company was required to remeasure its equity investment at fair value, which resulted in a non-recurring gain of approximately $203.6 million during the nine months ended September 30, 2014. Based on valuations performed as of the acquisition date, the natural gas properties had a fair value of approximately $343.0 million. The acquisition consolidated the resources of the Company and the Marcellus joint venture, which enables management to optimize and prioritize the development of their combined natural gas properties. The management team of the Company historically served as the management team of the Marcellus joint venture, providing it with familiarity with its assets and operations. As a result of these factors, the excess purchase price over net assets and liabilities assumed of $338.0 million was allocated to goodwill.
	The purchase price allocation and resulting impact on the corresponding condensed consolidated balance sheet relating to the Marcellus JV Buy-In is as follows:
	(in thousands)
	Financial assets		$	34,242
	Proved natural gas properties, net			288,000
	Unproved natural gas properties			55,000
	Goodwill			338,036
	Financial liabilities			(49,313	)
	Long-term debt			(75,400	)
	Deferred tax liability			(17,933	)
	Total identifiable net assets		$	572,632
	Cash paid for acquisitions		$	100,000
	Fair value of equity issued			222,000
	Fair value of pre-existing equity investment			250,632
	Total consideration		$	572,632
	Subsequent to the completion of the Marcellus JV Buy-In and excluding the related gain of $203.6 million recorded at January 29, 2014, the 100%-owned Marcellus joint venture contributed the following to the Company’s consolidated operating results for the three and nine months ended September 30, 2014:
	(in thousands)		Three Months			Nine Months
			Ended September 30,			Ended September 30,
			2014			2014
	Revenue		$	30,689		$	103,290
	Net income		$	12,008		$	57,419
	Pro Forma Information (Unaudited)
	The following unaudited pro forma combined financial information presents the Company’s results as though the Marcellus JV Buy-In had been completed at January 1, 2014 and January 1, 2013, respectively.
	(in thousands, except per share data)		Three Months Ended						Nine Months Ended
			September 30,						September 30,
			2014			2013			2014			2013
	Pro forma net revenues		$	79,127		$	42,959		$	273,480		$	123,676
	Pro forma net loss		$	(6,862	)	$	(29,088	)	$	(83,794	)	$	(1,540	)
	Pro forma loss per share (basic)		$	(0.05	)	$	(0.33	)	$	(0.65	)	$	(0.02	)
	Pro forma loss per share (diluted)		$	(0.05	)	$	(0.33	)	$	(0.65	)	$	(0.02	)
	Momentum Acquisition
	On February 12, 2014, the Company, through its indirect wholly-owned subsidiary Rice Poseidon Midstream LLC, a Delaware limited liability company (“Rice Poseidon”), entered into a purchase and sale agreement with M3 Appalachia Gathering LLC, a Delaware limited liability company (“M3”), to acquire (the “Momentum Acquisition”) certain gas gathering assets in eastern Washington and Greene Counties, Pennsylvania. On April 17, 2014, the Company completed the Momentum Acquisition for aggregate consideration of approximately $111.4 million (the “Purchase Price”). The Company funded the Purchase Price with cash on hand.
	As of September 30, 2014, $48.9 million of the Purchase Price was allocated to intangible assets related to customer contracts on the condensed consolidated balance sheets and the remaining balance was recorded to proved and unproved natural gas properties. The customer contracts are amortized over 30 years using a straight line method and amortization expense recorded in the condensed consolidated statements of operations for the three and nine months ended September 30, 2014 was $0.4 million and $0.7 million, respectively. The estimated annual amortization expense over the next five years is as follows: remainder of 2014—$0.4 million, 2015—$1.6 million, 2016—$1.6 million, 2017—$1.6 million, and 2018—$1.6 million.
	The properties acquired in the Momentum Acquisition consist of a 28-mile, 6-16 inch gathering system in eastern Washington County, Pennsylvania, and permits and rights of way in Washington and Greene Counties, Pennsylvania, necessary to construct an 18-mile, 30 inch gathering system connecting the northern system to the Texas Eastern pipeline. The northern system is supported by long-term contracts with acreage dedications covering approximately 20,000 acres from third parties. Once fully constructed, the acquired systems are expected to have an aggregate capacity of over 1 billion cubic feet of natural gas per day.
	Greene County Acquisition
	On July 7, 2014, the Company entered into a definitive purchase and sale agreement to acquire 21,913 net acres and 12 developed Marcellus wells in southwestern Greene County, Pennsylvania from Chesapeake Appalachia, L.L.C. and its partners for approximately $329.5 million (the “Greene County Acquisition”). The purchase price was allocated to proved and unproved natural gas properties in the amounts of $151.3 million and $178.2 million, respectively. The transaction closed on August 1, 2014, with an effective date of February 1, 2014. The Company funded the Greene County Acquisition with cash on hand.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended		12 Months Ended
	Sep. 30, 2014		Dec. 31, 2013
Commitments and Contingencies Disclosure [Abstract]	'		'
Commitments and Contingencies	'		'
	6	Commitments and Contingencies	12	Commitments and Contingencies
	On October 14, 2013, the Company entered into a Development Agreement and Area of Mutual Interest (“AMI”) Agreement with Gulfport Energy Corporation (“Gulfport”) covering approximately 50,000 aggregate net acres in the Utica Shale in Belmont County, Ohio. The Company refers to these agreements as “Utica Development Agreements.” Pursuant to the Utica Development Agreements, the Company had approximately 68.80% 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 42.63% 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.		On October 14, 2013, the Company entered into a Development Agreement and Area of Mutual Interest (“AMI”) Agreement with Gulfport Energy Corporation (“Gulfport”) covering approximately 50,000 aggregate net acres in the Utica Shale in Belmont County, Ohio. The Company refers to these agreements as “Utica Development Agreements.” Pursuant to the Utica Development Agreements, the Company had approximately 68.80% 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 42.63% 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 approximate the Company’s current relative acreage positions in each area.
	Each quarter during the term of the Development Agreement, the Company and Gulfport will establish a work program and budget detailing the proposed exploration and development to be performed in the Northern and Southern Contract Areas, respectively, for the following year. The number of horizontal wells proposed to be drilled in each of the Northern Contract Area and Southern Contract Area is limited by the Development Agreement as follows: in 2014, between eight and 40 wells; in 2015, between eight and 50 wells; and thereafter, unlimited.		Each quarter during the term of the Development Agreement, the Company and Gulfport will establish a work program and budget detailing the proposed exploration and development to be performed in the Northern and Southern Contract Areas, respectively, for the following year. The number of horizontal wells proposed to be drilled in each of the Northern Contract Area and Southern Contract Area is limited by the Development Agreement as follows: in 2013, no more than five wells; in 2014, between eight and 40 wells; in 2015, between eight and 50 wells; and thereafter, unlimited.
	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 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 AMI and Southern AMI, 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 September 30, 2014 totaled $2,887.2 million (remainder of 2014—$15.7 million, 2015—$94.3 million, 2016—$113.6 million, 2017—$113.4 million, 2018—$112.0 million, 2019 – $141.8 million and thereafter—$2,296.4 million).		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.
	As of September 30, 2014, the Company had seven drilling rigs (four horizontal and three tophole) under contract, of which five expire in 2015 and two expire in 2017. Future payments under these contracts as of September 30, 2014 totaled $85.9 million (remainder of 2014—$12.2 million, 2015—$46.0 million, 2016—$20.8 million and 2017—$6.9 million). Any other rig performing work for us 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 we are committed to pay without regard to our proportionate share based on our working interest.		The Company has commitments for gathering and firm transportation under existing contracts with third parties. Future payments for these items as of December 31, 2013 totaled $637.2 million (2014—$28.3 million, 2015—$52.1 million, 2016—$65.6 million, 2017—$65.4 million, 2018—$64.0 million and thereafter—$361.8 million).
	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.		As of December 31, 2013, the Company had two horizontal drilling rigs under contract. One of these contracts expires in 2014. A third rig, which we took delivery of in February 2014, expires in 2015. Future payments for these items as of December 31, 2013 totaled $21.4 million (2014—$11.7 million and 2015—$9.7 million). Any other rig performing work for us is doing so 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 we are committed to pay without regard to our proportionate share based on our working interest.
			Capital leases are entered into for vehicle purchases. The acquisition value of vehicles recorded under capital leases is $2.0 million. Accumulated amortization related to capital leases was $0.2 million and $8 thousand as of December 31, 2013 and 2012, respectively. Amortization expense related to capital leases was $0.2 million, $8 thousand and $0 as of December 31, 2013, 2012 and 2011, respectively. Future lease payments under capital leases as of December 31, 2013 totaled $1.6 million (2014—$0.4 million, 2015—$0.3 million, 2016—$0.3 million, 2017—$0.5 million and 2018—$0.1 million).
			Operating leases are primarily entered into for various office locations. Rental expense under operating leases was $0.2 million, $0.2 million and $0.1 million for the years ended December 31, 2013, 2012 and 2011, respectively. Future lease payments under non-cancelable operating leases as of December 31, 2013 totaled $4.5 million (2014—$0.6 million, 2015—$1.0 million, 2016—$0.9 million, 2017—$0.8 million, 2018—$0.8 million and thereafter—$0.4 million).

Stockholders_Equity

Stockholders' Equity	9 Months Ended		12 Months Ended
	Sep. 30, 2014		Dec. 31, 2013
Equity [Abstract]	'		'
Stockholders' Equity	'		'
	7	Stockholders’ Equity	8	Stockholders’ Equity
	On January 29, 2014, pursuant to the Master Reorganization Agreement (the “Master Reorganization Agreement”) among the Company, Rice Drilling B, Rice Appalachia, Rice Holdings, Rice Partners, NGP Holdings, NGP RE Holdings, L.L.C., (“NGP RE Holdings”) NGP RE Holdings II, L.L.C. (“NGP RE II” and, together with NGP RE Holdings, “Natural Gas Partners”), Mr. Daniel J. Rice III, Rice Merger LLC (“Merger Sub”) and each of the persons holding incentive units representing interests in Rice Appalachia (collectively, the “Incentive Unitholders”) dated as of January 23, 2014, (i) (a) Rice Partners contributed a portion of its interests in Rice Appalachia to Rice Holdings, (b) Natural Gas Partners contributed its interests in Rice Appalachia to NGP Holdings and (c) the Incentive Unitholders contributed a portion of their incentive units to Rice Holdings and NGP Holdings, in each case in return for substantially similar incentive units in such entities; (ii) NGP Holdings, Rice Holdings and Mr. Daniel J. Rice III contributed their respective interests in Rice Appalachia to the Company in exchange for 43,452,550, 20,300,923 and 2,356,844 shares of common stock, respectively; (iii) Rice Partners contributed its remaining interest in Rice Appalachia to the Company in exchange for 20,000,000 shares of common stock; (iv) the Incentive Unitholders contributed their remaining interests in Rice Appalachia to the Company in exchange for 160,831 shares of common stock, each of which were issued by the company in connection with the closing of the IPO. In connection with the IPO, in the first quarter of 2014, we recognized non-cash compensation expense of $3.4 million for these 160,831 shares.		Stockholders include consultants and employees of the Company as well as REA.
	In addition, on January 29, 2014, pursuant to the Agreement and Plan of Merger (the “Merger Agreement”) among the Company, Rice Drilling B and Merger Sub dated as of January 23, 2014, the Company issued 1,728,852 shares of common stock to the members of Rice Drilling B (other than Rice Appalachia) in exchange for their units in Rice Drilling B.		As of December 31, 2012, all common stock associated with the Class A units was reserved for issuance pursuant to a Restricted Unit Agreement (see Note 9). Additionally, in connection with NGP’s $100.0 million equity investment into REA in 2012, of which 100% of the net proceeds were invested into Rice Energy, Rice Energy issued 13,252,145 shares of common stock to REA.
	In August 2014, we completed a public offering (“August 2014 Equity Offering”) of 13,729,650 shares of our common stock at $27.30 per share, which included 7,500,000 shares sold by us and 6,229,650 shares sold by affiliates of Natural Gas Partners and Alpha Natural Resources (the “Selling Stockholders”). After deducting underwriting discounts and commissions of $7.7 million and transaction costs, the Company received net proceeds of $196.3 million. The Company received no proceeds from the sale of shares by the Selling Stockholders. The net proceeds from this offering are being used to fund a portion of our 2014 capital budget.		During 2013, the Company finalized a $300.0 million equity commitment from NGP of which approximately $200.0 million of NGP’s commitment was funded at closing in April 2013. Cash proceeds from the investment were used to fund Utica Shale leasehold acquisitions in southeastern Ohio. As a part of the reorganization that occurred in connection with the Rice Energy IPO, the Company became a wholly-owned subsidiary of REA and the restricted units were exchanged for common stock of Rice Energy. Furthermore, NGP’s equity commitments terminated in connection with the closing of the Rice Energy IPO.
	The Company’s Board of Directors did not declare or pay a dividend for the three or nine months ended September 30, 2014 or 2013.		Liquidation Preference
			Prior to the reorganization in connection with the Rice Energy IPO, the terms of the governance documents of the Company provided that in the event of any liquidation, dissolution or winding up of the Company, distributions would first be made to members holding senior preferred units until such members have received cumulative distributions in an amount equal to the preferred return as defined in the REA agreement, second to the members holding preferred units in the amount of $49.9 million, then, until the Company had achieved breakeven operations, as defined, to the members holding preferred and Class A common units in proportion to their ownership interests and thereafter to the members in proportion to their ownership units. Following the restructuring, distributions in such event would be made to the sole member.
			Repurchase Option
			Up until the third anniversary of the grant of Class A and B restricted units, the Company or a member of its affiliates had the right to repurchase all of the units from the member at $1,700 per unit, as defined and in accordance with the Company’s then-existing limited liability company agreement. Subsequent to the third anniversary of the grant of Class A and B restricted units, the Company or a member of its affiliates has the right to repurchase all of the units from the member at fair market value, not less than $1,700 per unit, in accordance with the Company’s then-existing limited liability company agreement.
			During 2012, REA exercised the option to repurchase all common shares associated with the 2,000 Class B restricted units for $3.4 million. In December 2012, a payment of $1.1 million was made by the Company to the member on behalf of REA. Additional payments of $2.3 million were made by the Company on behalf of REA in 2013. The Company was reimbursed these costs.

Incentive_Units

Incentive Units	12 Months Ended		9 Months Ended
	Dec. 31, 2013		Sep. 30, 2014				Sep. 30, 2014
			Incentive Units				Restricted Stock
Incentive Units	'		'				'
	10	Incentive Units	8	Incentive Units			9	Stock Compensation
	REA, as the parent company of Rice Drilling B, granted Incentive Units to certain members of management. The Incentive Units are not accounted for as equity instruments as the Incentive Units do not have the characteristics of a substantive class of equity. Rather, the Incentive Units provide the holders with a performance bonus for fair value accretion of REA equity. In connection with the January 2012 NGP investment in REA, 100,000 Tier I Legacy units, 13,000 Tier II Legacy units, and 17,000 Tier III Legacy units were issued. The Incentive Units will only be paid in cash and payout for each tier occurs when a specified level of cumulative cash distributions has been received by NGP.		In connection with the IPO and the related corporate reorganization, the Rice Appalachia incentive unit holders contributed their Rice Appalachia incentive units to Rice Holdings and NGP Holdings in return for substantially similar incentive units in such entities (except for those incentive units related to the incentive burden attributable to Mr. Daniel J. Rice III, which we acquired from the holders of such incentive units in exchange for the issuance of 160,831 shares of our common stock). In the first quarter of 2014, certain incentive units granted by NGP Holdings to certain employees triggered the pre-determined payout criteria, resulting in a cash payment by NGP Holdings of $4.4 million. No payments were made in respect of incentive units prior to the completion of the Company’s IPO. These two transactions resulted in non-cash compensation expense of $7.8 million being recorded in the first quarter of 2014 by the Company. As a result of the IPO, the payment likelihood related to the incentive units was deemed probable, requiring the Company to recognize expense.				During the nine months ended September 30, 2014, the Company granted stock compensation awards to certain non-employee directors and employees. The awards consisted of restricted stock units, which vest upon the passage of time, and performance units, which vest based upon attainment of specified performance criteria. Stock compensation expense related to these awards was $2.1 million and $3.3 million for the three and nine months ended September 30, 2014, respectively. As of September 30, 2014, the Company has unrecognized compensation expense related to these equity awards of $17.5 million.
	In connection with the April 2013 NGP investment in REA, an additional 900,000 Tier I Legacy units, 987,000 Tier II Legacy Units and 983,000 Tier III Legacy Units were issued. In addition, 100,000 New Tier I Units, 100,000 New Tier II Units, 100,000 New Tier III Units, and 100,000 New Tier IV Units were issued. In June 2013, an additional 717,546 New Tier I Units, 577,546 New Tier II Units, 577,546 New Tier III Units, and 577,546 New Tier IV Units were issued to certain members of management. Similar to above, there is no payout of the awards until specified level of cumulative cash distributions has been received by NGP.		For the three and nine months ended September 30, 2014, we recognized approximately $26.4 million and $101.7 million of compensation expense, respectively, relative to these interests, of which $12.0 million and $19.8 million has been paid by Mr. Daniel J. Rice III and NGP Holdings for the three and nine months ended September 30, 2014, respectively. We expect to recognize approximately $79.8 million of additional compensation expense over the remaining expected service periods, related to the Rice Holdings interests. The NGP Holdings interests are considered a liability-based award and will be adjusted on a quarterly basis until all payments have been made. As of September 30, 2014, the unrecognized compensation expense related to the NGP Holdings units is approximately $77.3 million which will be recognized over the remaining expected service period. The compensation expense related to these interests is treated as additional paid in capital from Rice Holdings and NGP Holdings in our financial statements and is not deductible for federal or state income tax purposes. The compensation expense recognized is a non-cash charge, with the settlement obligation resting on NGP Holdings and Rice Holdings, and as such are not dilutive to Rice Energy Inc.
	During 2012 and 2013, no payments were made in respect of Incentive Units. The Company has not recognized compensation cost on the Incentive Units because the payment conditions, which relate to a liquidity event are not probable at December 31, 2013. The estimated payout under these awards at December 31, 2013 is approximately $142.3 million if a liquidity event were to occur. Prior to December 31, 2013, this estimate was based upon an option pricing model with various Level 3 assumptions including internal business plans that were based on judgments and estimates regarding future economic conditions, costs, inflation rates and discount rates, among other factors. To the extent market transactions were known, this information was factored into the fair value estimate. At December 31, 2013, the Company no longer used an income approach to estimate the fair value and instead utilized a market approach to estimate the fair value. This change in fair value method was a result of the Rice Energy IPO.		In August 2014, the triggering event for the Rice Holdings incentive units was achieved. As a result, in August of 2015, 2016 and 2017, Rice Holdings will distribute one third, one half and all, respectively, of its then-remaining assets (consisting solely of shares of our common stock) to its members pursuant to the terms of its limited liability company agreement. As a result, over time, the shares of our common stock held by Rice Holdings will be transferred in their entirety to Rice Partners (or its successors) and the incentive unitholders.
	On January 23, 2014, in connection with our IPO and corporate reorganization, the incentive units described above were modified. As a result of these modifications, certain of these incentive units are to be settled in cash and others are to be settled by the issuance of stock. The Company has not yet quantified the amount of the expense associated with the modifications.		As a result of our August 2014 Equity Offering, NGP Holdings paid approximately $12.0 million to holders of certain NGP Holdings incentive units.
			Three tranches of the incentive units have a time vesting feature. A rollforward of those units from IPO to September 30, 2014 is included below.
			Vested Units Balance, January 29, 2014		853,630
			Vested During Period		565,881
			Forfeited During Period		(214,869	)
			Granted During Period		214,869
			Cancelled During Period		—
			Vested Units Balance, September 30, 2014		1,419,511
			Four tranches of the incentive units do not have a time vesting feature, and their payouts are triggered upon a future payment condition. The fair value of the incentive units was estimated using a Monte Carlo simulation valuation model with the following assumptions:
			Rice Holdings
			Valuation Date		1/29/14
			Dividend Yield		0	%
			Expected Volatility		47	%
			Risk-Free Rate		1.11	%
			Expected Life (Years)		4
			Rice Holdings
			Valuation Date		4/14/14
			Dividend Yield		0	%
			Expected Volatility		45.19	%
			Risk-Free Rate		1.13	%
			Expected Life (Years)		3.8
			Rice Holdings
			Valuation Date		4/16/14
			Dividend Yield		0	%
			Expected Volatility		44.32	%
			Risk-Free Rate		1.18	%
			Expected Life (Years)		3.8
			NGP Holdings
			Valuation Date		9/30/14
			Dividend Yield		0	%
			Expected Volatility		40.2	%
			Risk-Free Rate		0.58	%
			Expected Life (Years)		2

Earnings_Per_Share

Earnings Per Share	9 Months Ended													12 Months Ended
	Sep. 30, 2014													Dec. 31, 2013
Earnings Per Share [Abstract]	'													'
Earnings Per Share	'													'
	10	Earnings Per Share												15	Earnings Per Share
	Basic earnings per share (“EPS”) is computed by dividing net income (loss) by the weighted-average number of shares of common stock outstanding during the period. Diluted earnings per share takes into account the dilutive effect of potential common stock that could be issued by the Company in conjunction with stock awards that have been granted to directors and employees. In accordance with FASB ASC Topic 260, awards of nonvested shares shall be considered to be outstanding as of the grant date for purposes of computing diluted EPS even though their issuance is contingent upon vesting. The following is a calculation of the basic and diluted weighted-average number of shares of common stock outstanding and EPS for the three and nine months ended September 30, 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.													Basic earnings per share (“EPS”) is computed by dividing net income (loss) by the weighted-average number of shares of common stock outstanding during the period. Diluted earnings per share takes into account the dilutive effect of potential common stock that could be issued by the Company in conjunction with warrants and convertible debentures. 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. 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, 2013, 2012 and 2011:
			Three Months Ended						Nine Months Ended							Year Ended December 31,
			September 30,						September 30,					(in thousands, except per share data)		2013			2012			2011
	(in thousands, except share data)		2014			2013			2014		2013			Loss (numerator):
	Income (loss) (numerator):													Net loss		$	(35,776	)	$	(19,344	)	$	(936	)
	Net income (loss)		$	(6,862	)	$	(33,652	)	$	114,675	$	(20,841	)
														Weighted-average shares (denominator):
	Weighted-average shares (denominator):													Weighted-average number of shares of common stock – basic			80,441,905			57,966,572			39,958,066
	Weighted-average number of shares of common stock—basic			132,269,081			88,000,000			125,411,524		77,894,855		Weighted-average number of shares of common stock - diluted			80,441,905			57,966,572			39,958,066
	Weighted-average number of shares of common stock—diluted			132,269,081			88,000,000			125,678,095		77,894,855
	Earnings (loss) per share:													Loss per share:
	Basic		$	(0.05	)	$	(0.38	)	$	0.91	$	(0.27	)	Basic		$	(0.44	)	$	(0.33	)		(0.02	)
	Diluted		$	(0.05	)	$	(0.38	)	$	0.91	$	(0.27	)	Diluted		$	(0.44	)	$	(0.33	)		(0.02	)
	Due to the net loss for the periods presented herein, loss per share excludes dilution for 76,800 shares and 1,671,800 shares for the three months ended September 30, 2014 and for the three and nine months ended September 30, 2013, respectively.													Approximately 1,671,800, 1,671,800 and 648,404 shares at December 31, 2013, 2012 and 2011, respectively, were not considered dilutive as we incurred a net loss in all periods presented herein.

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	11	Income Taxes
	We are a corporation under the Internal Revenue Code subject to federal income tax at a statutory rate of 35% of pretax earnings and, as such, our future income taxes will be dependent upon our future taxable income. We did not report any income tax benefit or expense for periods prior to the consummation of our IPO because Rice Drilling B, our accounting predecessor, is a limited liability company that was not and currently is not subject to federal income tax. The reorganization of our business in connection with the closing of the 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 pro forma EPS for the nine month period ending September 30, 2014 disclosed in the accompanying condensed consolidated statements of operations assumes a statutory tax rate. The components of the income tax provision are as follows:
	(in thousands)		Three Months		Nine Months
			Ended		Ended
			September 30,		September 30,
			2014		2014
	Current tax expense:
	Federal		$	—	$	—
	State			—		—
	Total			—		—
	Deferred tax expense:
	Federal			11,813		15,847
	State			2,192		2,940
	Total			14,005		18,787
	Total income tax expense		$	14,005	$	18,787
	Tax expense for the three months ended September 30, 2014 is approximately $14.0 million resulting in an effective tax rate of 196%. Tax expense for the nine months ended September 30, 2014 is approximately $18.8 million resulting in an effective tax rate of 14%. The Company estimates an annual effective income tax rate based on projected results for the year and applies this rate to income before taxes to calculate income tax expense. The effective tax rate for the three and nine months ended September 30, 2014 differ from the statutory rate due principally to non-deductible incentive unit expense and for the nine months ended September 30, 2014 pre-tax income prior to the IPO. The Company recognizes deferred tax liabilities for temporary differences between the financial statement and tax basis of assets and liabilities. The deferred tax liabilities reflected above primarily relate to intangible drilling costs, depletion, and depreciation. The effect of changes in the tax laws or tax rates is recognized in income in the period such changes are enacted.
	Based on management’s analysis, the Company did not have any uncertain tax positions as of September 30, 2014 and December 31, 2013.

New_Accounting_Pronouncements

New Accounting Pronouncements	9 Months Ended
	Sep. 30, 2014
Accounting Changes and Error Corrections [Abstract]	'
New Accounting Pronouncements	'
	12	New Accounting Pronouncements
	In May 2014, the FASB issued ASU, No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” or ASU No. 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. ASU 2014-09 will enhance comparability of revenue recognition practices across entities, industries and capital markets compared to existing guidance. Additionally, ASU 2014-09 will reduce the number of requirements to which an entity must consider in recognizing revenue as this update will replace multiple locations for guidance. 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 is effective for fiscal and interim periods beginning after December 15, 2016 and should be applied retrospectively. Early adoption of this standard is not permitted. The Company is currently evaluating the impact of the provisions of ASU 2014-09.

Summary_of_Significant_Account

Summary of Significant Accounting Policies and Related Matters	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies and Related Matters	'
	1	Summary of Significant Accounting Policies and Related Matters
	Organization, Operations and Principles of Consolidation
	The consolidated financial statements of the Company include the accounts of Rice Energy Inc. (“the Company” or “Rice Energy”) and its wholly owned subsidiaries, Rice Drilling B LLC (“Rice Drilling B”), Rice Drilling C LLC (“Rice C”), Rice Drilling D LLC (“Rice D”), RDB Real Estate Holdings LLC (“RDB Real Estate”), Blue Tiger Oilfield Services LLC (“Blue Tiger”), Rice Poseidon Midstream LLC (“Rice PM”), and Rice Olympus Midstream LLC (“Rice OM”). All significant intercompany accounts have been eliminated in consolidation.
	In October 2013, the Company was formed as a Delaware corporation for the purpose of becoming a publicly traded company and the holding company of Rice Drilling B. The historical financial information contained in this report relates to periods that ended prior to the completion of the IPO of Rice Energy. In connection with the completion of its IPO and corporate reorganization on January 29, 2014, Rice Energy became a holding company whose sole material asset consists of a 100% indirect ownership interest in Rice Drilling B. As the sole managing member of Rice Drilling B, Rice Energy is responsible for all operational, management and administrative decisions relating to Rice Drilling B. Accordingly, 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 herein.
	On January 25, 2012, Rice Partners, the owner of 90% of the total shares outstanding in Rice Energy, assigned its preferred units in Rice Energy to its wholly owned subsidiary, Rice Energy Appalachia LLC (“REA”). Concurrent with Rice Partners’ assignment of its shares to REA, REA and Natural Gas Partners (“NGP”), a private equity firm, finalized a $100.0 million equity commitment to REA from NGP of which $75 million of NGP’s commitment was funded at closing on January 25, 2012. Cash proceeds from the investments were contributed by REA to Rice Energy. NGP received a put right with respect to their equity investment at REA which was contingently exercisable upon the occurrence of certain events. The earliest date that this put right could have been exercised is January 25, 2017. The fair value of this put right was de minimis given the accretion in fair value of REA. In conjunction with the equity investment in NGP, Daniel J. Rice III converted his outstanding promissory notes into equity of REA. On August 30, 2012, NGP funded the remaining $25 million of its commitment at REA.
	During the year ended December 31, 2013, REA finalized a $300 million equity commitment from NGP, of which approximately $200 million was funded in April 2013 and contributed to Rice Energy. Cash proceeds from the investment were used to partially fund our Utica Shale leasehold acquisitions in southeastern Ohio. NGP’s equity commitments terminated in connection with the closing of the Rice Energy Inc. (“Rice Energy”) initial public offering (“IPO”).
	Rice Drilling B is the operating company of Rice Energy and as such is engaged in the acquisition, exploration, and development of natural gas properties in the Appalachian Basin.
	Use of Estimates
	The preparation of consolidated financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the dates of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting periods. Actual results could differ from those estimates and changes in these estimates are recorded when known.
	Revenue Recognition
	Sales of natural gas are recognized when natural gas has 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 tied to the Platts Gas Daily market prices.
	Cash
	The Company maintains cash at financial institutions which may at times exceed federally insured amounts and which may at times significantly exceed consolidated balance sheet amounts due to outstanding checks. The Company has no other accounts that are considered cash equivalents.
	Accounts Receivable
	Accounts receivable are primarily from the Company’s two gas marketers. The Company extends credit to parties in the normal course of business based upon management’s assessment of their creditworthiness. A valuation allowance is provided for those accounts for which collection is estimated as doubtful; uncollectible accounts are written off and charged against the allowance. In estimating the allowance, management considers, among other things, how recently and how frequently payments have been received and the financial position of the party. There was no allowance recorded for any of the periods presented in the consolidated financial statements. Accounts receivable as of December 31, 2013 and 2012 are detailed below.
			December 31,
	(in thousands)		2013		2012
	Natural gas sales		$	16,534	$	5,564
	Joint interest			6,391		1,810
	Other			8,840		1,183
	Total accounts receivable		$	31,765	$	8,557
	Investments in Joint Ventures
	The Company accounts for its oilfield service company joint venture investment and for periods prior to the completion of the Marcellus JV Buy-In accounted for our Marcellus joint venture investment, under the equity method of accounting as we have significant influence, but not control, over the joint ventures as of December 31, 2013.
	Under the equity method of accounting, investments are carried at cost, adjusted for the Company’s proportionate share of the undistributed earnings or losses and reduced for any distributions from the investment. The Company also evaluates its equity method investments for potential impairment whenever events or changes in circumstances indicate that there is an other-than-temporary decline in value of the investment. Such events may include sustained operating losses by the investee or long-term negative changes in the investee’s industry. These indicators were not present, and as a result, the Company did not recognize any impairment charges related to its equity method investments for any of the periods presented in the consolidated financial statements.
	On January 29, 2014, in connection with the closing of the IPO and pursuant to the Transaction Agreement between it and Alpha Holdings dated as of December 6, 2013 (the “Transaction Agreement”), Rice Energy completed its acquisition of Alpha Holdings’ 50% interest in its Marcellus joint venture (“Marcellus JV Buy-In”) in exchange for total consideration of $322 million, consisting of $100 million of cash and its issuance to Alpha Holdings of 9,523,810 shares of our common stock. See Note 15 for additional information.
	Natural Gas Properties
	The Company uses the successful efforts method of accounting for gas-producing activities. Costs to acquire mineral interests in gas properties, to drill and equip exploratory wells that result in proved reserves, are capitalized. 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. The Company wrote off approximately $8.1 million of costs associated with the drilling of the Bigfoot 7H in the fourth quarter of 2013.
	Unproved gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance. Capitalized costs of producing 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. Support equipment and other property and equipment not directly related to gas properties are depreciated over their estimated useful lives.
	Management’s estimates of proved reserves are based on quantities of natural gas that engineering and geological analysis demonstrates, with reasonable certainty, to be recoverable from established reservoirs in the future under current operating and economic conditions. External engineers prepare the annual reserve and economic evaluation of all properties on a well-by-well basis. Additionally, the Company adjusts natural gas reserves for major well rework or abandonment during the year as needed. The process of estimating and evaluating natural gas reserves is complex, requiring significant decisions in the evaluation of available geological, geophysical, engineering, and economic data. The data for a given property may also change substantially over time as a result of numerous factors, including additional development activity, evolving production history and a continual reassessment of the viability of production under changing economic conditions. As a result, revisions in existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates represent the Company’s most accurate assessments possible, the subjective decisions and variances in available data for various properties increase the likelihood of significant changes in these estimates over time. Because estimates of reserves significantly affect the Company’s depreciation, depletion, and amortization expense, a change in the Company’s estimated reserves could have a material effect on the Company’s operating results.
	On 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.
	Interest
	The Company capitalizes interest on expenditures for significant exploration and development projects while activities are in progress to bring the assets to their intended use. Upon completion of construction of the asset, the associated capitalized interest costs are included within our asset base and depleted accordingly. The following table summarizes the components of the Company’s interest incurred for the periods indicated (in thousands):
			2013		2012		2011
	Interest incurred:
	Interest capitalized		$	8,034	$	7,695	$	5,405
	Interest expensed			17,915		3,487		531
	Total incurred		$	25,949	$	11,182	$	5,936
	Property and Equipment
	Property and equipment are recorded at cost and are being depreciated over estimated useful lives of three to forty years on a straight-line basis. Accumulated depreciation was $1.3 million and $0.6 million at December 31, 2013 and 2012, respectively. Depreciation expense was $0.7 million, $0.6 million and $0.1 million for the years ended December 31, 2013, 2012 and 2011, respectively, and is included in depreciation, depletion, and amortization expense in the accompanying statements of consolidated operations.
	Long-Lived Assets
	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.
	Deferred Financing Costs
	Deferred financing costs are amortized on a straight-line basis, which approximates the interest method, over the term of the related agreement. Accumulated amortization was $14.3 million and $9.9 million at December 31, 2013 and 2012, respectively. Amortization expense was $5.2 million , $7.2 million and $2.7 million for the years ended December 31, 2013, 2012 and 2011, respectively. The annual amortization of deferred financing costs for years subsequent to December 31, 2013, is expected to be approximately $1.9 million in 2014, $1.9 million in 2015, $1.9 million in 2016, $1.9 million in 2017 and $1.1 million in 2018.
	Delay Rental Agreements
	The Company has leased drilling rights under agreements which specify additional payments for the privilege of deferring drilling operations for another year. Costs incurred to extend such agreements were $1.6 million and $3.1 million for the years ended December 31, 2013 and 2012, respectively.
	Asset Retirement Obligations
	The Company records the fair value of a legal liability for an asset retirement obligation in the period in which it is incurred. For gas properties, this is the period in which a gas well is acquired or drilled. The Company’s retirement obligations relate to the abandonment of 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.
	Equity Incentives
	The cost of employee and consultant services received in exchange for an award of equity instruments, such as restricted units, is measured based on the fair value of those instruments. Management established an estimated fair value for issued units based upon an income approach prior to December 31, 2013. At December 31, 2013, in connection with the IPO, a market approach was used. The restricted units are subject to a call option held by the Company which requires liability accounting for the restricted units. Details related to the restricted units are included in Notes 8 and 9.
	Income Taxes
	The Company is treated as a partnership for federal and state income tax purposes. Consequently, the Company is not subject to income taxes; instead its members include the income in their tax returns.
	Reclassifications
	Certain reclassifications have been made to prior periods’ financial information related to post production costs, restricted unit liability and asset retirement obligations to conform to the 2013 presentation.
	Correction of Errors
	The Company’s net income for the year ended December 31, 2012 included expense of approximately $1.7 million that related to prior periods. These corrections resulted in additional exploration expense of approximately $1.1 million, lease operating expense of $0.5 million, and other expense of $0.1 million recorded in 2012. These errors were not material to prior periods, individually or in the aggregate, and were not material to the 2012 period. These errors did not impact debt covenant compliance nor distort operating results. Therefore, these items were corrected in fiscal 2012.

Capitalized_Costs_Relating_to_

Capitalized Costs Relating to Gas-Producing Activities	12 Months Ended
	Dec. 31, 2013
Extractive Industries [Abstract]	'
Capitalized Costs Relating to Gas-Producing Activities	'
	2	Capitalized Costs Relating to Gas-Producing Activities
	Proved and unproved capitalized costs related to the Company’s gas-producing activities are as follows (in thousands):
			2013		2012
	Capitalized costs:
	Unproved properties		$	457,836	$	111,030
	Proved, producing properties			244,771		119,374
	Proved, nonproducing properties			78,441		61,434
	Total			781,048		291,838
	Accumulated depreciation, depletion and amortization			52,689		20,820
	Net capitalized costs		$	728,359	$	271,018
	Entity’s share of equity method investees’ net capitalized costs		$	91,166	$	57,110

Sale_of_Interests_in_Gas_Prope

Sale of Interests in Gas Properties	12 Months Ended
	Dec. 31, 2013
Property, Plant and Equipment [Abstract]	'
Sale of Interests in Gas Properties	'
	3	Sale of Interests in Gas Properties
	In December 2013, the Company agreed to sell interests in noncore assets in Guernsey County, Ohio and Lycoming County, Pennsylvania in two separate transactions. The Company agreed to sell an undivided 75.0% interest in certain of its Guernsey County leaseholds (representing approximately 2,136 net acres) to a third party in exchange for approximately $22.0 million, consisting of $11.0 million in cash and an $11.0 million carried working interest. Of the 2,136 net acres, 1,033 net acres closed subsequent to December 31, 2013. No gain or loss was recorded on this transaction.
	In addition, the Company sold all of its Lycoming County acreage (100% non-operated) and related assets to another third party in exchange for $7.0 million of which $6.0 million will be paid on or before April 30, 2014. This receivable is included in accounts receivable on the accompanying consolidated balance sheet. There was no production or net proved reserves attributable to the interests sold in either transaction. The Company incurred a loss of $4.2 million in the fourth quarter of 2013 as a result of this transaction.
	In March 2011, the Company entered into a joint operating agreement with US Energy Development Corporation (US Energy) covering those certain properties whereby the Company sold a 50% non-operated working interest in the properties to US Energy. Subsequent to this transaction, the Company owns a 50% working interest in approximately 1,000 acres in the Whipkey field and has retained operatorship. The Company received cash consideration of $1.7 million and recorded a gain of $1.5 million on this transaction in the accompanying consolidated statements of operations.

Lease_Obligations

Lease Obligations	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Lease Obligations	'
	6	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, 2013 (in thousands):
	2014		$	18,606
	2015			1,398
	2016			153
	2017			124
	2018 and thereafter			—
	Total future minimum lease payments		$	20,281
	These lease payments are included as leasehold payables in the accompanying consolidated balance sheets.
	Additionally, the Company has leased drilling rights under agreements which specify additional payments due in the event that the Company does not meet predetermined criteria within a specified period of time. The Company could be required to pay up to approximately $2.0 million, $1.0 million and $0.3 million in 2014, 2015 and 2016, respectively, under these agreements.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Asset Retirement Obligations	'
	7	Asset Retirement Obligations
	The Company is subject to certain legal requirements which result in recognition of a liability related to the obligation to incur future plugging and abandonment costs. The Company records a liability for such asset retirement obligations and capitalizes a corresponding amount for asset retirement costs. The liability is estimated using the present value of expected future cash flows, adjusted for inflation and discounted at the Company’s credit adjusted risk-free rate.
	A reconciliation of the beginning and ending aggregate carrying amount of asset retirement obligations for the years ended December 31, 2013 and 2012 is as follows (in thousands):
	Balance at December 31, 2010		$	289
	Liabilities incurred			493
	Accretion expense			53
	Balance at December 31, 2011		$	835
	Liabilities incurred			382
	Accretion expense			164
	Balance at December 31, 2012		$	1,381
	Liabilities incurred			583
	Accretion expense			150
	Balance at December 31, 2013		$	2,114

Restricted_Unit_Agreements

Restricted Unit Agreements	12 Months Ended
	Dec. 31, 2013
Text Block [Abstract]	'
Restricted Unit Agreements	'
	9	Restricted Unit Agreements
	Effective November 13, 2009, the Company entered into restricted unit agreements with an employee and consultants. Under separate and individual restricted unit agreements, the eligible employee and consultants are granted units which vest over a specified period of time. Each unit entitles the holder to an equity ownership in the Company. The restricted units are accounted for as liability awards, which require remeasurement each reporting period, as a result of the existence of a call option that permits the Company to repurchase the awards at a fixed amount that could be above or below fair market value of the units. Prior to November 13, 2012, the Company had the ability to exercise the call option at a specified amount. Subsequently, the Company’s call right is at fair market value. As of December 31, 2013, the remaining liability recorded for the restricted units represented fair value. Management established an estimated fair value for issued units based upon an income approach prior to December 31, 2013. The income approach requires use of internal business plans that are based on judgments and estimates regarding future economic conditions, costs, inflation rates and discount rates, among other factors. At December 31, 2013, in connection with the Rice Energy IPO, a market approach was used.
	During 2012, REA exercised its option to repurchase all of the 2,000 Class B restricted units. A summary of the change in vested restricted units is as follows:
			Restricted Units
	Class A and Class B restricted units
	Vested restricted units			4,000
	Repurchased Class B restricted units			(2,000	)
	Vested restricted units as of December 31, 2012			2,000
	Repurchased Class B restricted units			—
	Vested restricted units as of December 31, 2013			2,000

RelatedParty_Transactions

Related-Party Transactions	12 Months Ended
	Dec. 31, 2013
Related Party Transactions [Abstract]	'
Related-Party Transactions	'
	13	Related-Party Transactions
	In prior periods, 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 $9.3 million, $4.8 million and $3.1 million for the years ended December 31, 2013 , 2012 and 2011, respectively. As of December 31, 2013 and 2012, $6.1 million and $2.5 million, respectively, of general and administrative expenses was due to Rice Partners and is recorded as due to affiliate on the consolidated balance sheet. Prior to the closing of the Rice Energy IPO, the Company terminated its agreement to reimburse Rice Partners for expenses incurred on its behalf.
	Payments totaling $2.2 million, $0.8 million and $0.6 million were made during the years ended December 31, 2013, 2012 and 2011 respectively to Geological Engineering Services, Inc. (“GES”) in respect of consultancy services. GES is a drilling and completion engineering consulting company specializing in unconventional reservoirs like the Marcellus Shale. John P. LaVelle, Rice Energy’s Vice President of Drilling, served as president of GES from February 1994 until February 2010. There were no amounts outstanding between the Company and GES as of any period presented.
	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 $1.6 million, $1.3 million and $0.0 million for the years ended December 31, 2013, 2012 and 2011, respectively.
	As of December 31, 2012, the Company recorded a receivable from its Marcellus joint venture for $6.0 million representing capitalized costs that were approved to be contributed to the joint venture.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	16	Subsequent Events
	Initial Public Offering
	On January 29, 2014, Rice Energy completed their IPO of 50,000,000 shares of our $0.01 par value common stock, which included 30,000,000 shares sold by Rice Energy Inc., 14,000,000 shares sold by the selling stockholder and 6,000,000 shares subject to an option granted to the underwriters by the selling stockholder.
	The net proceeds of the IPO, based on the public offering price of $21.00 per share, were approximately $993.5 million, which resulted in net proceeds to Rice Energy of $593.6 million after deducting estimated expenses and underwriting discounts and commissions of approximately $36.4 million and the net proceeds to the selling stockholders of approximately $399.0 million after deducting underwriting discounts of approximately $21.0 million. Rice Energy did not receive any proceeds from the sale of the shares by the selling stockholders. A portion of the net proceeds from the IPO were used to repay all outstanding borrowings under the revolving credit facility of the Company’s Marcellus joint venture, to make a $100.0 million payment to Alpha Holdings in partial consideration for the Marcellus JV Buy-In and to repay all outstanding borrowings under the Company’s revolving credit facility. The remainder of the net proceeds from the IPO will be used to fund a portion of our capital expenditure plan.
	Marcellus JV Buy-In
	On January 29, 2014, in connection with the closing of the IPO and pursuant to the Transaction Agreement between Rice Energy and Alpha Holdings dated as of December 6, 2013 (the “Transaction Agreement”), Rice Energy completed its acquisition of Alpha Holdings’ 50% interest in the Company’s Marcellus joint venture in exchange for total consideration of $300.0 million, consisting of $100.0 million of cash and the issuance to Alpha Holdings of 9,523,810 shares of Rice Energy common stock. Prior to the completion of the acquisition of Alpha Holdings’ 50% interest in the Company’s Marcellus joint venture, the Company accounted for its investment under the equity method of accounting.
	The company is currently assessing the fair value of assets acquired and liabilities assumed. Immediately prior to the acquisition, the fair value of the existing equity in the Marcellus joint venture, based upon preliminary valuations, was approximately $245.0 million. The acquisition-date fair value of the existing equity was based on an income approach. The income approach calculated the present value of the future cash flows related to the natural gas properties as of the date of the transaction, utilizing a discount rate based upon market participant assumptions, natural gas strip prices as of the date of the transaction, and a decline curve consistent with our geographic peers. As we acquired the remaining ownership in the Marcellus joint venture we are required to remeasure our equity investment at fair value which will result in a non-recurring gain of approximately $195.2 million during the quarter ended March 31, 2014. On a preliminary basis and based on preliminary valuations performed to determine the fair value of the assets as of the acquisition date, the company anticipates the natural gas properties have fair value of approximately $320.0 million. The preliminary estimate of excess purchase price over net assets and liabilities assumed which is to be allocated to goodwill is approximately $365.0 million and will be deductible for tax purposes.
	The acquisition consolidates the resources of the Company and the Marcellus joint venture which will enable the Company to efficiently develop the natural gas properties concurrently. The management team of the Company has historically also served as the management team of the joint venture, so the team is intimately familiar with the assets. These factors resulted in the aforementioned goodwill.
	The following unaudited pro forma combined financial information presents the Company’s results as though the Company and the incremental 50% interest in our Marcellus joint venture had occurred at January 1, 2013.
	(in thousands)		Year Ended
			December 31, 2013
			(Pro forma)
	Pro forma net revenues		$	179,281
	Pro forma net loss		$	(30,509	)
	Pro forma earnings per share		$	(0.24	)
	The Company expects to complete the purchase price allocation during 2014 and may adjust the preliminary amounts set forth above to reflect the final valuation. This final valuation of the assets and liabilities could have a material impact on the pro forma information and preliminary purchase price allocation discussed above.
	Income Taxes
	At the date of IPO, Rice Energy owned 100% of Rice Drilling B and its subsidiaries. Rice Drilling B was a limited liability company not subject to federal income taxes before IPO. However, in connection with the closing of the IPO, as a result of our corporate reorganization, we became a corporation subject to federal income tax and, as such, our future income taxes will be dependent upon our future taxable income. The change in tax status would require the recognition of a deferred tax asset or liability for the initial temporary differences at the time of the change in status. The resulting deferred tax liability is approximately $145.1 million.
	No current tax expense would result as of the date of the change in status. The recognition of the initial deferred tax liability will be recorded in equity at the date of IPO, but not in the financials as of December 31, 2013.
	Unregistered Sales of Equity Securities
	On January 29, 2014, pursuant to the Master Reorganization Agreement (the “Master Reorganization Agreement”) among Rice Energy Inc., Rice Drilling B, REA, Rice Holdings, Rice Partners, NGP Holdings, NGP RE Holdings, L.L.C., (“NGP RE Holdings”) NGP RE Holdings II, L.L.C. (“NGP RE II” and, together with NGP RE Holdings, “Natural Gas Partners”), Mr. Daniel J. Rice III, Rice Merger LLC (“Merger Sub”) and each of the persons holding incentive units representing interests in REA (collectively, the “Incentive Unitholders”) dated as of January 23, 2014, (i) (a) Rice Partners contributed a portion of its interests in REA to Rice Holdings, (b) Natural Gas Partners contributed its interests in REA to NGP Holdings and (c) the Incentive Unitholders contributed a portion of their incentive units to Rice Holdings and NGP Holdings, each in return for substantially similar incentive units in such entities; (ii) NGP Holdings, Rice Holdings and Mr. Daniel J. Rice III contributed their respective interests in Rice Appalachia to the Company in exchange for 43,452,550, 20,300,923 and 2,356,844 shares of Common Stock, respectively; (iii) Rice Partners contributed its remaining interest in Rice Appalachia to Rice Energy Inc. in exchange for 20,000,000 shares of Common Stock; (iv) the Incentive Unitholders contributed their remaining interests in Rice Appalachia to the Company in exchange for 160,831 shares of Common Stock, each of which were issued by the company in connection with the closing of the IPO. In connection with the IPO, in the first quarter of 2014, we recognized a non-cash compensation expense of $3.4 million.
	In addition, on January 29, 2014, pursuant to the Agreement and Plan of Merger (the “Merger Agreement”) among the Company, Rice Drilling B and Merger Sub dated as of January 23, 2014, Rice Energy Inc. issued 1,728,852 shares of Common Stock to the members of Rice Drilling B (other than Rice Appalachia) for settlement of the restricted units.
	Incentive Units
	In connection with the IPO, in the first quarter of 2014, certain incentive units granted by NGP Holdings to certain members of management triggered the pre-determined payout criteria, resulting in a cash payment by NGP Holdings of $4.4 million. This resulted in additional non-cash compensation expense being recorded in the first quarter of 2014 by the Company.
	Convertible Debentures and Warrants
	In connection with the IPO, the convertible debentures and warrants of Rice Drilling B were amended to become convertible or exercisable for an aggregate 1,671,800 shares of common stock of Rice Energy. Through March 10, 2014, approximately $5.0 million of the convertible debentures have been converted into 433,073 shares of Rice Energy Inc. common stock. On February 28, 2014, the Company issued a call notice on the remaining convertible debentures, requiring a response by March 30, 2014. Amounts not converted by the response date will require payment by the Company of 100% of the principal amount plus a premium of 50%, which could result in additional costs of $1.0 million. As the principal amount of the convertible debentures outstanding has been reduced to less than $5.0 million, the Company is no longer required to maintain restricted cash. Through March 10, 2014, two warrants have been exercised in exchange for 1,728 shares of Rice Energy common stock.
	Amendment to Senior Secured Revolving Credit Facility
	On January 29, 2014, Rice Energy, as parent guarantor, and Rice Drilling B, as borrower, entered into an amendment (the “Sixth Amendment”) to the Second Amended and Restated Credit Agreement, dated as of April 25, 2013 with Wells Fargo Bank, N.A., as administrative agent and the lenders and other parties thereto (the “Second Amended and Restated Credit Agreement”). Rice Drilling B is a wholly-owned subsidiary of Rice Energy Inc. Among other things, the Sixth Amendment (i) added Rice Energy Inc. as a guarantor, (ii) increased the maximum commitment to $1.5 billion from $500.0 million, (iii) increased the borrowing base to $350.0 million from $200.0 million, (iv) lowered the interest rate on amounts borrowed, and (v) allowed for the corporate reorganization that was completed simultaneously with the closing of the IPO.
	Subsequent to December 31, 2013, the Company issued additional letters of credit with Wells Fargo Bank, N.A. of $55.9 million (refer to Note 4 for further details on letters of credit as required by the Company’s natural gas marketer and pipeline).
	Momentum Acquisition
	On February 12, 2014, the Company’s wholly owned subsidiary, Rice Poseidon, entered into a Purchase Agreement with M3 to acquire certain gas gathering assets in eastern Washington and Greene Counties, Pennsylvania, for aggregate consideration of approximately $110.0 million in cash, subject to customary purchase price adjustments. Rice Energy expects the Momentum Acquisition to close in the second quarter of 2014, subject to customary closing conditions. The effective date for the Momentum Acquisition is March 1, 2014 and will be funded with proceeds received from our IPO.
	The properties to be acquired in the Momentum Acquisition consist of a 28-mile, 6”-16” gathering system in eastern Washington County, Pennsylvania, and permits and rights of way in Washington and Greene Counties, Pennsylvania, necessary to construct an 18-mile, 30” gathering system connecting the northern system to the Texas Eastern pipeline. The northern system is supported by long-term contracts with acreage dedications covering approximately 20,000 acres from third parties. Once fully constructed, the acquired systems are expected to have an aggregate capacity of over 1 Bcf/d.
	Subsequent events have been considered for disclosure and recognition through March 21, 2014, the same date the consolidated financial statements were available to be issued.

Quarterly_Financial_Informatio

Quarterly Financial Information (Unaudited)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Information (Unaudited)	'
	17	Quarterly Financial Information (Unaudited)
	The Company’s quarterly financial information for the years ended December 31, 2013 and 2012 is as follows (in thousands):
			First			Second			Third			Fourth
			quarter			quarter			quarter			quarter
	Year ended December 31, 2013:
	Total operating revenues		$	13,233		$	23,840		$	23,665		$	27,866
	Total operating expenses			10,705			25,833			52,274			27,755
	Operating income (loss)			2,528			(1,993	)		(28,609	)		111
	Net income (loss)		$	(6,775	)	$	19,586		$	(33,652	)	$	(14,935	)
			First			Second			Third			Fourth
			quarter			quarter			quarter			quarter
	Year ended December 31, 2012:
	Total operating revenues		$	4,792		$	4,155		$	6,580		$	11,673
	Total operating expenses			6,353			11,984			8,123			9,640
	Operating income (loss)			(1,561	)		(7,829	)		(1,543	)		2,033
	Net income (loss)		$	(2,334	)	$	(12,884	)	$	(6,523	)	$	2,397

Supplemental_Information_on_Ga

Supplemental Information on Gas-Producing Activities (Unaudited)	12 Months Ended
	Dec. 31, 2013
Extractive Industries [Abstract]	'
Supplemental Information on Gas-Producing Activities (Unaudited)	'
	18	Supplemental Information on Gas-Producing Activities (Unaudited)
	Costs incurred for property acquisitions, exploration and development are as follows for Rice Energy (in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Acquisitions:
	Unproved leaseholds		$	305,000		$	47,396		$	16,877
	Development costs			184,217			89,307			72,776
	Exploration costs:
	Geological and geophysical			9,951			3,275			660
	Total costs incurred		$	499,168		$	139,978		$	90,313
	The following table presents the results of operations related to natural gas production for Rice Energy (in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Revenues		$	87,847		$	26,743		$	13,972
	Production costs			19,712			8,824			2,157
	Exploration costs			9,951			3,275			660
	Depreciation, depletion and amortization			29,808			13,329			5,920
	Write-down of abandoned leases			—			2,253			109
	General and administrative expenses			5,108			3,050			2,212
	Results of operations from producing activities		$	23,268		$	(3,988	)	$	2,914
	Reserve quantity information is as follows for Rice Energy:
			Natural Gas (MMcf)
			For the Years Ended December 31,
			2013			2012			2011
	Proved developed and undeveloped reserves:
	Beginning of year			304,272			232,996			12,230
	Extensions and discoveries			100,626			176,956			223,538
	Revision of previous estimates			757			(96,911	)		620
	Production			(22,995	)		(8,769	)		(3,392	)
	End of year			382,660			304,272			232,996
	Proved developed reserves:
	End of year			144,310			61,225			25,397
	Proved undeveloped reserves:
	End of year			238,350			243,047			207,599
	Extensions, Discoveries and Other Additions
	The Company added 100,626 MMcf, 176,956 MMcf and 223,538 MMcf through its drilling program in the Marcellus Shale in 2013, 2012 and 2011, respectively.
	Revision of Previous Estimates
	In 2012, the Company had net negative revisions of 96,911 MMcf, as 32 proved undeveloped locations were removed from its estimate of reserves at December 31, 2011 due primarily to declines in natural gas pricing and changes to the Company’s drilling plans with regards to horizontal drilling.
	The reserve quantity information is limited to reserves which had been evaluated as of December 31, 2013. Proved developed reserves represent only those reserves expected to be recovered from existing wells and support equipment. Proved undeveloped reserves are expected to be recovered from new wells after substantial development costs are incurred. Netherland, Sewell and Associates, Inc. reviewed 100% of the total net gas proved reserves attributable to the Company’s interests and the Company’s Marcellus joint venture as of December 31, 2013 and 2012.
	The information presented represents estimates of proved natural gas reserves based on evaluations prepared by the independent petroleum engineering firms of Netherland, Sewell and Associates, Inc. and Wright & Company in accordance with Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Evaluation Engineers and definitions and guidelines established by the SEC. The Company’s independent reserve engineers were selected for their historical experience and geographic expertise in engineering unconventional resources. Since 1961, Netherland, Sewell and Associates, Inc. has evaluated oil and gas properties and independently certified petroleum reserves quantities in the United States and internationally. Wright & Company was founded in 1988 and performs consulting petroleum engineering services under the Texas Board of Professional Engineers.
	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. Gas prices are held constant throughout the lives of the properties.
	The assumptions used to compute estimated future net revenues do not necessarily reflect the Company’s expectations of actual revenues or costs, or their present worth. In addition, variations from the expected production rates also could result directly or indirectly from factors outside of the Company’s control, such as unintentional delays in development, changes in prices, or regulatory controls. The standardized measure calculation further assumes that all reserves will be disposed of by production. However, if reserves are sold in place, this could affect the amount of cash eventually realized.
	Future development and production costs are computed by estimating the expenditures to be incurred in developing and producing the proved natural gas reserves at the end of the year, based on period-end costs and assuming continuation of existing economic conditions.
	An annual discount rate of 10% was used to reflect the timing of the future net cash flows relating to proved natural gas reserves.
	Information with respect to Rice Energy’s estimated discounted future net cash flows related to its proved natural gas reserves is as follows (in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Future cash inflows		$	1,496,294		$	869,882		$	1,015,589
	Future production costs			(517,101	)		(323,855	)		(208,733	)
	Future development costs			(219,879	)		(262,084	)		(206,612	)
	Future net cash flows			759,314			283,943			600,244
	10% annual discount for estimated timing of cash flows			(342,150	)		(181,725	)		(330,924	)
	Standardized measure of discounted future net cash flows(1)		$	417,164		$	102,218		$	269,320
	-1	Does not include the effects of income taxes on future revenues at December 31, 2013 and 2012 because as of December 31, 2013 and 2012, the Company was 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 the Company’s equity holders. However, in connection with the closing of the IPO, as a result of the corporate reorganization, the Company became a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income.
	For 2013, the reserves for Rice Energy were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2013, adjusted for energy content and a regional price differential. For 2013, this adjusted gas price was $3.91 per Mcf.
	For 2012, the reserves for Rice Energy were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2012, adjusted for energy content and a regional price differential. For 2012, this adjusted gas price was $2.86 per Mcf.
	For 2011, the reserves for Rice Energy were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2011, adjusted for energy content and a regional price differential. For 2011, this adjusted gas price was $4.36 per Mcf.
	The following are the principal sources of changes in the standardized measure of discounted future net cash flows for Rice Energy (in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Balance at beginning of period		$	102,218		$	269,320		$	46,422
	Net change in prices and production costs			101,345			(83,873	)		(15,929	)
	Net change in future development costs			29,336			(31,811	)		(3,695	)
Natural gas net revenues			(68,135	)		(18,376	)		(11,815	)
Extensions			114,489			38,937			243,003
Revisions of previous quantity estimates			1,133			(108,209	)		(14,259	)
Previously estimated development costs incurred			66,894			17,036			3,040
Accretion of discount			10,230			26,932			4,642
Changes in timing and other			59,654			(7,738	)		17,911
Balance at end of period		$	417,164		$	102,218		$	269,320
Gains on sales of interests in gas properties are not included in the information set forth above. We have also allocated certain general and administrative expenses to the Company’s results of operations as these expenses relate to production activities.
Costs incurred for property acquisitions, exploration and development related to the Company’s Marcellus joint venture (“the Marcellus joint venture”) are as follows (represents Rice Energy’s proportionate share, in thousands):
		For the Years Ended December 31,
		2013			2012			2011
Acquisitions:
Unproved leaseholds		$	—		$	—		$	519
Development costs			46,571			46,725			21,700
Exploration costs:
Geological and geophysical			—			—			—
Total costs incurred		$	46,571		$	46,725		$	22,219
The following table presents Rice Energy’s share of the results of operations related to natural gas production of the Marcellus joint venture (represents Rice Energy’s proportionate share, in thousands):
		For the Years Ended December 31,
		2013			2012			2011
Revenues		$	45,339		$	13,142		$	2,872
Production costs			12,557			5,436			379
Impairment of oil and gas properties			—			—			1,296
Depreciation, depletion and accretion			12,500			4,702			1,092
General and administrative expenses			1,557			986			—
Results of operations from producing activities		$	18,725		$	2,018		$	105
Reserve quantity information is as follows for the Marcellus joint venture (represents Rice Energy’s proportionate share, in thousands):
		Natural Gas (MMcf)
		For the Years Ended December 31,
		2013			2012			2011
Proved developed and undeveloped reserves:
Beginning of year			128,118			58,103			—
Extensions and discoveries			19,812			98,119			58,800
Revision of previous estimates			(26,803	)		(23,808	)		—
Production			(11,443	)		(4,296	)		(697	)
End of year			109,684			128,118			58,103
Proved developed reserves:
End of year			52,370			35,013			14,474
Proved undeveloped reserves:
End of year			57,314			93,105			43,629
Rice Energy’s 50% equity interest in the Marcellus joint venture added 19,812 MMcf, 98,119 MMcf and 58,800 MMcf through its drilling program in the Marcellus Shale in 2013, 2012 and 2011, respectively. In 2013, Rice Energy’s 50% equity interest in the Marcellus joint venture had net negative revisions of 26,803 MMcf due primarily to performance revisions. In 2012, Rice Energy’s 50% equity interest in the Marcellus joint venture had net negative revisions of 23,808 MMcf due primarily to declines in natural gas pricing.
Information with respect to Rice Energy’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):
		For the Years Ended December 31,
		2013			2012			2011
Future cash inflows		$	427,167		$	364,157		$	252,384
Future production costs			(132,427	)		(127,086	)		(29,683	)
Future development costs			(46,344	)		(86,213	)		(51,882	)
Future net cash flows			248,396			150,858			170,819
10% annual discount for estimated timing of cash flows			(102,293	)		(79,781	)		(100,232	)
Standardized measure of discounted future net cash flows(1)		$	146,103		$	71,077		$	70,587
-1	Does not include the effects of income taxes on future revenues at December 31, 2013 and 2012 because as of December 31, 2013 and 2012, the Company was 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 the Company’s equity holders. However, in connection with the closing of the IPO, as a result of the corporate reorganization, the Company became a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income.
For 2013, the reserves for the Marcellus joint venture were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2013, adjusted for energy content and a regional price differential. For 2013, this adjusted gas price was $3.90 per Mcf.
For 2012, the reserves for the Marcellus joint venture were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2012, adjusted for energy content and a regional price differential. For 2012, this adjusted gas price was $2.84 per Mcf.
For 2011, the reserves for the Marcellus joint venture were computed using unweighted arithmetic averages of the closing prices on the first day of each month during 2011, adjusted for energy content and a regional price differential. For 2011, this adjusted gas price was $4.34 per Mcf.
The following is for the Marcellus joint venture (represents Rice Energy’s proportionate share, in thousands), the principal sources of changes in the standardized measure of discounted future net cash flows:
		For the Years Ended December 31,
		2013			2012			2011
Balance at beginning of period		$	71,077		$	70,587		$	—
Net change in prices and production costs			81,974			(26,855	)		—
Net change in future development costs			2,781			(262	)		—
Natural gas net revenues			(32,782	)		(7,707	)		(2,494	)
Extensions			18,950			38,131			73,081
Revisions of previous quantity estimates			(14,752	)		(28,923	)		—
Previously estimated development costs incurred			31,253			12,862			—
Accretion of discount			7,111			7,059			—
Changes in timing and other			(19,509	)		6,185			—
Balance at end of period		$	146,103		$	71,077		$	70,587

Basis_of_Presentation_Policies

Basis of Presentation (Policies)	9 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
Accounting Policies [Abstract]	'	'
Basis of Presentation	'	'
	The accompanying unaudited condensed 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 interim financial information and applicable rules and regulations promulgated under the Exchange Act. Accordingly, they do not include all of the information and footnotes required by GAAP for annual financial statements. The unaudited condensed consolidated financial statements included herein contain all adjustments which are, in the opinion of management, necessary to present fairly the Company’s financial position as of September 30, 2014 and its condensed consolidated statements of operations for the three and nine months ended September 30, 2014 and 2013 and of cash flows for the nine months ended September 30, 2014 and 2013. The condensed consolidated statements of operations for the three and nine months ended September 30, 2014 and 2013 are not necessarily indicative of the results to be expected for future periods. A corporate reorganization occurred concurrently with the completion of our IPO on January 29, 2014. As a part of this corporate reorganization, we acquired all of the outstanding membership interests in Rice Appalachia and Rice Drilling B (other than those already held by Rice Appalachia) in exchange for shares of our common stock. Our business 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. These condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes therein for the year ended December 31, 2013, as filed with the Securities and Exchange Commission by the Company in its 2013 Annual Report. Certain prior period financial statement amounts have been reclassified to conform to current period presentation.
New Accounting Pronouncements	'	'
	In May 2014, the FASB issued ASU, No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” or ASU No. 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. ASU 2014-09 will enhance comparability of revenue recognition practices across entities, industries and capital markets compared to existing guidance. Additionally, ASU 2014-09 will reduce the number of requirements to which an entity must consider in recognizing revenue as this update will replace multiple locations for guidance. 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 is effective for fiscal and interim periods beginning after December 15, 2016 and should be applied retrospectively. Early adoption of this standard is not permitted. The Company is currently evaluating the impact of the provisions of ASU 2014-09.
Organization, Operations and Principles of Consolidation	'	'
		Organization, Operations and Principles of Consolidation
		The consolidated financial statements of the Company include the accounts of Rice Energy Inc. (“the Company” or “Rice Energy”) and its wholly owned subsidiaries, Rice Drilling B LLC (“Rice Drilling B”), Rice Drilling C LLC (“Rice C”), Rice Drilling D LLC (“Rice D”), RDB Real Estate Holdings LLC (“RDB Real Estate”), Blue Tiger Oilfield Services LLC (“Blue Tiger”), Rice Poseidon Midstream LLC (“Rice PM”), and Rice Olympus Midstream LLC (“Rice OM”). All significant intercompany accounts have been eliminated in consolidation.
		In October 2013, the Company was formed as a Delaware corporation for the purpose of becoming a publicly traded company and the holding company of Rice Drilling B. The historical financial information contained in this report relates to periods that ended prior to the completion of the IPO of Rice Energy. In connection with the completion of its IPO and corporate reorganization on January 29, 2014, Rice Energy became a holding company whose sole material asset consists of a 100% indirect ownership interest in Rice Drilling B. As the sole managing member of Rice Drilling B, Rice Energy is responsible for all operational, management and administrative decisions relating to Rice Drilling B. Accordingly, 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 herein.
		On January 25, 2012, Rice Partners, the owner of 90% of the total shares outstanding in Rice Energy, assigned its preferred units in Rice Energy to its wholly owned subsidiary, Rice Energy Appalachia LLC (“REA”). Concurrent with Rice Partners’ assignment of its shares to REA, REA and Natural Gas Partners (“NGP”), a private equity firm, finalized a $100.0 million equity commitment to REA from NGP of which $75 million of NGP’s commitment was funded at closing on January 25, 2012. Cash proceeds from the investments were contributed by REA to Rice Energy. NGP received a put right with respect to their equity investment at REA which was contingently exercisable upon the occurrence of certain events. The earliest date that this put right could have been exercised is January 25, 2017. The fair value of this put right was de minimis given the accretion in fair value of REA. In conjunction with the equity investment in NGP, Daniel J. Rice III converted his outstanding promissory notes into equity of REA. On August 30, 2012, NGP funded the remaining $25 million of its commitment at REA.
		During the year ended December 31, 2013, REA finalized a $300 million equity commitment from NGP, of which approximately $200 million was funded in April 2013 and contributed to Rice Energy. Cash proceeds from the investment were used to partially fund our Utica Shale leasehold acquisitions in southeastern Ohio. NGP’s equity commitments terminated in connection with the closing of the Rice Energy Inc. (“Rice Energy”) initial public offering (“IPO”).
		Rice Drilling B is the operating company of Rice Energy and as such is engaged in the acquisition, exploration, and development of natural gas properties in the Appalachian Basin.
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 are recognized when natural gas has 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 tied to the Platts Gas Daily market prices.
Cash	'	'
		Cash
		The Company maintains cash at financial institutions which may at times exceed federally insured amounts and which may at times significantly exceed consolidated balance sheet amounts due to outstanding checks. The Company has no other accounts that are considered cash equivalents.
Accounts Receivable	'	'
		Accounts Receivable
		Accounts receivable are primarily from the Company’s two gas marketers. The Company extends credit to parties in the normal course of business based upon management’s assessment of their creditworthiness. A valuation allowance is provided for those accounts for which collection is estimated as doubtful; uncollectible accounts are written off and charged against the allowance. In estimating the allowance, management considers, among other things, how recently and how frequently payments have been received and the financial position of the party. There was no allowance recorded for any of the periods presented in the consolidated financial statements. Accounts receivable as of December 31, 2013 and 2012 are detailed below.
			December 31,
		(in thousands)	2013		2012
		Natural gas sales	$	16,534	$	5,564
		Joint interest		6,391		1,810
		Other		8,840		1,183
		Total accounts receivable	$	31,765	$	8,557
Investments in Joint Ventures	'	'
		Investments in Joint Ventures
		The Company accounts for its oilfield service company joint venture investment and for periods prior to the completion of the Marcellus JV Buy-In accounted for our Marcellus joint venture investment, under the equity method of accounting as we have significant influence, but not control, over the joint ventures as of December 31, 2013.
		Under the equity method of accounting, investments are carried at cost, adjusted for the Company’s proportionate share of the undistributed earnings or losses and reduced for any distributions from the investment. The Company also evaluates its equity method investments for potential impairment whenever events or changes in circumstances indicate that there is an other-than-temporary decline in value of the investment. Such events may include sustained operating losses by the investee or long-term negative changes in the investee’s industry. These indicators were not present, and as a result, the Company did not recognize any impairment charges related to its equity method investments for any of the periods presented in the consolidated financial statements.
		On January 29, 2014, in connection with the closing of the IPO and pursuant to the Transaction Agreement between it and Alpha Holdings dated as of December 6, 2013 (the “Transaction Agreement”), Rice Energy completed its acquisition of Alpha Holdings’ 50% interest in its Marcellus joint venture (“Marcellus JV Buy-In”) in exchange for total consideration of $322 million, consisting of $100 million of cash and its issuance to Alpha Holdings of 9,523,810 shares of our common stock. See Note 15 for additional information.
Natural Gas Properties	'	'
		Natural Gas Properties
		The Company uses the successful efforts method of accounting for gas-producing activities. Costs to acquire mineral interests in gas properties, to drill and equip exploratory wells that result in proved reserves, are capitalized. 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. The Company wrote off approximately $8.1 million of costs associated with the drilling of the Bigfoot 7H in the fourth quarter of 2013.
		Unproved gas properties that are individually significant are periodically assessed for impairment of value, and a loss is recognized at the time of impairment by providing an impairment allowance. Capitalized costs of producing 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. Support equipment and other property and equipment not directly related to gas properties are depreciated over their estimated useful lives.
		Management’s estimates of proved reserves are based on quantities of natural gas that engineering and geological analysis demonstrates, with reasonable certainty, to be recoverable from established reservoirs in the future under current operating and economic conditions. External engineers prepare the annual reserve and economic evaluation of all properties on a well-by-well basis. Additionally, the Company adjusts natural gas reserves for major well rework or abandonment during the year as needed. The process of estimating and evaluating natural gas reserves is complex, requiring significant decisions in the evaluation of available geological, geophysical, engineering, and economic data. The data for a given property may also change substantially over time as a result of numerous factors, including additional development activity, evolving production history and a continual reassessment of the viability of production under changing economic conditions. As a result, revisions in existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates represent the Company’s most accurate assessments possible, the subjective decisions and variances in available data for various properties increase the likelihood of significant changes in these estimates over time. Because estimates of reserves significantly affect the Company’s depreciation, depletion, and amortization expense, a change in the Company’s estimated reserves could have a material effect on the Company’s operating results.
		On 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.
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. The following table summarizes the components of the Company’s interest incurred for the periods indicated (in thousands):
			2013		2012		2011
		Interest incurred:
		Interest capitalized	$	8,034	$	7,695	$	5,405
		Interest expensed		17,915		3,487		531
		Total incurred	$	25,949	$	11,182	$	5,936
Property and Equipment	'	'
		Property and Equipment
		Property and equipment are recorded at cost and are being depreciated over estimated useful lives of three to forty years on a straight-line basis. Accumulated depreciation was $1.3 million and $0.6 million at December 31, 2013 and 2012, respectively. Depreciation expense was $0.7 million, $0.6 million and $0.1 million for the years ended December 31, 2013, 2012 and 2011, respectively, and is included in depreciation, depletion, and amortization expense in the accompanying statements of consolidated operations.
Long-Lived Assets	'	'
		Long-Lived Assets
		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.
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. Accumulated amortization was $14.3 million and $9.9 million at December 31, 2013 and 2012, respectively. Amortization expense was $5.2 million , $7.2 million and $2.7 million for the years ended December 31, 2013, 2012 and 2011, respectively. The annual amortization of deferred financing costs for years subsequent to December 31, 2013, is expected to be approximately $1.9 million in 2014, $1.9 million in 2015, $1.9 million in 2016, $1.9 million in 2017 and $1.1 million in 2018.
Delay Rental Agreements	'	'
		Delay Rental Agreements
		The Company has leased drilling rights under agreements which specify additional payments for the privilege of deferring drilling operations for another year. Costs incurred to extend such agreements were $1.6 million and $3.1 million for the years ended December 31, 2013 and 2012, respectively.
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 gas properties, this is the period in which a gas well is acquired or drilled. The Company’s retirement obligations relate to the abandonment of 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.
Equity Incentives	'	'
		Equity Incentives
		The cost of employee and consultant services received in exchange for an award of equity instruments, such as restricted units, is measured based on the fair value of those instruments. Management established an estimated fair value for issued units based upon an income approach prior to December 31, 2013. At December 31, 2013, in connection with the IPO, a market approach was used. The restricted units are subject to a call option held by the Company which requires liability accounting for the restricted units. Details related to the restricted units are included in Notes 8 and 9.
Income Taxes	'	'
		Income Taxes
		The Company is treated as a partnership for federal and state income tax purposes. Consequently, the Company is not subject to income taxes; instead its members include the income in their tax returns.
Reclassifications	'	'
		Reclassifications
		Certain reclassifications have been made to prior periods’ financial information related to post production costs, restricted unit liability and asset retirement obligations to conform to the 2013 presentation.
Correction of Errors	'	'
		Correction of Errors
		The Company’s net income for the year ended December 31, 2012 included expense of approximately $1.7 million that related to prior periods. These corrections resulted in additional exploration expense of approximately $1.1 million, lease operating expense of $0.5 million, and other expense of $0.1 million recorded in 2012. These errors were not material to prior periods, individually or in the aggregate, and were not material to the 2012 period. These errors did not impact debt covenant compliance nor distort operating results. Therefore, these items were corrected in fiscal 2012.

LongTerm_Debt_Tables

Long-Term Debt (Tables)	9 Months Ended						12 Months Ended
	Sep. 30, 2014						Dec. 31, 2013
Debt Disclosure [Abstract]	'						'
Schedule of Long-term Debt Instruments	'						'
							Long-term debt consists of the following as of December 31, 2013 and 2012 (in thousands):
	Long-term debt consists of the following as of September 30, 2014 and December 31, 2013.
							Description	December 31, 2013			December 31, 2012
							Long-term Debt
	(in thousands)	September 30,			December 31,		Debentures (a)	$	6,890		$	60,000
		2014			2013		Wells Fargo Energy Capital Credit Facility (b)		—			70,000
	Long-term Debt						Second Lien Term Loan Facility (c)		293,821			—
	Senior Notes Due 2022 (a)	$	900,000		$	—	NPI Note (d)		8,028			15,282
	Second Lien Term Loan Facility (b)		—			293,821	Senior Secured Revolving Credit Facility (e)		115,000			—
	Senior Secured Revolving Credit Facility (c)		—			115,000	Other		3,203			4,038
	Debentures (d)		—			6,890
	NPI Note		—			8,028	Total debt	$	426,942		$	149,320
	Other		1,006			3,203	Less current portion		20,120			8,814
	Total debt	$	901,006		$	426,942	Long-term debt	$	406,822		$	140,506
	Less current portion		1,006			20,120
	Long-term debt	$	900,000		$	406,822
Schedule of Maturities of Long-term Debt	'						'
	Expected aggregate maturities of notes payable as of September 30, 2014 are as follows (in thousands):						Expected aggregate maturities of notes payable subsequent to December 31, 2013, are as follows (in thousands):
	Remainder of Year Ending December 31, 2014	$	326				2014	$	20,120
	Year Ending December 31, 2015		680				2015		3,058
	Year Ending December 31, 2016						2016		2,277
	Year Ending December 31, 2017						2017		2,173
	Year Ending December 31, 2018 and Beyond		900,000				2018		399,314
	Total	$	901,006				Total	$	426,942
Assumption Used to Estimate Fair Value of Warrants	'						'
	The fair value of the incentive units was estimated using a Monte Carlo simulation valuation model with the following assumptions:						The fair value of these warrants at the date of grant was estimated using the Black-Scholes valuation model with the following assumptions:
	Rice Holdings						Dividend yield		—	%
	Valuation Date		1/29/14				Expected volatility		72.1	%
	Dividend Yield		0	%			Risk-free rate		0.96	%
	Expected Volatility		47	%			Expected life		5 years
	Risk-Free Rate		1.11	%
	Expected Life (Years)		4				“Normal” warrant
							Number of warrants issued		1,044
	Rice Holdings						Exercise price	$	10,000
	Valuation Date		4/14/14				Grant date fair value, per unit	$	2,569
	Dividend Yield		0	%			Weighted average contractual life		5 years
	Expected Volatility		45.19	%
	Risk-Free Rate		1.13	%			“Bonus” warrant
	Expected Life (Years)		3.8				Number of warrants issued		192
							Exercise price	$	6,250
	Rice Holdings						Grant date fair value, per unit	$	3,184
	Valuation Date		4/16/14				Weighted average contractual life		5 years
	Dividend Yield		0	%
	Expected Volatility		44.32	%
	Risk-Free Rate		1.18	%
	Expected Life (Years)		3.8
	NGP Holdings
	Valuation Date		9/30/14
	Dividend Yield		0	%
	Expected Volatility		40.2	%
	Risk-Free Rate		0.58	%
	Expected Life (Years)		2

Derivative_Instruments_Tables

Derivative Instruments (Tables)	9 Months Ended												12 Months Ended
	Sep. 30, 2014												Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'												'
Schedule of Notional Amounts of Outstanding Derivative Positions	'												'
	As of September 30, 2014, the Company has entered into derivative instruments with various financial institutions, fixing the price it receives for a portion of its natural gas through December 1, 2017, as summarized in the following table:												As of December 31, 2013, the Company entered into derivative instruments with Wells Fargo Bank, N.A. and Bank of Montreal fixing the price it receives for natural gas through November 28, 2017, as summarized in the following table:
	Swap Contract Expiration	MMBtu/day		Weighted									Swap Contract Expiration	MMbtu/day			Weighted
				Average Price													Average Price
	Fourth quarter of 2014		173,000	$	4.15								2014		87,219		$	4.112
	2015		166,000	$	4.09								2015		58,781		$	4.153
	2016		214,000	$	4.14								2016		68,326		$	4.233
	2017		60,000	$	4.24								2017		30,000		$	4.343
	Collar Contract Expiration	MMBtu/day		Floor/Ceiling
	Fourth quarter of 2014		10,000	$	3.00/5.80								Collar Contract Expiration	MMbtu/day			Floor/Ceiling
	2015		139,000	$	3.96/4.65								2014		10,000		$	3.000/$5.800
													2015		45,000		$	4.000/$4.500
	Basis Contract Expiration	MMBtu/day		Swap
				($/MMBtu)
	Fourth quarter of 2014		60,000	$	(0.46	)							Basis Contract Expiration	MMbtu/day			Swap
	2015		62,000	$	(0.57	)											($/MMBtu)
	2016		38,000	$	(0.63	)							2014		15,000		$	(0.205	)
													2015		10,000		$	(0.410	)
	Put Contract Expiration	MMBtu/day		Put Premium
				($/MMBtu)
	2014		50,000	$	0.45
Offsetting Assets	'												'
	The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the condensed consolidated balance sheets for the periods presented, all at fair value:												The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the consolidated balance sheets for the periods presented, all at fair value (in thousands):
		As of September 30, 2014												December 31, 2013
	(in thousands)	Derivative instruments, recorded		Derivative instruments subject to			Derivative Instruments, net						Description	Gross Amounts of			Gross Amounts			Net Amounts of
		in the Condensed Consolidated		master netting arrangements										Recognized Assets			Offset on			Assets (Liabilities) on
		Balance Sheet, gross															Balance Sheet			Balance Sheet
	Derivative assets	$	39,672	$	(22,571	)	$	17,101					Derivative assets	$	13,000		$	(4,700	)	$	8,300
	Derivative liabilities	$	22,571	$	(22,571	)	$	—					Derivative liabilities	$	256		$	(4,600	)	$	(4,344	)
		As of December 31, 2013												December 31, 2012
	(in thousands)	Derivative instruments, recorded		Derivative instruments subject to			Derivative Instruments, net						Description	Gross Amounts of			Gross Amounts			Net Amounts of
		in the Condensed Consolidated		master netting arrangements										Recognized Assets			Offset on			Assets (Liabilities) on
		Balance Sheet, gross															Balance Sheet			Balance Sheet
	Derivative assets	$	13,000	$	(4,700	)	$	8,300					Derivative assets	$	416		$	(370	)	$	46
	Derivative liabilities	$	256	$	(4,600	)	$	(4,344	)				Derivative liabilities	$	—		$	(2,306	)	$	(2,306	)
Derivative Instruments, Gain (Loss)	'												'
	The following table presents the realized and unrealized gains or losses presented as gain or loss on derivatives in the condensed consolidated statements of operations for the periods presented:
		Three Months Ended September 30,					Nine Months Ended September 30,
	(in thousands)	2014		2013			2014			2013
	Realized gain (loss)	$	171	$	788		$	(20,782	)	$	(1,053	)
	Unrealized gain	$	36,764	$	7,262		$	26,139		$	17,751
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'												'
													The following is a summary of the Company’s derivative instruments, which are recorded in the consolidated balance sheets as of December 31, 2013 and 2012 (in thousands):
														December 31, 2013			December 31, 2012
													Current derivative assets	$	2,270		$	46
													Long-term derivative assets		6,030			—
														$	8,300		$	46
													Current derivative liabilities	$	3,235		$	2,306
													Long-term derivative liabilities		1,109			—
														$	4,344		$	2,306
													Net current value of derivative liabilities	$	(965	)	$	(2,260	)
													Net long-term value of derivative assets	$	4,921		$	—
Offsetting Liabilities	'												'
													The following tables present the gross amounts of recognized derivative assets and liabilities, the amounts offset under netting arrangements with counterparties, and the resulting net amounts presented in the consolidated balance sheets for the periods presented, all at fair value (in thousands):
														December 31, 2013
													Description	Gross Amounts of			Gross Amounts			Net Amounts of
														Recognized Assets			Offset on			Assets (Liabilities) on
																	Balance Sheet			Balance Sheet
													Derivative assets	$	13,000		$	(4,700	)	$	8,300
													Derivative liabilities	$	256		$	(4,600	)	$	(4,344	)
														December 31, 2012
													Description	Gross Amounts of			Gross Amounts			Net Amounts of
														Recognized Assets			Offset on			Assets (Liabilities) on
																	Balance Sheet			Balance Sheet
													Derivative assets	$	416		$	(370	)	$	46
													Derivative liabilities	$	—		$	(2,306	)	$	(2,306	)

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments (Tables)	9 Months Ended													12 Months Ended
	Sep. 30, 2014													Dec. 31, 2013
Fair Value Disclosures [Abstract]	'													'
Fair Value Measurements, Recurring and Nonrecurring	'													'
	The following assets and liabilities were measured at fair value on a recurring basis during the period (refer to Note 3 for details relating to derivative instruments):													The following liabilities were measured at fair value on a recurring basis during the period (refer to Notes 9 and 11 for details relating to the restricted units and derivative instruments) (in thousands):
		As of September 30, 2014																Fair Value Measurements at
					Fair Value Measurements at Reporting Date Using													Reporting Date Using
	(in thousands)	Carrying			Total			Quoted Prices		Significant		Significant		Description	December 31,			Quoted Prices in		Significant Other		Significant
		Value			Fair			in Active		Other		Unobservable			2013			Active Markets		Observable		Unobservable
					Value			Markets for		Observable		Inputs						for Identical		Inputs		Inputs (Level 3)
								Identical Assets		Inputs		(Level 3)						Assets		(Level 2)
								(Level 1)		(Level 2)								(Level 1)
	Assets:													Assets:
	Derivative instruments, at fair value	$	17,101		$	17,101		$	—	$	17,101	$	—	Derivative Instruments, at fair value	$	4,921		$	—	$	4,921	$	—
	Total assets	$	17,101		$	17,101		$	—	$	17,101	$	—	Total assets	$	4,921		$	—	$	4,921	$	—
	Liabilities:													Liabilities:
	Derivative instruments, at fair value	$	—		$	—		$	—	$	—	$	—	Restricted units, at fair value	$	36,306		$	—	$	—	$	36,306
														Derivative Instruments, at fair value		965			—		965		—
	Total liabilities	$	—		$	—		$	—	$	—	$	—
														Total liabilities	$	37,271		$	—	$	965	$	36,306
		As of December 31, 2013
					Fair Value Measurements at Reporting Date Using													Fair Value Measurements at
	(in thousands)	Carrying			Total			Quoted Prices		Significant		Significant						Reporting Date Using
		Value			Fair			in Active		Other		Unobservable		Description	December 31,			Quoted Prices in		Significant Other		Significant
					Value			Markets for		Observable		Inputs			2012			Active Markets		Observable		Unobservable
								Identical		Inputs		(Level 3)						for Identical		Inputs		Inputs (Level 3)
								Assets		(Level 2)								Assets		(Level 2)
								(Level 1)										(Level 1)
	Assets:													Liabilities:
	Derivative instruments, at fair value	$	4,921		$	4,921		$	—	$	4,921	$	—	Restricted units, at fair value	$	5,667		$	—	$	—	$	5,667
														Derivative Instruments, at fair value		2,260			—		2,260		—
	Total assets	$	4,921		$	4,921		$	—	$	4,921	$	—
														Total liabilities	$	7,927		$	—	$	2,260	$	5,667
	Liabilities:
	Restricted units, at fair value	$	36,306		$	36,306		$	—	$	—	$	36,306
	Derivative instruments, at fair value		965			965		$	—		965	$	—
	Total liabilities	$	37,271		$	37,271		$	—	$	965	$	36,306
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation	'													'
		Fair Value Measurements Using													Fair Value
		Significant Unobservable Inputs													Measurements
		(Level 3)													Using
	(in thousands)	2014			2013										Significant
	Balance as of January 1,	$	36,306		$	5,667									Unobservable
	Total gain or losses:		—			—									Inputs (Level 3)
	Included in earnings		—			—								Balance at December 31, 2011	$	6,800
	Transfers in and/or out of Level 3		—			—								Total gain or losses:
	Repurchase of restricted units		—			(2,267	)							Included in earnings		115
	Converted to shares of common stock		(36,306	)		—								Transfers in and/or out of Level 3		—
														Repurchase of restricted units		(1,133	)
	Balance as of September 30,	$	—		$	3,400								Settlement		(115	)
														Balance at December 31, 2012	$	5,667
														Total gain or losses:
														Included in earnings		32,906
														Transfers in and/or out of Level 3		—
														Repurchase of restricted units		(2,267	)
														Settlement		—
														Balance at December 31, 2013	$	36,306
Fair Value, by Balance Sheet Grouping	'													'
	The estimated fair value and carrying amount of long-term debt as reported on the condensed consolidated balance sheets as of September 30, 2014 and December 31, 2013 is shown in the table below (refer to Note 2 for details relating to the borrowing arrangements). The fair value was estimated using Level 2 inputs based on rates reflective of the remaining maturity as well as the Company’s financial position.													The estimated fair value of long-term debt on the consolidated balance sheets at December 31, 2013 and 2012 is shown in the table below (refer to Note 4 for details relating to the borrowing arrangements) (in thousands). The fair value was estimated using Level 3 inputs based on rates reflective of the remaining maturity as well as the Company’s financial position.
		As of September 30, 2014						As of December 31, 2013						Description	2013			2012
		Carrying Value			Fair Value			Carrying Value		Fair Value				Long-term debt, at fair value
	Long-Term Debt (in thousands)													Debentures	$	12,671		$	70,220
	Senior Notes Offering	$	900,000		$	866,864		$	—	$	—			Wells Fargo Energy Capital Credit Facility		—			70,000
	Second Lien Term Loan Facility		—			—			293,821		315,284			Second Lien Term Loan Facility		315,284			—
	Senior Secured Revolving Credit Facility		—			—			115,000		115,000			NPI Note		8,028			15,282
	Debentures		—			—			6,890		12,671			Senior Secured Revolving Credit Facility		115,000			—
	NPI Note		—			—			8,028		8,028			Other		3,203			4,038
	Other		1,006			1,006			3,203		3,203
														Total	$	454,186		$	159,540
	Total	$	901,006		$	867,870		$	426,942	$	454,186

Acquisitions_Tables

Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2014
Business Combinations [Abstract]	'
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	'
	The purchase price allocation and resulting impact on the corresponding condensed consolidated balance sheet relating to the Marcellus JV Buy-In is as follows:
	(in thousands)
	Financial assets	$	34,242
	Proved natural gas properties, net		288,000
	Unproved natural gas properties		55,000
	Goodwill		338,036
	Financial liabilities		(49,313	)
	Long-term debt		(75,400	)
	Deferred tax liability		(17,933	)
	Total identifiable net assets	$	572,632
	Cash paid for acquisitions	$	100,000
	Fair value of equity issued		222,000
	Fair value of pre-existing equity investment		250,632
	Total consideration	$	572,632
Schedule of Business Acquisitions, by Acquisition	'
	Subsequent to the completion of the Marcellus JV Buy-In and excluding the related gain of $203.6 million recorded at January 29, 2014, the 100%-owned Marcellus joint venture contributed the following to the Company’s consolidated operating results for the three and nine months ended September 30, 2014:
	(in thousands)	Three Months			Nine Months
		Ended September 30,			Ended September 30,
		2014			2014
	Revenue	$	30,689		$	103,290
	Net income	$	12,008		$	57,419
Business Acquisition, Pro Forma Information	'
	The following unaudited pro forma combined financial information presents the Company’s results as though the Marcellus JV Buy-In had been completed at January 1, 2014 and January 1, 2013, respectively.
	(in thousands, except per share data)	Three Months Ended						Nine Months Ended
		September 30,						September 30,
		2014			2013			2014			2013
	Pro forma net revenues	$	79,127		$	42,959		$	273,480		$	123,676
	Pro forma net loss	$	(6,862	)	$	(29,088	)	$	(83,794	)	$	(1,540	)
	Pro forma loss per share (basic)	$	(0.05	)	$	(0.33	)	$	(0.65	)	$	(0.02	)
	Pro forma loss per share (diluted)	$	(0.05	)	$	(0.33	)	$	(0.65	)	$	(0.02	)

Incentive_Units_Tables

Incentive Units (Tables)	9 Months Ended
	Sep. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
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 IPO to September 30, 2014 is included below.
	Vested Units Balance, January 29, 2014	853,630
	Vested During Period	565,881
	Forfeited During Period	(214,869	)
	Granted During Period	214,869
	Cancelled During Period	—
	Vested Units Balance, September 30, 2014	1,419,511

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	9 Months Ended												12 Months Ended
	Sep. 30, 2014												Dec. 31, 2013
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 three and nine months ended September 30, 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.												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, 2013, 2012 and 2011:
		Three Months Ended						Nine Months Ended						Year Ended December 31,
		September 30,						September 30,					(in thousands, except per share data)	2013			2012			2011
	(in thousands, except share data)	2014			2013			2014		2013			Loss (numerator):
	Income (loss) (numerator):												Net loss	$	(35,776	)	$	(19,344	)	$	(936	)
	Net income (loss)	$	(6,862	)	$	(33,652	)	$	114,675	$	(20,841	)
													Weighted-average shares (denominator):
	Weighted-average shares (denominator):												Weighted-average number of shares of common stock – basic		80,441,905			57,966,572			39,958,066
	Weighted-average number of shares of common stock—basic		132,269,081			88,000,000			125,411,524		77,894,855		Weighted-average number of shares of common stock - diluted		80,441,905			57,966,572			39,958,066
	Weighted-average number of shares of common stock—diluted		132,269,081			88,000,000			125,678,095		77,894,855
	Earnings (loss) per share:												Loss per share:
	Basic	$	(0.05	)	$	(0.38	)	$	0.91	$	(0.27	)	Basic	$	(0.44	)	$	(0.33	)		(0.02	)
	Diluted	$	(0.05	)	$	(0.38	)	$	0.91	$	(0.27	)	Diluted	$	(0.44	)	$	(0.33	)		(0.02	)

Income_Taxes_Tables

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2014
Income Tax Disclosure [Abstract]	'
Schedule of Components of Income Tax Expense (Benefit)	'
	The components of the income tax provision are as follows:
	(in thousands)	Three Months		Nine Months
		Ended		Ended
		September 30,		September 30,
		2014		2014
	Current tax expense:
	Federal	$	—	$	—
	State		—		—
	Total		—		—
	Deferred tax expense:
	Federal		11,813		15,847
	State		2,192		2,940
	Total		14,005		18,787
	Total income tax expense	$	14,005	$	18,787

Summary_of_Significant_Account1

Summary of Significant Accounting Policies and Related Matters (Tables)	12 Months Ended
	Dec. 31, 2013
Accounting Policies [Abstract]	'
Details of Accounts Receivable	'
	Accounts receivable as of December 31, 2013 and 2012 are detailed below.
		December 31,
	(in thousands)	2013		2012
	Natural gas sales	$	16,534	$	5,564
	Joint interest		6,391		1,810
	Other		8,840		1,183
	Total accounts receivable	$	31,765	$	8,557
Components of Interest Incurred	'
	The following table summarizes the components of the Company’s interest incurred for the periods indicated (in thousands):
		2013		2012		2011
	Interest incurred:
	Interest capitalized	$	8,034	$	7,695	$	5,405
	Interest expensed		17,915		3,487		531
	Total incurred	$	25,949	$	11,182	$	5,936

Capitalized_Costs_Relating_to_1

Capitalized Costs Relating to Gas-Producing Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Extractive Industries [Abstract]	'
Proved and Unpoved Capitalized Cost	'
	Proved and unproved capitalized costs related to the Company’s gas-producing activities are as follows (in thousands):
		2013		2012
	Capitalized costs:
	Unproved properties	$	457,836	$	111,030
	Proved, producing properties		244,771		119,374
	Proved, nonproducing properties		78,441		61,434
	Total		781,048		291,838
	Accumulated depreciation, depletion and amortization		52,689		20,820
	Net capitalized costs	$	728,359	$	271,018
	Entity’s share of equity method investees’ net capitalized costs	$	91,166	$	57,110

Lease_Obligations_Tables

Lease Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Leases [Abstract]	'
Future Minimum Lease Payments	'
	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, 2013 (in thousands):
	2014	$	18,606
	2015		1,398
	2016		153
	2017		124
	2018 and thereafter		—
	Total future minimum lease payments	$	20,281

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligation Disclosure [Abstract]	'
Reconciliation of Asset Retirement Obligations	'
	A reconciliation of the beginning and ending aggregate carrying amount of asset retirement obligations for the years ended December 31, 2013 and 2012 is as follows (in thousands):
	Balance at December 31, 2010	$	289
	Liabilities incurred		493
	Accretion expense		53
	Balance at December 31, 2011	$	835
	Liabilities incurred		382
	Accretion expense		164
	Balance at December 31, 2012	$	1,381

Restricted_Unit_Agreements_Tab

Restricted Unit Agreements (Tables)	12 Months Ended
	Dec. 31, 2013
Text Block [Abstract]	'
Summary of Change in Vested Restricted Units	'
	During 2012, REA exercised its option to repurchase all of the 2,000 Class B restricted units. A summary of the change in vested restricted units is as follows:
		Restricted Units
	Class A and Class B restricted units
	Vested restricted units		4,000
	Repurchased Class B restricted units		(2,000	)
	Vested restricted units as of December 31, 2012		2,000
	Repurchased Class B restricted units		—

Subsequent_Events_Tables

Subsequent Events (Tables)	12 Months Ended
	Dec. 31, 2013
Subsequent Events [Abstract]	'
Unaudited Proforma Combined Financial Information	'
	The following unaudited pro forma combined financial information presents the Company’s results as though the Company and the incremental 50% interest in our Marcellus joint venture had occurred at January 1, 2013.
	(in thousands)	Year Ended
		December 31, 2013
		(Pro forma)
	Pro forma net revenues	$	179,281
	Pro forma net loss	$	(30,509	)
	Pro forma earnings per share	$	(0.24	)

Quarterly_Financial_Informatio1

Quarterly Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Information Disclosure [Abstract]	'
Quarterly Financial Information	'
	The Company’s quarterly financial information for the years ended December 31, 2013 and 2012 is as follows (in thousands):
		First			Second			Third			Fourth
		quarter			quarter			quarter			quarter
	Year ended December 31, 2013:
	Total operating revenues	$	13,233		$	23,840		$	23,665		$	27,866
	Total operating expenses		10,705			25,833			52,274			27,755
	Operating income (loss)		2,528			(1,993	)		(28,609	)		111
	Net income (loss)	$	(6,775	)	$	19,586		$	(33,652	)	$	(14,935	)
		First			Second			Third			Fourth
		quarter			quarter			quarter			quarter
	Year ended December 31, 2012:
	Total operating revenues	$	4,792		$	4,155		$	6,580		$	11,673
	Total operating expenses		6,353			11,984			8,123			9,640
	Operating income (loss)		(1,561	)		(7,829	)		(1,543	)		2,033
	Net income (loss)	$	(2,334	)	$	(12,884	)	$	(6,523	)	$	2,397

Supplemental_Information_on_Ga1

Supplemental Information on Gas-Producing Activities (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Costs Incurred for Property Acquisitions, Exploration and Development	'
	Costs incurred for property acquisitions, exploration and development are as follows for Rice Energy (in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Acquisitions:
	Unproved leaseholds		$	305,000		$	47,396		$	16,877
	Development costs			184,217			89,307			72,776
	Exploration costs:
	Geological and geophysical			9,951			3,275			660
	Total costs incurred		$	499,168		$	139,978		$	90,313
Results of Operations Related to Natural Gas Production	'
	The following table presents the results of operations related to natural gas production for Rice Energy (in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Revenues		$	87,847		$	26,743		$	13,972
	Production costs			19,712			8,824			2,157
	Exploration costs			9,951			3,275			660
	Depreciation, depletion and amortization			29,808			13,329			5,920
	Write-down of abandoned leases			—			2,253			109
	General and administrative expenses			5,108			3,050			2,212
	Results of operations from producing activities		$	23,268		$	(3,988	)	$	2,914
Reserve Quantity Information	'
	Reserve quantity information is as follows for Rice Energy:
			Natural Gas (MMcf)
			For the Years Ended December 31,
			2013			2012			2011
	Proved developed and undeveloped reserves:
	Beginning of year			304,272			232,996			12,230
	Extensions and discoveries			100,626			176,956			223,538
	Revision of previous estimates			757			(96,911	)		620
	Production			(22,995	)		(8,769	)		(3,392	)
	End of year			382,660			304,272			232,996
	Proved developed reserves:
	End of year			144,310			61,225			25,397
	Proved undeveloped reserves:
	End of year			238,350			243,047			207,599
Estimated Discounted Future Net Cash Flows Related to Proved Natural Gas Reserves	'
	Information with respect to Rice Energy’s estimated discounted future net cash flows related to its proved natural gas reserves is as follows (in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Future cash inflows		$	1,496,294		$	869,882		$	1,015,589
	Future production costs			(517,101	)		(323,855	)		(208,733	)
	Future development costs			(219,879	)		(262,084	)		(206,612	)
	Future net cash flows			759,314			283,943			600,244
	10% annual discount for estimated timing of cash flows			(342,150	)		(181,725	)		(330,924	)
	Standardized measure of discounted future net cash flows(1)		$	417,164		$	102,218		$	269,320
	-1	Does not include the effects of income taxes on future revenues at December 31, 2013 and 2012 because as of December 31, 2013 and 2012, the Company was 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 the Company’s equity holders. However, in connection with the closing of the IPO, as a result of the corporate reorganization, the Company became a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income.
Principal Sources 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 Rice Energy (in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Balance at beginning of period		$	102,218		$	269,320		$	46,422
	Net change in prices and production costs			101,345			(83,873	)		(15,929	)
	Net change in future development costs			29,336			(31,811	)		(3,695	)
	Natural gas net revenues			(68,135	)		(18,376	)		(11,815	)
	Extensions			114,489			38,937			243,003
	Revisions of previous quantity estimates			1,133			(108,209	)		(14,259	)
	Previously estimated development costs incurred			66,894			17,036			3,040
	Accretion of discount			10,230			26,932			4,642
	Changes in timing and other			59,654			(7,738	)		17,911
	Balance at end of period		$	417,164		$	102,218		$	269,320
Marcellus Joint Venture	'
Costs Incurred for Property Acquisitions, Exploration and Development	'
	Costs incurred for property acquisitions, exploration and development related to the Company’s Marcellus joint venture (“the Marcellus joint venture”) are as follows (represents Rice Energy’s proportionate share, in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Acquisitions:
	Unproved leaseholds		$	—		$	—		$	519
	Development costs			46,571			46,725			21,700
	Exploration costs:
	Geological and geophysical			—			—			—
	Total costs incurred		$	46,571		$	46,725		$	22,219
Results of Operations Related to Natural Gas Production	'
	The following table presents Rice Energy’s share of the results of operations related to natural gas production of the Marcellus joint venture (represents Rice Energy’s proportionate share, in thousands):
			For the Years Ended December 31,
			2013			2012			2011
	Revenues		$	45,339		$	13,142		$	2,872
	Production costs			12,557			5,436			379
	Impairment of oil and gas properties			—			—			1,296
	Depreciation, depletion and accretion			12,500			4,702			1,092
	General and administrative expenses			1,557			986			—
	Results of operations from producing activities		$	18,725		$	2,018		$	105
Reserve Quantity Information	'
	Reserve quantity information is as follows for the Marcellus joint venture (represents Rice Energy’s proportionate share, in thousands):
			Natural Gas (MMcf)
			For the Years Ended December 31,
			2013			2012			2011
	Proved developed and undeveloped reserves:
	Beginning of year			128,118			58,103			—
	Extensions and discoveries			19,812			98,119			58,800
	Revision of previous estimates			(26,803	)		(23,808	)		—
	Production			(11,443	)		(4,296	)		(697	)
	End of year			109,684			128,118			58,103
	Proved developed reserves:
	End of year			52,370			35,013			14,474
	Proved undeveloped reserves:
	End of year			57,314			93,105			43,629
Estimated Discounted Future Net Cash Flows Related to Proved Natural Gas Reserves	'
	Information with respect to Rice Energy’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):
			For the Years Ended December 31,
			2013			2012			2011
	Future cash inflows		$	427,167		$	364,157		$	252,384
	Future production costs			(132,427	)		(127,086	)		(29,683	)
	Future development costs			(46,344	)		(86,213	)		(51,882	)
	Future net cash flows			248,396			150,858			170,819
	10% annual discount for estimated timing of cash flows			(102,293	)		(79,781	)		(100,232	)
	Standardized measure of discounted future net cash flows(1)		$	146,103		$	71,077		$	70,587
	-1	Does not include the effects of income taxes on future revenues at December 31, 2013 and 2012 because as of December 31, 2013 and 2012, the Company was 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 the Company’s equity holders. However, in connection with the closing of the IPO, as a result of the corporate reorganization, the Company became a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income.
Principal Sources of Changes in Standardized Measure of Discounted Future Net Cash Flows	'
	The following is for the Marcellus joint venture (represents Rice Energy’s proportionate share, in thousands), the principal sources of changes in the standardized measure of discounted future net cash flows:
			For the Years Ended December 31,
			2013			2012			2011
	Balance at beginning of period		$	71,077		$	70,587		$	—
	Net change in prices and production costs			81,974			(26,855	)		—
	Net change in future development costs			2,781			(262	)		—
	Natural gas net revenues			(32,782	)		(7,707	)		(2,494	)
	Extensions			18,950			38,131			73,081
	Revisions of previous quantity estimates			(14,752	)		(28,923	)		—
	Previously estimated development costs incurred			31,253			12,862			—
	Accretion of discount			7,111			7,059			—
	Changes in timing and other			(19,509	)		6,185			—
	Balance at end of period		$	146,103		$	71,077		$	70,587

Basis_of_Presentation_Detail

Basis of Presentation (Detail) (USD $)

1 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

3 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

Jan. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Jan. 29, 2014

Mar. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2014

Mar. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Mar. 31, 2014

Sep. 30, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

NGP Holdings

NGP Holdings

NGP Holdings

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

Rice Energy Inc

Marcellus Joint Venture

Marcellus Joint Venture

Incentive Units

Incentive Units

Incentive Units

Mr. Daniel J. Rice III

Rice Partners

Incentive Unitholders

Rice Drilling B

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Selling Stockholder

Underwriters of Initial Public Offering

NGP Holdings

NGP Holdings

NGP Holdings

Rice Holdings

IPO

Rice Holdings

Incentive Unitholders

Incentive Units

Incentive Units

Subsidiary, Sale of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares sold with the completion of the IPO

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

'

14,000,000

6,000,000

'

'

'

'

30,000,000

'

'

Common Stock, par value per share

'

'

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public offering price per share

'

'

'

'

'

'

'

'

'

'

'

'

$21

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds of IPO

'

'

'

'

'

'

'

'

'

'

$992,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds of IPO after deducting expenses and underwriting discounts and commissions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

399,000,000

'

'

'

'

'

593,600,000

'

'

Underwriting discounts and commissions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21,000,000

'

'

'

'

'

36,400,000

'

'

Cash paid for acquisitions

3,300,000

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

Common stock (shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

2,356,844

20,000,000

160,831

1,728,852

'

'

'

'

'

'

43,452,550

'

'

20,300,923

'

'

'

Issuance of shares of common stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,523,810

'

Common stock outstanding (shares)

'

'

'

'

'

'

'

'

'

'

'

'

127,523,810

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payment for pre-determined payout criteria

'

'

'

'

'

'

'

'

12,000,000

19,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,400,000

'

'

'

'

'

Incentive unit expense

'

26,418,000

0

101,695,000

0

'

'

'

'

'

'

3,400,000

'

'

'

'

'

26,400,000

101,700,000

'

7,800,000

'

'

'

'

'

'

'

'

'

Unrecognized compensation cost

'

'

'

'

'

'

'

142,300,000

'

'

'

'

'

'

'

'

'

'

'

79,800,000

'

'

'

'

'

77,300,000

'

'

'

'

Percentage of voting interests acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

Total consideration amount

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

322,000,000

'

Gain on purchase of Marcellus joint venture

'

$0

$0

$203,579,000

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$203,600,000

'

Long_Term_Debt_Schedule_of_Lon

Long Term Debt (Schedule of Long-term Debt) (Detail) (USD $)	Sep. 30, 2014		Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Debt Instrument [Line Items]	'		'		'
Total debt	$901,006		$426,942		$149,320
Less current portion	1,006		20,120		8,814
Long-term debt	900,000		406,822		140,506
Senior Notes | Senior Notes Due 2022	'		'		'
Debt Instrument [Line Items]	'		'		'
Total debt	900,000	[1]	0	[1]	'
Second Lien Term Loan Facility | Second Lien Term Loan Facility	'		'		'
Debt Instrument [Line Items]	'		'		'
Total debt	0	[2]	293,821	[2],[3]	0	[3]
Senior Secured Revolving Credit Facility | Wells Fargo Energy Capital Credit Facility	'		'		'
Debt Instrument [Line Items]	'		'		'
Total debt	'		0	[4]	70,000	[4]
Senior Secured Revolving Credit Facility | Senior Secured Revolving Credit Facility	'		'		'
Debt Instrument [Line Items]	'		'		'
Total debt	0	[5]	115,000	[5],[6]	0	[6]
Debentures | Senior Subordinated Convertible Debentures Maturing in 2014	'		'		'
Debt Instrument [Line Items]	'		'		'
Total debt	0	[7]	6,890	[7],[8]	60,000	[8]
NPI Note | NPI Note	'		'		'
Debt Instrument [Line Items]	'		'		'
Total debt	0		8,028	[9]	15,282	[9]
Other	'		'		'
Debt Instrument [Line Items]	'		'		'
Total debt	$1,006		$3,203		$4,038
[1]	6.25% Senior Notes Due 2022 (a) On April 25, 2014, the Company issued $900.0 million (the "Senior Notes Offering") in aggregate principal amount of 6.25% senior notes due 2022 (the "Notes") in a private placement to eligible purchasers under Rule 144A and Regulation S of the Securities Act, which resulted in net proceeds of $882.7 million, after deducting estimated 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), with the remainder expected to be used to fund a portion of the Company's 2014 capital expenditure program. The Notes will mature on May 1, 2022, and interest is payable on the Notes on each May 1 and November 1, commencing on November 1, 2014. At any time prior to May 1, 2017, the Company may redeem up to 35% of the 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 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 notes (the "Indenture")), unless the Company has given notice to redeem the Notes, the holders of the Notes will have the right to require the Company to repurchase all or a portion of the Notes at a price equal to 101% of the aggregate principal amount of the 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 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. 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.
[2]	Second Lien Term Loan Facility (b) On April 25, 2013, Rice Drilling B entered into a Second Lien Term Loan Facility ("Second Lien Term Loan Facility") with Barclays Bank PLC, as administrative agent, and a syndicate of lenders in an aggregate principal amount of $300.0 million. Rice Drilling B estimated the discount on issuance of this instrument based upon an estimate of market rates at the inception of the instrument and recorded a discount of $4.5 million. The discount was being amortized over the life of the note using an effective interest rate of 0.284%. Approximately $7.4 million in fees were capitalized in connection with the Second Lien Term Loan Facility. On April 25, 2014, the Company used a portion of the net proceeds from the Senior Notes Offering to repay and retire the Second Lien Term Loan Facility in the amount of $301.8 million. The payment was comprised of repayment of the principal balance of $297.0 million, a pre-payment penalty of $3.0 million and accrued but unpaid interest of $1.8 million. The pre-payment penalty is presented as loss on extinguishment of debt in the condensed consolidated statements of operations for the three months ended June 30, 2014. The pre-payment also resulted in a debt extinguishment and subsequent write-off of the unamortized deferred finance costs of $6.1 million presented in the condensed consolidated statements of operations for the three months ended June 30, 2014.
[3]	Second Lien Term Loan Facility (c) On April 25, 2013, the Company entered into a Second Lien Term Loan Facility ("Second Lien Term Loan Facility") with Barclays Bank PLC, as administrative agent, and a syndicate of lenders in an aggregate principal amount of $300.0 million. The Company estimated the discount on issuance of this instrument based upon an estimate of market rates at the inception of the instrument and recorded a discount of $4.5 million. The discount is being amortized over the life of the note using an effective interest rate of 0.284% using the effective yield method. As of December 31, 2013, the Company had a balance of $293.8 million relating to the Second Lien Term Loan Facility, this includes borrowings outstanding of $297.7 million less a discount of $3.9 million. The Second Lien Term Loan Facility matures October 25, 2018. Approximately $7.3 million in fees were capitalized in connection with the Second Lien Term Loan Facility.
[4]	Wells Fargo Energy Capital Credit Facility (b) In November of 2012, the Company amended and restated its then existing credit facility with Wells Fargo. In connection with the amendment and restatement, a lender was added to the new facility. The amendment and restatement was accounted for as a modification of the debt, resulting in $0.2 million of third-party costs associated with the amendment and restatement being expensed. The Wells Fargo Energy Capital Credit Facility ("Wells Fargo Energy Capital Credit Facility") was subject to a maximum borrowing base equal to $200.0 million, as determined unanimously by Wells Fargo Energy Capital, in accordance with customary lending practices. This loan was repaid using proceeds from the Second Lien Term Loan Facility during the second quarter of 2013.
[5]	Senior Secured Revolving Credit Facility (c) On April 25, 2013, Rice Drilling B entered into a Senior Secured Revolving Credit Facility ("Senior Secured Revolving Credit Facility") with Wells Fargo Bank, N.A., as administrative agent, and a syndicate of lenders with a maximum credit amount of $500.0 million and a sublimit for letters of credit of $10.0 million. Concurrently with the closing of the IPO, on January 29, 2014, Rice Drilling B amended its Senior Secured Revolving Credit Facility to, among other things, allow for the corporate reorganization that was completed simultaneously with the closing of the IPO, add the Company as a guarantor, increase the maximum commitment amount to $1.5 billion and lower the interest rate on amounts borrowed under the Senior Secured Revolving Credit Facility. The Company used a portion of the net proceeds of the IPO to repay $115.0 million of borrowings under the Senior Secured Revolving Credit Facility. After giving effect to the amendment, the borrowing base under the Senior Secured Revolving Credit Facility was increased to $350.0 million as a result of the Marcellus JV Buy-In.
[6]	Senior Secured Revolving Credit Facility (e) On April 25, 2013, the Company entered into a revolving credit facility with Wells Fargo Bank, N.A., as administrative agent, and a syndicate of lenders with a maximum credit amount of $500.0 million and a sublimit for letters of credit of $10.0 million. As of December 31, 2013, the sublimit for the letters of credit was $100.0 million. The amount available to be borrowed under the revolving credit facility is subject to a borrowing base that is redetermined semiannually as of each January 1 and July 1 and depends on the volumes of our proved oil and gas reserves and estimated cash flows from these reserves and our commodity hedge positions. The next redetermination is scheduled to occur in April 2014. As of December 31 2013, the borrowing base was $200.0 million. As of December 31, 2013, we had $115.0 million in borrowings and approximately $22.5 million in letters of credit outstanding under our revolving credit facility. The revolving credit facility matures April 25, 2018.
[7]	Debentures (d) In June of 2011, Rice Drilling B sold $60.0 million of its 12% Senior Subordinated Convertible Debentures due 2014 (the "Debentures") in a private placement to certain accredited investors as defined in Rule 501 of Regulation D. The Debentures accrued interest at 12% per year payable monthly in arrears by the 15th day of the month and had a scheduled maturity date of July 31, 2014 ("Maturity Date"). The Debentures were Rice Drilling B's unsecured senior obligations and ranked equally with all of Rice Drilling B's then-current and future senior unsecured indebtedness. From July 31, 2013 through August 20, 2013 (the "put redemption period"), any holder of Debentures had the right to cause Rice Drilling B to repurchase all or any portion of the Debentures owned by such holder at 100% of the portion of the principal amount of the Debentures as to which the right was being exercised, plus a premium of 20%. During the put redemption period, Rice Drilling B repurchased $53.1 million of outstanding Debentures and paid a put premium of $10.6 million in accordance with the terms of the agreements. At any time after July 31, 2013 until the Maturity Date, Rice Drilling B had the right to redeem all, but not less than all, of the Debentures on 30 days prior written notice at a redemption price equal to 100% of the principal amount of the Debentures plus a premium of 50%. In connection with the IPO, the Debentures and warrants of Rice Drilling B were amended to become convertible or exercisable for shares of common stock of the Company. On February 28, 2014, Rice Drilling B issued a redemption notice on the remaining Debentures, which set a redemption date of March 28, 2014. Prior to the redemption date, $6.6 million of the Debentures were converted into 570,945 shares of the Company's common stock. The remaining principal balance of $0.3 million that was not converted will be paid upon request from holders of the remaining Debentures. The premium of $0.1 million was recorded to expense in the six months ended June 30, 2014. As of June 30, 2014, the remaining principal balance was $0.2 million. In connection with the convertible debt offering, Rice Drilling B granted warrants that were issued on August 15, 2011, to certain of the broker-dealers involved in the private placement. These warrants are considered to be separate instruments issued solely in lieu of cash compensation for services provided by the broker-dealers. Two separate classes of warrants were issued with the sole difference being the exercise price. At June 30, 2014, 266 warrants remain exercisable at a weighted average price of $11.57 per share of the Company's common stock. The 266 warrants are exercisable into up to 229,668 shares. During the first quarter of 2014, warrants were exercised in exchange for 54,032 shares of the Company's common stock, and during the second quarter of 2014, warrants were exercised for 505,734 shares of the Company's common stock.
[8]	Debentures (a) In June of 2011, the Company sold $60.0 million of its 12% Senior Subordinated Convertible Debentures due 2014 ("the Debentures") in a private placement to certain accredited investors as defined in Rule 501 of Regulation D. The Debentures accrue interest at 12% per year payable monthly in arrears by the 15th day of the month and mature on July 31, 2014 ("Maturity Date"). The Debentures are the Company's unsecured senior obligations and rank equally with all of the Company's current and future senior unsecured indebtedness. From July 31, 2013 through August 20, 2013 ("the put redemption period"), any holder of Debentures had the right to cause the Company to repurchase all or any portion of the Debentures owned by such holder at 100% of the portion of the principal amount of the Debentures as to which the right was being exercised, plus a premium of 20%. During the put redemption period, the Company repurchased $53.1 million of outstanding Debentures and paid a put premium of $10.6 million in accordance with the terms of the agreements. The put redemption period expired in the nine months ended September 30, 2013 and the Company recorded the premium of $10.6 million as a loss on extinguishment of debt in the statement of consolidated operations for the year ended December 31, 2013. At any time after July 31, 2013 until the Maturity Date, the Company has the right to redeem all, but not less than all, of the Debentures on 30 days prior written notice at a redemption price equal to 100% of the principal amount of the Debentures plus a premium of 50%. In connection with the IPO, the convertible debentures and warrants of Rice Drilling B were amended to become convertible or exercisable for an aggregate 1,671,800 shares of common stock of Rice Energy Inc. Through March 10, 2014, approximately $5.0 million of the convertible debentures had been converted into 433,073 shares of Rice Energy Inc. common stock. On February 28, 2014, the Company issued a call notice on the remaining convertible debentures, requiring a response by March 30, 2014. Amounts not converted by the redemption date will receive a cash payment from the Company of 100% of the principal amount plus a premium of 50%, which could result in additional costs of $1.0 million if all remaining convertible debentures are redeemed. As the principal amount of the convertible debentures outstanding has been reduced to less than $5.0 million, the Company is no longer required to maintain restricted cash. In connection with the convertible debt offering, Rice Drilling B granted warrants that were issued on August 15, 2011, to certain of the broker-dealers involved in the private placement. These warrants are considered to be separate instruments issued solely in lieu of cash compensation for services provided by the broker-dealers. Two separate classes of warrants were issued (Normal and Bonus), the sole difference being the exercise price.
[9]	NPI Note (d) In November of 2012, in connection with the amendment of the Wells Fargo Credit Facility, the Company repurchased the NPI it had previously assigned to Wells Fargo for $26.5 million, of which $9.5 million was paid at the closing of the Wells Fargo Energy Capital Credit Facility and $17.0 million was financed by a note to Wells Fargo. The Company accounted for this as the acquisition of a mineral right and therefore capitalized this amount in proved properties and will amortize using the units of production method. There is no stated interest rate associated with this note and as a result, this note was considered to have below market financing rates. The Company estimated the discount on issuance of this instrument based upon an estimate of market rates at the inception of the instrument and recorded a discount of $2.0 million. The discount is being amortized over the life of the note using an effective interest rate of 12.10% using the effective yield method. As part of the use of proceeds from the Second Lien Term Loan Facility, the Company repaid $8.5 million of this note during the second quarter of 2013. A final payment of $8.5 million is due to be repaid in June of 2014.

Long_Term_Debt_625_Senior_Note

Long Term Debt (6.25% Senior Notes Due 2022) (Detail) (USD $)

9 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 25, 2014

Apr. 25, 2014

Apr. 25, 2014

Apr. 25, 2014

Apr. 25, 2014

Apr. 25, 2014

Apr. 25, 2014

Apr. 25, 2014

Apr. 25, 2014

Jun. 30, 2013

Apr. 25, 2013

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Senior Notes

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Senior Notes Due 2022

Senior Notes Due 2022

Senior Notes Due 2022

Senior Notes Due 2022

Senior Notes Due 2022

Senior Notes Due 2022

Senior Notes Due 2022

Senior Notes Due 2022

Prior to May 1, 2017

On or after May 1, 2017

12 month period beginning May 1, 2018

12 month period beginning on May 1, 2019

12 month period beginning on May 1, 2020

Maximum

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate

'

'

'

'

'

'

6.25%

'

'

'

'

'

'

'

'

'

Aggregate principal amounts of debt offered

'

'

'

'

'

'

$900,000,000

'

'

'

'

'

'

'

'

$300,000,000

Proceeds from borrowings

900,000,000

321,003,000

435,500,000

44,361,000

82,972,000

882,700,000

'

'

'

'

'

'

'

'

'

'

Underwriting discounts and commissions

19,401,000

9,480,000

12,194,000

1,913,000

9,699,000

17,300,000

'

'

'

'

'

'

'

'

'

'

Repayments of debt obligations

498,983,000

159,726,000

160,760,000

10,152,000

7,726,000

'

'

'

'

'

'

'

'

301,800,000

8,500,000

'

Percentage of principal amount redeemed

'

'

'

'

'

'

'

35.00%

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

65.00%

'

'

'

'

'

'

'

'

Percentage of redemption price of principal amount plus applicable make-whole premium and accrued and unpaid interest

'

'

'

'

'

'

'

100.00%

104.69%

103.13%

101.56%

100.00%

'

'

'

'

Percentage that may be redeemed upon change in control

'

'

'

'

'

'

'

101.00%

'

'

'

'

'

'

'

'

Restricted assets as a percentage of net assets

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

Period for default of interest payment

'

'

'

'

'

'30 days

'

'

'

'

'

'

'

'

'

'

Aggregate principal amount in default

'

'

'

'

'

'

25,000,000

'

'

'

'

'

'

'

'

'

Amount of failure to pay final judgments

'

'

'

'

'

'

$25,000,000

'

'

'

'

'

'

'

'

'

Period for failure to pay final judgments amount

'

'

'

'

'

'60 days

'

'

'

'

'

'

'

'

'

'

Long_Term_Debt_Second_Lien_Ter

Long Term Debt (Second Lien Term Loan Facility) (Detail) (USD $)

3 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 25, 2014

Apr. 25, 2013

Jun. 30, 2013

Sep. 30, 2014

Dec. 31, 2013

Apr. 25, 2014

Apr. 25, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Apr. 25, 2013

Dec. 31, 2013

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Eurodollar

Base Rate

First Year

Second Year

Scenario, Previously Reported

Minimum

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate principal amounts of debt offered

'

'

'

'

'

'

'

'

'

'

'

'

'

$300,000,000

'

'

'

'

'

'

'

Amount of discount

'

'

'

'

'

'

'

'

'

'

'

3,900,000

'

4,500,000

'

'

'

'

'

'

'

Effective interest rate (percentage)

'

'

'

'

'

'

'

'

'

'

'

'

'

0.28%

'

'

'

'

'

'

'

Fees capitalized

'

'

'

'

'

'

'

'

7,400,000

'

'

'

'

'

'

'

'

'

'

7,300,000

'

Repayments of debt obligations

'

'

498,983,000

159,726,000

160,760,000

10,152,000

7,726,000

301,800,000

'

8,500,000

'

'

'

'

'

'

'

'

'

'

'

Borrowings outstanding

'

'

'

'

'

'

'

'

'

'

'

297,700,000

297,000,000

'

'

'

'

'

'

'

'

Loss on extinguishment of debt

'

'

-3,934,000

0

'

'

'

-800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued but unpaid interest

'

'

'

'

'

'

'

'

'

'

'

'

1,800,000

'

'

'

'

'

'

'

'

Write-off of deferred financing costs

0

0

-6,896,000

0

'

'

'

'

'

'

-6,900,000

'

'

'

'

'

'

'

'

'

'

Outstanding balance

$901,006,000

'

$901,006,000

'

$426,942,000

$149,320,000

'

'

'

'

$0

[1]

$293,821,000

[1],[2]

'

'

$0

[2]

'

'

'

'

'

'

Percentage of principal amount payable in each quarter

'

'

'

'

'

'

'

'

'

'

'

0.25%

'

'

'

'

'

'

'

'

'

Interest rate spread (percentage)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

7.25%

'

'

'

'

'

Interest rate terms

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'Base rate loans bear interest at a rate per annum equal to the greatest of (i) 2.25%, (ii) the agent bank's reference rate, (iii) the federal funds effective rate plus 50 basis points and (iv) the rate for one month Eurodollar loans plus 100 basis points, plus 625 basis points.

'

'

'

'

Prepayments of principal amounts subject to premium

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.00%

1.00%

'

'

Interest rate at period end

'

'

'

'

'

'

'

'

'

'

'

8.50%

'

'

'

'

'

'

'

'

'

Discount factor used in calculating present value of oil and gas reserves

'

'

'

'

'

'

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

Asset coverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

150.00%

[1]

Second Lien Term Loan Facility (b) On April 25, 2013, Rice Drilling B entered into a Second Lien Term Loan Facility ("Second Lien Term Loan Facility") with Barclays Bank PLC, as administrative agent, and a syndicate of lenders in an aggregate principal amount of $300.0 million. Rice Drilling B estimated the discount on issuance of this instrument based upon an estimate of market rates at the inception of the instrument and recorded a discount of $4.5 million. The discount was being amortized over the life of the note using an effective interest rate of 0.284%. Approximately $7.4 million in fees were capitalized in connection with the Second Lien Term Loan Facility. On April 25, 2014, the Company used a portion of the net proceeds from the Senior Notes Offering to repay and retire the Second Lien Term Loan Facility in the amount of $301.8 million. The payment was comprised of repayment of the principal balance of $297.0 million, a pre-payment penalty of $3.0 million and accrued but unpaid interest of $1.8 million. The pre-payment penalty is presented as loss on extinguishment of debt in the condensed consolidated statements of operations for the three months ended June 30, 2014. The pre-payment also resulted in a debt extinguishment and subsequent write-off of the unamortized deferred finance costs of $6.1 million presented in the condensed consolidated statements of operations for the three months ended June 30, 2014.

[2]

Second Lien Term Loan Facility (c) On April 25, 2013, the Company entered into a Second Lien Term Loan Facility ("Second Lien Term Loan Facility") with Barclays Bank PLC, as administrative agent, and a syndicate of lenders in an aggregate principal amount of $300.0 million. The Company estimated the discount on issuance of this instrument based upon an estimate of market rates at the inception of the instrument and recorded a discount of $4.5 million. The discount is being amortized over the life of the note using an effective interest rate of 0.284% using the effective yield method. As of December 31, 2013, the Company had a balance of $293.8 million relating to the Second Lien Term Loan Facility, this includes borrowings outstanding of $297.7 million less a discount of $3.9 million. The Second Lien Term Loan Facility matures October 25, 2018. Approximately $7.3 million in fees were capitalized in connection with the Second Lien Term Loan Facility.

Long_Term_Debt_Senior_Secured_

Long Term Debt (Senior Secured Revolving Credit Facility) (Detail) (USD $)

Jan. 29, 2014

Dec. 31, 2013

Jan. 29, 2414

Sep. 30, 2014

Apr. 25, 2014

Dec. 31, 2013

Apr. 25, 2013

Oct. 31, 2014

Jan. 29, 2014

Mar. 31, 2013

Dec. 31, 2013

Apr. 25, 2013

Jan. 29, 2014

Apr. 25, 2013

Dec. 31, 2013

Jan. 29, 2014

Apr. 25, 2013

Dec. 31, 2013

Jan. 29, 2014

Apr. 25, 2013

Dec. 31, 2013

Jan. 29, 2014

Apr. 25, 2013

Dec. 31, 2013

Jan. 29, 2014

Apr. 25, 2013

Dec. 31, 2013

Jan. 29, 2014

Apr. 25, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2014

Dec. 31, 2013

Apr. 25, 2013

Letter of Credit

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Subsequent Event

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Minimum

Minimum

Minimum

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

LIBOR

Federal Funds Rate

Federal Funds Rate

Federal Funds Rate

Eurodollar

Eurodollar

Eurodollar

Base Rate

Base Rate

Base Rate

Base Rate

Base Rate

Base Rate

At the end of each fiscal quarter thereafter

Letter of Credit

Letter of Credit

Letter of Credit

Subsequent Event

Subsequent Event

Wells Fargo Bank N. A.

Minimum

Minimum

Minimum

Maximum

Maximum

Maximum

Minimum

Minimum

Minimum

Maximum

Maximum

Maximum

Minimum

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Line of Credit Facility [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum credit amount

'

$1,500,000,000

$1,500,000,000

'

'

$500,000,000

$500,000,000

'

$1,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$100,000,000

$10,000,000

Amount of borrowings repaid

'

'

115,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base after amendment

'

350,000,000

350,000,000

385,000,000

'

200,000,000

'

550,000,000

350,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

Borrowings outstanding

55,900,000

'

'

'

'

115,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

66,800,000

22,500,000

'

Availability under revolving credit facility

'

'

'

$318,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate spread (percentage)

'

'

'

'

'

'

'

'

'

'

'

'

1.50%

1.75%

1.50%

2.50%

2.75%

2.50%

0.50%

0.50%

0.50%

1.00%

1.00%

1.00%

0.50%

0.75%

0.50%

1.50%

1.75%

1.50%

'

'

'

'

Percentage lien on proved oil and gas reserves

'

'

'

'

'

'

'

'

'

'

'

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current ratio

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum interest coverage ratio

'

'

'

'

2.5

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted average interest rate

'

2.39%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current ratio

'

'

'

'

'

'

'

'

'

75.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

Interest coverage ratio

'

'

'

'

'

'

'

'

'

'

250.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Discount factor used in calculating present value of oil and gas reserves

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Asset coverage ratio

'

'

'

'

'

'

'

'

'

'

150.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maturity period

'

'5 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period prior to maturity of second lien term loan facility

'

'180 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long_Term_Debt_Debentures_Deta

Long Term Debt (Debentures) (Detail) (USD $)

3 Months Ended

9 Months Ended

12 Months Ended

12 Months Ended

1 Months Ended

8 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

8 Months Ended

9 Months Ended

14 Months Ended

0 Months Ended

1 Months Ended

Sep. 30, 2014

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Aug. 15, 2011

Dec. 31, 2013

Dec. 31, 2011

Jun. 30, 2011

Aug. 20, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 30, 2014

Mar. 27, 2014

Mar. 31, 2014

Sep. 30, 2014

Sep. 30, 2014

Mar. 30, 2014

Mar. 27, 2014

Mar. 31, 2014

Class

Warrants

Warrants

Senior Subordinated Convertible Debentures Maturing in 2014

Prior to May 1, 2017

Prior to May 1, 2017

Prior to May 1, 2017

At any time after July 31, 2013

At any time after July 31, 2013

At any time after July 31, 2013

At any time after July 31, 2013

At any time after July 31, 2013

At any time after July 31, 2013

At any time after July 31, 2013

At any time after July 31, 2013

Debentures

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Senior Subordinated Convertible Debentures Maturing in 2014

Debentures

Debentures

Debentures

Debentures

Debentures

Debentures

Debentures

Debentures

Debentures

Debentures

Other Accrued Liabilities

Common Stock ($0.01 par)

Common Stock ($0.01 par)

Debentures

Short-term Debt [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate principal amounts of debt offered

'

'

'

'

'

'

'

'

'

$60,000,000

'

'

'

'

'

'

'

'

'

'

'

Interest rate

'

'

'

'

'

'

'

'

'

12.00%

'

'

'

'

'

'

'

'

'

'

'

Number of days of prior written notice

'

'

'

'

'

'

'

'

'

'

'

'30 days

'

'

'

'

'

'30 days

'

'

'

Percentage of principal amount redeemed

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

100.00%

'

100.00%

'

'

'

Call premium redemption percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

50.00%

'

'

'

Amount of converted debentures

'

'

'

255,000

11,332,000

0

'

'

'

'

'

'

'

5,000,000

6,600,000

'

'

'

'

'

'

Shares converted into common stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

433,073

570,945

'

Remaining principal balance

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000

Loss on extinguishment of debt

'

-3,934,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

-100,000

'

'

'

'

Remaining principal balance not converted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,000

200,000

'

'

'

Number of different classes of warrants issued

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of warrants that are exercisable

90

90

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Warrants weighted average exercise price per share

11.57

11.57

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares in which warrants are convertible

'

77,363

'

1,671,800

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares issued due to the exercise of warrants

126,240

686,006

'

1,728

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Put premium redemption percentage

'

'

'

'

'

'

'

'

'

'

20.00%

'

'

'

'

'

'

'

'

'

'

Amount of debt repurchased

'

'

'

'

'

'

'

'

'

'

53,100,000

'

'

'

'

'

'

'

'

'

'

Put premium paid

'

'

'

'

'

'

'

'

'

'

10,600,000

'

10,600,000

'

'

'

'

'

'

'

'

Additional cost if convertible debentures are redeemed

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred financing cost

'

'

'

'

'

'

'

'

3,300,000

'

'

'

'

'

'

'

'

'

'

'

'

Shares subject for issuance if warrants are exercised

'

'

'

'

'

'

'

$1,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Long_Term_Debt_Schedule_of_Exp

Long Term Debt (Schedule of Expected Maturities of Notes Payable) (Detail) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012
Debt Disclosure [Abstract]	'	'	'	'	'	'
Remainder of Year Ending December 31, 2014	$326	'	$326	'	'	'
Year Ending December 31, 2015	680	'	680	'	3,058	'
Year Ending December 31, 2016	0	'	0	'	2,277	'
Year Ending December 31, 2017	0	'	0	'	2,173	'
Year Ending December 31, 2018 and Beyond	900,000	'	900,000	'	399,314	'
Total	901,006	'	901,006	'	426,942	149,320
Interest paid in cash	30	6,500	8,900	17,200	27,700	10,200
Year Ending December 31, 2014	'	'	'	'	$20,120	'

Derivative_Instruments_Summary

Derivative Instruments (Summary of Derivative Instruments) (Detail) (Not Designated as Hedging Instrument, Natural Gas)	Sep. 30, 2014	Dec. 31, 2013
	MMBTU_day	MMBTU_day
Swap Commodity Contract 2014 | Swap Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	173,000	87,219
Weighted Average Price	4.15	4.112
Swap Commodity Contract 2015 | Swap Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	166,000	58,781
Weighted Average Price	4.09	4.153
Swap Commodity Contract 2016 | Swap Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	214,000	68,326
Weighted Average Price	4.14	4.233
Swap Commodity Contract 2017 | Swap Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	60,000	30,000
Weighted Average Price	4.24	4.343
Collar Commodity Contract 2014 | Collar Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	10,000	10,000
Floor	3	3
Ceiling	5.8	5.8
Collar Commodity Contract 2014 | Basis Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	'	15,000
Swap ($/MMBtu)	'	-0.205
Collar Commodity Contract 2015 | Collar Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	139,000	45,000
Floor	3.96	3.91
Ceiling	4.65	4.68
Basis Commodity Contract 2014 | Basis Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	60,000	'
Swap ($/MMBtu)	-0.46	'
Basis Commodity Contract 2015 | Basis Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	62,000	10,000
Swap ($/MMBtu)	-0.57	-0.41
Basis Commodity Contract 2016 | Basis Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	38,000	'
Swap ($/MMBtu)	-0.63	'
Put Commodity Contract 2014 | Put Contract Expiration	'	'
Derivative [Line Items]	'	'
MMBtu/day	50,000	'
Swap ($/MMBtu)	0.45	'

Derivative_Instruments_Schedul

Derivative Instruments (Schedule of Offsetting Assets and Liabilities) (Detail) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'
Gross Amounts of Recognized Assets, Derivative Assets	$39,672	$13,000	$416
Gross Amounts Offset on Balance Sheet, Derivative Assets	-22,571	-4,700	-370
Net Amounts of Assets (Liabilities) on Balance Sheet, Derivative Assets	17,101	8,300	46
Gross Amounts Offset on Balance Sheet, Derivative liabilities	22,571	256	0
Derivative Liability, Fair Value, Gross Liability	-22,571	-4,600	-2,306
Net Amounts of Assets (Liabilities) on Balance Sheet, Derivative liabilities	$0	($4,344)	($2,306)

Derivative_Instruments_Schedul1

Derivative Instruments (Schedule of Unrealized and Realized Gains or Losses on Derivatives) (Detail) (Not Designated as Hedging Instrument, USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Not Designated as Hedging Instrument	'	'	'	'
Derivative Instruments, Gain (Loss) [Line Items]	'	'	'	'
Realized gain (loss)	$171	$788	($20,782)	($1,053)
Unrealized gain	$36,764	$7,262	$26,139	$17,751

Fair_Value_of_Financial_Instru2

Fair Value of Financial Instruments (Schedule of Assets and Liabilities Measured at Fair Value) (Detail) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Assets:	'	'	'
Derivative instruments, at fair value	$17,101	$8,300	$46
Liabilities:	'	'	'
Derivative instruments, at fair value	0	4,344	2,306
Fair Value, Measurements, Recurring	'	'	'
Assets:	'	'	'
Derivative instruments, at fair value	17,101	4,921	'
Total assets	17,101	4,921	'
Liabilities:	'	'	'
Restricted units, at fair value	'	36,306	5,667
Derivative instruments, at fair value	0	965	2,260
Total liabilities	0	37,271	7,927
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:	'	'	'
Restricted units, at fair value	'	0	0
Derivative instruments, at fair value	0	0	0
Total liabilities	0	0	0
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2)	'	'	'
Assets:	'	'	'
Derivative instruments, at fair value	17,101	4,921	'
Total assets	17,101	4,921	'
Liabilities:	'	'	'
Restricted units, at fair value	'	0	0
Derivative instruments, at fair value	0	965	2,260
Total liabilities	0	965	2,260
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3)	'	'	'
Assets:	'	'	'
Derivative instruments, at fair value	0	0	'
Total assets	0	0	'
Liabilities:	'	'	'
Restricted units, at fair value	'	36,306	5,667
Derivative instruments, at fair value	0	0	0
Total liabilities	0	36,306	5,667
Carrying Value | Fair Value, Measurements, Recurring	'	'	'
Assets:	'	'	'
Derivative instruments, at fair value	17,101	4,921	'
Total assets	17,101	4,921	'
Liabilities:	'	'	'
Restricted units, at fair value	'	36,306	'
Derivative instruments, at fair value	0	965	'
Total liabilities	$0	$37,271	'

Fair_Value_of_Financial_Instru3

Fair Value of Financial Instruments (Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation) (Detail) (Restricted Units, USD $)	9 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012
Restricted Units	'	'	'	'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'	'
Balance as of the beginning of the period	$36,306	$5,667	$5,667	$6,800
Included in earnings	0	0	32,906	115
Transfers in and/or out of Level 3	0	0	0	0
Repurchase of restricted units	0	-2,267	-2,267	-1,133
Converted to shares of common stock	-36,306	0	0	-115
Balance as of the end of the period	$0	$3,400	$36,306	$5,667

Fair_Value_of_Financial_Instru4

Fair Value of Financial Instruments (Schedule of the Estimated Fair Value and Carrying Amount of Long-term Debt) (Detail) (Significant Unobservable Inputs (Level 3), USD $)	Sep. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Carrying Value	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Other	$1,006	$3,203	'
Total fair value	901,006	426,942	'
Carrying Value | Senior Secured Revolving Credit Facility	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Credit Facility	0	115,000	'
Carrying Value | Senior Notes Due 2022	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Notes	900,000	0	'
Carrying Value | Second Lien Term Loan Facility	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Second Lien Term Loan Facility	0	293,821	'
Carrying Value | Senior Subordinated Convertible Debentures Maturing in 2014	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Debentures	0	6,890	'
Carrying Value | NPI Note	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Notes	0	8,028	'
Fair Value	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Other	1,006	3,203	4,038
Debentures	'	12,671	70,220
Total fair value	867,870	454,186	159,540
Second Lien Term Loan Facility	'	315,284	0
Notes	'	8,028	15,282
Fair Value | Wells Fargo Energy Capital Credit Facility	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Credit Facility	'	0	70,000
Fair Value | Senior Secured Revolving Credit Facility	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Credit Facility	0	115,000	0
Fair Value | Senior Notes Due 2022	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Notes	866,864	0	'
Fair Value | Second Lien Term Loan Facility	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Second Lien Term Loan Facility	0	315,284	'
Fair Value | Senior Subordinated Convertible Debentures Maturing in 2014	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Debentures	0	12,671	'
Fair Value | NPI Note	'	'	'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'	'	'
Notes	$0	$8,028	'

Acquisitions_Narrative_Detail

Acquisitions (Narrative) (Detail) (USD $)

1 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

Jan. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Jan. 29, 2014

Sep. 30, 2014

Jan. 29, 2014

Dec. 31, 2013

Jan. 27, 2014

Dec. 31, 2013

Apr. 17, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Sep. 30, 2014

Sep. 30, 2014

Jul. 07, 2014

Jul. 07, 2014

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Greene County Acquisition

Greene County Acquisition

Significant Unobservable Inputs (Level 3)

Significant Unobservable Inputs (Level 3)

MMcf_day

Washington County, Pennsylvania

Washington and Greene Counties, Pennsylvania

Minimum

Maximum

Customer Lists

Customer Lists

Greene County, Pennsylvania

Greene County, Pennsylvania

acre

mi

in

Washington County, Pennsylvania

Washington County, Pennsylvania

Well

acre

mi

in

in

acre

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity investment ownership percentage

'

'

'

'

'

'

'

'

'

'

50.00%

'

50.00%

'

'

'

'

'

'

'

'

'

'

Fair value of pre-existing equity investment

'

'

'

'

'

'

'

$250,632,000

'

'

'

$250,600,000

'

'

'

'

'

'

'

'

'

'

'

Gain on purchase of Marcellus joint venture

'

0

0

203,579,000

0

'

'

203,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of natural gas properties

'

'

'

'

'

'

'

'

'

343,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill

'

'

'

'

'

'

'

'

'

338,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total consideration amount

'

'

'

'

'

'

10,000,000

322,000,000

'

'

'

'

'

111,400,000

'

'

'

'

'

'

'

329,500,000

'

Amount of purchase price allocated to intangible assets related to customer lists

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

48,900,000

48,900,000

'

'

Amortization period for customer contracts

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 years

'

'

Amortization of intangibles

'

408,000

0

748,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000

700,000

'

'

Remainder of 2014

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

400,000

400,000

'

'

2015

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

1,600,000

'

'

2016

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

1,600,000

'

'

2017

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

1,600,000

'

'

2018

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,600,000

1,600,000

'

'

Length of gathering system (miles)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28

'

'

'

'

'

'

'

Width of gathering system (inches)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6

16

'

'

'

'

Length of pipelines to be constructed (miles)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

18

'

'

'

'

'

'

Width of gathering system to be constructed (inches)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30

'

'

'

'

'

'

Number of acres dedicated

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000

'

'

'

'

'

'

'

'

Aggregate capacity of acquired systems (Bcf)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000,000

'

'

'

'

'

'

'

'

Net acres

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21,913

Number of developed wells

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12

'

Purchase price allocated to proved natural gas properties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

151,300,000

Purchase price allocated to unproved natural gas properties

'

'

'

'

'

'

'

'

'

55,000,000

'

'

'

'

'

'

'

'

'

'

'

'

178,200,000

Payment to acquire business

3,300,000

'

'

'

'

1,000,000

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Funding for development of the unproved properties

'

'

'

'

'

'

$3,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_Schedule_of_Purch

Acquisitions (Schedule of Purchase Price Allocations) (Detail) (USD $)	1 Months Ended	12 Months Ended		0 Months Ended
In Thousands, unless otherwise specified	Jan. 31, 2013	Dec. 31, 2013	Sep. 30, 2014	Jan. 29, 2014	Jan. 29, 2014
				Marcellus Joint Venture	Marcellus Joint Venture
Assets	'	'	'	'	'
Financial assets	'	'	'	'	$34,242
Proved natural gas properties, net	'	'	'	'	288,000
Unproved natural gas properties	'	'	'	'	55,000
Goodwill	'	0	338,036	'	338,036
Liabilities	'	'	'	'	'
Financial liabilities	'	'	'	'	-49,313
Long-term debt	'	'	'	'	-75,400
Deferred tax liability	'	'	'	'	-17,933
Total identifiable net assets	'	'	'	'	572,632
Cash paid for acquisitions	3,300	1,000	'	100,000	'
Fair value of equity issued	'	'	'	222,000	'
Fair value of pre-existing equity investment	'	'	'	250,632	'
Total consideration	'	'	'	$572,632	'

Acquisitions_Schedule_of_Profo

Acquisitions (Schedule of Proforma Information) (Detail) (Marcellus Joint Venture, USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Marcellus Joint Venture	'	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'	'
Revenue	$30,689	'	$103,290	'	'
Net income	12,008	'	57,419	'	'
Pro forma net revenues	79,127	42,959	273,480	123,676	179,281
Pro forma net loss	($6,862)	($29,088)	($83,794)	($1,540)	($30,509)
Pro forma loss per share (basic)	($0.05)	($0.33)	($0.65)	($0.02)	'
Pro forma loss per share (diluted)	($0.05)	($0.33)	($0.65)	($0.02)	'

Commitments_and_Contingencies_

Commitments and Contingencies (Detail) (USD $)	12 Months Ended					0 Months Ended		9 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Sep. 30, 2014	Dec. 31, 2013	Oct. 14, 2013	Oct. 14, 2013	Sep. 30, 2014	Sep. 30, 2014	Oct. 14, 2013	Oct. 14, 2013
				Drilling_Rig	Non- Cancellable Operating Lease	Utica Development Agreements	Utica Development Agreements	Utica Development Agreements	Utica Development Agreements	Goshen and Smith Townships in Belmont County, Ohio	Wayne and Washington Townships in Belmont County, Ohio
							acre	Minimum	Maximum	Utica Development Agreements	Utica Development Agreements
								Well	Well
Other Commitments [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Net acres	'	'	'	'	'	'	50,000	'	'	'	'
Participating interest in acreage (percentage)	'	'	'	'	'	'	'	'	'	68.80%	42.63%
Number of horizontal wells to be drilled in 2014	'	'	'	'	'	'	'	8	40	'	'
Number of horizontal wells to be drilled in 2015	'	'	'	'	'	'	'	8	50	'	'
Utica Development Agreements, terms	'	'	'	'	'	'10 years	'	'	'	'	'
Period of notice prior to termination	'	'	'	'	'	'90 days	'	'	'	'	'
Number of drilling rigs under contract	'	'	'	7	'	'	'	'	'	'	'
Number of horizontal drilling rigs under contract	'	'	'	4	'	'	'	'	'	'	'
Number of tophole rigs under contract	'	'	'	3	'	'	'	'	'	'	'
Total future payments for horizontal drilling rigs under contract	$21,400,000	'	'	$85,900,000	'	'	'	'	'	'	'
Future payments for horizontal drilling rigs under contract, remainder of 2014	'	'	'	12,200,000	'	'	'	'	'	'	'
Future payments for horizontal drilling rigs under contract, 2015	9,700,000	'	'	46,000,000	'	'	'	'	'	'	'
Future payments for horizontal drilling rigs under contract, 2016	'	'	'	20,800,000	'	'	'	'	'	'	'
Future payments for horizontal drilling rigs under contract, 2017	'	'	'	6,900,000	'	'	'	'	'	'	'
Future payments for horizontal drilling rigs under contract, 2014	11,700,000	'	'	'	'	'	'	'	'	'	'
Property purchased under capital leases	2,000,000	'	'	'	'	'	'	'	'	'	'
Property purchased under capital leases, accumulated amortization	200,000	8,000	'	'	'	'	'	'	'	'	'
Property purchased under capital leases, amortization expense	200,000	8,000	0	'	'	'	'	'	'	'	'
Future lease payments under capital leases, 2013	1,600,000	'	'	'	'	'	'	'	'	'	'
Future lease payments under capital leases, 2014	400,000	'	'	'	'	'	'	'	'	'	'
Future lease payments under capital leases, 2015	300,000	'	'	'	'	'	'	'	'	'	'
Future lease payments under capital leases, 2016	300,000	'	'	'	'	'	'	'	'	'	'
Future lease payments under capital leases, 2017	500,000	'	'	'	'	'	'	'	'	'	'
Future lease payments under capital leases, 2018	100,000	'	'	'	'	'	'	'	'	'	'
Rental expense under operating leases	200,000	200,000	100,000	'	'	'	'	'	'	'	'
Future lease payments under non-cancelable operating leases, 2013	18,606,000	'	'	'	4,500,000	'	'	'	'	'	'
Future lease payments under operating leases, 2014	1,398,000	'	'	'	600,000	'	'	'	'	'	'
Future lease payments under operating leases, 2015	153,000	'	'	'	1,000,000	'	'	'	'	'	'
Future lease payments under operating leases, 2016	124,000	'	'	'	900,000	'	'	'	'	'	'
Future lease payments under operating leases, 2017	'	'	'	'	800,000	'	'	'	'	'	'
Future lease payments under operating leases, 2018	'	'	'	'	800,000	'	'	'	'	'	'
Future lease payments operating leases, thereafter	'	'	'	'	$400,000	'	'	'	'	'	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Commitment for Gathering and Firm Transportation) (Detail) (Gathering and Firm Transportation, USD $)	Sep. 30, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Gathering and Firm Transportation	'	'
Other Commitments [Line Items]	'	'
Future payments under contracts	$2,887.20	$637.20
Commitment for gathering and firm transportation, remainder of 2014	15.7	'
Commitment for gathering and firm transportation, 2015	94.3	52.1
Commitment for gathering and firm transportation, 2016	113.6	65.6
Commitment for gathering and firm transportation, 2017	113.4	65.4
Commitment for gathering and firm transportation, 2018	112	64
Commitment for gathering and firm transportation, 2019	141.8	'
Commitment for gathering and firm transportation, Thereafter	2,296.40	'
Commitment for gathering and firm transportation, 2014	'	28.3
Commitment for gathering and firm transportation, Thereafter	'	$361.80

Stockholders_Equity_Detail

Stockholders' Equity (Detail) (USD $)

3 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

1 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Aug. 31, 2014

Aug. 31, 2014

Aug. 31, 2014

Aug. 30, 2012

Jan. 25, 2012

Apr. 30, 2013

Dec. 31, 2012

Dec. 31, 2013

Jan. 25, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Class A units

Class B units

IPO

IPO

NGP Holdings

Rice Holdings

Mr. Daniel J. Rice III

Rice Partners

Incentive Unitholders

Rice Drilling B

Common Stock ($0.01 par)

Common Stock ($0.01 par)

Common Stock ($0.01 par)

Natural Gas Partners

Natural Gas Partners

Natural Gas Partners

Natural Gas Partners

Natural Gas Partners

Natural Gas Partners

Rice Energy Appalachia LLC (REA)

Rice Energy Appalachia LLC (REA)

Rice Energy Appalachia LLC (REA)

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

Class B units

Class B units

Common Stock ($0.01 par)

Rice Energy Inc

Affiliates of Natural Gas Partners and Alpha Natural Resources

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock (shares)

'

'

'

'

'

'

'

'

'

'

'

43,452,550

20,300,923

2,356,844

20,000,000

160,831

1,728,852

'

'

'

'

'

'

'

'

'

'

'

'

Compensation expense

$26,418,000

$0

$101,695,000

$0

'

'

'

'

'

$3,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Public offering price per share

'

'

'

'

'

'

'

'

'

'

$21

'

'

'

'

'

'

$27.30

'

'

'

'

'

'

'

'

'

'

'

Shares sold in Equity Offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,729,650

7,500,000

6,229,650

'

'

'

'

'

'

'

'

13,252,145

Underwriting discounts and commissions

'

'

784,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

7,700,000

'

'

'

'

'

'

'

'

'

'

'

Proceeds from issuance of common stock sold in August 2014 Equity Offering, net of underwriting fees

'

'

197,072,000

0

195,977,000

96,782,000

7,900,000

'

'

'

'

'

'

'

'

'

'

196,300,000

'

'

'

'

'

'

'

'

'

'

'

Equity commitment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

300,000,000

100,000,000

'

'

'

Percentage of net proceeds from equity commitment invested

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

Equity commitment funded

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25,000,000

75,000,000

200,000,000

'

'

'

'

'

'

Preferred unit amount

'

'

'

'

'Prior to the reorganization in connection with the Rice Energy IPO, the terms of the governance documents of the Company provided that in the event of any liquidation, dissolution or winding up of the Company, distributions would first be made to members holding senior preferred units until such members have received cumulative distributions in an amount equal to the preferred return as defined in the REA agreement, second to the members holding preferred units in the amount of $49.9 million, then, until the Company had achieved breakeven operations, as defined, to the members holding preferred and Class A common units in proportion to their ownership interests and thereafter to the members in proportion to their ownership units. Following the restructuring, distributions in such event would be made to the sole member.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchased stock unit per unit

'

'

'

'

'

'

'

$1,700

$1,700

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Option to repurchase units exercised

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000

'

Option to repurchase units exercised, value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,400,000

'

Payments made on behalf of REA

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,300,000

$1,100,000

'

Incentive_Units_Narrative_Deta

Incentive Units Narrative (Detail) (USD $)

3 Months Ended

9 Months Ended

3 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Mar. 31, 2014

Jan. 29, 2014

Sep. 30, 2014

Sep. 30, 2014

Mar. 31, 2014

Sep. 30, 2014

Dec. 31, 2013

Apr. 30, 2013

Dec. 31, 2012

Apr. 30, 2013

Dec. 31, 2012

Apr. 30, 2013

Dec. 31, 2012

Jun. 30, 2013

Apr. 30, 2013

Jun. 30, 2013

Apr. 30, 2013

Jun. 30, 2013

Apr. 30, 2013

Jun. 30, 2013

Apr. 30, 2013

Sep. 30, 2014

Sep. 30, 2014

Jan. 29, 2014

Mar. 31, 2014

Sep. 30, 2014

Incentive Units

Incentive Units

IPO

IPO

IPO

IPO

IPO

IPO

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

NGP Holdings

Time Vesting Feature

Future Payment Condition Vesting Feature

Incentive Unitholders

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

Incentive Units

IPO

IPO

IPO

Tranche

Tranche

Incentive Unitholders

Rice Holdings

Tier one Legacy units [Member]

Tier one Legacy units [Member]

Tier Two Legacy units [Member]

Tier Two Legacy units [Member]

Tier Three Legacy units [Member]

Tier Three Legacy units [Member]

New Tier One Units [Member]

New Tier One Units [Member]

New Tier Two Units [Member]

New Tier Two Units [Member]

New Tier Three Units [Member]

New Tier Three Units [Member]

New Tier Four Units [Member]

New Tier Four Units [Member]

Incentive Units

Incentive Units

Transactions

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock (shares)

'

'

'

'

'

'

'

160,831

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

43,452,550

'

'

Payment for pre-determined payout criteria

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$12,000,000

$19,800,000

'

$4,400,000

'

Number of transactions

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Incentive unit expense

26,418,000

0

101,695,000

0

'

'

3,400,000

'

26,400,000

101,700,000

7,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized compensation cost

'

'

'

'

'

'

'

'

'

'

'

79,800,000

142,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

77,300,000

Number of tranches with time vest feature

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of tranches without time vest feature

'

'

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Units issued

'

'

'

'

'

'

'

'

'

'

'

'

'

$900,000

$100,000

$987,000

$13,000

$983,000

$17,000

$717,546

$100,000

$577,546

$100,000

$577,546

$100,000

$577,546

$100,000

'

'

'

'

'

Incentive_Units_Roll_Forward_o

Incentive Units Roll Forward of Incentive Units (Detail) (Incentive Units, Time Vesting Feature)	8 Months Ended
	Sep. 30, 2014
Incentive Units | Time Vesting Feature	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]	'
Vested Units Balance, January 29, 2014	853,630
Vested During Period	565,881
Forfeited During Period	-214,869
Granted During Period	214,869
Cancelled During Period	0
Vested Units Balance, September 30, 2014	1,419,511

Incentive_Units_Fair_Value_of_

Incentive Units Fair Value of Incentive Units (Detail) (Incentive Units)	0 Months Ended
	Jan. 29, 2014	Apr. 14, 2014	Apr. 16, 2014	Sep. 30, 2014
	Rice Holdings	Rice Holdings	Rice Holdings	NGP Holdings
	1/29/14	4/14/14	4/16/14	6/30/14
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Dividend Yield	0.00%	0.00%	0.00%	0.00%
Expected Volatility	47.00%	45.19%	44.32%	40.20%
Risk-Free Rate	1.11%	1.13%	1.18%	0.58%
Expected Life (Years)	'4 years	'3 years 9 months 18 days	'3 years 9 months 18 days	'2 years

Stock_Compensation_Detail

Stock Compensation (Detail) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Compensation expense	$2,058,000	$0	$3,274,000	$0
Restricted Stock	'	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Compensation expense	2,100,000	'	3,300,000	'
Unrecorded compensation expense	$17,500,000	'	$17,500,000	'

Earnings_Per_Share_Detail

Earnings Per Share (Detail) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Share [Abstract]	'	'	'	'	'	'	'
Net income (loss)	($6,862)	($33,652)	$114,675	($20,841)	($35,776)	($19,344)	($936)
Weighted-average shares (denominator):	'	'	'	'	'	'	'
Weighted-average number of shares of common stock - basic	132,269,081	88,000,000	125,411,524	77,894,855	80,441,905	57,966,572	39,958,066
Weighted-average number of shares of common stock - diluted	132,269,081	88,000,000	125,678,095	77,894,855	80,441,905	57,966,572	39,958,066
Earnings (loss) per share:	'	'	'	'	'	'	'
Earnings (loss) per share-basic	($0.05)	($0.38)	$0.91	($0.27)	($0.44)	($0.33)	($0.02)
Earnings (loss) per share-diluted	($0.05)	($0.38)	$0.91	($0.27)	($0.44)	($0.33)	($0.02)
Number of shares not considered dilutive	76,800	1,671,800	'	1,671,800	1,671,800	1,671,800	648,404

Income_Taxes_Narrative_Detail

Income Taxes (Narrative) (Detail) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Jan. 29, 2014
									IPO
									Deferred Tax Liability Recorded In Equity
Income Taxes [Line Items]	'	'	'	'	'	'	'	'	'
Federal income tax statutory rate	'	'	35.00%	'	'	'	'	'	'
Deferred tax liability recorded in equity	$1,412,558	$315,340	$1,412,558	$315,340	$298,647	$138,191	$46,821	$36,563	$162,300
Deferred income tax expense	$14,005	$0	$18,787	$0	'	'	'	'	'
Effective tax rate (percentage)	196.00%	'	14.00%	'	'	'	'	'	'

Income_Taxes_Schedule_of_Compo

Income Taxes (Schedule of Components of Income Tax Provision) (Detail) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Current tax expense:	'	'	'	'
Federal	$0	'	$0	'
State	0	'	0	'
Total	0	'	0	'
Deferred tax expense:	'	'	'	'
Federal	11,813	'	15,847	'
State	2,192	'	2,940	'
Total	14,005	'	18,787	'
Total income tax expense	$14,005	$0	$18,787	$0

Summary_of_Significant_Account2

Summary of Significant Accounting Policies and Related Matters - Additional Information (Detail) (USD $)

1 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

Jan. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Dec. 31, 2012

Jan. 29, 2014

Jan. 29, 2014

Dec. 31, 2013

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Dec. 31, 2013

Dec. 31, 2013

Aug. 30, 2012

Jan. 25, 2012

Apr. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Jan. 25, 2012

Minimum

Maximum

Net Income

Exploration Expense

Lease Operating Expense

Other Expense

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Rice Partners

Natural Gas Partners

Natural Gas Partners

Natural Gas Partners

Natural Gas Partners

Natural Gas Partners

Natural Gas Partners

IPO

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Summary Of Significant Accounting Policies [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

100.00%

'

'

50.00%

'

'

'

'

'

'

'

Ownership interest of total units outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

90.00%

'

'

'

'

'

'

Equity commitment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$300,000,000

$100,000,000

$100,000,000

Equity commitment funded

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25,000,000

75,000,000

200,000,000

'

'

'

Percentage of voting interests acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

50.00%

'

'

'

'

'

'

'

'

Total consideration amount

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

'

322,000,000

'

'

'

322,000,000

'

'

'

'

'

'

'

'

'

Cash paid for acquisitions

3,300,000

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

100,000,000

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

Issuance of shares of common stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,523,810

'

'

'

9,523,810

'

'

'

'

'

'

'

'

'

Write-off of unsuccessful exploratory well costs

'

'

'

'

'

8,143,000

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Property and equipment, useful life

'

'

'

'

'

'

'

'

'3 years

'40 years

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accumulated depreciation

'

'

'

'

'

1,300,000

600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Depreciation expense

'

'

'

'

'

700,000

600,000

100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred financing costs, accumulated amortization

'

'

'

'

'

14,300,000

9,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred financing costs, amortization expense

'

707,000

958,000

1,728,000

4,760,000

5,230,000

7,220,000

2,675,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred financing costs, expected amortization in 2014

'

'

'

'

'

1,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred financing costs, expected amortization in 2015

'

'

'

'

'

1,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred financing costs, expected amortization in 2016

'

'

'

'

'

1,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred financing costs, expected amortization in 2017

'

'

'

'

'

1,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred financing costs, expected amortization in 2018

'

'

'

'

'

1,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cost of extending drilling right lease

'

'

'

'

'

1,600,000

3,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Effect of correction of expense related to prior periods

'

'

'

'

'

'

'

'

'

'

($1,700,000)

$1,100,000

$500,000

$100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts_Receivable_Detail

Accounts Receivable (Detail) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Student Loan Portfolio By Program [Line Items]	'	'	'
Total accounts receivable	$136,560	$31,765	$8,557
Natural Gas Sales	'	'	'
Student Loan Portfolio By Program [Line Items]	'	'	'
Total accounts receivable	'	16,534	5,564
Joint Interest	'	'	'
Student Loan Portfolio By Program [Line Items]	'	'	'
Total accounts receivable	'	6,391	1,810
Other	'	'	'
Student Loan Portfolio By Program [Line Items]	'	'	'
Total accounts receivable	'	$8,840	$1,183

Summary_of_Components_of_Inter

Summary of Components of Interest Cost (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other Income and Expenses [Abstract]	'	'	'
Interest capitalized	$8,034	$7,695	$5,405
Interest expensed	17,915	3,487	531
Total incurred	$25,949	$11,182	$5,936

Proved_and_Unproved_Capitalize

Proved and Unproved Capitalized Costs Related to Company's Gas-Producing Activities (Detail) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Capitalized costs:	'	'
Unproved properties	$457,836	$111,030
Total	781,048	291,838
Accumulated depreciation, depletion and amortization	52,689	20,820
Net capitalized costs	728,359	271,018
Equity Method Investee	'	'
Capitalized costs:	'	'
Net capitalized costs	91,166	57,110
Proved, producing properties	'	'
Capitalized costs:	'	'
Proved properties	244,771	119,374
Proved, nonproducing properties	'	'
Capitalized costs:	'	'
Proved properties	$78,441	$61,434

Sale_of_Interests_in_Gas_Prope1

Sale of Interests in Gas Properties (Detail) (USD $)	9 Months Ended		12 Months Ended			1 Months Ended	12 Months Ended		1 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Mar. 31, 2011
						Sale of Interests in Non-core Leasehold Assets	Sale of Interests in Non-core Leasehold Assets	Sale of Interests in Non-core Leasehold Assets	Sale of Interests in Non-core Leasehold Assets
						Guernsey County, Ohio	Guernsey County, Ohio	Lycoming County	Whipkey Field
						acre	acre		acre
Significant Acquisitions and Disposals [Line Items]	'	'	'	'	'	'	'	'	'
Undivided interest in leaseholds (percentage)	'	'	'	'	'	75.00%	75.00%	'	'
Net acres	'	'	'	'	'	2,136	2,136	'	1,000
Amount exchanged in sale of interests in gas properties	'	'	'	'	'	$22,000,000	$22,000,000	$7,000,000	'
Proceeds from sale of interest in gas properties	11,542,000	0	6,792,000	0	5,710,000	11,000,000	'	6,000,000	1,700,000
Proceeds from sale of carried working interest	'	'	'	'	'	11,000,000	'	'	'
Net acres closed	'	'	'	'	'	1,033	1,033	'	'
Gain (loss) from sale of interest in gas properties	'	'	($4,230,000)	$0	$1,478,000	'	$0	($4,200,000)	$1,500,000
Percentage of non-operated working interest in properties sold	'	'	'	'	'	'	'	100.00%	50.00%
Percentage of working interest in properties own	'	'	'	'	'	'	'	'	50.00%

Warrants_Valuation_Model_Assum

Warrants Valuation Model Assumptions (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013
Class of Warrant or Right [Line Items]	'
Dividend yield	0.00%
Expected volatility	72.10%
Risk-free rate	0.96%
Expected life	'5 years
Normal warrant	'
Class of Warrant or Right [Line Items]	'
Number of warrants issued	1,044
Exercise price	10,000
Grant date fair value, per unit	2,569
Weighted average contractual life	'5 years
Bonus warrant	'
Class of Warrant or Right [Line Items]	'
Number of warrants issued	192
Exercise price	6,250
Grant date fair value, per unit	3,184
Weighted average contractual life	'5 years

Long_Term_Debt_Wells_Fargo_Ene

Long Term Debt (Wells Fargo Energy Capital Credit Facility) (Detail) (Wells Fargo Energy Capital Credit Facility, USD $)	1 Months Ended
	Nov. 30, 2012
Wells Fargo Energy Capital Credit Facility	'
Short-term Debt [Line Items]	'
Debt modification cost	$200,000
Maximum credit amount	$200,000,000

Long_Term_Debt_NPI_Note_Detail

Long Term Debt (NPI Note) (Detail) (USD $)

9 Months Ended

12 Months Ended

1 Months Ended

0 Months Ended

3 Months Ended

1 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Nov. 30, 2012

Nov. 30, 2012

Nov. 30, 2012

Nov. 30, 2012

Apr. 25, 2014

Jun. 30, 2013

Dec. 31, 2013

Apr. 25, 2013

Jun. 30, 2014

NPI Note

NPI Note

NPI Note

Senior Secured Revolving Credit Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Second Lien Term Loan Facility

Scenario, Forecast

Wells Fargo [Member]

NPI Note

Second Lien Term Loan Facility

Wells Fargo [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase of long term debt

'

'

'

'

'

'

$26,500,000

$17,000,000

$9,500,000

'

'

'

'

'

Discount recorded on instrument

'

'

'

'

'

'

2,000,000

'

'

'

'

3,900,000

4,500,000

'

Effective interest rate

'

'

'

'

'

12.10%

'

'

'

'

'

'

'

'

Repayment of long term debt

$498,983,000

$159,726,000

$160,760,000

$10,152,000

$7,726,000

'

'

'

'

$301,800,000

$8,500,000

'

'

$8,500,000

Future_Minimum_Lease_Payments_

Future Minimum Lease Payments (Detail) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Leases [Abstract]	'
2014	$18,606
2015	1,398
2016	153
2017	124
2018 and thereafter	0
Total future minimum lease payments	$20,281

Lease_Obligations_Additional_I

Lease Obligations - Additional Information (Detail) (Scenario, Forecast, USD $)	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Scenario, Forecast	'	'	'
Schedule Of Operating Leases [Line Items]	'	'	'
Contingent lease obligation	$0.30	$1	$2

Reconciliation_of_Asset_Retire

Reconciliation of Asset Retirement Obligations (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Asset Retirement Obligation Disclosure [Abstract]	'	'	'
Beginning balance	$1,381	$835	$289
Liabilities incurred	583	382	493
Accretion expense	150	164	53
Ending balance	$2,114	$1,381	$835

Restricted_Unit_Agreements_Add

Restricted Unit Agreements - Additional Information (Detail) (Class B, Restricted Units)	12 Months Ended
	Dec. 31, 2012
Class B | Restricted Units	'
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'
Repurchased	2,000

Summary_of_Change_in_Vested_Re

Summary of Change in Vested Restricted Units (Detail) (Restricted Units)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012
				Class B
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'
Vested Units Balance, January 29, 2014	2,000	2,000	4,000	'
Repurchased	'	'	'	-2,000
Vested Units Balance, September 30, 2014	2,000	2,000	4,000	'

Derivative_Instruments_Summary1

Derivative Instruments (Summary of Derivative Instruments in Condensed Consolidated Balance Sheet) (Detail) (USD $)	Sep. 30, 2014	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'	'	'
Current derivative assets	'	$2,270	$46
Long-term derivative assets	'	6,030	0
Net Amounts of Assets (Liabilities) on Balance Sheet, Derivative Assets	17,101	8,300	46
Derivative liabilities	'	3,235	2,306
Long-term derivative liabilities	'	1,109	'
Net Amounts of Assets (Liabilities) on Balance Sheet, Derivative liabilities	0	4,344	2,306
Net current value of derivative liabilities	0	-965	-2,260
Net long-term value of derivative assets	$8,555	$4,921	$0

Derivative_Instruments_Narrati

Derivative Instruments (Narrative) (Detail) (Not Designated as Hedging Instrument, USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
					Gain or loss on derivatives	Gain or loss on derivatives	Gain or loss on derivatives
Derivative [Line Items]	'	'	'	'	'	'	'
Unrealized gain (loss)	$36,764	$7,262	$26,139	$17,751	$6,200	($2,300)	$0
Realized gain (losses) related to contract settlements	$171	$788	($20,782)	($1,053)	$700	$900	$600

Related_Party_Transactions_Add

Related Party Transactions - Additional Information (Detail) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Sep. 30, 2014
Related Party Transaction [Line Items]	'	'	'	'
Due to affiliate	$6,148,000	$2,482,000	'	$0
Payment to related party for consulting services	2,200,000	800,000	600,000	'
Receivable from affiliate	2,244,000	11,879,000	'	222,000
Rice Partners	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
General and administrative expenses incurred from transaction with related party	9,300,000	4,800,000	3,100,000	'
Due to affiliate	6,100,000	2,500,000	'	'
Marcellus Joint Venture	'	'	'	'
Related Party Transaction [Line Items]	'	'	'	'
General and administrative expenses incurred from transaction with related party	1,600,000	1,300,000	0	'
Receivable from affiliate	'	$6,000,000	'	'

Subsequent_Events_Detail

Subsequent Events (Detail) (USD $)

1 Months Ended

3 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

3 Months Ended

9 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

3 Months Ended

0 Months Ended

Jan. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Aug. 15, 2011

Sep. 30, 2014

Aug. 31, 2014

Dec. 31, 2013

Sep. 30, 2014

Sep. 30, 2014

Jan. 29, 2014

Sep. 30, 2014

Jan. 29, 2014

Dec. 31, 2013

Apr. 17, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Dec. 31, 2013

Jan. 29, 2414

Sep. 30, 2014

Dec. 31, 2013

Apr. 25, 2013

Sep. 30, 2014

Dec. 31, 2013

Apr. 25, 2013

Jan. 29, 2014

Mar. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Sep. 30, 2014

Sep. 30, 2014

Mar. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Mar. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Mar. 10, 2014

Jan. 29, 2014

Jan. 29, 2014

Mar. 10, 2014

Jan. 29, 2014

Jan. 29, 2014

Mar. 31, 2014

Jan. 29, 2014

Dec. 31, 2013

Jan. 29, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Feb. 12, 2014

Oct. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Mar. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Jan. 29, 2014

Mar. 31, 2014

Jan. 29, 2014

Jan. 29, 2014

Class

Common Stock ($0.01 par)

Common Stock ($0.01 par)

Common Stock ($0.01 par)

NGP Holdings

NGP Holdings

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Letter of Credit

Letter of Credit

Letter of Credit

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Incentive Units

Incentive Units

MMcf_day

Washington County, Pennsylvania

Washington and Greene Counties, Pennsylvania

Minimum

Maximum

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Mr. Daniel J. Rice III

Rice Partners

Incentive Unitholders

Rice Drilling B

Incentive Units

Incentive Units

Incentive Units

Selling Stockholder

Underwriters of Initial Public Offering

NGP Holdings

NGP Holdings

Rice Holdings

Rice Energy Inc

Debentures

Debentures

Debentures

Common Stock ($0.01 par)

Common Stock ($0.01 par)

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Marcellus Joint Venture

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Momentum Acquisition

Senior Secured Revolving Credit Facility

Senior Secured Revolving Credit Facility

Letter of Credit

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

IPO

acre

mi

in

Washington County, Pennsylvania

Washington County, Pennsylvania

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Incentive Unitholders

Incentive Units

Class

Debentures

Debentures

Adjustment

acre

Washington County, Pennsylvania

Washington and Greene Counties, Pennsylvania

Minimum

Maximum

Wells Fargo Bank N. A.

Wells Fargo Bank N. A.

Mr. Daniel J. Rice III

Rice Partners

Incentive Unitholders

Rice Drilling B

Selling Stockholder

Underwriters of Initial Public Offering

NGP Holdings

NGP Holdings

Rice Holdings

Rice Energy Inc

mi

in

in

MMcf_day

mi

mi

Washington County, Pennsylvania

Washington County, Pennsylvania

Incentive Units

in

in

in

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares sold with the completion of the IPO

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

14,000,000

6,000,000

'

'

'

30,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

'

14,000,000

6,000,000

'

'

'

30,000,000

Common Stock, par value per share

'

'

'

'

'

'

'

'

'

$0.01

'

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

'

'

'

'

'

'

'

'

Public offering price per share

'

'

'

'

'

'

'

'

'

'

$27.30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$21

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$21

'

'

'

'

'

'

'

'

'

'

Net proceeds of IPO

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$992,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$993,500,000

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds of IPO after deducting expenses and underwriting discounts and commissions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

399,000,000

'

'

'

'

593,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

399,000,000

'

'

'

'

593,600,000

Underwriting discounts and commissions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21,000,000

'

'

'

'

36,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

21,000,000

'

'

'

'

36,400,000

Cash paid for acquisitions

3,300,000

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity investment ownership percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

Percentage of voting interests acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total consideration amount

'

'

'

'

'

'

10,000,000

'

'

'

'

'

'

'

322,000,000

'

'

'

111,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

322,000,000

'

'

'

300,000,000

110,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Issuance of shares of common stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,523,810

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

9,523,810

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of pre-existing equity investment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

250,632,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

245,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain on purchase of Marcellus joint venture

'

0

0

203,579,000

0

'

'

'

'

'

'

'

'

'

203,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

195,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Fair value of natural gas properties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

343,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

320,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Goodwill

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

338,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

365,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deferred tax liability recorded

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

17,933,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

145,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock (shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,356,844

20,000,000

160,831

1,728,852

'

'

'

'

'

43,452,550

'

20,300,923

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,356,844

20,000,000

160,831

1,728,852

'

'

43,452,550

'

20,300,923

'

Compensation expense

'

26,418,000

0

101,695,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,400,000

'

'

'

'

'

26,400,000

101,700,000

7,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,400,000

'

'

'

'

'

'

'

'

'

'

'

Payment for pre-determined payout criteria

'

'

'

'

'

'

'

'

'

'

'

'

12,000,000

19,800,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,400,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4,400,000

'

'

Shares converted into common stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

433,073

1,671,800

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Amount of converted debentures

'

'

'

'

'

255,000

11,332,000

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

5,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of principal amount redeemed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Call premium redemption percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional cost to be paid if amounts not converted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of different classes of warrants issued

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares issued due to the exercise of warrants

'

126,240

'

686,006

'

1,728

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,728

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum credit amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,500,000,000

1,500,000,000

'

500,000,000

500,000,000

'

100,000,000

10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,500,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base after amendment

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

350,000,000

350,000,000

385,000,000

200,000,000

'

100,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

550,000,000

350,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Letters of credit outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$115,000,000

'

$66,800,000

$22,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$55,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Length of gathering system (miles)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Width of gathering system (inches)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6

16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6

16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Length of pipelines to be constructed (miles)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

18

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Width of gathering system to be constructed (inches)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of acres dedicated

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate capacity of acquired systems (Bcf)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Business_Acquisition_Pro_Forma

Business Acquisition, Pro Forma Information (Detail) (Marcellus Joint Venture, USD $)	3 Months Ended		9 Months Ended		12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Marcellus Joint Venture	'	'	'	'	'
Business Acquisition [Line Items]	'	'	'	'	'
Pro forma net revenues	$79,127	$42,959	$273,480	$123,676	$179,281
Pro forma net loss	($6,862)	($29,088)	($83,794)	($1,540)	($30,509)
Pro forma earnings per share	'	'	'	'	($0.24)

Quarterly_Financial_Informatio2

Quarterly Financial Information (Detail) (USD $)

3 Months Ended

9 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Quarterly Financial Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

$79,127

$27,866

$23,689

$23,840

$13,233

$11,673

$6,580

$4,155

$4,792

$261,545

$60,799

$88,604

$27,200

$13,972

Total operating expenses

91,452

27,755

52,274

25,833

10,705

9,640

8,123

11,984

6,353

283,248

88,812

116,567

36,100

12,807

Operating income (loss)

-12,325

111

-28,585

-1,993

2,528

2,033

-1,543

-7,829

-1,561

-21,703

-28,013

-27,963

-8,900

1,165

Net income (loss)

7,143

-14,935

-33,652

19,586

-6,775

2,397

-6,523

-12,884

-2,334

133,462

-20,841

'

'

'

Scenario, Previously Reported

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Quarterly Financial Information [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total operating revenues

'

'

23,665

'

'

'

'

'

'

'

'

'

'

'

Operating income (loss)

'

'

($28,609)

'

'

'

'

'

'

'

'

'

'

'

Costs_Incurred_for_Property_Ac

Costs Incurred for Property Acquisitions, Exploration and Development (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'	'
Unproved leaseholds	$305,000	$47,396	$16,877
Development costs	184,217	89,307	72,776
Exploration costs	9,951	3,275	660
Total costs incurred	499,168	139,978	90,313
Marcellus Joint Venture	'	'	'
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Line Items]	'	'	'
Unproved leaseholds	'	'	519
Development costs	46,571	46,725	21,700
Total costs incurred	$46,571	$46,725	$22,219

Results_of_Operations_Related_

Results of Operations Related to Natural Gas Production (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'	'
Revenues	$87,847	$26,743	$13,972
Production costs	19,712	8,824	2,157
Exploration costs	9,951	3,275	660
Depreciation, depletion and accretion	29,808	13,329	5,920
Impairment of oil and gas properties	'	2,253	109
General and administrative expenses	5,108	3,050	2,212
Results of operations from producing activities	23,268	-3,988	2,914
Marcellus Joint Venture	'	'	'
Results of Operations for Oil and Gas Producing Activities, by Geographic Area [Line Items]	'	'	'
Revenues	45,339	13,142	2,872
Production costs	12,557	5,436	379
Depreciation, depletion and accretion	12,500	4,702	1,092
Impairment of oil and gas properties	'	'	1,296
General and administrative expenses	1,557	986	'
Results of operations from producing activities	$18,725	$2,018	$105

Reserve_Quantity_Information_D

Reserve Quantity Information (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MMcf	MMcf	MMcf
Supplemental Oil And Gas Reserve Information [Line Items]	'	'	'
Beginning of year	304,272	232,996	12,230
Extensions and discoveries	100,626	176,956	223,538
Revision of previous estimates	757	-96,911	620
Production	-22,995	-8,769	-3,392
End of year	382,660	304,272	232,996
Proved developed reserves, ending balance	144,310	61,225	25,397
Proved undeveloped reserves, ending balance	238,350	243,047	207,599
Marcellus Joint Venture	'	'	'
Supplemental Oil And Gas Reserve Information [Line Items]	'	'	'
Beginning of year	128,118	58,103	'
Extensions and discoveries	19,812	98,119	58,800
Revision of previous estimates	-26,803	-23,808	'
Production	-11,443	-4,296	-697
End of year	109,684	128,118	58,103
Proved developed reserves, ending balance	52,370	35,013	14,474
Proved undeveloped reserves, ending balance	57,314	93,105	43,629

Supplemental_Information_on_Ga2

Supplemental Information on Gas-Producing Activities - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MMcf	MMcf	Location
			MMcf
Reserve Quantities [Line Items]	'	'	'
Extensions and discoveries	100,626	176,956	223,538
Revision of previous estimates	757	-96,911	620
Number of proved undeveloped locations removed from estimate of reserves	'	'	32
Percentage of proved undeveloped reserves reviewed	100.00%	'	'
Adjusted gas price used for computation of reserves	3.91	2.86	4.36
Marcellus Shale	'	'	'
Reserve Quantities [Line Items]	'	'	'
Extensions and discoveries	100,626	176,956	223,538
Marcellus Joint Venture	'	'	'
Reserve Quantities [Line Items]	'	'	'
Extensions and discoveries	19,812	98,119	58,800
Revision of previous estimates	-26,803	-23,808	'
Adjusted gas price used for computation of reserves	3.9	2.84	4.34
Equity investment ownership percentage	50.00%	'	'

Estimated_Discounted_Future_Ne

Estimated Discounted Future Net Cash Flows Related to Proved Natural Gas Reserves (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'		'		'
Future cash inflows	$1,496,294		$869,882		$1,015,589
Future production costs	-517,101		-323,855		-208,733
Future development costs	-219,879		-262,084		-206,612
Future net cash flows	759,314		283,943		600,244
10% annual discount for estimated timing of cash flows	-342,150		-181,725		-330,924
Standardized measure of discounted future net cash flows	417,164	[1]	102,218	[1]	269,320	[1]
Marcellus Joint Venture	'		'		'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'		'		'
Future cash inflows	427,167		364,157		252,384
Future production costs	-132,427		-127,086		-29,683
Future development costs	-46,344		-86,213		-51,882
Future net cash flows	248,396		150,858		170,819
10% annual discount for estimated timing of cash flows	-102,293		-79,781		-100,232
Standardized measure of discounted future net cash flows	$146,103	[1]	$71,077	[1]	$70,587	[1]
[1]	Does not include the effects of income taxes on future revenues at December 31, 2013 and 2012 because as of December 31, 2013 and 2012, the Company was 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 the Company's equity holders. However, in connection with the closing of the IPO, as a result of the corporate reorganization, the Company became a corporation subject to federal income tax and, as such, its future income taxes will be dependent upon its future taxable income.

Principal_Sources_of_Changes_i

Principal Sources of Changes in Standardized Measure of Discounted Future Net Cash Flows (Detail) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'	'
Balance at beginning of period	$102,218	$269,320	$46,422
Net change in prices and production costs	101,345	-83,873	-15,929
Net change in future development costs	29,336	-31,811	-3,695
Natural gas net revenues	-68,135	-18,376	-11,815
Extensions	114,489	38,937	243,003
Revisions of previous quantity estimates	1,133	-108,209	-14,259
Previously estimated development costs incurred	66,894	17,036	3,040
Accretion of discount	10,230	26,932	4,642
Changes in timing and other	59,654	-7,738	17,911
Balance at end of period	417,164	102,218	269,320
Marcellus Joint Venture	'	'	'
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves [Line Items]	'	'	'
Balance at beginning of period	71,077	70,587	'
Net change in prices and production costs	81,974	-26,855	'
Net change in future development costs	2,781	-262	'
Natural gas net revenues	-32,782	-7,707	-2,494
Extensions	18,950	38,131	73,081
Revisions of previous quantity estimates	-14,752	-28,923	'
Previously estimated development costs incurred	31,253	12,862	'
Accretion of discount	7,111	7,059	'
Changes in timing and other	-19,509	6,185	'
Balance at end of period	$146,103	$71,077	$70,587