Jones Energy (JONEQ) 10-Q 9 May 14 2014 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2014	1-May-14	1-May-14
		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	31-Mar-14	'	'
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	'2014	'	'
Document Fiscal Period Focus	'Q1	'	'

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets	'	'
Cash	$27,297	$23,820
Restricted Cash	67	45
Accounts receivable, net	'	'
Oil and gas sales	80,500	51,233
Joint interest owners	58,895	42,481
Other	4,247	16,782
Commodity derivative assets	4,168	8,837
Other current assets	2,501	2,392
Deferred tax assets	12	12
Total current assets	177,687	145,602
Oil and gas properties, net, at cost under the successful efforts method	1,363,393	1,297,228
Other property, plant and equipment, net	3,472	3,444
Commodity derivative assets	20,806	25,398
Other assets	14,264	15,006
Deferred tax assets	618	1,301
Total assets	1,580,240	1,487,979
Current liabilities	'	'
Trade accounts payable	126,785	89,430
Oil and gas sales payable	82,979	66,179
Accrued liabilities	17,485	10,805
Commodity derivative liabilities	11,830	10,664
Asset retirement obligations	2,794	2,590
Total current liabilities	241,873	179,668
Long-term debt	678,000	658,000
Deferred revenue	14,287	14,531
Commodity derivative liabilities	104	190
Asset retirement obligations	8,633	8,373
Deferred tax liabilities	3,375	3,093
Total liabilities	946,272	863,855
Commitments and contingencies (Note 9)	'	'
Stockholders' equity	'	'
Additional paid-in-capital	173,626	173,169
Retained deficit	-514	-2,186
Stockholders' equity	173,162	171,033
Non-controlling interest	460,806	453,091
Total stockholders' equity	633,968	624,124
Total liabilities and stockholders' equity	1,580,240	1,487,979
Class A common stock	'	'
Stockholders' equity	'	'
Common stock	13	13
Class B common stock	'	'
Stockholders' equity	'	'
Common stock	$37	$37

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (Common stock, USD $)	Mar. 31, 2014	Dec. 31, 2013
Class A common stock	'	'
Common Stock, par value (in dollars per share)	$0.00	$0.00
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 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
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating revenues	'	'
Oil and gas sales	$97,867	$55,259
Other revenues	377	221
Total operating revenues	98,244	55,480
Operating costs and expenses	'	'
Lease operating	10,014	5,345
Production taxes	4,762	2,452
Exploration	2,821	126
Depletion, depreciation and amortization	39,345	25,101
Accretion of discount	170	97
General and administrative (including non-cash compensation expense)	5,260	4,312
Total operating expenses	62,372	37,433
Operating income	35,872	18,047
Other income (expense)	'	'
Interest expense	-8,043	-8,187
Net loss on commodity derivatives	-17,250	-11,383
Gain on sales of assets	65	70
Other income (expense), net	-25,228	-19,500
Income (loss) before income tax	10,644	-1,453
Income tax provision	1,257	-1
Net income (loss)	9,387	-1,452
Net income attributable to non-controlling interests	7,715	'
Net income (loss) attributable to controlling interests	$1,672	($1,452)
Earnings per share:	'	'
Basic (in dollars per share)	$0.13	'
Diluted (in dollars per share)	$0.13	'
Weighted average shares outstanding:	'	'
Basic (in shares)	12,500	'
Diluted (in shares)	12,512	'

Consolidated_Statement_of_Chan

Consolidated Statement of Changes In Stockholders' Equity (USD $)	Total	Common Stock	Common Stock	Additional Paid-in-Capital	Retained Earnings	Non-controlling Interest
In Thousands, except Share data, unless otherwise specified		Class A common stock	Class B common stock
Balance at Dec. 31, 2013	$624,124	$13	$37	$173,169	($2,186)	$453,091
Balance (in shares) at Dec. 31, 2013	'	12,526,580	36,836,333	'	'	'
Increase (Decrease) Stockholders' equity	'	'	'	'	'	'
Stock-compensation expense	457	'	'	457	'	'
Net income	9,387	'	'	'	1,672	7,715
Balance at Mar. 31, 2014	$633,968	$13	$37	$173,626	($514)	$460,806
Balance (in shares) at Mar. 31, 2014	'	12,526,580	36,836,333	'	'	'

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Cash flows from operating activities	'	'
Net income (loss)	$9,387	($1,452)
Adjustments to reconcile net income to net cash provided by operating activities	'	'
Exploration expense	2,767	'
Depletion, depreciation, and amortization	39,345	25,101
Accretion of discount	170	97
Amortization of debt issuance costs	700	664
Stock compensation expense	457	120
Other non-cash compensation expense	127	'
Amortization of deferred revenue	-244	'
Net loss on commodity derivatives	17,250	11,383
Gain on sales of assets	-65	-70
Deferred income taxes	966	-23
Other - net	67	165
Changes in assets and liabilities	'	'
Accounts receivable	-46,893	-7,846
Other assets	428	-2,768
Accounts payable and accrued liabilities	35,746	5,625
Net cash provided by operations	60,208	30,996
Cash flows from investing activities	'	'
Additions to oil and gas properties	-85,028	-36,883
Net adjustments to purchase price of properties acquired	13,681	'
Proceeds from sales of assets	66	2
Acquisition of other property, plant and equipment	-270	-51
Current period settlements of matured derivative contracts	-4,663	4,039
Change in restricted cash	-22	'
Net cash used in investing	-76,236	-32,893
Cash flows from financing activities	'	'
Proceeds from issuance of long-term debt	20,000	'
Repayment under long-term debt	'	-5,000
Payment of debt issuance costs	-495	-25
Net cash provided by (used in) financing	19,505	-5,025
Net increase (decrease) in cash	3,477	-6,922
Cash	'	'
Beginning of period	23,820	23,726
End of period	27,297	16,804
Supplemental disclosure of cash flow information	'	'
Cash paid for interest	6,814	6,325
Change in accrued additions to oil and gas properties	22,714	6,625
Current additions to ARO	330	69
Deferred offering costs	$408	$1,534

Organization_and_Description_o

Organization and Description of Business	3 Months Ended
	Mar. 31, 2014
Organization and Description of Business	'
Organization and Description of Business	'
	1.                            Organization and Description of Business
	Organization
	Jones Energy, Inc. (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”). As the sole managing member of JEH, Jones Energy, Inc. is responsible for all operational, management and administrative decisions relating to JEH’s business and consolidates the financial results of JEH and its subsidiaries.
	JEH 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 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.
	Pursuant to the terms of a corporate reorganization that was completed in connection with the closing of Jones Energy, Inc.’s initial public offering (“IPO”) on July 29, 2013, the pre-IPO owners of JEH converted their existing membership interests in JEH into JEH Units and amended the existing LLC agreement to, among other things, modify its equity capital to consist solely of JEH Units and to admit Jones Energy, Inc. as the sole managing member of JEH. Jones Energy, Inc.’s certificate of incorporation authorizes two classes of common stock, Class A common stock and Class B common stock. Only Class A common stock was offered to investors pursuant to the IPO. The Class B common stock is held by the pre-IPO owners of JEH and can be exchanged (together with a corresponding number of JEH 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. The Class B common stock has no economic rights but entitles its holder to one vote on all matters to be voted on by the Company’s stockholders generally. As a result of the IPO, the pre-IPO owners retained 74.7% of the total economic interest in JEH, but with no voting rights or management power over JEH, resulting in the Company reporting this ownership interest as a non-controlling interest.
	Description of Business
	The Company is engaged in the acquisition, exploration, and production of oil and natural gas properties in the mid-continent United States. The Company’s assets are located within two distinct basins in the Texas Panhandle and Oklahoma, the Anadarko Basin and the Arkoma Basin, and are owned by JEH 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.
	Revision of Previously Issued Financial Statements
	In conjunction with our year-end audit and the preparation of our annual Form 10-K, we identified an error in our previously issued financial statements which would have been material to our fourth quarter of 2013 if recorded as an out of period adjustment in such period. We recorded the adjustments on a quarterly basis in prior periods and therefore, have revised our Consolidated Statement of Operations for the three months ended March 31, 2013 to record $0.2 million of additional interest expense on obligations that are unrelated to our credit agreements discussed in Note 6.

Significant_Accounting_Policie

Significant Accounting Policies	3 Months Ended
	Mar. 31, 2014
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”). All significant intercompany transactions and balances have been eliminated in consolidation. The financial statements reported for March 31, 2014, and the three month period then ended include the Company and all of its subsidiaries.
	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 Annual Report on Form 10-K for the year ended December 31, 2013.
	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, fair value associated with business combinations, 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 March 31, 2014 and December 31, 2013:
		March 31,			December 31,
	(in thousands of dollars)	2014			2013
	Mineral interests in properties
	Unproved	$	93,386		$	99,134
	Proved	970,222			958,816
	Wells and equipment and related facilities	709,358			609,748
		1,772,966			1,667,698
	Less: Accumulated depletion and impairment	(409,573		)	(370,470		)
	Net oil and gas properties	$	1,363,393		$	1,297,228
	Costs to acquire mineral interests in oil and natural gas properties are capitalized. Costs to drill and equip development wells and the related asset retirement costs are capitalized. The costs to drill and equip exploratory wells are capitalized pending determination of whether the Company has discovered proved commercial reserves. If proved commercial reserves are not discovered, such drilling costs are charged to expense. In some circumstances, it may be uncertain whether proved commercial reserves have been found when drilling has been completed. Such exploratory well drilling costs may continue to be capitalized if the anticipated reserve quantity is sufficient to justify its completion as a producing well and sufficient progress in assessing the reserves and the economic and operating viability of the project is being made. In the first quarter of 2014 we had no material capitalized costs associated with exploratory wells.
	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 three months ended March 31, 2014 as no projects lasted more than six months. Depletion of oil and gas properties amounted to $39.1 million and $24.9 million for the periods ended March 31, 2014 and March 31, 2013, respectively.
	Other Property, Plant and Equipment
	Other property, plant and equipment consisted of the following at March 31, 2014 and December 31, 2013:
		March 31,			December 31,
	(in thousands of dollars)	2014			2013
	Leasehold improvements	$	1,116		$	1,060
	Furniture, fixtures, computers and software	2,705			2,491
	Vehicles	833			835
	Aircraft	910			910
	Other	133			134
		5,697			5,430
	Less: Accumulated depreciation and amortization	(2,225		)	(1,986		)
	Net other property, plant and equipment	$	3,472		$	3,444
	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 $0.2 million during the three months ended March 31, 2014 and 2013, 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 periods ended March 31, 2014 and 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 the Company 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
	The Company’s asset retirement obligations consist of future plugging and abandonment expenses on oil and natural gas properties.
	A summary of the Company’s ARO for three months ended March 31, 2014 is as follows:
	(in thousands of dollars)
	Balance at December 31, 2013	$	10,963
	Liabilities incurred	330
	Accretion of discount	170
	Liabilities settled due to sale of related properties	—
	Liabilities settled due to plugging and abandonment	(49		)
	Change in estimate	13
	Balance at March 31, 2014	11,427
	Less: Current portion of ARO	(2,794		)
	Total long-term ARO at March 31, 2014	$	8,633
	Income Taxes
	Following its IPO on July 29, 2013, the Company began recording a federal and state income tax liability associated with its status as a corporation. No provision for federal income taxes was recorded prior to the IPO because the taxable income or loss was includable in the income tax returns of the individual partners and members. The Company is also subject to state income taxes. The State of Texas includes in its tax system a franchise tax applicable to the Company and an accrual for franchise taxes is included in the financial statements when appropriate.
	Income taxes are accounted for under the asset and liability method, which requires recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial statements and tax basis of assets and liabilities using enacted tax rates in effect for the year in which differences are expected to be recovered or settled pursuant to the provisions of ASC 740—Income Taxes. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date.
	The Company records a valuation allowance if it is deemed more likely than not that all or a portion of its deferred income tax assets will not be realized. In addition, income tax rules and regulations are subject to interpretation and the application of those rules and regulations require judgment by the Company and may be challenged by the taxation authorities. The Company follows ASC 740-10-25, which requires the use of a two-step approach for recognizing and measuring tax benefits taken or expected to be taken in a tax return and disclosures regarding uncertainties in income tax positions. Only tax positions that meet the more likely than not recognition threshold are recognized. The Company’s policy is to include any interest and penalties recorded on uncertain tax positions as a component of income tax expense. The Company’s unrecognized tax benefits or related interest and penalties are immaterial.
	Tax Receivable Agreement
	In conjunction with the IPO, the Company entered into a Tax Receivable Agreement (“TRA”) with JEH and the pre-IPO owners. Upon any exchange of JEH—Units and Class B common stock of the Company held by JEH’s pre-IPO owners for Class A common stock of the Company, the TRA provides for the payment by the Company, directly to such exchanging owners, of 85% of the amount of cash savings in income or franchise taxes that the Company realizes as a result of (i) the tax basis increases resulting from the exchange of JEH Units for shares of Class A common stock (or resulting from a sale of JEH 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 the TRA will be recognized upon the exchange of shares. As of March 31, 2014, there had been no exchanges and no liability is recorded on the Consolidated Balance Sheet.
	Stock Compensation
	JEH has a management incentive plan that provides membership-interest awards in JEH to members of senior management (“management units”). The management unit grants awarded prior to the initial filing of the registration statement in March 2013 had a dual vesting schedule. Sixty percent of the units awarded vested in five equal annual installments, with the remaining 40% vesting upon a company restructuring event, including the IPO. All grants awarded after the initial registration statement but prior to the IPO have a single vesting structure of five equal annual installments and were valued at the IPO price, adjusted for equivalent shares. Both the vested and unvested management units were converted into JEH Units and shares of Class B common stock at the IPO date.
	Under the Jones Energy, Inc. 2013 Omnibus Incentive Plan, established in conjunction with the Company’s IPO, the Company reserved 3,850,000 shares of Class A common stock for director and employee stock-based compensation awards. As of March 31, 2014 no such awards had been issued or granted to any of the Company’s employees.
	In September 2013, the Company granted each of the four outside members of the Board of Directors 6,645 shares of restricted Class A common stock under the Jones Energy, Inc. 2013 Omnibus Incentive Plan. The fair value of the restricted stock grants was based on the value of the Company’s Class A common stock on the date of grant and is expensed on a straight-line basis over the one-year vesting period.
	Refer to Note 7, “Stock-based Compensation,” for additional information regarding the management units and restricted stock awards.
	Recent Accounting Developments
	There are no recent accounting developments applicable to the Company as of March 31, 2014.

Acquisition_of_Properties

Acquisition of Properties	3 Months Ended
	Mar. 31, 2014
Acquisition of Properties	'
Acquisition of Properties	'
	3.                            Acquisition of Properties
	No property acquisitions that would qualify as a business combination occurred during the three months ended March 31, 2014.
	On December 18, 2013, JEH closed on the purchase of certain oil and natural gas properties located in Texas and western Oklahoma from Sabine Mid-Continent, LLC, for a purchase price of $193.5 million (referred to herein as the “Sabine acquisition” or “Sabine”), subject to customary closing adjustments. The acquired assets include both producing properties and undeveloped acreage. The purchase was financed with borrowings under the senior secured credit facility.
	In connection with the closing, approximately $24 million of the purchase price was placed in an escrow account. This amount represented the allocated value of the Sabine properties that had unresolved title defects claimed by JEH. In March, the Company settled the title negotiations resulting in $13.7 million of the escrowed funds being returned to the Company. In addition, preliminary adjustments to the purchase price totaling $1.6 million were accrued as of the end of the quarter. The amount of the total purchase price allocated to unproven oil and gas properties was reduced by these adjustments. The adjustments were retroactively applied to our December 31, 2013 Consolidated Balance Sheet as a reduction to oil and gas properties and an increase in receivables. The adjusted purchase price is allocated as follows:
	(in thousands of dollars)
	Oil and gas properties
	Unproved	$	24,273
	Proved	154,724
	Asset retirement obligations	(824		)
	Total purchase price	$	178,173
	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 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 determination of fair value is dependent on factors as of the acquisition date and the final adjustments to the purchase price, which when they occur, may result in an adjustment to the value of the acquired properties reflected in the consolidated financial statements. Any such adjustment may be material.
	The unaudited pro forma results presented below have been prepared to give the effect of the acquisition on our results of operations for the quarter ended March 31, 2013. 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, 2013 or to project our results of operations for any future date or period.
		Three Months Ended March 31, 2013
	(in thousands of dollars)	Actual			Pro Forma
	Total operating revenue	$	55,480		$	69,668
	Total operating expenses	37,433			44,668
	Operating income (loss)	18,047			25,000
	Net income (loss)	(1,452		)	5,501

Fair_Value_Measurement

Fair Value Measurement	3 Months Ended
	Mar. 31, 2014
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 March 31, 2014 and December 31, 2013, by consolidated balance sheet caption and by valuation hierarchy, as described above are as follows:
		March 31, 2014
	(in thousands of dollars)	Fair Value Measurements
	Commodity Price Hedges	(Level 1)		(Level 2)			(Level 3)			Total
	Current assets			$	4,289		$	(121	)	$	4,168
	Long-term assets			20,796			10			20,806
	Current liabilities			11,214			616			11,830
	Long-term liabilities			—			104			104
		December 31, 2013
	(in thousands of dollars)	Fair Value Measurements
	Commodity Price Hedges	(Level 1)			(Level 2)			(Level 3)			Total
	Current assets	$	—		$	8,837		$	—		$	8,837
	Long-term assets	—			25,967			(569		)	25,398
	Current liabilities	—			10,188			476			10,664
	Long-term liabilities	—			—			190			190
	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 March 31, 2014.
		Quantitative Information About Level 3 Fair Value Measurements
	Commodity Price Hedges	Fair Value		Valuation Technique		Unobservable Input		Range
	Natural gas liquid swaps			Use a discounted cash flow approach using inputs including forward price statements from counterparties		Natural gas liquid futures prices		$8.93 - $84.68 per barrel
	Basis swaps			Use a discounted cash flow approach using inputs including forward price statements from counterparties		Forward basis prices		$(0.22) - $0.25 per mmbtu
	Significant increases/decreases in natural gas liquid futures 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 three months ended March 31, 2014. 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, 2013, net	$	(1,235	)
	Purchases	—
	Settlements	—
	Transfers to Level 2	(152		)
	Transfers to Level 3	(204		)
	Changes in fair value	760
	Balance at March 31, 2014, net	$	(831	)
	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 hedges 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 March 31, 2014. There were no purchases or settlements in the period that resulted in changes to Level 3.
	Offsetting Assets and Liabilities
	As of March 31, 2014 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 Consolidated Balance Sheet as of March 31, 2014 and December 31, 2013:
	(in thousands)	Gross Amounts		Gross Amounts		Net Amounts of		Gross Amounts		Net Amount
		of Recognized		Offset in the		Assets / Liabilities		Not Offset in the
		Assets /		Balance Sheet		Presented in the		Balance Sheet
		Liabilities				Balance Sheet
	March 31, 2014
	Commodity derivative contracts
	Assets	32,656		(7,807	)	24,849		125		24,974
	Liabilities	(19,741	)	7,807		(11,934	)	—		(11,934	)
	December 31, 2013
	Commodity derivative contracts
	Assets	38,071		(6,035	)	32,036		2,199		34,235
	Liabilities	(14,347	)	6,035		(8,312	)	(2,542	)	(10,854	)
	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. No impairment charges on the Company’s proved properties were recorded during the three months ended March 31, 2014. Additionally, the Company assessed its unproved properties for impairment as of March 31, 2014 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.

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2014
Derivative Instruments and Hedging Activities	'
Derivative Instruments and Hedging Activities	'
	5.                            Derivative Instruments and Hedging Activities
	The Company had various commodity derivatives in place to offset uncertain price fluctuations that could affect its future operations as of March 31, 2014 and December 31, 2013, as follows:
	Hedging Positions
		March 31, 2014
									Weighted			Final
			Low			High			Average			Expiration
	Oil swaps	Exercise price	$	81.7		$	102.33		$	88.78
		Barrels per month	29,000			157,884			91,912			December 2017
	Natural gas swaps	Exercise price	$	3.88		$	6.9		$	4.84
		mmbtu per month	510,000			1,220,000			802,738			December 2017
	Basis swaps	Contract differential	$	(0.43	)	$	(0.11	)	$	(0.33	)
		mmbtu per month	320,000			630,000			441,667			March 2016
	Natural gas liquids swaps	Exercise price	$	6.72		$	95.24		$	33.64
		Barrels per month	2,000			115,000			42,000			December 2017
		December 31, 2013
									Weighted			Final
			Low			High			Average			Expiration
	Oil swaps	Exercise price	$	81.7		$	102.84		$	89.03
		Barrels per month	29,000			161,613			96,149			December 2017
	Natural gas swaps	Exercise price	$	3.88		$	6.9		$	4.26
		mmbtu per month	510,000			1,290,000			830,275			December 2017
	Basis swaps	Contract differential	$	(0.43	)	$	(0.11	)	$	(0.34	)
		mmbtu per month	320,000			690,000			467,037			March 2016
	Natural gas liquids swaps	Exercise price	$	6.72		$	95.24		$	32.98
		Barrels per month	2,000			118,000			46,646			December 2017
	The Company recognized a net loss on derivative instruments of $17.3 million for the three months ended March 31, 2014 and a net loss of $11.4 million for the three months ended March 31, 2013.

LongTerm_Debt

Long-Term Debt	3 Months Ended
	Mar. 31, 2014
Long-Term Debt	'
Long-Term Debt	'
	6.                            Long-Term Debt
	In December 2009, the Company entered into two credit agreements, with Wells Fargo Bank N.A, the Senior Secured Revolving Credit Facility (the “Revolver”) and the Second Lien Term Loan (the “Term Loan”), each of which were subsequently amended in November 2011, November 2012, December 2012, June 2013, December 2013 and January 2014. 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, and in connection with the December 2013 amendment, the borrowing base on the Revolver was subsequently increased to $575.0 million in conjunction with the Sabine acquisition. The Company’s oil and gas properties are pledged as collateral against these credit agreements.
	Terms of the Revolver require the Company to pay interest on the loan on the earlier of the London InterBank Offered Rate (LIBOR) tranche maturity date or three months, with the entire principal and interest due on the loan maturity date. Borrowings may be drawn on the principal amount up to the maximum available credit amount. Interest on the Revolver is calculated at a base rate (LIBOR or prime), plus a margin of 0.50% to 2.50% based on the actual amount borrowed compared to the borrowing base amount and the base rate selected. For the three months ended March 31, 2014, the average interest rate under the Revolver was 2.87% on an average outstanding balance of $510.4 million.
	Terms of the Term Loan require the Company to pay interest on the loan every three months with the principal and interest due on the loan maturity date of May 5, 2018. Interest on the Term Loan is calculated at a base rate (LIBOR, prime, or federal funds), plus a margin of 6% to 7% based on the base rate selected. For the three months ended March 31, 2014, the average interest rate under the Term Loan was 9.13% on an average outstanding balance of $160.0 million.
	Total interest and commitment fees under the two facilities were $7.3 million and $7.3 million for the three months ended March 31, 2014 and 2013, respectively.
	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. The Company was in compliance with these covenants at March 31, 2014.

Stockbased_Compensation

Stock-based Compensation	3 Months Ended
	Mar. 31, 2014
Stock-based Compensation	'
Stock-based Compensation	'
	7.                            Stock-based Compensation
	JEH granted membership-interest awards in JEH to members of senior management (“management units”) under a management incentive plan prior to the IPO. These awards had various vesting schedules, and a portion of the management units vested in a lump sum at the IPO date. Both the vested and unvested management units were converted into JEH Units and shares of Class B common stock at the IPO date. As of March 31, 2014, there were 457,150 unvested JEH Units and shares of Class B common stock. The Units/shares will become convertible into a like number of shares of Class A common stock upon vesting. The following table summarizes information related to the Units/shares held by management:
		JEH Units	Weighted Average
			Grant Date Fair Value
			per Share
	Unvested at January 1, 2014	457,150	$	12.46
	Granted	—	—
	Forfeited	—	—
	Vested	—	—
	Unvested at March 31, 2014	457,150	$	12.46
	Stock compensation expense associated with the management units for the three months ended March 31, 2014 and 2013 was $0.4 million and $0.1 million, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations.
	On September 4, 2013, the Company granted restricted stock awards to non-employee members of the Board of Directors. Each of the four directors was awarded 6,645 restricted shares of Class A common stock, contingent on the director serving as a director of the Company for a one-year service period from the date of grant. The fair value of the awards was based on the value of the Company’s Class A common stock on the date of grant. The total value of the awards to the directors is as follows:
		Restricted	Weighted Average
		Stock Awards	Grant Date Fair Value
			per Share
	Unvested at January 1, 2014	26,580	$	15.05
	Granted	—	—
	Forfeited	—	—
	Vested	—	—
	Unvested at March 31, 2014	26,580	$	15.05
	Stock compensation expense associated with the Board of Directors awards for the three months ended March 31, 2014 was $0.1 million and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations.

Earnings_per_Share

Earnings per Share	3 Months Ended
	Mar. 31, 2014
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. Class B common stock is not included in the calculation of earnings per share because they are not participating securities and have no economic interest in the Company. 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 outstanding as of the grant date for purposes of computing diluted EPS even though their exercise is contingent upon vesting. 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 months ended March 31, 2014.
	(in thousands, except per share data)	Three Months Ended
		March 31, 2014
	Income (numerator):
	Net income attributable to controlling interests	$	1,672
	Weighted-average shares (denominator):
	Weighted-average number of shares of Class A common stock - basic	12,500
	Weighted-average number of shares of Class A common stock - diluted	12,512
	Earnings per share:
	Basic	$	0.13
	Diluted	$	0.13

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2014
Commitments and Contingencies	'
Commitments and Contingencies	'
	9.                            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	3 Months Ended
	Mar. 31, 2014
Income Taxes	'
Income Taxes	'
	10.                     Income Taxes
	Following its IPO, the the Company began recording federal and state income tax liabilities associated with its status as a corporation. Prior to the IPO, the Company only recorded a provision for Texas franchise tax as the Company’s taxable income or loss was includable in the income tax returns of the individual partners and members. The Company will recognize a tax liability on its share of pre-tax book income, exclusive of the non-controlling interest. JEH is not subject to income tax at the federal level and only recognizes Texas franchise tax expense.
	The Company’s effective tax rate for the three months ended March 31, 2014 was 10.1%. The rate is consistent with the statutory tax rate applicable to the U.S. and the states in which the Company conducts its business. The effective rate differs from the statutory rate of 35% primarily due to net income allocated to the non-controlling interest and to state income taxes. The Company’s income tax provision was an expense of $1.3 million and a benefit of $0.001 million for the three months ended March 31, 2014 and 2013, respectively. This includes income tax expense of $0.2 million and income tax benefit of $0.001 million for the three months ended March 31, 2014 and 2013, respectively, allocated to the non-controlling interest. As of March 31, 2014, the Company did not have any uncertain tax positions requiring adjustments to its tax liability.
	The Company had deferred tax assets for its federal and state loss carryforwards at March 31, 2014 recorded in noncurrent deferred taxes. Deferred tax assets are reduced by a valuation allowance, when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. As of March 31, 2014, management determined that a valuation alowance was not required for the tax loss carryforwards as they are expected to be fully utilized before expiration.

Subsequent_Events

Subsequent Events	3 Months Ended
	Mar. 31, 2014
Subsequent Events	'
Subsequent Events	'
	11.                     Subsequent Events
	On April 1, 2014, JEH and Jones Energy Finance Corp. (the “Issuers”) sold $500 million in aggregate principal amount of the Issuers’ 6.75% Senior Notes due 2022 (the “2022 Notes”). On April 1, 2014, the Company used the proceeds from the issuance of the 2022 Notes to repay all outstanding borrowings under the Term Loan and a portion of the borrowing under its Revolver. The Company subsequently terminated the Term Loan in accordance with its terms.

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2014
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”). All significant intercompany transactions and balances have been eliminated in consolidation. The financial statements reported for March 31, 2014, and the three month period then ended include the Company and all of its subsidiaries.
	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 Annual Report on Form 10-K for the year ended December 31, 2013.
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, fair value associated with business combinations, 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 March 31, 2014 and December 31, 2013:
		March 31,			December 31,
	(in thousands of dollars)	2014			2013
	Mineral interests in properties
	Unproved	$	93,386		$	99,134
	Proved	970,222			958,816
	Wells and equipment and related facilities	709,358			609,748
		1,772,966			1,667,698
	Less: Accumulated depletion and impairment	(409,573		)	(370,470		)
	Net oil and gas properties	$	1,363,393		$	1,297,228
	Costs to acquire mineral interests in oil and natural gas properties are capitalized. Costs to drill and equip development wells and the related asset retirement costs are capitalized. The costs to drill and equip exploratory wells are capitalized pending determination of whether the Company has discovered proved commercial reserves. If proved commercial reserves are not discovered, such drilling costs are charged to expense. In some circumstances, it may be uncertain whether proved commercial reserves have been found when drilling has been completed. Such exploratory well drilling costs may continue to be capitalized if the anticipated reserve quantity is sufficient to justify its completion as a producing well and sufficient progress in assessing the reserves and the economic and operating viability of the project is being made. In the first quarter of 2014 we had no material capitalized costs associated with exploratory wells.
	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 three months ended March 31, 2014 as no projects lasted more than six months. Depletion of oil and gas properties amounted to $39.1 million and $24.9 million for the periods ended March 31, 2014 and March 31, 2013, respectively.
Other Property, Plant and Equipment	'
	Other Property, Plant and Equipment
	Other property, plant and equipment consisted of the following at March 31, 2014 and December 31, 2013:
		March 31,			December 31,
	(in thousands of dollars)	2014			2013
	Leasehold improvements	$	1,116		$	1,060
	Furniture, fixtures, computers and software	2,705			2,491
	Vehicles	833			835
	Aircraft	910			910
	Other	133			134
		5,697			5,430
	Less: Accumulated depreciation and amortization	(2,225		)	(1,986		)
	Net other property, plant and equipment	$	3,472		$	3,444
	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 $0.2 million during the three months ended March 31, 2014 and 2013, 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 periods ended March 31, 2014 and 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 the Company 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
	The Company’s asset retirement obligations consist of future plugging and abandonment expenses on oil and natural gas properties.
	A summary of the Company’s ARO for three months ended March 31, 2014 is as follows:
	(in thousands of dollars)
	Balance at December 31, 2013	$	10,963
	Liabilities incurred	330
	Accretion of discount	170
	Liabilities settled due to sale of related properties	—
	Liabilities settled due to plugging and abandonment	(49		)
	Change in estimate	13
	Balance at March 31, 2014	11,427
	Less: Current portion of ARO	(2,794		)
	Total long-term ARO at March 31, 2014	$	8,633
Income Taxes	'
	Income Taxes
	Following its IPO on July 29, 2013, the Company began recording a federal and state income tax liability associated with its status as a corporation. No provision for federal income taxes was recorded prior to the IPO because the taxable income or loss was includable in the income tax returns of the individual partners and members. The Company is also subject to state income taxes. The State of Texas includes in its tax system a franchise tax applicable to the Company and an accrual for franchise taxes is included in the financial statements when appropriate.
	Income taxes are accounted for under the asset and liability method, which requires recognition of deferred tax assets and liabilities for the expected future tax consequences of events that have been included in the financial statements. Under this method, deferred tax assets and liabilities are determined based on the differences between the financial statements and tax basis of assets and liabilities using enacted tax rates in effect for the year in which differences are expected to be recovered or settled pursuant to the provisions of ASC 740—Income Taxes. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in income in the period that includes the enactment date.
	The Company records a valuation allowance if it is deemed more likely than not that all or a portion of its deferred income tax assets will not be realized. In addition, income tax rules and regulations are subject to interpretation and the application of those rules and regulations require judgment by the Company and may be challenged by the taxation authorities. The Company follows ASC 740-10-25, which requires the use of a two-step approach for recognizing and measuring tax benefits taken or expected to be taken in a tax return and disclosures regarding uncertainties in income tax positions. Only tax positions that meet the more likely than not recognition threshold are recognized. The Company’s policy is to include any interest and penalties recorded on uncertain tax positions as a component of income tax expense. The Company’s unrecognized tax benefits or related interest and penalties are immaterial.
Tax Receivable Agreement	'
	Tax Receivable Agreement
	In conjunction with the IPO, the Company entered into a Tax Receivable Agreement (“TRA”) with JEH and the pre-IPO owners. Upon any exchange of JEH—Units and Class B common stock of the Company held by JEH’s pre-IPO owners for Class A common stock of the Company, the TRA provides for the payment by the Company, directly to such exchanging owners, of 85% of the amount of cash savings in income or franchise taxes that the Company realizes as a result of (i) the tax basis increases resulting from the exchange of JEH Units for shares of Class A common stock (or resulting from a sale of JEH 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 the TRA will be recognized upon the exchange of shares. As of March 31, 2014, there had been no exchanges and no liability is recorded on the Consolidated Balance Sheet.
Stock Compensation	'
	Stock Compensation
	JEH has a management incentive plan that provides membership-interest awards in JEH to members of senior management (“management units”). The management unit grants awarded prior to the initial filing of the registration statement in March 2013 had a dual vesting schedule. Sixty percent of the units awarded vested in five equal annual installments, with the remaining 40% vesting upon a company restructuring event, including the IPO. All grants awarded after the initial registration statement but prior to the IPO have a single vesting structure of five equal annual installments and were valued at the IPO price, adjusted for equivalent shares. Both the vested and unvested management units were converted into JEH Units and shares of Class B common stock at the IPO date.
	Under the Jones Energy, Inc. 2013 Omnibus Incentive Plan, established in conjunction with the Company’s IPO, the Company reserved 3,850,000 shares of Class A common stock for director and employee stock-based compensation awards. As of March 31, 2014 no such awards had been issued or granted to any of the Company’s employees.
	In September 2013, the Company granted each of the four outside members of the Board of Directors 6,645 shares of restricted Class A common stock under the Jones Energy, Inc. 2013 Omnibus Incentive Plan. The fair value of the restricted stock grants was based on the value of the Company’s Class A common stock on the date of grant and is expensed on a straight-line basis over the one-year vesting period.
	Refer to Note 7, “Stock-based Compensation,” for additional information regarding the management units and restricted stock awards.
Recent Accounting Developments	'
	Recent Accounting Developments
	There are no recent accounting developments applicable to the Company as of March 31, 2014.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	3 Months Ended
	Mar. 31, 2014
Significant Accounting Policies	'
Schedule of oil and gas properties	'
		March 31,			December 31,
	(in thousands of dollars)	2014			2013
	Mineral interests in properties
	Unproved	$	93,386		$	99,134
	Proved	970,222			958,816
	Wells and equipment and related facilities	709,358			609,748
		1,772,966			1,667,698
	Less: Accumulated depletion and impairment	(409,573		)	(370,470		)
	Net oil and gas properties	$	1,363,393		$	1,297,228
Schedule of other property, plant and equipment	'
		March 31,			December 31,
	(in thousands of dollars)	2014			2013
	Leasehold improvements	$	1,116		$	1,060
	Furniture, fixtures, computers and software	2,705			2,491
	Vehicles	833			835
	Aircraft	910			910
	Other	133			134
		5,697			5,430
	Less: Accumulated depreciation and amortization	(2,225		)	(1,986		)
	Net other property, plant and equipment	$	3,472		$	3,444
Summary of the Company's ARO	'
	(in thousands of dollars)
	Balance at December 31, 2013	$	10,963
	Liabilities incurred	330
	Accretion of discount	170
	Liabilities settled due to sale of related properties	—
	Liabilities settled due to plugging and abandonment	(49		)
	Change in estimate	13
	Balance at March 31, 2014	11,427
	Less: Current portion of ARO	(2,794		)
	Total long-term ARO at March 31, 2014	$	8,633

Acquisition_of_Properties_Tabl

Acquisition of Properties (Tables) (Sabine acquisition)	3 Months Ended
	Mar. 31, 2014
Sabine acquisition	'
Acquisition of Properties	'
Schedule of purchase price allocation	'
	(in thousands of dollars)
	Oil and gas properties
	Unproved	$	24,273
	Proved	154,724
	Asset retirement obligations	(824		)
	Total purchase price	$	178,173
Schedule of unaudited pro forma results of operations	'
		Three Months Ended March 31, 2013
	(in thousands of dollars)	Actual			Pro Forma
	Total operating revenue	$	55,480		$	69,668
	Total operating expenses	37,433			44,668
	Operating income (loss)	18,047			25,000
	Net income (loss)	(1,452		)	5,501

Fair_Value_Measurement_Tables

Fair Value Measurement (Tables)	3 Months Ended
	Mar. 31, 2014
Fair Value Measurement	'
Schedule of financial instruments carried at fair value	'
		March 31, 2014
	(in thousands of dollars)	Fair Value Measurements
	Commodity Price Hedges	(Level 1)		(Level 2)			(Level 3)			Total
	Current assets			$	4,289		$	(121	)	$	4,168
	Long-term assets			20,796			10			20,806
	Current liabilities			11,214			616			11,830
	Long-term liabilities			—			104			104
		December 31, 2013
	(in thousands of dollars)	Fair Value Measurements
	Commodity Price Hedges	(Level 1)			(Level 2)			(Level 3)			Total
	Current assets	$	—		$	8,837		$	—		$	8,837
	Long-term assets	—			25,967			(569		)	25,398
	Current liabilities	—			10,188			476			10,664
	Long-term liabilities	—			—			190			190
Schedule of quantitative information about Level 3 inputs used in the fair value measurement	'
		Quantitative Information About Level 3 Fair Value Measurements
	Commodity Price Hedges	Fair Value		Valuation Technique		Unobservable Input		Range
	Natural gas liquid swaps			Use a discounted cash flow approach using inputs including forward price statements from counterparties		Natural gas liquid futures prices		$8.93 - $84.68 per barrel
	Basis swaps			Use a discounted cash flow approach using inputs including forward price statements from counterparties		Forward basis prices		$(0.22) - $0.25 per mmbtu
Schedule of changes in fair value of Level 3 financial instruments	'
	(in thousands of dollars)
	Balance at December 31, 2013, net	$	(1,235	)
	Purchases	—
	Settlements	—
	Transfers to Level 2	(152		)
	Transfers to Level 3	(204		)
	Changes in fair value	760
	Balance at March 31, 2014, net	$	(831	)
Schedule of commodity derivative contracts which are netted on Consolidated Balance Sheet	'
	(in thousands)	Gross Amounts		Gross Amounts		Net Amounts of		Gross Amounts		Net Amount
		of Recognized		Offset in the		Assets / Liabilities		Not Offset in the
		Assets /		Balance Sheet		Presented in the		Balance Sheet
		Liabilities				Balance Sheet
	March 31, 2014
	Commodity derivative contracts
	Assets	32,656		(7,807	)	24,849		125		24,974
	Liabilities	(19,741	)	7,807		(11,934	)	—		(11,934	)
	December 31, 2013
	Commodity derivative contracts
	Assets	38,071		(6,035	)	32,036		2,199		34,235
	Liabilities	(14,347	)	6,035		(8,312	)	(2,542	)	(10,854	)

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2014
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	'
	Hedging Positions
		March 31, 2014
									Weighted			Final
			Low			High			Average			Expiration
	Oil swaps	Exercise price	$	81.7		$	102.33		$	88.78
		Barrels per month	29,000			157,884			91,912			December 2017
	Natural gas swaps	Exercise price	$	3.88		$	6.9		$	4.84
		mmbtu per month	510,000			1,220,000			802,738			December 2017
	Basis swaps	Contract differential	$	(0.43	)	$	(0.11	)	$	(0.33	)
		mmbtu per month	320,000			630,000			441,667			March 2016
	Natural gas liquids swaps	Exercise price	$	6.72		$	95.24		$	33.64
		Barrels per month	2,000			115,000			42,000			December 2017
		December 31, 2013
									Weighted			Final
			Low			High			Average			Expiration
	Oil swaps	Exercise price	$	81.7		$	102.84		$	89.03
		Barrels per month	29,000			161,613			96,149			December 2017
	Natural gas swaps	Exercise price	$	3.88		$	6.9		$	4.26
		mmbtu per month	510,000			1,290,000			830,275			December 2017
	Basis swaps	Contract differential	$	(0.43	)	$	(0.11	)	$	(0.34	)
		mmbtu per month	320,000			690,000			467,037			March 2016
	Natural gas liquids swaps	Exercise price	$	6.72		$	95.24		$	32.98
		Barrels per month	2,000			118,000			46,646			December 2017

Stockbased_Compensation_Tables

Stock-based Compensation (Tables)	3 Months Ended
	Mar. 31, 2014
Non-employee members of Board Of Directors | Restricted stock	'
Stock-based Compensation	'
Summary of information related to the Units/shares or awards	'
		Restricted	Weighted Average
		Stock Awards	Grant Date Fair Value
			per Share
	Unvested at January 1, 2014	26,580	$	15.05
	Granted	—	—
	Forfeited	—	—
	Vested	—	—
	Unvested at March 31, 2014	26,580	$	15.05
Management incentive plan | Management units | Management	'
Stock-based Compensation	'
Summary of information related to the Units/shares or awards	'
		JEH Units	Weighted Average
			Grant Date Fair Value
			per Share
	Unvested at January 1, 2014	457,150	$	12.46
	Granted	—	—
	Forfeited	—	—
	Vested	—	—
	Unvested at March 31, 2014	457,150	$	12.46

Earnings_per_Share_Tables

Earnings per Share (Tables)	3 Months Ended
	Mar. 31, 2014
Earnings per Share	'
Schedule of calculation of the basic and diluted weighted-average shares and EPS	'
	(in thousands, except per share data)	Three Months Ended
		March 31, 2014
	Income (numerator):
	Net income attributable to controlling interests	$	1,672
	Weighted-average shares (denominator):
	Weighted-average number of shares of Class A common stock - basic	12,500
	Weighted-average number of shares of Class A common stock - diluted	12,512
	Earnings per share:
	Basic	$	0.13
	Diluted	$	0.13

Organization_and_Description_o1

Organization and Description of Business (Details)	3 Months Ended	0 Months Ended
	Mar. 31, 2014	Jul. 29, 2013	Jul. 29, 2013
	item	Pre-IPO owners of JEH	JEH
		item
Organization and description of business	'	'	'
Number of classes of common stock	2	'	'
Exchange ratio	'	1	'
Number of votes for each holder of common stock	'	1	'
Economic interest (as a percent)	'	'	74.70%
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	'	'

Organization_and_Description_o2

Organization and Description of Business (Details 2) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Interest expense	$8,043	$8,187
Adjustment	'	'
Interest expense	'	$200

Significant_Accounting_Policie3

Significant Accounting Policies (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
	item
Mineral interests in properties	'	'	'
Unproved	$93,386,000	'	$99,134,000
Proved	970,222,000	'	958,816,000
Wells and equipment and related facilities	709,358,000	'	609,748,000
Gross oil and gas properties	1,772,966,000	'	1,667,698,000
Less: Accumulated depletion and impairment	-409,573,000	'	-370,470,000
Net oil and gas properties	1,363,393,000	'	1,297,228,000
Costs capitalized in connection with exploratory wells	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	$39,100,000	$24,900,000	'

Significant_Accounting_Policie4

Significant Accounting Policies (Details 2) (USD $)	3 Months Ended		7 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Jul. 29, 2013	Dec. 31, 2013
	item
Other Property, Plant and Equipment	'	'	'	'
Gross other property, plant and equipment	$5,697,000	'	'	$5,430,000
Less: Accumulated depreciation and amortization	-2,225,000	'	'	-1,986,000
Net other property, plant and equipment	3,472,000	'	'	3,444,000
Depreciation and amortization of other property, plant and equipment	200,000	200,000	'	'
Asset Retirement Obligations	'	'	'	'
ARO liability at beginning of year	10,963,000	'	'	'
Liabilities incurred	330,000	69,000	'	'
Accretion of discount	170,000	'	'	'
Liabilities settled due to plugging and abandonment	-49,000	'	'	'
Change in estimate	13,000	'	'	'
ARO liability at end of year	11,427,000	'	'	'
Less: Current portion of ARO at end of year	-2,794,000	'	'	-2,590,000
Total long-term ARO at end of year	8,633,000	'	'	8,373,000
Income tax provision	1,257,000	-1,000	0	'
Tax Receivable Agreement	'	'	'	'
Cash savings to be paid under tax receivable agreement with JEH and the pre-IPO owners (as a percent)	85.00%	'	'	'
Benefits of cash savings retained under tax receivable agreement (as a percent)	15.00%	'	'	'
Liabilities recorded	0	'	'	'
Number of exchanges	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	1,116,000	'	'	1,060,000
Furniture, fixtures, computers and software	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'
Gross other property, plant and equipment	2,705,000	'	'	2,491,000
Vehicles	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'
Gross other property, plant and equipment	833,000	'	'	835,000
Aircraft	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'
Gross other property, plant and equipment	910,000	'	'	910,000
Other	'	'	'	'
Other Property, Plant and Equipment	'	'	'	'
Gross other property, plant and equipment	$133,000	'	'	$134,000

Significant_Accounting_Policie5

Significant Accounting Policies (Details 3)	1 Months Ended	3 Months Ended
	Sep. 30, 2013	Mar. 31, 2014
	item
Management incentive plan | JEH | Management units | Dual vesting	'	'
Stock Compensation	'	'
Percentage of units vesting in equal annual installments	'	60.00%
Vesting term	'	'5 years
Percentage of units vesting upon restructuring event	'	40.00%
Management incentive plan | JEH | Management units | Single vesting	'	'
Stock Compensation	'	'
Vesting term	'	'5 years
2013 Omnibus Incentive Plan | Class A common stock	'	'
Stock Compensation	'	'
Shares reserved (in shares)	'	3,850,000
Awards granted (in shares)	'	0
2013 Omnibus Incentive Plan | Restricted stock	'	'
Stock Compensation	'	'
Vesting term	'	'1 year
Number of outside members of the Board of Directors to whom awards were granted	4	'
Awards granted, per outside member of the Board of Directors (in shares)	6,645	'

Acquisition_of_Properties_Deta

Acquisition of Properties (Details) (USD $)	1 Months Ended	3 Months Ended		0 Months Ended	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2013	Dec. 18, 2013	Mar. 31, 2013
		item		Sabine acquisition	Sabine acquisition
Acquisition of Properties	'	'	'	'	'
Number of property acquisitions	'	0	'	'	'
Acquisition of Properties	'	'	'	'	'
Initial purchase price	'	'	'	$193,500,000	'
Repayment of escrow fund due to settlement of title negotiation	13,700,000	'	'	'	'
Accrued preliminary adjustments to purchase price	'	1,600,000	'	'	'
Oil and gas properties	'	'	'	'	'
Unproved	'	'	'	24,273,000	'
Proved	'	'	'	154,724,000	'
Asset retirement obligations	'	'	'	-824,000	'
Total purchase price	'	'	'	178,173,000	'
Purchase price placed in escrow account	'	'	'	24,000,000	'
Pro Forma	'	'	'	'	'
Total operating revenue	'	'	'	'	69,668,000
Total operating expenses	'	'	'	'	44,668,000
Operating income (loss)	'	'	'	'	25,000,000
Net income (loss)	'	'	'	'	5,501,000
Actual	'	'	'	'	'
Total operating revenues	'	98,244,000	55,480,000	'	55,480,000
Total operating expenses	'	62,372,000	37,433,000	'	37,433,000
Operating income	'	35,872,000	18,047,000	'	18,047,000
Net income (loss)	'	$1,672,000	($1,452,000)	'	($1,452,000)

Fair_Value_Measurement_Details

Fair Value Measurement (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value Measurements	'	'
Current assets	$4,168	$8,837
Long-term assets	20,806	25,398
Current liabilities	11,830	10,664
Long-term liabilities	104	190
Level 2 | Commodity Price Hedges	'	'
Fair Value Measurements	'	'
Current assets	4,289	8,837
Long-term assets	20,796	25,967
Current liabilities	11,214	10,188
Level 3 | Commodity Price Hedges	'	'
Fair Value Measurements	'	'
Current assets	-121	'
Long-term assets	10	-569
Current liabilities	616	476
Long-term liabilities	104	190
Total | Commodity Price Hedges	'	'
Fair Value Measurements	'	'
Current assets	4,168	8,837
Long-term assets	20,806	25,398
Current liabilities	11,830	10,664
Long-term liabilities	$104	$190

Fair_Value_Measurement_Details1

Fair Value Measurement (Details 2) (USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
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)	95.24	95.24
Commodity derivatives	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Fair Value	$19,741	$14,347
Discounted cash flow approach | Level 3 | Commodity derivatives | Basis swaps | Minimum	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Swap price (in dollars per barrel/mmbtu)	-0.22	'
Discounted cash flow approach | Level 3 | Commodity derivatives | Basis swaps | Maximum	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Swap price (in dollars per barrel/mmbtu)	0.25	'
Discounted cash flow approach | Level 3 | Commodity derivatives | Natural gas liquid | Swap	'	'
Quantitative Information About Level 3 Fair Value Measurements	'	'
Fair Value	$0	'
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)	8.93	'
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)	84.68	'

Fair_Value_Measurement_Details2

Fair Value Measurement (Details 3) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2013
	item	Commodity derivative contracts	Commodity derivative contracts
Changes in fair value of Level 3 instruments	'	'	'
Balance at the beginning of the period	($1,235,000)	'	'
Transfer to Level 2	-152,000	'	'
Transfers to Level 3	-204,000	'	'
Changes in fair value	760,000	'	'
Balance at the end of the period	-831,000	'	'
Offsetting Assets and Liabilities	'	'	'
Number of counterparties to commodity derivative contracts	6	'	'
Assets	'	'	'
Gross Amounts of Recognized Assets / Liabilities	'	32,656,000	38,071,000
Gross Amounts Offset in the Balance Sheet	'	-7,807,000	-6,035,000
Net Amounts of Assets Presented in the Balance Sheet	'	24,849,000	32,036,000
Gross Amounts Not Offset in the Balance Sheet	'	125,000	2,199,000
Net Amount	'	24,974,000	34,235,000
Liabilities	'	'	'
Gross Amounts of Recognized Assets	'	-19,741,000	-14,347,000
Gross Amounts Offset in the Balance Sheet	'	7,807,000	6,035,000
Net Amounts of Assets Presented in the Balance Sheet	'	-11,934,000	-8,312,000
Gross Amounts Not Offset in the Balance Sheet	'	'	-2,542,000
Net Amount	'	-11,934,000	-10,854,000
Nonfinancial Assets and Liabilities	'	'	'
Impairment of proved properties	0	'	'
Impairment of unproved properties	$0	'	'

Derivative_Instruments_and_Hed2

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

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

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

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)

'

'

'

'

'

'

81.7

81.7

102.33

102.84

88.78

89.03

'

'

'

'

'

'

6.72

6.72

95.24

95.24

33.64

32.98

'

'

Nonmonetary notional amount

'

'

'

'

'

'

29,000

29,000

157,884

161,613

91,912

96,149

'

'

'

'

'

'

2,000

2,000

115,000

118,000

42,000

46,646

'

'

Exercise price (in dollars per mmbtu)

'

'

'

'

'

'

'

'

'

'

'

'

3.88

3.88

6.9

6.9

4.84

4.26

'

'

'

'

'

'

'

'

Contract differential (in dollars per mmbtu)

-0.43

-0.43

-0.11

-0.11

-0.33

-0.34

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Nonmonetary notional amount

320,000

320,000

630,000

690,000

441,667

467,037

'

'

'

'

'

'

510,000

510,000

1,220,000

1,290,000

802,738

830,275

'

'

'

'

'

'

'

'

Net Loss recognized on derivative instruments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$17.30

$11.40

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)

3 Months Ended

3 Months Ended

3 Months Ended

In Millions, unless otherwise specified

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2009

Mar. 31, 2014

Dec. 31, 2013

Jun. 30, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

item

item

Revolver

Revolver

Revolver

Revolver

Revolver

Revolver

Term Loan

Term Loan

Term Loan

Term Loan

Base rate

Base rate

Base rate

Base rate

Base rate

Base rate

Minimum

Maximum

Minimum

Maximum

Credit agreements

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of credit agreements

2

'

2

'

'

'

'

'

'

'

'

'

'

Borrowing base

'

'

'

'

$575

$500

'

'

'

'

'

'

'

Frequency of interest payments

'

'

'

'3 months

'

'

'

'

'

'3 months

'

'

'

Reference rate

'

'

'

'

'

'

'base rate (LIBOR or prime)

'

'

'

'base rate (LIBOR, prime, or federal funds)

'

'

Margin interest rate (as a percent)

'

'

'

'

'

'

'

0.50%

2.50%

'

'

6.00%

7.00%

Average interest rates (as a percent)

'

'

'

2.87%

'

'

'

'

'

'

'

'

'

Average outstanding balance

'

'

'

510.4

'

'

'

'

'

160

'

'

'

Average interest rate (as a percent)

'

'

'

'

'

'

'

'

'

9.13%

'

'

'

Total interest and commitment fees

$7.30

$7.30

'

'

'

'

'

'

'

'

'

'

'

Stockbased_Compensation_Detail

Stock-based Compensation (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Sep. 04, 2013	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Dec. 31, 2013
In Millions, except Share data, unless otherwise specified	Non-employee members of Board Of Directors	Non-employee members of Board Of Directors	Non-employee members of Board Of Directors	Non-employee members of Board Of Directors	Non-employee members of Board Of Directors	Management incentive plan	Management incentive plan	Management incentive plan	Management incentive plan	Management incentive plan
	Restricted stock	Restricted stock	Class A	Class A	General and administrative expenses	Management units	Management units	Management units	Management units	Management units
			Restricted stock	Restricted stock	Restricted stock	JEH	JEH	JEH	JEH	JEH
			item			Common Class B	General and administrative expenses	General and administrative expenses	Management	Management
Units/ Awards	'	'	'	'	'	'	'	'	'	'
Unvested at the beginning of the period (in shares)	26,580	26,580	'	'	'	457,150	'	'	457,150	457,150
Unvested at the end of the period (in shares)	26,580	26,580	'	'	'	457,150	'	'	457,150	457,150
Weighted Average Grant Date Fair Value per Share	'	'	'	'	'	'	'	'	'	'
Unvested at the beginning of the period (in dollars per share)	$15.05	$15.05	'	'	'	'	'	'	$12.46	$12.46
Unvested at the end of the period (in dollars per share)	$15.05	$15.05	'	'	'	'	'	'	$12.46	$12.46
Stock compensation expense	'	'	'	'	$0.10	'	$0.40	$0.10	'	'
Number of non-employee members of the Board of Directors to whom awards were granted	'	'	4	'	'	'	'	'	'	'
Awards granted to each non-employee director (in shares)	'	'	6,645	'	'	'	'	'	'	'
Service period from date of grant	'	'	'	'1 year	'	'	'	'	'	'

Earnings_per_Share_Details

Earnings per Share (Details) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Income (numerator):	'	'
Net income attributable to controlling interests	$1,672	($1,452)
Weighted-average shares (denominator):	'	'
Weighted-average number of shares of Class A common stock - basic	12,500	'
Weighted-average number of shares of Class A common stock - diluted	12,512	'
Earnings per share:	'	'
Basic (in dollars per share)	$0.13	'
Diluted (in dollars per share)	$0.13	'
Common Class B	'	'
Earnings per Share	'	'
Economic interest (as a percent)	0.00%	'

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended		7 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Jul. 29, 2013
Income Taxes	'	'	'
Effective tax rate (as a percent)	10.10%	'	'
Statutory rate (as a percent)	35.00%	'	'
Income tax expense (benefit)	$1,257	($1)	$0
Income tax expense (benefit) allocated to the non-controlling interest	$200	($1)	'

Subsequent_Events_Details

Subsequent Events (Details) (Subsequent events, Senior notes, 2022 Notes, USD $)	Apr. 01, 2014
In Millions, unless otherwise specified
Subsequent events | Senior notes | 2022 Notes	'
Subsequent events	'
Issuance of debt	$500
Stated interest rate (as a percent)	6.75%