Jones Energy (JONEQ) 10-Q 8 Nov 13 2013 Q3 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 06, 2013	Nov. 06, 2013
		Class A common stock	Class B common stock
Entity Registrant Name	'Jones Energy, Inc.	'	'
Entity Central Index Key	'0001573166	'	'
Document Type	'10-Q	'	'
Document Period End Date	30-Sep-13	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Non-accelerated Filer	'	'
Entity Common Stock, Shares Outstanding	'	12,526,580	36,836,333
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'Q3	'	'

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets	'	'
Cash	$23,055	$23,726
Accounts receivable, net	'	'
Oil and gas sales	52,766	29,684
Joint interest owners	23,280	21,876
Other	818	4,590
Other current assets	1,687	1,088
Commodity derivative assets	14,681	17,648
Total current assets	116,287	98,612
Oil and gas properties, net, at cost under the successful efforts method	1,080,054	1,007,344
Other property, plant and equipment, net	2,479	3,398
Commodity derivative assets	26,591	25,199
Other assets	15,345	16,133
Deferred tax assets	359	'
Total assets	1,241,115	1,150,686
Current liabilities	'	'
Trade accounts payable	58,516	38,036
Oil and gas sales payable	63,858	45,860
Accrued liabilities	7,796	3,873
Deferred tax liabilities	17	61
Asset retirement obligations	174	174
Commodity derivative liabilities	10,424	4,035
Total current liabilities	140,785	92,039
Long-term debt	438,000	610,000
Deferred revenue	14,886	'
Commodity derivative liabilities	511	7,657
Asset retirement obligations	10,025	9,332
Deferred tax liabilities	2,138	1,876
Total liabilities	606,345	720,904
Commitments and contingencies (Note 10)	'	'
Stockholders' / members' equity	'	'
Members' equity	'	429,782
Additional paid-in-capital	172,652	'
Retained earnings	-821	'
Stockholders' / members' equity	171,881	429,782
Non-controlling interest	462,889	'
Total stockholders' / members' equity	634,770	429,782
Total liabilities and stockholders' / members' equity	1,241,115	1,150,686
Class A common stock	'	'
Stockholders' / members' equity	'	'
Common stock	13	'
Class B common stock	'	'
Stockholders' / members' equity	'	'
Common stock	$37	'

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Sep. 30, 2013	Dec. 31, 2012
Class A common stock	'	'
Common Stock, par value (in dollars per share)	$0.00	$0.00
Common Stock, shares authorized	12,526,580	12,526,580
Common Stock, shares issued	12,526,580	12,526,580
Common Stock, shares outstanding	12,526,580	12,526,580
Class B common stock	'	'
Common Stock, par value (in dollars per share)	$0.00	$0.00
Common Stock, shares authorized	36,836,333	36,836,333
Common Stock, shares issued	36,836,333	36,836,333
Common Stock, shares outstanding	36,836,333	36,836,333

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Operating revenues	'	'	'	'
Oil and gas sales	$68,625	$31,803	$188,184	$105,426
Other revenues	226	132	673	660
Total operating revenues	68,851	31,935	188,857	106,086
Operating costs and expenses	'	'	'	'
Lease operating	7,761	5,776	19,308	17,107
Production taxes	3,469	1,192	9,103	3,951
Exploration	853	84	1,458	265
Depletion, depreciation and amortization	30,529	21,229	82,552	58,251
Impairment of oil and gas properties	'	'	'	61
Accretion of discount	170	146	434	427
General and administrative (including non-cash compensation expense)	13,974	3,832	25,611	11,508
Total operating expenses	56,756	32,259	138,466	91,570
Operating income (expense)	12,095	-324	50,391	14,516
Other income (expense)	'	'	'	'
Interest expense	-6,879	-5,716	-22,712	-17,868
Net gain (loss) on commodity derivatives	-20,728	-18,436	4,444	20,122
Gain (loss) on sales of assets	-55	205	-30	1,561
Other income (expense), net	-27,662	-23,947	-18,298	3,815
Income (loss) before income tax	-15,567	-24,271	32,093	18,331
Income tax provision	'	'	'	'
Current	15	'	48	'
Deferred	-359	104	-141	327
Total income tax provision	-344	104	-93	327
Net income (loss) including non-controlling interests	-15,223	-24,375	32,186	18,004
Net income (loss) attributable to non-controlling interests	-14,402	'	33,007	'
Net income (loss) attributable to controlling interests	($821)	($24,375)	($821)	$18,004
Earnings (loss) per share:	'	'	'	'
Basic and diluted (in dollars per share)	($0.07)	'	($0.07)	'
Weighted average shares outstanding:	'	'	'	'
Basic and diluted (in shares)	12,500	'	12,500	'

Statements_of_Changes_In_Stock

Statements of Changes In Stockholders'/ Members' Equity (USD $)	Total	Common Stock	Common Stock	Members' Equity	Additional Paid-in-Capital	Retained Earnings	Non-controlling interest
In Thousands, unless otherwise specified		Class A common stock	Class B common stock
Balance at Dec. 31, 2012	$429,782	'	'	$429,782	'	'	'
Increase (Decrease) Stockholders' / members' equity	'	'	'	'	'	'	'
Issuance of common stock	50	13	37	'	'	'	'
Issuance of common stock (in shares)	'	12,500	36,836	'	'	'	'
Proceeds from the sale of common stock	172,373	'	'	'	172,373	'	'
Reclassification of members' contributions	'	'	'	-465,945	'	'	465,945
Stock-compensation expense	10,379	'	'	10,100	279	'	'
Distribution to members	-10,000	'	'	-10,000	'	'	'
Net income	32,186	'	'	36,063	'	-821	-3,056
Balance at Sep. 30, 2013	$634,770	$13	$37	'	$172,652	($821)	$462,889
Balance (in shares/units) at Sep. 30, 2013	'	12,500	36,836	'	'	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	3 Months Ended	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities	'	'	'
Net income	($15,223)	$32,186	$18,004
Adjustments to reconcile net income to net cash provided by operating activities	'	'	'
Depletion, depreciation, and amortization	30,529	82,552	58,251
Impairment of oil and gas properties	'	'	61
Accretion of discount	170	434	427
Amortization of debt issuance costs	'	2,003	2,650
Stock compensation expense	9,900	10,379	425
Other non-cash compensation expense (Note 9)	'	2,592	'
Amortization of deferred revenue	'	-114	'
Gain on commodity derivatives	20,728	-4,444	-20,122
Loss (gain) on sales of assets	55	30	-1,561
Deferred income tax provision	-359	-141	327
Other - net	'	227	60
Changes in assets and liabilities	'	'	'
Accounts receivable	'	-23,359	26,143
Other assets	'	643	1,170
Accounts payable and accrued liabilities	'	15,577	-22,362
Net cash provided by operations	'	118,565	63,473
Cash flows from investing activities	'	'	'
Additions to oil and gas properties	'	-127,478	-95,878
Proceeds from sales of assets	'	629	9,151
Acquisition of other property, plant and equipment	'	-440	-743
Current period settlements of matured derivative contracts	'	7,680	21,778
Net cash used in investing	'	-119,609	-65,692
Cash flows from financing activities	'	'	'
Proceeds from issuance of long-term debt	'	'	49,243
Repayment under long-term debt	'	-172,000	-38,243
Payment of debt issuance costs	'	-49	-18
Proceeds from sale of common stock, net of expenses of $15.1 million	'	172,422	'
Net cash provided by financing	'	373	10,982
Net increase (decrease) in cash	'	-671	8,763
Cash	'	'	'
Beginning of period	'	23,726	6,136
End of period	23,055	23,055	14,899
Supplemental disclosure of cash flow information	'	'	'
Cash paid for interest	'	19,442	15,275
Change in accrued additions to oil and gas properties	'	26,826	-8,952
Current additions to ARO	'	499	257
Deferred offering costs	60	60	'
Noncash distributions to members (Note 9)	'	$10,000	'

Consolidated_Statements_of_Cas1

Consolidated Statements of Cash Flows (Parenthetical) (USD $)	9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013
Consolidated Statements of Cash Flows	'
Payment of stock issuance expenses	$15.10

Organization_and_Description_o

Organization and Description of Business	9 Months Ended
	Sep. 30, 2013
Organization and Description of Business	'
Organization and Description of Business	'
	1.                            Organization and Description of Business
	Organization
	Jones Energy, Inc. (“Jones” or the “Company”) was formed in March 2013 as a Delaware corporation to become a publicly traded entity and the holding company of Jones Energy Holdings, LLC (“JEH LLC”). As the sole managing member of JEH LLC, Jones Energy, Inc. is responsible for all operational, management and administrative decisions relating to JEH LLC’s business and consolidates the financial results of JEH LLC and its subsidiaries.
	JEH LLC was formed as a Delaware limited liability company on December 16, 2009 through investments made by the Jones family and through private equity funds managed by Metalmark Capital and Wells Fargo Energy Capital. JEH LLC acts as a holding company of operating subsidiaries that own and operate assets that are used in the exploration, development, production and acquisition of oil and natural gas properties.
	A corporate reorganization and recapitalization occurred in connection with the Company’s initial public offering (the “Offering”) which closed on July 29, 2013. The pre-Offering owners of JEH LLC converted their existing membership interests in JEH LLC into JEH LLC Units and amended the existing LLC agreement to, among other things, modify its equity capital to consist solely of JEH LLC Units. Jones Energy, Inc. became the sole managing member of JEH LLC. Two classes of common stock, Class A common stock and Class B common stock, were authorized in connection with the Offering. Only Class A common stock was offered to investors pursuant to the Offering. The Class B common stock is held by the pre-Offering owners of JEH LLC and can be exchanged (together with a corresponding number of JEH LLC Units) for shares of Class A common stock on a one-for-one basis, subject to customary conversion rate adjustments for stock splits, stock dividends and reclassifications and other similar transactions. As a result of the Offering, the pre-Offering owners retained 74.7% of the total economic interest in JEH LLC, but with no voting rights or management power over Jones, resulting in the Company reporting this ownership interest as a non-controlling interest. Prior to the the Offering, JEH LLC was the controlling interest in the Company; hence all of the net income (loss) earned prior to the Offering date is reflected in the net income (loss) attributable to non-controlling interests on the Consolidated Statement of Operations for the three and nine months ended September 30, 2013.
	Description of Business
	The Company is engaged in the acquisition, exploration, and production of oil and natural gas properties in the mid-continent U.S. The Company’s assets are located within two distinct basins in the Texas Panhandle and Oklahoma, the Anadarko Basin and the Arkoma Basin, respectively, and are owned by JEH LLC and its operating subsidiaries. The Company operates in one industry segment and all of its operations are conducted in one geographic area of the United States. The Company is headquartered in Austin, Texas.

Significant_Accounting_Policie

Significant Accounting Policies	9 Months Ended
	Sep. 30, 2013
Significant Accounting Policies	'
Significant Accounting Policies	'
	2.                            Significant Accounting Policies
	Basis of Presentation
	The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). The accompanying consolidated financial statements include Jones Energy, Inc. and all of its subsidiaries.  All significant intercompany transactions and balances have been eliminated in consolidation.
	These interim financial statements have not been audited.  However, in the opinion of management, all adjustments consisting of only normal and recurring adjustments necessary for a fair statement of the financial statements have been included. As these are interim financial statements, they do not include all disclosures required for financial statements prepared in conformity with GAAP. Interim period results are not necessarily indicative of results of operations or cash flows for a full year.
	These consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Accordingly, they do not include all disclosures required by GAAP and should be read in conjunction with our most recent audited consolidated financial statements included in Jones Energy, Inc.’s final prospectus dated July 23, 2013 and filed with the SEC on July 25, 2013 pursuant to Rule 424(b) under the Securities Act of 1933, as amended.
	Use of Estimates
	In preparing the accompanying financial statements, management has made certain estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent liabilities, and the reported amounts of revenue and expenses during the reporting period.  Actual results could differ from these estimates. Changes in estimates are recorded prospectively.
	Significant assumptions are required in the valuation of proved oil and natural gas reserves, which affect the Company’s estimates of depletion expense, impairment, and the allocation of value in our business combinations. Significant assumptions are also required in the Company’s estimates of the net gain or loss on commodity derivative assets and liabilities and asset retirement obligations (ARO).
	Oil and Gas Properties
	The Company accounts for its oil and natural gas exploration and production activities under the successful efforts method of accounting. Oil and gas properties consisted of the following at September 30, 2013 and December 31, 2012:
		September 30,			December 31,
	(in thousands of dollars)	2013			2012
	Mineral interests in properties
	Unproved	$	107,971		$	137,254
	Proved	784,268			737,558
	Wells and equipment and related facilities	526,930			389,727
		1,419,169			1,264,539
	Less: Accumulated depletion and impairment	(339,115		)	(257,195		)
	Net oil and gas properties	$	1,080,054		$	1,007,344
	As of September 30, 2013 and December 31, 2012, there were no costs capitalized in connection with exploratory wells in progress.
	The Company capitalizes interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use. The Company did not capitalize any interest during the period ended September 30, 2013 as no projects lasted more than six months. Depletion of oil and gas properties amounted to $30.3 million and $81.9 million for the three and nine months ended September 30, 2013, respectively, and $21.0 million and $57.7 million for the three and nine months ended September 30, 2012, respectively.
	Other Property, Plant and Equipment
	Other property, plant and equipment consisted of the following at September 30, 2013 and December 31, 2012:
		September 30,			December 31,
	(in thousands of dollars)	2013			2012
	Leasehold improvements	$	1,004		$	983
	Furniture, fixtures, computers and software	2,346			2,204
	Vehicles	732			719
	Aircraft	—			1,295
	Land	62			62
	Production Equipment	72			72
		4,216			5,335
	Less: Accumulated depreciation and amortization	(1,737		)	(1,937		)
	Net other property, plant and equipment	$	2,479		$	3,398
	Other property, plant and equipment is depreciated on a straight-line basis over the estimated useful lives of the property, plant and equipment, which range from three years to ten years.  Depreciation and amortization of other property, plant and equipment amounted to $0.2 million and $0.6 million during the three and nine months ended September 30, 2013, respectively, and $0.2 million and $0.6 million during the three and nine months ended September 30, 2012, respectively.
	Commodity Derivatives
	The Company records its commodity derivative instruments on the Consolidated Balance Sheet as either an asset or liability measured at its fair value. Changes in the derivative’s fair value are recognized currently in earnings, unless specific hedge accounting criteria are met. During the three month period ended September 30, 2013, the Company elected not to designate any of its commodity price risk management activities as cash-flow or fair value hedges. The changes in the fair values of outstanding financial instruments are recognized as gains or losses in the period of change.
	Although Jones does not designate its commodity derivative instruments as cash-flow hedges, management uses those instruments to reduce the Company’s exposure to fluctuations in commodity prices related to its natural gas and oil production. Net gains and losses, at fair value, are included on the Consolidated Balance Sheet as current or noncurrent assets or liabilities based on the anticipated timing of cash settlements under the related contracts. Changes in the fair value of commodity derivative contracts are recorded in earnings as they occur and are included in other income (expense) on the Consolidated Statement of Operations. See Note 4, “Fair Value Measurement”, for disclosure about the fair values of commodity derivative instruments.
	Asset Retirement Obligations
	A summary of the Company’s ARO for the nine months ended September 30, 2013 is as follows:
	(in thousands of dollars)
	Balance at December 31, 2012	$	9,506
	Liabilities incurred	499
	Accretion of discount	434
	Liabilities settled due to sale of related properties	(4		)
	Liabilities settled due to plugging and abandonment	(437		)
	Change in estimate	201
	Balance at September 30, 2013	10,199
	Less: Current portion of ARO	(174		)
	Total long-term ARO at September 30, 2013	$	10,025
	Income Taxes
	Prior to the Offering, the Company was a limited liability company and not subject to federal income tax. Accordingly, no provision for federal income taxes was recorded prior to the Offering because the taxable income or loss was includable in the income tax returns of the individual partners and members. The Company was and still is subject to state income taxes as the State of Texas includes in its tax system a gross margin tax applicable to the Company, and an accrual for gross margin taxes is included in the financial statements when appropriate. In connection with the corporate reorganization, the Company became a corporation and is now subject to federal income taxes.
	Based on management’s analysis, the Company did not have any uncertain tax positions as of September 30, 2013 and December 31, 2012.
	Tax Receivable Agreement
	In conjunction with the Offering, the Company entered into a Tax Receivable Agreement (“TRA”) with JEH LLC and its existing owners. Upon any exchange of JEH LLC Units and Class B common stock of the Company held by JEH LLC’s pre-Offering owners for Class A common stock of the Company, the TRA provides for the payment by Jones, directly to such exchanging owners, of 85% of the amount of cash savings in income or franchise taxes that Jones realizes as a result of (i) the tax basis increases resulting from the exchange of JEH LLC Units for shares of Class A common stock (or resulting from a sale of JEH LLC Units for cash) and (ii) imputed interest deemed to be paid by the Company as a result of, and additional tax basis arising from, any payments the Company makes under the TRA. The Company will retain the benefit of the remaining 15% of the cash savings. Liabilities under this agreement will be recognized upon the exchange of shares. As of September 30, 2013, there have been no exchanges.
	Recent Accounting Developments
	The following recently issued accounting pronouncements have or will be adopted by the Company:
	Offsetting Assets and Liabilities
	In December 2011, the Financial Accounting Standards Board (“FASB”), issued authoritative guidance requiring entities to disclose both gross and net information about instruments and transactions eligible for offset arrangement. The additional disclosures enable users of the financial statements to evaluate the effect or potential effect of netting arrangements on an entity’s financial position. These disclosure requirements are effective for interim and annual periods beginning after January 1, 2013. The Company has provided all required disclosures for the periods presented in the third quarter of 2013 as they pertain to its commodity derivative instruments (see Note 4, “Fair Value Measurement”). These disclosure requirements did not affect the Company’s operating results, financial position, or cash flows.

Acquisition_of_Properties

Acquisition of Properties	9 Months Ended
	Sep. 30, 2013
Acquisition of Properties	'
Acquisition of Properties	'
	3.                            Acquisition of Properties
	No significant property acquisitions that would qualify as business combinations occurred during the nine months ended September 30, 2013 and 2012.
	On December 20, 2012, JEH LLC acquired certain oil and natural gas properties located in Texas for a purchase price of $251.9 million (referred to herein as the “Chalker acquisition” or “Chalker”).  The acquired assets represented a strategic fit with the Company’s existing Texas Panhandle properties and included both producing properties and undeveloped acreage. The purchase was financed with additional equity capital and long-term debt. In the second quarter of 2013, Jones made a final determination with the sellers as to the purchase price adjustments resulting in a final purchase price of $253.5 million. The final purchase price was allocated as follows:
	Oil and gas properties
	Unproved	$	71,264
	Proved	182,493
	Asset retirement obligations	(293		)
	Total purchase price	$	253,464
	This acquisition qualified as a business combination under ASC 805. The valuation to determine the fair value was principally based on the discounted cash flows of both the producing and undeveloped properties, including projected drilling and equipment costs, recoverable reserves, production streams, future prices and operating costs, and risk-adjusted discount rates reflective of the current market.
	The unaudited pro forma results presented below have been prepared to include the effect of the acquisition on our results of operations for the three and nine months ended September 30, 2012.  The unaudited pro forma results do not purport to represent what our actual results of operations would have been if the acquisition had been completed on January 1, 2012 or to project our results of operations for any future date or period.
		Three Months Ended September 30, 2012
	(in thousands of dollars)	Actual			Pro Forma
	Total operating revenue	$	31,935		$	43,384
	Total operating expenses	32,259			33,185
	Operating income (loss)	(324		)	10,199
	Net income (loss)	(24,375		)	(13,852		)
		Nine Months Ended September 30, 2012
	(in thousands of dollars)	Actual			Pro Forma
	Total operating revenue	$	106,086		$	135,824
	Total operating expenses	91,570			94,128
	Operating income	14,516			41,696
	Net income	18,004			45,184

Fair_Value_Measurement

Fair Value Measurement	9 Months Ended
	Sep. 30, 2013
Fair Value Measurement	'
Fair Value Measurement	'
	4.                           Fair Value Measurement
	Fair Value of Financial Instruments
	The Company determines fair value amounts using available market information and appropriate valuation methodologies. Fair value is the price that would be received to sell an asset or would be paid to transfer a liability in an orderly transaction between market participants at the measurement date. Considerable judgment is required in interpreting market data to develop the estimates of fair value. The use of different market assumptions and/or estimation methods may have a material effect on the estimated fair value amounts.
	The Company enters into a variety of derivative financial instruments, which may include over-the-counter instruments, such as natural gas, crude oil, and natural gas liquid contracts. The Company utilizes valuation techniques that maximize the use of observable inputs, where available. If listed market prices or quotes are not published, fair value is determined based upon a market quote, adjusted by other market-based or independently sourced market data, such as trading volume, historical commodity volatility, and counterparty-specific considerations. These adjustments may include amounts to reflect counterparty credit quality, the time value of money, and the liquidity of the market.
	Counterparty credit valuation adjustments are necessary when the market price of an instrument is not indicative of the fair value as a result of the credit quality of the counterparty. Generally, market quotes assume that all counterparties have low default rates and equal credit quality. Therefore, an adjustment may be necessary to reflect the quality of a specific counterparty to determine the fair value of the instrument. The Company currently has all of its derivative positions placed and held by members of its lending group, which have strong credit quality.
	Liquidity valuation adjustments are necessary when the Company is not able to observe a recent market price for financial instruments that trade in less active markets. Exchange traded contracts are valued at market value without making any additional valuation adjustments; therefore, no liquidity reserve is applied.
	Valuation Hierarchy
	Fair value measurements are grouped into a three-level valuation hierarchy. The valuation hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date. A financial instrument’s categorization within the hierarchy is based upon the input that requires the highest degree of judgment in the determination of the instrument’s fair value. The three levels are defined as follows:
	Level 1                  Pricing inputs are based on published prices in active markets for identical assets or liabilities as of the reporting date. The Company does not classify any of its financial instruments as Level 1.
	Level 2                  Pricing inputs include quoted prices for similar assets and liabilities in active markets, and inputs that are observable for the asset or liability, either directly or indirectly, as of the reporting date. Contracts that are not traded on a recognized exchange or are tied to pricing transactions for which forward curve pricing is readily available are classified as Level 2 instruments. These include natural gas, crude oil and some natural gas liquids price swaps and natural gas basis swaps.
	Level 3                  Pricing inputs include significant inputs that are generally unobservable from objective sources. The Company classifies natural gas liquid swaps and basis swaps for which future pricing is not readily available as Level 3. The Company obtains estimates from independent third parties for its open positions and subjects those to the credit adjustment criteria described above.
	The financial instruments carried at fair value as of September 30, 2013 and December 31, 2012, by consolidated balance sheet caption and by valuation hierarchy, as described above are as follows:
		September 30, 2013
	(in thousands of dollars)	Fair Value Measurements
	Commodity Price Hedges	(Level 1)			(Level 2)			(Level 3)			Total
	Current assets	$	—		$	14,501		$	180		$	14,681
	Long-term assets	—			24,431			2,160			26,591
	Current liabilities	—			10,349			75			10,424
	Long-term liabilities	—			511			—			511
		December 31, 2012
	(in thousands of dollars)	Fair Value Measurements
	Commodity Price Hedges	(Level 1)			(Level 2)			(Level 3)			Total
	Current assets	$	—		$	17,648		$	—		$	17,648
	Long-term assets	—			24,756			443			25,199
	Current liabilities	—			2,992			1,043			4,035
	Long-term liabilities	—			6,739			918			7,657
	The following table represents quantitative information about Level 3 inputs used in the fair value measurement of the Company’s commodity derivative contracts as of September 30, 2013.
		Quantitative Information About Level 3 Fair Value Measurements
	Commodity Price Hedges	Fair Value			Valuation Technique		Unobservable Input		Range
	Natural gas liquid swaps	$	2,354		Use a discounted cash flow approach using inputs including forward price statements from counterparties		Natural gas liquid futures prices		$8.09 - $84.89 per barrel
	Basis swaps	$	(89	)	Use a discounted cash flow approach using inputs including forward price statements from counterparties		Forward basis prices		$(0.17) - $0.05 per mmbtu
	Significant increases / decreases in natural gas liquid futures prices in isolation would result in a significantly lower / higher fair value measurement. The following table presents the changes in the Level 3 financial instruments for the nine months ended September 30, 2013. Changes in fair value of Level 3 instruments represent changes in gains and losses for the periods that are reported in other income (expense). New contracts entered into during the year are generally entered into at no cost with changes in fair value from the date of agreement representing the entire fair value of the instrument. Transfers between levels are evaluated at the end of the reporting period.
	(in thousands of dollars)
	Balance at December 31, 2012, net	$	(1,519	)
	Purchases	—
	Settlements	(5		)
	Transfers to Level 2	260
	Transfers to Level 3	(716		)
	Changes in fair value	4,245
	Balance at September 30, 2013, net	$	2,265
	Transfers from Level 3 to Level 2 represent all of the Company’s natural gas liquids swaps for which observable forward curve pricing information has become readily available. Transfers to Level 3 represent basis swaps that were previously considered Level 2 but due to the unavailability of forward prices at the valuation date were classified as Level 3 as of September 30, 2013. There were no purchases in the period that resulted in changes to Level 3.
	Offsetting Assets and Liabilities
	As of September 30, 2013, the counterparties to our commodity derivative contracts consisted of six financial institutions. All of our counterparties or their affiliates are also lenders under our credit facility. Therefore, we are not generally required to post additional collateral under our derivative agreements.
	Our derivative agreements contain set-off provisions that state that in the event of default or early termination, any obligation owed by the defaulting party may be offset against any obligation owed to the defaulting party.
	We adopted the guidance requiring disclosure of both gross and net information about financial instruments eligible for netting in the balance sheet under our derivative agreements. The following table presents information about our commodity derivative contracts which are netted on our balance sheet as of September 30, 2013 and December 31, 2012:
	(in thousands)	Gross Amounts		Gross Amounts		Net Amounts of		Gross Amounts		Net Amount
		of Recognized		Offset in the		Assets /		Not Offset in
		Assets /		Balance Sheet		Liabilities		the Balance
		Liabilities				Presented in the		Sheet
						Balance Sheet
	September 30, 2013
	Commodity derivative contracts
	Assets	45,843		(4,711	)	41,132		140		41,272
	Liabilities	(15,646	)	4,711		(10,935	)	—		(10,935	)
	December 31, 2012
	Commodity derivative contracts
	Assets	49,200		(7,831	)	41,369		1,478		42,847
	Liabilities	(17,928	)	7,831		(10,097	)	(1,595	)	(11,692	)
	Nonfinancial Assets and Liabilities
	Assets and liabilities acquired in business combinations are recorded at their fair value on the date of acquisition. Significant Level 3 assumptions associated with the calculation of future cash flows used in the analysis of fair value of the oil and gas property acquired include the Company’s estimate of future commodity prices, production costs, development expenditures, production, risk-adjusted discount rates, and other relevant data. Additionally, fair value is used to determine the inception value of the Company’s AROs. The inputs used to determine such fair value are primarily based upon costs incurred historically for similar work, as well as estimates from independent third parties for costs that would be incurred to restore leased property to the contractually stipulated condition. Additions to the Company’s ARO represent a nonrecurring Level 3 measurement.
	The Company reviews its proved oil and gas properties for impairment purposes by comparing the expected undiscounted future cash flows at a producing field level to the unamortized capitalized cost of the asset. During the nine months ended September 30, 2013 and 2012, no significant impairment charges on the Company’s proved properties were recorded. Additionally, the Company assessed its unproved properties for impairment as of September 30, 2013 and 2012 and no impairments were noted. In the event of an impairment, charges are recorded on the Consolidated Statement of Operations. Significant assumptions associated with the calculation of future cash flows used in the impairment analysis include the Company’s estimate of future commodity prices, production costs, development expenditures, production, risk-adjusted discount rates, and other relevant data.  As such, the fair value of oil and gas properties used in estimating impairment represents a nonrecurring Level 3 measurement.
	The fair value measurement of Monarch shares (see Note 9, “Monarch Investment”) is based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair value was measured using a market approach valuation technique. Significant inputs to the valuation include estimates of future revenue, and operating costs, and related valuation multiples. These inputs require significant judgments and estimates by management at the time of the valuation and are subject to change.

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities	'
Derivative Instruments and Hedging Activities	'
	5.                            Derivative Instruments and Hedging Activities
	Jones had various commodity derivatives in place to offset uncertain price fluctuations that could affect its future operations as of September 30, 2013 and December 31, 2012, as follows:
	Hedging Positions
		September 30, 2013
									Weighted			Final
			Low			High			Average			Expiration
	Oil swaps	Exercise price	$	81		$	104.45		$	89.26
		Barrels per month	24,000			143,116			88,325			December 2017
	Natural gas swaps	Exercise price	$	3.52		$	6.9		$	4.97
		mmbtu per month	430,000			1,110,000			726,337			December 2017
	Basis swaps	Contract differential	$	(0.45	)	$	(0.03	)	$	(0.33	)
		mmbtu per month	320,000			570,000			399,000			March 2016
	Natural gas liquids swaps	Exercise price	$	6.72		$	97.13		$	32.97
		Barrels per month	2,000			144,973			40,705			December 2017
		December 31, 2012
									Weighted			Final
			Low			High			Average			Expiration
	Oil swaps	Exercise price	$	81		$	104.45		$	89.6
		Barrels per month	24,000			143,116			89,323			December 2017
	Natural gas swaps	Exercise price	$	3.52		$	6.9		$	4.96
		mmbtu per month	430,000			1,110,000			767,053			December 2017
	Basis swaps	Contract differential	$	(0.65	)	$	(0.03	)	$	(0.31	)
		mmbtu per month	320,000			850,000			484,615			March 2016
	Natural gas liquids swaps	Exercise price	$	6.72		$	97.13		$	33.81
		Barrels per month	2,000			144,973			55,616			December 2017
	The Company recognized a net loss on derivative instruments of $20.7 million for the three months ended September 30, 2013 and a net gain of $4.4 million for the nine months ended September 30, 2013. The Company recognized a net loss of $18.4 million for the three months ended September 30, 2012 and a net gain of $20.1 million for the nine months ended September 30, 2012.

LongTerm_Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2013
Long-Term Debt	'
Long-Term Debt	'
	6.                            Long-Term Debt
	The Company entered into two credit agreements dated December 31, 2009, with Wells Fargo Bank N.A, the Senior Secured Revolving Credit Facility (the “Revolver”) and the Second Lien Term Loan (the “Term Loan”) which were subsequently amended on November 18, 2011, November 5, 2012, December 20, 2012 and June 12, 2013. In connection with the November 2012 amendment, the maturity date of the Revolver was extended to November 5, 2017 and the maturity date of the Term loan was extended to May 5, 2018. In connection with the June 2013 amendment, the borrowing base on the Revolver was increased to $500.0 million. The Company’s oil and gas properties are pledged as collateral against these credit agreements.
	Terms of the two credit facilities require Jones to pay interest on the loan as LIBOR tranches mature and every three months on the remaining balance, with the principal and interest due on the loan maturity date.  Prepayment of the principal balance of the Term Loan is allowed in whole or in part at any time with a premium payment due in certain conditions.
	For the three and nine months ended September 30, 2013, the average interest rates under the Revolver were 2.74% and 3.04%, respectively, on average outstanding balances of $330.6 million and $406.7 million.  For the same periods in 2012, the average interest rates were 3.39% and 3.23%, respectively, on average outstanding balances of $304.3 million and $299.0 million.  Total interest and commitment fees under the two facilities were $6.2 million and $20.7 million for the three and nine months ended September 30, 2013, respectively, and $4.8 million and $15.2 million for the three and nine months ended September 30, 2012, respectively.
	In connection with the initial public offering, the Company used the net proceeds to repay outstanding borrowings under the Revolver of $167.0 million.
	The Revolver and Term Loans are categorized as Level 3 in the valuation hierarchy as the debt is not publicly traded and no observable market exists to determine the fair value; however, the carrying value of the Revolver and Term Loans approximate fair value, as they are subject to short-term floating interest rates that approximate the rates available to the Company for those periods.
	The Revolver and Term Loans include covenants that require, among other things, restrictions on asset sales, distributions to members, and additional indebtedness, and the maintenance of certain financial ratios, including leverage, proven reserves to debt, and current ratio. At September 30, 2013 and December 31, 2012, the Company was in compliance with its financial debt covenants.

Stockbased_Compensation

Stock-based Compensation	9 Months Ended
	Sep. 30, 2013
Stock-based Compensation	'
Stock-based Compensation	'
	7.                            Stock-based Compensation
	JEH LLC implemented a management incentive plan effective January 1, 2010, that provided membership-interest awards in JEH LLC to members of senior management (“management units”). These awards had various vesting schedules, and a portion of the management units vested in a lump sum at the Offering date. Both the vested and unvested management units were converted into JEH LLC Units and shares of Class B common stock at the Offering date. At the Offering date and at September 30, 2013 there were 559,061 unvested JEH LLC Units and shares of Class B common stock that will be convertible into a like number of shares of Class A common stock upon vesting.
	Stock compensation expense of $9.9 million and $0.1 million for the three months ended September 30, 2013 and 2012, respectively, and $10.4 million and $0.4 million for the nine months ended September 30, 2013 and 2012, respectively, is included in general and administrative expense on the Consolidated Statements of Operations.
		JEH LLC		Weighted Average
		Units		Grant Date Fair
				Value per Share
	Unvested at January 1, 2013	710,767		$	3.62
	Granted	911,654		$	15
	Forfeited	(167,239	)	$	(3.62	)
	Vested	(896,121	)	$	(10.68	)
	Unvested at September 30, 2013	559,061		$	10.85

Earnings_per_Share

Earnings per Share	9 Months Ended
	Sep. 30, 2013
Earnings per Share	'
Earnings per Share	'
	8.                            Earnings per Share
	Basic earnings per share (“EPS”) is computed by dividing net income (loss) attributable to controlling interests by the weighted-average number of shares of Class A 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. On September 4, 2013 (the “grant date”), the Company granted to its directors restricted shares of Class A common stock, which vest on the first anniversary of the grant date. In accordance with ASC 260, Earnings Per Share, awards of nonvested shares shall be considered to be outstanding as of the grant date for purposes of computing diluted EPS even though their exercise is contingent upon vesting. For the three and nine months ended September 30, 2013, the directors’ restricted shares of Class A common stock were excluded from the diluted calculation as their inclusion would have been anti-dilutive as the Company was in a net loss position. The following is a calculation of the basic and diluted weighted-average number of shares of Class A common stock outstanding and EPS for the three and nine months ended September 30, 2013. Net income and the weighted-average number of shares of Class A common stock outstanding is based on the actual days in which the shares were outstanding for the period from July 29, 2013, the closing date of the Offering, to September 30, 2013.
	(in thousands of dollars, except per share data)	Three Months Ended			Nine Months Ended
		September 30, 2013			September 30, 2013
	Income (numerator):
	Net income (loss) attributable to controlling interests	$	(821	)	$	(821	)
	Weighted-average shares (denominator):
	Weighted-average number of shares of Class A common stock - basic and diluted	12,500			12,500
	Earnings (loss) per share:
	Basic and diluted	$	(0.07	)	$	(0.07	)

Monarch_Investment

Monarch Investment	9 Months Ended
	Sep. 30, 2013
Monarch Investment	'
Monarch Investment	'
	9.                            Monarch Investment
	On May 7, 2013, the Company entered into a marketing agreement with Monarch Natural Gas, LLC (“Monarch”), a company related through common ownership, for the sale to Monarch of natural gas produced from certain properties. In connection with that agreement, Monarch issued to the Company equity interests in its parent, Monarch Natural Gas Holdings, LLC, having an estimated fair value of $15.0 million. Contemporaneous with the execution of the marketing agreement and the issuance of the equity interests, the Company distributed  67% of the Monarch equity interests to the Company’s owners pro rata based on equity contributions and approximately 16% of the interests to management. The remaining approximately 17% of the equity interests were reserved for distribution to management through an incentive plan. The Company recognized $0.1 million of compensation expense in the third quarter of 2013 in connection with the incentive plan. In addition, the Company recorded deferred revenue of $15.0 million which is being amortized on an estimated units-of-production basis commencing in September 2013, the first month of production sales to Monarch. The Company amortized $0.1 million of the deferred revenue balance during the three months ended September 30, 2013.

Commitments_and_Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2013
Commitments and Contingencies	'
Commitments and Contingencies	'
	10.                     Commitments and Contingencies
	The Company is subject to legal proceedings and claims that arise in the ordinary course of its business.  The Company believes that the final disposition of such matters will not have a material adverse effect on its financial position, results of operations, or liquidity.

Income_Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2013
Income Taxes	'
Income Taxes	'
	11.                     Income Taxes
	Following the Offering, Jones began recording a federal income tax liability associated with its status as a corporation. The Company will recognize a tax liability on its share of pre-tax book income, exclusive of the non-controlling interest. JEH LLC is not subject to income tax at the federal level and only recognizes Texas margin tax. The following table summarizes the tax provision for the three and nine months ended September 30, 2013 and 2012:
		Three Months Ended September 30,					Nine Months Ended September 30,
	(in thousands of dollars)	2013			2012		2013			2012
	Current tax expense
	Federal	$	—		$	—	$	—		$	—
	State	15			—		48			—
	Total current expense	$	15		$	—	$	48		$	—
	Deferred tax expense (benefit)
	Federal	(359		)	—		(358		)	—
	State	—			104		217			327
	Total deferred expense (benefit)	$	(359	)	$	104	$	(141	)	$	327
	Total tax expense (benefit)	$	(344	)	$	104	$	(93	)	$	327
	Tax expense (benefit) attributable to controlling interests	(375		)	—		(375		)	—
	Tax expense attributable to non-controlling interests	31			104		282			327
	Total tax expense (benefit)	$	(344	)	$	104	$	(93	)	$	327

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2013
Significant Accounting Policies	'
Basis of Presentation	'
	Basis of Presentation
	The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (GAAP). The accompanying consolidated financial statements include Jones Energy, Inc. and all of its subsidiaries.  All significant intercompany transactions and balances have been eliminated in consolidation.
	These interim financial statements have not been audited.  However, in the opinion of management, all adjustments consisting of only normal and recurring adjustments necessary for a fair statement of the financial statements have been included. As these are interim financial statements, they do not include all disclosures required for financial statements prepared in conformity with GAAP. Interim period results are not necessarily indicative of results of operations or cash flows for a full year.
	These consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Accordingly, they do not include all disclosures required by GAAP and should be read in conjunction with our most recent audited consolidated financial statements included in Jones Energy, Inc.’s final prospectus dated July 23, 2013 and filed with the SEC on July 25, 2013 pursuant to Rule 424(b) under the Securities Act of 1933, as amended.
Use of Estimates	'
	Use of Estimates
	In preparing the accompanying financial statements, management has made certain estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent liabilities, and the reported amounts of revenue and expenses during the reporting period.  Actual results could differ from these estimates. Changes in estimates are recorded prospectively.
	Significant assumptions are required in the valuation of proved oil and natural gas reserves, which affect the Company’s estimates of depletion expense, impairment, and the allocation of value in our business combinations. Significant assumptions are also required in the Company’s estimates of the net gain or loss on commodity derivative assets and liabilities and asset retirement obligations (ARO).
Oil and Gas Properties	'
	Oil and Gas Properties
	The Company accounts for its oil and natural gas exploration and production activities under the successful efforts method of accounting. Oil and gas properties consisted of the following at September 30, 2013 and December 31, 2012:
		September 30,			December 31,
	(in thousands of dollars)	2013			2012
	Mineral interests in properties
	Unproved	$	107,971		$	137,254
	Proved	784,268			737,558
	Wells and equipment and related facilities	526,930			389,727
		1,419,169			1,264,539
	Less: Accumulated depletion and impairment	(339,115		)	(257,195		)
	Net oil and gas properties	$	1,080,054		$	1,007,344
	As of September 30, 2013 and December 31, 2012, there were no costs capitalized in connection with exploratory wells in progress.
	The Company capitalizes interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use. The Company did not capitalize any interest during the period ended September 30, 2013 as no projects lasted more than six months. Depletion of oil and gas properties amounted to $30.3 million and $81.9 million for the three and nine months ended September 30, 2013, respectively, and $21.0 million and $57.7 million for the three and nine months ended September 30, 2012, respectively.
Other Property, Plant and Equipment	'
	Other Property, Plant and Equipment
	Other property, plant and equipment consisted of the following at September 30, 2013 and December 31, 2012:
		September 30,			December 31,
	(in thousands of dollars)	2013			2012
	Leasehold improvements	$	1,004		$	983
	Furniture, fixtures, computers and software	2,346			2,204
	Vehicles	732			719
	Aircraft	—			1,295
	Land	62			62
	Production Equipment	72			72
		4,216			5,335
	Less: Accumulated depreciation and amortization	(1,737		)	(1,937		)
	Net other property, plant and equipment	$	2,479		$	3,398
	Other property, plant and equipment is depreciated on a straight-line basis over the estimated useful lives of the property, plant and equipment, which range from three years to ten years.  Depreciation and amortization of other property, plant and equipment amounted to $0.2 million and $0.6 million during the three and nine months ended September 30, 2013, respectively, and $0.2 million and $0.6 million during the three and nine months ended September 30, 2012, respectively.
Commodity Derivatives	'
	Commodity Derivatives
	The Company records its commodity derivative instruments on the Consolidated Balance Sheet as either an asset or liability measured at its fair value. Changes in the derivative’s fair value are recognized currently in earnings, unless specific hedge accounting criteria are met. During the three month period ended September 30, 2013, the Company elected not to designate any of its commodity price risk management activities as cash-flow or fair value hedges. The changes in the fair values of outstanding financial instruments are recognized as gains or losses in the period of change.
	Although Jones does not designate its commodity derivative instruments as cash-flow hedges, management uses those instruments to reduce the Company’s exposure to fluctuations in commodity prices related to its natural gas and oil production. Net gains and losses, at fair value, are included on the Consolidated Balance Sheet as current or noncurrent assets or liabilities based on the anticipated timing of cash settlements under the related contracts. Changes in the fair value of commodity derivative contracts are recorded in earnings as they occur and are included in other income (expense) on the Consolidated Statement of Operations. See Note 4, “Fair Value Measurement”, for disclosure about the fair values of commodity derivative instruments.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	A summary of the Company’s ARO for the nine months ended September 30, 2013 is as follows:
	(in thousands of dollars)
	Balance at December 31, 2012	$	9,506
	Liabilities incurred	499
	Accretion of discount	434
	Liabilities settled due to sale of related properties	(4		)
	Liabilities settled due to plugging and abandonment	(437		)
	Change in estimate	201
	Balance at September 30, 2013	10,199
	Less: Current portion of ARO	(174		)
	Total long-term ARO at September 30, 2013	$	10,025
Income Taxes	'
	Income Taxes
	Prior to the Offering, the Company was a limited liability company and not subject to federal income tax. Accordingly, no provision for federal income taxes was recorded prior to the Offering because the taxable income or loss was includable in the income tax returns of the individual partners and members. The Company was and still is subject to state income taxes as the State of Texas includes in its tax system a gross margin tax applicable to the Company, and an accrual for gross margin taxes is included in the financial statements when appropriate. In connection with the corporate reorganization, the Company became a corporation and is now subject to federal income taxes.
	Based on management’s analysis, the Company did not have any uncertain tax positions as of September 30, 2013 and December 31, 2012.
Tax Receivable Agreement	'
	Tax Receivable Agreement
	In conjunction with the Offering, the Company entered into a Tax Receivable Agreement (“TRA”) with JEH LLC and its existing owners. Upon any exchange of JEH LLC Units and Class B common stock of the Company held by JEH LLC’s pre-Offering owners for Class A common stock of the Company, the TRA provides for the payment by Jones, directly to such exchanging owners, of 85% of the amount of cash savings in income or franchise taxes that Jones realizes as a result of (i) the tax basis increases resulting from the exchange of JEH LLC Units for shares of Class A common stock (or resulting from a sale of JEH LLC Units for cash) and (ii) imputed interest deemed to be paid by the Company as a result of, and additional tax basis arising from, any payments the Company makes under the TRA. The Company will retain the benefit of the remaining 15% of the cash savings. Liabilities under this agreement will be recognized upon the exchange of shares. As of September 30, 2013, there have been no exchanges.
Recent Accounting Developments	'
	Recent Accounting Developments
	The following recently issued accounting pronouncements have or will be adopted by the Company:
Offsetting Assets and Liabilities	'
	Offsetting Assets and Liabilities
	In December 2011, the Financial Accounting Standards Board (“FASB”), issued authoritative guidance requiring entities to disclose both gross and net information about instruments and transactions eligible for offset arrangement. The additional disclosures enable users of the financial statements to evaluate the effect or potential effect of netting arrangements on an entity’s financial position. These disclosure requirements are effective for interim and annual periods beginning after January 1, 2013. The Company has provided all required disclosures for the periods presented in the third quarter of 2013 as they pertain to its commodity derivative instruments (see Note 4, “Fair Value Measurement”). These disclosure requirements did not affect the Company’s operating results, financial position, or cash flows.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2013
Significant Accounting Policies	'
Schedule of oil and gas properties	'
		September 30,			December 31,
	(in thousands of dollars)	2013			2012
	Mineral interests in properties
	Unproved	$	107,971		$	137,254
	Proved	784,268			737,558
	Wells and equipment and related facilities	526,930			389,727
		1,419,169			1,264,539
	Less: Accumulated depletion and impairment	(339,115		)	(257,195		)
	Net oil and gas properties	$	1,080,054		$	1,007,344
Schedule of other property, plant and equipment	'
		September 30,			December 31,
	(in thousands of dollars)	2013			2012
	Leasehold improvements	$	1,004		$	983
	Furniture, fixtures, computers and software	2,346			2,204
	Vehicles	732			719
	Aircraft	—			1,295
	Land	62			62
	Production Equipment	72			72
		4,216			5,335
	Less: Accumulated depreciation and amortization	(1,737		)	(1,937		)
	Net other property, plant and equipment	$	2,479		$	3,398
Summary of the Company's ARO	'
	(in thousands of dollars)
	Balance at December 31, 2012	$	9,506
	Liabilities incurred	499
	Accretion of discount	434
	Liabilities settled due to sale of related properties	(4		)
	Liabilities settled due to plugging and abandonment	(437		)
	Change in estimate	201
	Balance at September 30, 2013	10,199
	Less: Current portion of ARO	(174		)
	Total long-term ARO at September 30, 2013	$	10,025

Acquisition_of_Properties_Tabl

Acquisition of Properties (Tables)	9 Months Ended
	Sep. 30, 2013
Acquisition of Properties	'
Schedule of final purchase price allocation	'
	Oil and gas properties
	Unproved	$	71,264
	Proved	182,493
	Asset retirement obligations	(293		)
	Total purchase price	$	253,464
Schedule of unaudited pro forma results of operations	'
		Three Months Ended September 30, 2012
	(in thousands of dollars)	Actual			Pro Forma
	Total operating revenue	$	31,935		$	43,384
	Total operating expenses	32,259			33,185
	Operating income (loss)	(324		)	10,199
	Net income (loss)	(24,375		)	(13,852		)
		Nine Months Ended September 30, 2012
	(in thousands of dollars)	Actual			Pro Forma
	Total operating revenue	$	106,086		$	135,824
	Total operating expenses	91,570			94,128
	Operating income	14,516			41,696
	Net income	18,004			45,184

Fair_Value_Measurement_Tables

Fair Value Measurement (Tables)	9 Months Ended
	Sep. 30, 2013
Fair Value Measurement	'
Schedule of financial instruments carried at fair value	'
		September 30, 2013
	(in thousands of dollars)	Fair Value Measurements
	Commodity Price Hedges	(Level 1)			(Level 2)			(Level 3)			Total
	Current assets	$	—		$	14,501		$	180		$	14,681
	Long-term assets	—			24,431			2,160			26,591
	Current liabilities	—			10,349			75			10,424
	Long-term liabilities	—			511			—			511
		December 31, 2012
	(in thousands of dollars)	Fair Value Measurements
	Commodity Price Hedges	(Level 1)			(Level 2)			(Level 3)			Total
	Current assets	$	—		$	17,648		$	—		$	17,648
	Long-term assets	—			24,756			443			25,199
	Current liabilities	—			2,992			1,043			4,035
	Long-term liabilities	—			6,739			918			7,657
Schedule of quantitative information about Level 3 inputs used in the fair value measurement	'
	The following table represents quantitative information about Level 3 inputs used in the fair value measurement of the Company’s commodity derivative contracts as of September 30, 2013.
		Quantitative Information About Level 3 Fair Value Measurements
	Commodity Price Hedges	Fair Value			Valuation Technique		Unobservable Input		Range
	Natural gas liquid swaps	$	2,354		Use a discounted cash flow approach using inputs including forward price statements from counterparties		Natural gas liquid futures prices		$8.09 - $84.89 per barrel
	Basis swaps	$	(89	)	Use a discounted cash flow approach using inputs including forward price statements from counterparties		Forward basis prices		$(0.17) - $0.05 per mmbtu
Schedule of changes in fair value of Level 3 financial instruments	'
	(in thousands of dollars)
	Balance at December 31, 2012, net	$	(1,519	)
	Purchases	—
	Settlements	(5		)
	Transfers to Level 2	260
	Transfers to Level 3	(716		)
	Changes in fair value	4,245
	Balance at September 30, 2013, net	$	2,265
Schedule of commodity derivative contracts which are netted on balance sheet	'
	(in thousands)	Gross Amounts		Gross Amounts		Net Amounts of		Gross Amounts		Net Amount
		of Recognized		Offset in the		Assets /		Not Offset in
		Assets /		Balance Sheet		Liabilities		the Balance
		Liabilities				Presented in the		Sheet
						Balance Sheet
	September 30, 2013
	Commodity derivative contracts
	Assets	45,843		(4,711	)	41,132		140		41,272
	Liabilities	(15,646	)	4,711		(10,935	)	—		(10,935	)
	December 31, 2012
	Commodity derivative contracts
	Assets	49,200		(7,831	)	41,369		1,478		42,847
	Liabilities	(17,928	)	7,831		(10,097	)	(1,595	)	(11,692	)

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities( Tables)	9 Months Ended
	Sep. 30, 2013
Derivative Instruments and Hedging Activities	'
Schedule of various commodity derivatives in place to offset uncertain price fluctuations that could affect the entity's future operations	'
		September 30, 2013
									Weighted			Final
			Low			High			Average			Expiration
	Oil swaps	Exercise price	$	81		$	104.45		$	89.26
		Barrels per month	24,000			143,116			88,325			December 2017
	Natural gas swaps	Exercise price	$	3.52		$	6.9		$	4.97
		mmbtu per month	430,000			1,110,000			726,337			December 2017
	Basis swaps	Contract differential	$	(0.45	)	$	(0.03	)	$	(0.33	)
		mmbtu per month	320,000			570,000			399,000			March 2016
	Natural gas liquids swaps	Exercise price	$	6.72		$	97.13		$	32.97
		Barrels per month	2,000			144,973			40,705			December 2017
		December 31, 2012
									Weighted			Final
			Low			High			Average			Expiration
	Oil swaps	Exercise price	$	81		$	104.45		$	89.6
		Barrels per month	24,000			143,116			89,323			December 2017
	Natural gas swaps	Exercise price	$	3.52		$	6.9		$	4.96
		mmbtu per month	430,000			1,110,000			767,053			December 2017
	Basis swaps	Contract differential	$	(0.65	)	$	(0.03	)	$	(0.31	)
		mmbtu per month	320,000			850,000			484,615			March 2016
	Natural gas liquids swaps	Exercise price	$	6.72		$	97.13		$	33.81
		Barrels per month	2,000			144,973			55,616			December 2017

Stockbased_Compensation_Tables

Stock-based Compensation (Tables)	9 Months Ended
	Sep. 30, 2013
Stock-based Compensation	'
Summary of JEH LLC Units and weighted average grant date fair value per share subject to the prior incentive plan held by the Company's management	'
		JEH LLC		Weighted Average
		Units		Grant Date Fair
				Value per Share
	Unvested at January 1, 2013	710,767		$	3.62
	Granted	911,654		$	15
	Forfeited	(167,239	)	$	(3.62	)
	Vested	(896,121	)	$	(10.68	)
	Unvested at September 30, 2013	559,061		$	10.85

Earnings_per_Share_Tables

Earnings per Share (Tables)	9 Months Ended
	Sep. 30, 2013
Earnings per Share	'
Schedule of calculation of the basic and diluted weighted-average shares	'
	(in thousands of dollars, except per share data)	Three Months Ended			Nine Months Ended
		September 30, 2013			September 30, 2013
	Income (numerator):
	Net income (loss) attributable to controlling interests	$	(821	)	$	(821	)
	Weighted-average shares (denominator):
	Weighted-average number of shares of Class A common stock - basic and diluted	12,500			12,500
	Earnings (loss) per share:
	Basic and diluted	$	(0.07	)	$	(0.07	)

Income_Taxes_Tables

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2013
Income Taxes	'
Schedule of income tax provision	'
		Three Months Ended September 30,					Nine Months Ended September 30,
	(in thousands of dollars)	2013			2012		2013			2012
	Current tax expense
	Federal	$	—		$	—	$	—		$	—
	State	15			—		48			—
	Total current expense	$	15		$	—	$	48		$	—
	Deferred tax expense (benefit)
	Federal	(359		)	—		(358		)	—
	State	—			104		217			327
	Total deferred expense (benefit)	$	(359	)	$	104	$	(141	)	$	327
	Total tax expense (benefit)	$	(344	)	$	104	$	(93	)	$	327
	Tax expense (benefit) attributable to controlling interests	(375		)	—		(375		)	—
	Tax expense attributable to non-controlling interests	31			104		282			327
	Total tax expense (benefit)	$	(344	)	$	104	$	(93	)	$	327

Organization_and_Description_o1

Organization and Description of Business (Details)	9 Months Ended	0 Months Ended
	Sep. 30, 2013	Jul. 29, 2013	Jul. 29, 2013
	item	JEH LLC	Class A common stock
			Owners of JEH LLC
Organization and description of business	'	'	'
Number of classes of common stock	2	'	'
Number of distinct basins where entity's assets are located	2	'	'
Number of industry segments	1	'	'
Number of geographic areas in which the entity operates	1	'	'
Exchange ratio	0	'	1
Economic interest (as a percent)	'	74.70%	'

Significant_Accounting_Policie3

Significant Accounting Policies (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
			item
Mineral interests in properties	'	'	'	'	'
Unproved	$107,971,000	'	$107,971,000	'	$137,254,000
Proved	784,268,000	'	784,268,000	'	737,558,000
Wells and equipment and related facilities	526,930,000	'	526,930,000	'	389,727,000
Gross oil and gas properties	1,419,169,000	'	1,419,169,000	'	1,264,539,000
Less: Accumulated depletion and impairment	-339,115,000	'	-339,115,000	'	-257,195,000
Net oil and gas properties	1,080,054,000	'	1,080,054,000	'	1,007,344,000
Costs capitalized in connection with exploratory wells in progress	0	'	0	'	0
Minimum project period for capitalization of interest on expenditures	'	'	'6 months	'	'
Number of projects for which interest on expenditure is capitalized	'	'	0	'	'
Depletion of oil and gas properties	30,300,000	21,000,000	81,900,000	57,700,000	'
Other Property, Plant and Equipment	'	'	'	'	'
Gross other property, plant and equipment	4,216,000	'	4,216,000	'	5,335,000
Less: Accumulated depreciation and amortization	-1,737,000	'	-1,737,000	'	-1,937,000
Net other property, plant and equipment	2,479,000	'	2,479,000	'	3,398,000
Depreciation and amortization of other property, plant and equipment	200,000	200,000	600,000	600,000	'
Asset Retirement Obligations	'	'	'	'	'
Balance at the beginning of the period	'	'	9,506,000	'	'
Liabilities incurred	'	'	499,000	257,000	'
Accretion of discount	'	'	434,000	'	'
Liabilities settled due to sale of related properties	'	'	-4,000	'	'
Liabilities settled due to plugging and abandonment	'	'	-437,000	'	'
Change in estimate	'	'	201,000	'	'
Balance at the end of the period	10,199,000	'	10,199,000	'	'
Less: Current portion of ARO	-174,000	'	-174,000	'	-174,000
Total long-term ARO	10,025,000	'	10,025,000	'	9,332,000
Income Taxes	'	'	'	'	'
Provision for federal income taxes	'	'	0	'	'
Tax Receivable Agreement	'	'	'	'	'
Cash savings to be paid under tax receivable agreement with JEH LLC and the existing owners (as a percent)	'	'	85.00%	'	'
Benefits of cash savings retained under tax receivable agreement (as a percent)	'	'	15.00%	'	'
Exchange ratio of units with JEH LLC and the existing owners	0	'	0	'	'
Minimum	'	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'	'
Estimated useful lives	'	'	'3 years	'	'
Maximum	'	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'	'
Estimated useful lives	'	'	'10 years	'	'
Leasehold improvements	'	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'	'
Gross other property, plant and equipment	1,004,000	'	1,004,000	'	983,000
Furniture, fixtures, computers and software	'	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'	'
Gross other property, plant and equipment	2,346,000	'	2,346,000	'	2,204,000
Vehicles	'	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'	'
Gross other property, plant and equipment	732,000	'	732,000	'	719,000
Aircraft	'	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'	'
Gross other property, plant and equipment	'	'	'	'	1,295,000
Land	'	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'	'
Gross other property, plant and equipment	62,000	'	62,000	'	62,000
Production Equipment	'	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'	'
Gross other property, plant and equipment	$72,000	'	$72,000	'	$72,000

Acquisition_of_Properties_Deta

Acquisition of Properties (Details) (USD $)	3 Months Ended		9 Months Ended		0 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 20, 2012
					Chalker acquisition
Acquisition of Properties	'	'	'	'	'
Initial purchase price	'	'	'	'	$251,900,000
Oil and gas properties	'	'	'	'	'
Unproved	'	'	'	'	71,264,000
Proved	'	'	'	'	182,493,000
Asset retirement obligations	'	'	'	'	-293,000
Total purchase price	'	'	'	'	253,464,000
Actual	'	'	'	'	'
Total operating revenues	68,851,000	31,935,000	188,857,000	106,086,000	'
Total operating expenses	56,756,000	32,259,000	138,466,000	91,570,000	'
Operating income (expense)	12,095,000	-324,000	50,391,000	14,516,000	'
Net income	-821,000	-24,375,000	-821,000	18,004,000	'
Pro Forma	'	'	'	'	'
Total operating revenue	'	43,384,000	'	135,824,000	'
Total operating expenses	'	33,185,000	'	94,128,000	'
Operating income (loss)	'	10,199,000	'	41,696,000	'
Net income (loss)	'	($13,852,000)	'	$45,184,000	'

Fair_Value_Measurement_Details

Fair Value Measurement (Details) (USD $)	Sep. 30, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Fair Value Measurements	'	'
Current assets	$14,681	$17,648
Long-term assets	26,591	25,199
Current liabilities	10,424	4,035
Long-term liabilities	511	7,657
Level 2 | Commodity Price Hedges	'	'
Fair Value Measurements	'	'
Current assets	14,501	17,648
Long-term assets	24,431	24,756
Current liabilities	10,349	2,992
Long-term liabilities	511	6,739
Level 3 | Commodity Price Hedges	'	'
Fair Value Measurements	'	'
Current assets	180	'
Long-term assets	2,160	443
Current liabilities	75	1,043
Long-term liabilities	'	918
Total | Commodity Price Hedges	'	'
Fair Value Measurements	'	'
Current assets	14,681	17,648
Long-term assets	26,591	25,199
Current liabilities	10,424	4,035
Long-term liabilities	$511	$7,657

Fair_Value_Measurement_Details1

Fair Value Measurement (Details 2) (USD $)	9 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Natural gas liquid | Swap | Minimum	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Swap price (in dollars per barrel/mmbtu)	6.72	6.72
Natural gas liquid | Swap | Maximum	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Swap price (in dollars per barrel/mmbtu)	97.13	97.13
Commodity derivatives	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Fair Value	$15,646	$17,928
Discounted cash flow approach | Level 3 | Commodity derivatives | Basis swaps | Forward basis	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Fair Value	-89	'
Discounted cash flow approach | Level 3 | Commodity derivatives | Basis swaps | Forward basis | Minimum	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Swap price (in dollars per barrel/mmbtu)	-0.17	'
Discounted cash flow approach | Level 3 | Commodity derivatives | Basis swaps | Forward basis | Maximum	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Swap price (in dollars per barrel/mmbtu)	0.05	'
Discounted cash flow approach | Level 3 | Commodity derivatives | Natural gas liquid | Swap	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Fair Value	$2,354	'
Discounted cash flow approach | Level 3 | Commodity derivatives | Natural gas liquid | Swap | Minimum	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Swap price (in dollars per barrel/mmbtu)	8.09	'
Discounted cash flow approach | Level 3 | Commodity derivatives | Natural gas liquid | Swap | Maximum	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Swap price (in dollars per barrel/mmbtu)	84.89	'

Fair_Value_Measurement_Details2

Fair Value Measurement (Details 3) (USD $)	9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Dec. 31, 2012
	item		Commodity derivative contracts	Commodity derivative contracts
Changes in fair value of Level 3 instruments	'	'	'	'
Balance at the beginning of the period	($1,519)	'	'	'
Settlements	-5	'	'	'
Transfer to Level 2	260	'	'	'
Transfers to Level 3	-716	'	'	'
Changes in fair value	4,245	'	'	'
Balance at the end of the period	2,265	'	'	'
Offsetting Assets and Liabilities	'	'	'	'
Number of counterparties to commodity derivative contracts	6	'	'	'
Assets	'	'	'	'
Gross Amounts of Recognized Assets / Liabilities	'	'	45,843	49,200
Gross Amounts Offset in the Balance Sheet	'	'	-4,711	-7,831
Net Amounts of Assets Presented in the Balance Sheet	'	'	41,132	41,369
Gross Amounts Not Offset in the Balance Sheet	'	'	140	1,478
Net Amount	'	'	41,272	42,847
Liabilities	'	'	'	'
Gross Amounts of Recognized Assets	'	'	-15,646	-17,928
Gross Amounts Offset in the Balance Sheet	'	'	4,711	7,831
Net Amounts of Assets Presented in the Balance Sheet	'	'	-10,935	-10,097
Gross Amounts Not Offset in the Balance Sheet	'	'	'	-1,595
Net Amount	'	'	-10,935	-11,692
Nonfinancial Assets and Liabilities	'	'	'	'
Impairment of oil and gas properties	'	61	'	'
Impairment of proved properties	0	0	'	'
Impairment of unproved properties	$0	$0	'	'

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Details) (USD $)

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

3 Months Ended

9 Months Ended

In Millions, unless otherwise specified

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2012

Sep. 30, 2013

Sep. 30, 2012

Sep. 30, 2013

Sep. 30, 2012

Basis swaps

Basis swaps

Basis swaps

Basis swaps

Basis swaps

Basis swaps

Oil

Oil

Oil

Oil

Oil

Oil

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas

Natural gas liquids

Natural gas liquids

Natural gas liquids

Natural gas liquids

Natural gas liquids

Natural gas liquids

Commodity derivatives

Commodity derivatives

Commodity derivatives

Commodity derivatives

Low

Low

High

High

Weighted Average

Weighted Average

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Swaps

Low

Low

High

High

Weighted Average

Weighted Average

Low

Low

High

High

Weighted Average

Weighted Average

Low

Low

High

High

Weighted Average

Weighted Average

Derivative instruments and hedging activities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Exercise price (in dollars per barrels)

'

'

'

'

'

'

81

81

104.45

104.45

89.26

89.6

'

'

'

'

'

'

6.72

6.72

97.13

97.13

32.97

33.81

'

'

'

'

Nonmonetary notional amount

'

'

'

'

'

'

24,000

24,000

143,116

143,116

88,325

89,323

'

'

'

'

'

'

2,000

2,000

144,973

144,973

40,705

55,616

'

'

'

'

Exercise price (in dollars per mmbtu)

'

'

'

'

'

'

'

'

'

'

'

'

3.52

3.52

6.9

6.9

4.97

4.96

'

'

'

'

'

'

'

'

'

'

Nonmonetary notional amount

320,000

320,000

570,000

850,000

399,000

484,615

'

'

'

'

'

'

430,000

430,000

1,110,000

1,110,000

726,337

767,053

'

'

'

'

'

'

'

'

'

'

Contract differential (in dollars per mmbtu)

-0.45

-0.65

-0.03

-0.03

-0.33

-0.31

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net gain (loss) recognized on derivative instruments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($20.70)

($18.40)

$4.40

$20.10

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended			9 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2009	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Jun. 12, 2013	Sep. 30, 2013
			item		item	Revolver	Revolver	Revolver	Revolver	Revolver	Term Loan
Credit agreements	'	'	'	'	'	'	'	'	'	'	'
Number of credit agreements	'	'	'	'	2	'	'	'	'	'	'
Borrowing base	'	'	'	'	'	'	'	'	'	$500	'
Number of credit facilities	'	'	2	'	'	'	'	'	'	'	'
Frequency of interest payments	'	'	'3 months	'	'	'	'	'	'	'	'3 months
Average interest rates (as a percent)	'	'	'	'	'	2.74%	3.39%	3.04%	3.23%	'	'
Average outstanding balance	'	'	'	'	'	330.6	304.3	406.7	299	'	'
Total interest and commitment fees	6.2	4.8	20.7	15.2	'	'	'	'	'	'	'
Repayment of borrowings	'	'	'	'	'	'	'	$167	'	'	'

Stockbased_Compensation_Detail

Stock-based Compensation (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Stock-based Compensation	'	'	'	'
Stock compensation expense	'	'	$2,592	'
Management units | JEH LLC | General and administrative expenses	'	'	'	'
Stock-based Compensation	'	'	'	'
Stock compensation expense	$9,900	$100	$10,400	$400
Management units | JEH LLC | Management	'	'	'	'
JEH LLC Units	'	'	'	'
Unvested at the beginning of the period (in shares)	'	'	710,767	'
Granted (in shares)	'	'	911,654	'
Forfeited (in shares)	'	'	-167,239	'
Vested (in shares)	'	'	-896,121	'
Unvested at the end of the period (in shares)	559,061	'	559,061	'
Weighted Average Grant Date Fair Value per Share	'	'	'	'
Unvested at the beginning of the period (in dollars per share)	'	'	$3.62	'
Granted (in dollars per share)	'	'	$15	'
Forfeited (in dollars per share)	'	'	($3.62)	'
Vested (in dollars per share)	'	'	($10.68)	'
Unvested at the end of the period (in dollars per share)	$10.85	'	$10.85	'

Earnings_per_Share_Details

Earnings per Share (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, except Share data, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Income (numerator):	'	'	'	'
Net income (loss) applicable to controlling interests	($821)	($24,375)	($821)	$18,004
Weighted-average shares (denominator):	'	'	'	'
Weighted-average number of shares of Class A common stock - basic and diluted	12,500	'	12,500	'
Earnings (loss) per share:	'	'	'	'
Basic and diluted (in dollars per share)	($0.07)	'	($0.07)	'

Monarch_Investment_Details

Monarch Investment (Details) (USD $)	9 Months Ended	3 Months Ended	0 Months Ended	3 Months Ended
	Sep. 30, 2013	Sep. 30, 2013	7-May-13	Sep. 30, 2013	7-May-13
		Equity interests issued to the Company in connection with the marketing agreement	Equity interests issued to the Company in connection with the marketing agreement	Monarch	Monarch
			Equity interests		Equity interests issued to the Company in connection with the marketing agreement
			Monarch Natural Gas Holdings, LLC		Equity interests
					Monarch Natural Gas Holdings, LLC
Monarch Investment	'	'	'	'	'
Estimated fair value of equity interests issued to the entity	'	'	'	'	$15,000,000
Equity interests distributed to the entity's owners (as a percent)	'	'	67.00%	'	'
Equity interests distributed to the management (as a percent)	'	'	16.00%	'	'
Equity interests reserved for distribution to management through incentive plan (as a percent)	'	'	17.00%	'	'
Compensation expense recognized under management distributions and incentive plan	2,592,000	0	'	'	'
Deferred revenue recorded	14,886,000	15,000,000	'	'	'
Amortization of deferred revenue	'	'	'	$100,000	'

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended		9 Months Ended
In Thousands, unless otherwise specified	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Current tax expense	'	'	'	'
State	$15	'	$48	'
Total current expense	15	'	48	'
Deferred tax expense (benefit)	'	'	'	'
Federal	-359	'	-358	'
State	'	104	217	327
Total deferred expense (benefit)	-359	104	-141	327
Total income tax provision	-344	104	-93	327
Tax expense (benefit) attributable to controlling interests	-375	'	-375	'
Tax expense attributable to non-controlling interests	$31	$104	$282	$327