Jones Energy (JONEQ) 10-K 6 Mar 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Jun. 30, 2014	Feb. 27, 2015
Entity Registrant Name	Jones Energy, Inc.
Entity Central Index Key	1573166
Document Type	10-K
Document Period End Date	31-Dec-14
Amendment Flag	FALSE
Current Fiscal Year End Date	-19
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Public Float		$256
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Class A common stock
Entity Common Stock, Shares Outstanding			25,208,402
Class B common stock
Entity Common Stock, Shares Outstanding			36,422,660

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, unless otherwise specified
Current assets
Cash	$13,566	$23,820
Restricted Cash	149	45
Accounts receivable, net
Oil and gas sales	49,861	51,233
Joint interest owners	41,761	42,481
Other	12,512	16,782
Commodity derivative assets	121,519	8,837
Other current assets	3,374	2,392
Deferred tax assets		12
Total current assets	242,742	145,602
Oil and gas properties, net, at cost under the successful efforts method	1,638,860	1,297,228
Other property, plant and equipment, net	4,048	3,444
Commodity derivative assets	87,055	25,398
Other assets	20,352	15,006
Deferred tax assets	171	1,301
Total assets	1,993,228	1,487,979
Current liabilities
Trade accounts payable	136,337	89,430
Oil and gas sales payable	70,469	66,179
Accrued liabilities	19,401	10,805
Commodity derivative liabilities		10,664
Deferred tax liabilities	718
Asset retirement obligations	3,074	2,590
Total current liabilities	229,999	179,668
Long-term debt	360,000	658,000
Senior notes	500,000
Deferred revenue	13,377	14,531
Commodity derivative liabilities	28	190
Asset retirement obligations	10,536	8,373
Liability under tax receivable agreement	803
Deferred tax liabilities	26,612	3,093
Total liabilities	1,141,355	863,855
Commitments and contingencies (Note 10)
Stockholders' equity
Treasury stock, at cost; 22,602 shares at December 31, 2014 and 0 shares at December 31, 2013	-358
Additional paid-in-capital	177,133	173,169
Retained earnings (deficit)	38,682	-2,186
Stockholders' equity	215,507	171,033
Non-controlling interest	636,366	453,091
Total stockholders' equity	851,873	624,124	428,400	345,909
Total liabilities and stockholders' equity	1,993,228	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) (USD $)	Dec. 31, 2014	Dec. 31, 2013
Treasury stock, shares	22,602	0
Class A common stock
Common Stock, par value (in dollars per share)	0.001	0.001
Common Stock, shares issued	12,672,260	12,526,580
Common Stock, shares outstanding	12,649,658	12,526,580
Class B common stock
Common Stock, par value (in dollars per share)	0.001	0.001
Common Stock, shares issued	36,719,499	36,836,333
Common Stock, shares outstanding	36,719,499	36,836,333

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating revenues
Oil and gas sales	$378,401	$258,063	$148,967
Other revenues	2,196	1,106	847
Total operating revenues	380,597	259,169	149,814
Operating costs and expenses
Lease operating	43,843	27,781	23,097
Production taxes	18,094	12,865	5,583
Exploration	3,453	1,710	356
Depletion, depreciation and amortization	181,669	114,136	80,709
Impairment of oil and gas properties		14,415	18,821
Accretion of discount	770	608	533
General and administrative (including non-cash compensation expense)	25,763	31,902	15,875
Total operating expenses	273,592	203,417	144,974
Operating income	107,005	55,752	4,840
Other income (expense)
Interest expense	-46,726	-30,774	-25,292
Net gain (loss) on commodity derivatives	189,641	-2,566	16,684
Gain (loss) on sales of assets	297	-78	1,162
Other income (expense), net	143,212	-33,418	-7,446
Income (loss) before income tax	250,217	22,334	-2,606
Income tax provision (benefit)
Current	53	85
Deferred	26,021	-156	473
Total income tax provision	26,074	-71	473
Net income (loss)	224,143	22,405	-3,079
Net income attributable to non-controlling interests	183,275	24,591
Net income (loss) attributable to controlling interests	$40,868	($2,186)	($3,079)
Earnings per share:
Basic	$3.26	($0.17)
Diluted	$3.26	($0.17)
Weighted average shares outstanding:
Basic	12,526	12,500
Diluted	12,535	12,500

Consolidated_Statement_of_Chan

Consolidated Statement of Changes In Stockholders' / Members' Equity (USD $)	Common Stock	Common Stock	Treasury Stock	Members' Equity	Additional Paid-in-Capital	Retained (Deficit) Earnings	Non-controlling Interest	Total
In Thousands, except Share data, unless otherwise specified	Class A common stock	Class B common stock	Class A common stock
Balance - Members' Equity at Dec. 31, 2011				$345,909
Balance - Total Stockholders' / Members' Equity at Dec. 31, 2011								345,909
Increase (Decrease) Stockholders' equity
Issuance of Class C Preferred Units				85,000				85,000
Stock-compensation expense				570				570
Net income (loss)				-3,079				-3,079
Balance - Members' Equity at Dec. 31, 2012				428,400
Balance - Total Stockholders' / Members' Equity at Dec. 31, 2012								428,400
Increase (Decrease) Stockholders' equity
Issuance of common stock	13	37
Issuance of common stock (in shares)	12,500	36,836
Issuance of Class C Preferred Units								50
Proceeds from the sale of common stock					172,431			172,431
Reclassification of members' contributions				-464,037			464,037
Stock-compensation expense				10,100	738			10,838
Distribution to members				-10,000				-10,000
Net income (loss)				35,537		-2,186	-10,946	22,405
Balance (in shares) at Dec. 31, 2013	12,500	36,836
Balance - Total Stockholders' / Members' Equity at Dec. 31, 2013	13	37			173,169	-2,186	453,091	624,124
Increase (Decrease) Stockholders' equity
Vested restricted shares	28
Stock-compensation expense					4,040			4,040
Exchange of Class B Shares for Class A Shares (in dollars)					-76			-76
Exchange of Class B shares for Class A shares (in shares)	117	-117
Treasury Stock			-358					-358
Treasury Stock (in shares)	-23		23
Net income (loss)						40,868	183,275	224,143
Balance (in shares) at Dec. 31, 2014	12,622	36,719	23
Balance - Total Stockholders' / Members' Equity at Dec. 31, 2014	$13	$37	($358)		$177,133	$38,682	$636,366	$851,873

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities
Net income (loss)	$224,143	$22,405	($3,079)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, and amortization	181,669	114,136	80,709
Exploration expense	2,952
Impairment of oil and gas properties		14,415	18,821
Accretion of discount	770	608	533
Amortization of debt issuance costs	6,878	2,677	3,544
Accrued interest expense	7,823	1,891	456
Stock compensation expense	4,040	10,838	570
Other non-cash compensation expense (Note 9)	758	2,719
Amortization of deferred revenue	-1,154	-469
(Gain) loss on commodity derivatives	-189,641	2,566	-16,684
(Gain) loss on sales of assets	-297	78	-1,162
Deferred income tax provision	26,021	-156	473
Other - net	376	79	129
Changes in assets and liabilities
Accounts receivable	-832	-56,804	11,568
Other assets	-565	163	1,873
Accounts payable and accrued liabilities	2,482	33,427	-13,201
Net cash provided by operations	265,423	148,573	84,550
Cash flows from investing activities
Additions to oil and gas properties	-474,619	-197,618	-125,493
Acquisition of properties		-178,173	-249,007
Net adjustments to purchase price of properties acquired	15,709
Proceeds from sales of assets	448	1,607	9,158
Acquisition of other property, plant and equipment	-1,683	-1,634	-969
Current period settlements of matured derivative contracts	-3,654	7,586	28,675
Change in restricted cash	-104	-45
Net cash (used in) investing	-463,903	-368,277	-337,636
Cash flows from financing activities
Proceeds from issuance of long-term debt	170,000	220,000	233,243
Repayment under long-term debt	-468,000	-172,000	-38,243
Proceeds from senior notes	500,000
Payment of debt issuance costs	-13,416	-683	-9,324
Issuance of preferred units			85,000
Proceeds from sale of common stock, net of expenses of $15.1 million		172,481
Purchases of treasury stock	-358
Net cash provided by financing	188,226	219,798	270,676
Net increase (decrease) in cash	-10,254	94	17,590
Cash
Beginning of period	23,820	23,726	6,136
End of period	13,566	23,820	23,726
Supplemental disclosure of cash flow information
Cash paid for interest	29,560	25,414	20,759
Cash paid for income taxes	155
Change in accrued additions to oil and gas properties	49,025	41,945	3,355
Noncash acquisition of oil and gas properties			2,918
Current additions to ARO	1,995	1,516	662
Noncash distributions to members (Note 9)		$10,000

Consolidated_Statements_of_Cas1

Consolidated Statements of Cash Flows (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Consolidated Statements of Cash Flows
Payment of stock issuance expenses	$15.10

Organization_and_Description_o

Organization and Description of Business	12 Months Ended
	Dec. 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, the Company 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.
	The Company's certificate of incorporation authorizes two classes of common stock, Class A common stock and Class B common stock. The Class B common stock is held by the owners of JEH prior to the Company's initial public offering ("IPO") and can be exchanged (together with a corresponding number of units representing membership interests in JEH ("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. Prior to the IPO, JEH owned the controlling interest in the Company; hence all of the net income earned prior to the IPO date is reflected in the net income attributable to non-controlling interests on the Consolidated Statement of Operations for the year ended December 31, 2013.
	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 is headquartered in Austin, Texas.

Significant_Accounting_Policie

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Significant Accounting Policies
Significant Accounting Policies
	2. Significant Accounting Policies
	Basis of Presentation
	The accompanying 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 December 31, 2014 and 2013 and the results of the operations and the cash flows for each of the three years in the period ended December 31, 2014 include the Company and all of its subsidiaries.
	Segment Information
	The Company operates in one industry segment, which is the exploration, development and production of oil and natural gas, and all of its operations are conducted in one geographic area of the United States.
	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, fair value associated with business combinations, and asset retirement obligations ("ARO").
	Financial Instruments
	Cash, accounts receivable and accounts payable are recorded at cost. The fair value of accounts receivable and accounts payable are not materially different from their carrying amounts because of the short-term nature of these instruments. The carrying value of the outstanding balance under the Company's Revolver (as defined in Note 6) represents fair value because the Revolver has variable interest rates, which are reflective of the Company's credit risk. The Company's senior notes have a fixed interest rate and are reported at historical value as of the initial measurement date when issued and their fair value is discussed in Note 4. Derivative instruments are recorded at fair value, as discussed below.
	Cash
	Cash and cash equivalents include highly liquid investments with a maturity of three months or less. At times, the amount of cash on deposit in financial institutions exceeds federally insured limits. Management monitors the soundness of the financial institutions and believes the Company's risk is not significant.
	Accounts Receivable
	Accounts receivable—Oil and gas sales consist of uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 to 60 days of production. Accounts receivable—Joint interest owners consist of uncollateralized joint interest owner obligations due within 30 days of the invoice date. Accounts receivable—Other consists at December 31, 2014 of derivative positions not settled as of the balance sheet date and severance tax refunds due from state agencies and at December 31, 2013 of the adjustments to the purchase price of the Sabine properties purchased in December 2013 and severance tax refunds due from state agencies. No interest is charged on past-due balances. The Company routinely assesses the recoverability of all material trade, joint interest and other receivables to determine their collectability, and reduces the carrying amounts by a valuation allowance that reflects management's best estimate of the amounts that may not be collected. As of December 31, 2014 and 2013, the Company did not have significant allowances for doubtful accounts.
	Concentration of Risk
	Substantially all of the Company's accounts receivable are related to the oil and gas industry. This concentration of entities may affect the Company's overall credit risk in that these entities may be affected similarly by changes in economic and other conditions, including declines in commodity prices. As of December 31, 2014, 70% of Accounts receivable—Oil and gas sales are due from 5 purchasers and 67% of Accounts receivable—Joint interest owners are due from 5 working interest owners. As of December 31, 2013, 79% of Accounts receivable—Oil and gas sales were due from 8 purchasers, and 77% of 2013 Accounts receivable—Joint interest owners were due from 5 working interest owners. If any or all of these significant counterparties were to fail to pay amounts due to the Company, the Company's financial position and results of operations could be materially and adversely affected.
	Dependence on Major Customers
	The Company maintains a portfolio of crude oil and natural gas marketing contracts with large, established refiners and oil and gas purchasers. During the year ended December 31, 2014, the largest purchasers were Valero Energy Corp. ("Valero"), NGL Energy Partners LP, PVR Midstream LLC ("PVR Midstream"), Plains Marketing LP ("Plains Marketing"), and Monarch Natural Gas LLC which accounted for approximately 22%, 12%, 12%, 10% and 10% of consolidated oil and gas sales, respectively. During the year ended December 31, 2013, the largest purchasers were PVR Midstream, Unimark LLC, Mercuria Energy Group Ltd. ("Mercuria"), Valero, and Plains Marketing, which accounted for approximately 15%, 13%, 13%, 13% and 6% of consolidated oil and gas sales, respectively. During the year ended December 31, 2012, the largest purchasers were Unimark LLC, Mercuria, PVR Midstream, and Plains Marketing, which accounted for approximately 24%, 18%, 18% and 15% of consolidated oil and gas sales, respectively.
	Management believes that there are alternative purchasers and that it may be necessary to establish relationships with such new purchasers. However, there can be no assurance that the Company can establish such relationships and that those relationships will result in an increased number of purchasers. Although the Company is exposed to a concentration of credit risk, management believes that all of the Company's purchasers are credit worthy.
	Dependence on Suppliers
	The Company's industry is cyclical, and from time to time, there can be an imbalance between the supply of and demand for drilling rigs, equipment, services, supplies and qualified personnel. During periods of oversupply, there can be financial pressure on suppliers. If the financial pressure leads to work interruptions or stoppages, the Company could be materially and adversely affected. Management believes that there are adequate alternative providers of drilling and completion services although it may become necessary to establish relationships with new contractors. However, there can be no assurance that the Company can establish such relationships and that those relationships will result in increased availability of drilling rigs or other services, or that they could be obtained on the same terms.
	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 December 31, 2014 and 2013:
	(in thousands of dollars)		2014			2013
	Mineral interests in properties
	Unproved		$	94,526		$	99,134
	Proved			1,001,194			958,816
	Wells and equipment and related facilities			1,094,202			609,748
				2,189,922			1,667,698
	Less: Accumulated depletion and impairment			(551,062	)		(370,470	)
	Net oil and gas properties		$	1,638,860		$	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. As of December 31, 2014 and 2013, 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 capitalized less than $0.1 million in interest costs during 2014 for one project. No interest costs were capitalized in 2013. Costs incurred to maintain wells and related equipment are charged to expense as incurred.
	On the sale or retirement of a proved field, the cost and related accumulated depletion, depreciation and amortization are eliminated from the field accounts, and the resultant gain or loss is recognized.
	Capitalized amounts attributable to proved oil and gas properties are depleted by the unit-of-production method over proved reserves, using the unit conversion ratio of six thousand cubic feet of gas to one barrel of oil equivalent. Depletion of the costs of wells and related equipment and facilities, including capitalized asset retirement costs, net of salvage values, is computed using proved developed reserves. The reserve base used to calculate depreciation, depletion, and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. Depletion of oil and gas properties amounted to $180.6 million, $113.3 million and $79.9 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	The Company reviews its proved oil and natural gas properties, including related wells and equipment, for impairment by comparing expected undiscounted future cash flows at a producing field level to the net capitalized cost of the asset. If the future undiscounted cash flows, based on the Company's estimate of future commodity prices, operating costs, and production, are lower than the net capitalized cost, the capitalized cost is reduced to fair value. Fair value is calculated by discounting the future cash flows at an appropriate risk-adjusted discount rate. Due to the significant assumptions associated with the inputs and calculations described, the fair value of oil and gas properties used in estimating impairment represents a nonrecurring Level 3 measurement. No impairments of proved properties were recorded in 2014 or 2013. The Company incurred impairment charges of $18.8 million related to its proved oil and natural gas properties and equipment in 2012.
	The Company evaluates its unproved properties for impairment on a property-by-property basis. The Company's unproved property consists of acquisition costs related to its undeveloped acreage. The Company reviews the unproved property for indicators of impairment based on the Company's current exploration plans with consideration given to results of any drilling and seismic activity during the period and known information regarding exploration and development activity by other companies on adjacent blocks. The Company incurred no impairment charges related to its unproved properties in 2014 or 2012. In the fourth quarter of 2013, the Company recorded an impairment charge of $14.4 million related to its unproved Southridge properties in the Arkoma basin. As the Company did not drill the required number of wells by October 31, 2013 necessary to keep its joint development agreement with Southridge in effect, the Company lost its right to the undeveloped acreage. Impairment of oil and gas properties charges are recorded on the Consolidated Statement of Operations.
	On the sale of an entire interest in an unproved property, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.
	Other Property, Plant and Equipment
	Other property, plant and equipment consisted of the following at December 31, 2014 and 2013:
	(in thousands of dollars)		2014			2013
	Leasehold improvements		$	1,218		$	1,060
	Furniture, fixtures, computers and software			3,727			2,491
	Vehicles			988			835
	Aircraft			910			910
	Other			219			134
				7,062			5,430
	Less: Accumulated depreciation and amortization			(3,014	)		(1,986	)
	Net other property, plant and equipment		$	4,048		$	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 $1.1 million, $0.8 million and $0.8 million during the years ended December 31, 2014, 2013 and 2012, respectively.
	Oil and Gas Sales Payable
	Oil and gas sales payable represents amounts collected from purchasers for oil and gas sales, which are due to other revenue interest owners. Generally, the Company is required to remit amounts due under these liabilities within 60 days of receipt.
	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 years ended December 31, 2014, 2013 and 2012, 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 ("ARO") consist of future plugging and abandonment expenses on oil and natural gas properties. The Company estimates an ARO for each well in the period in which it is incurred based on estimated present value of plugging and abandonment costs, increased by an inflation factor to the estimated date that the well would be plugged. The resulting liability is recorded by increasing the carrying amount of the related long- lived asset. The liability is then accreted to its then-present value each period and the capitalized cost is depleted over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. The ARO is classified as current or noncurrent based on the expect timing of payments. A summary of the Company's ARO for the years ended December 31, 2014 and 2013 is as follows:
	(in thousands of dollars)		2014			2013
	ARO liability at beginning of year		$	10,963		$	9,506
	Liabilities incurred(1)			1,995			1,515
	Accretion of discount			770			608
	Liabilities settled due to sale of related properties			(109	)		(271	)
	Liabilities settled due to plugging and abandonment			(55	)		(702	)
Change in estimate			46			307
ARO liability at end of year			13,610			10,963
Less: Current portion of ARO at end of year			(3,074			(2,590
				)			)
Total long-term ARO at end of year		$	10,536		$	8,373
-1	Includes $824 related to wells acquired in 2013 (see Note 3, "Acquisition of Properties").
Revenue Recognition
Revenues from the sale of crude oil, natural gas, and natural gas liquids are recognized when the product is delivered at a fixed or determinable price, title has transferred, collectability is reasonably assured and evidenced by a contract. The Company follows the "sales method" of accounting for its oil and natural gas revenue, so it recognizes revenue on all crude oil, natural gas, and natural gas liquids sold to purchasers. A receivable or liability is recognized only to the extent that the Company has an imbalance on a specific property greater than the expected remaining proved reserves.
Production Costs
Production costs, including compressor rental, pumpers' salaries, saltwater disposal, ad valorem taxes, insurance, repairs and maintenance, expensed workovers and other operating expenses are expensed as incurred and included in lease operating expense on the Consolidated Statement of Operations.
Exploration Expenses
Exploration expenses include dry hole costs, lease extensions, delay rentals and geological and geophysical costs.
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.
Liability under Tax Receivable Agreement
In connection with the IPO, the Company entered into a Tax Receivable Agreement (the "TRA") which obligated the Company to make payments to certain current and former owners equal to 85% of the applicable cash savings that the Company realizes as a result of tax attributes arising from exchanges of JEH Units and JEI Class B shares held by those owners for Class A shares of JEI common stock. The Company will retain the benefit of the remaining 15% of these tax savings.
As a result of exchanges made through December 31, 2014, the Company has accrued future tax benefits of $0.9 million and has recorded this amount as a deferred tax asset on its consolidated balance sheet. As of December 31, 2014, the Company has recorded a liability of $0.8 million associated with its future TRA obligation. The actual amount and timing of payments made under the TRA will depend upon a number of factors, including the amount and timing of taxable income generated in the future, changes in future tax rates, the use of loss carryovers, and the portion of the Company's payments under the TRA constituting imputed interest. To the extent the Company does not realize all of the tax benefits in future years or in the event of a change in future tax rates, this liability may change.
As of December 31, 2014, the Company has made no payments under the TRA and does not anticipate making a material payment under the TRA in 2015.
Comprehensive Income
The Company has no elements of comprehensive income other than net income.
Statement of Cash Flows
The Company presents its cash flows using the indirect method.
Related Party Transactions
In the years ended December 31, 2013 and 2012, the Company paid an annual administration fee to Metalmark of $0.7 million. This amount was charged to expense. As a result of the IPO, this fee is no longer payable to Metalmark.
On May 7, 2013, the Company entered into a natural gas sale and purchase agreement with Monarch Natural Gas, LLC, ("Monarch"), under which Monarch has the first right to gather the natural gas the Company produces from dedicated properties, process the NGLs from this natural gas production and market the processed natural gas and extracted NGLs. Under the Monarch agreement, the Company is paid a specified percentage of the value of the NGLs extracted and sold by Monarch, based on a set liquids recovery percentage, and the amount received from the sale of the residue gas, after deducting a fixed volume for fuel, lost and unaccounted for gas. The Company produced approximately 1.4 MMBoe of natural gas and NGLs for the year ended December 31, 2014 and 0.8 MMBoe of natural gas and NGLs for the year ended December 31, 2013, from the properties that became subject to the Monarch agreement. The initial term of the agreement runs for 10 years from the effective date of September 1, 2013.
At the time the Company entered into the agreement, Metalmark Capital owned approximately 81% of the outstanding equity interests of Monarch. In addition, Metalmark Capital beneficially owns in excess of five percent of the Company's outstanding equity interests and two of our directors, Howard I. Hoffen and Gregory D. Myers, are managing directors of Metalmark Capital. In connection with the Company's entering into the Monarch agreement, Monarch issued to JEH equity interests in Monarch having a deemed value of $15 million. JEH assigned $2.4 million of the Monarch equity interests to Jonny Jones, the Company's chief executive officer and chairman of the board, and reserved $2.6 million of the Monarch equity interests to a benefit plan established for certain of the Company's officers, including Mike McConnell, Robert Brooks and Eric Niccum. The remaining $10 million of Monarch equity was distributed to certain of the pre-IPO owners, which include Metalmark Capital, Wells Fargo, the Jones family entities, and certain of the Company's officers and directors, including Jonny Jones, Mike McConnell and Eric Niccum.
In September 2014, the Company signed a 10-year oil gathering and transportation agreement with Monarch Oil Pipeline LLC, pursuant to which Monarch Oil Pipeline, LLC will build, at its expense, a new oil gathering system and connect to dedicated Company leases in Texas. At the time the Company entered into the agreement, Metalmark Capital owned the majority of the outstanding equity interests of Monarch Oil Pipeline, LLC and/or its parent. The system is expected to begin service during the second quarter of 2015 and provide connectivity to both a regional refinery market as well as the Cushing market hub. The Company has reserved capacity of up to 12,000 barrels per day on the system with the potential to increase throughput at a future date.
Stock Compensation
JEH implemented a management incentive plan effective January 1, 2010, that provided awards of membership interests in JEH to members of senior management ("management units"). The management unit grants awarded prior to the initial filing of the IPO registration statement in March 2013 had a dual vesting schedule and were fully vested as of December 31, 2014. Grants awarded after the initial IPO registration statement generally 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. At December 31, 2014, there were 274,385 unvested JEH Units and shares of Class B common stock that will become convertible into a like number of shares of Class A common stock upon vesting.
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.
During 2014, the Company granted performance unit and restricted stock unit awards to certain officers and employees under the Jones Energy, Inc. 2013 Omnibus Incentive Plan. The fair value of the performance units was based on the grant date fair value (using a Monte Carlo simulation model) and is expensed on a straight-line basis over the applicable three-year performance period. The number of shares of Class A common stock issuable upon vesting of the performance unit awards ranges from zero to 200% based on the Company's total shareholder return relative to an industry peer group over the applicable three-year performance period. The fair value of the restricted stock unit awards 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 applicable three-year vesting period.
In September 2014 and 2013, the Company granted each of the outside members of the Board of Directors 5,486 and 6,645 shares, respectively, 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 director and employee stock-based compensation awards
Business Combinations
For acquisitions of working interests that are accounted for as business combinations, the results of operations are included in the Consolidated Statement of Operations from the date of acquisition. Purchase prices are allocated to assets acquired based on their estimated fair values at the time of acquisition. 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. The fair value measurement is based on the assumptions of market participants and not those of the reporting entity. Therefore, entity-specific intentions do not impact the measurement of fair value. The fair value of oil and natural gas properties is determined using a risk-adjusted after-tax discounted cash flow analysis based upon significant inputs including: 1) oil and gas prices, 2) projections of estimated quantities of oil and natural gas reserves, including those classified as proved, probable and possible, 3) projections of future rates of production, 4) timing and amount of future development and operating costs, 5) projected reserve recovery factors, and 6) weighted average cost of capital.
Recent Accounting Pronouncements
In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2014-09, "Revenue from Contracts with Customers," which creates a new topic in the Accounting Standards Codification ("ASC"), topic 606, "Revenue from Contracts with Customers." This ASU sets forth a five-step model for determining when and how revenue is recognized. Under the model, an entity will be required to recognize revenue to depict the transfer of goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods or services. Additional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. The amendments are effective for fiscal years, and interim periods within those years, beginning after December 15, 2016 and may be applied on either a full or modified retrospective basis. Early adoption is not permitted. We do not expect the adoption of these provisions to have a significant impact on the Company's consolidated financial statements. However, we will continue to assess the anticipated impact as further implementation guidance is released from the FASB.
In August 2014, the FASB issued ASU No. 2014-15, "Presentation of Financial Statements—Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern." This ASU requires management to evaluate whether there are conditions or events that raise substantial doubt about an entity's ability to continue as a "going concern" and to provide disclosures when certain criteria are met. Substantial doubt exists when relevant conditions and events, considered in the aggregate, indicate that it is probable that the entity will be unable to meet its obligations as they become due within one year after the date that the financial statements are issued (or available to be issued). The amendments are effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Early adoption is permitted. We do not expect the adoption of these disclosures to have a significant impact on the Company's consolidated financial statements.
In January 2015, the FASB issued Accounting Standards Update No. 2015-01, Income Statement—Extraordinary and Unusual Items ("ASU 2015-01"). ASU 2015-01 removes the concept of extraordinary items from GAAP. Under existing guidance, an entity is required to separately disclose extraordinary items, net of tax, in the income statement after income from continuing operations if an event or transaction is of an unusual nature and occurs infrequently. This separate, net-of-tax presentation will no longer be allowed. ASU 2015-01 is effective for interim and annual reporting periods beginning after December 15, 2015. The Company does not expect the adoption of this guidance to have a material impact on its financial position, cash flows or results of operations.

Acquisition_of_Properties

Acquisition of Properties	12 Months Ended
	Dec. 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 twelve months ended December 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 included both producing properties and undeveloped acreage. The purchase was financed with borrowings under the Revolver. In the second quarter of 2014, the Company made a final determination with the sellers as to the purchase price resulting in a final purchase price of $179.2 million. The amount of the total purchase price allocated to undeveloped 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 was allocated as follows:
	(in thousands of dollars)
	Oil and gas properties
	Unproved		$	32,964
	Proved			147,024
	Asset retirement obligations			(824	)
	Total purchase price		$	179,164
	The unaudited pro forma results presented below have been prepared to include the effect of the Sabine acquisition on our results of operations for the year ended December 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.
						Year Ended
						December 31,
			Post			2013
	(in thousands of dollars)		Acquisition(1)			Pro Forma
			(unaudited)			(unaudited)
	Total operating revenue		$	1,365		$	308,773
	Total operating expenses			291			229,648
	Operating income			1,074			79,125
	Net income			1,074			45,778
	-1	Represents revenues and expenses for the post acquisition period of December 18, 2013 to December 31, 2013 included in the Consolidated Statement of Operations.
	On December 20, 2012, JEH 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 included both producing properties and undeveloped acreage. The purchase was financed with additional equity capital and borrowings under the Revolver. In the second quarter of 2013, the Company 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:
	(in thousands of dollars)
	Oil and gas properties
	Unproved		$	71,264
	Proved			182,493
	Asset retirement obligations			(293	)
	Total purchase price		$	253,464
	The unaudited pro forma results presented below have been prepared to include the effect of the Chalker acquisition on our results of operations for the year ended December 31, 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.
			Year Ended
			December 31,
			2012
	(in thousands of dollars)		Pro Forma
			(unaudited)
	Total operating revenue		$	194,685
	Total operating expenses			161,053
	Operating income			33,632
	Net income			25,713
	Both acquisitions qualified as a business combination under ASC 805. The valuation to determine the fair values were 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 market at the time of acquisition.

Fair_Value_Measurement

Fair Value Measurement	12 Months Ended
	Dec. 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 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 in 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 December 31, 2014 and 2013, by consolidated balance sheet caption and by valuation hierarchy, as described above are as follows:
		December 31, 2014
		Fair Value Measurements Using
	(in thousands of dollars)	(Level 1)			(Level 2)			(Level 3)			Total
	Commodity Price Hedges
	Current assets	$	—		$	120,604		$	915		$	121,519
	Long-term assets		—			85,162			1,893			87,055
	Current liabilities		—			—			—			—
	Long-term liabilities		—			—			28			28
		December 31, 2013
		Fair Value Measurements Using
	(in thousands of dollars)	(Level 1)			(Level 2)			(Level 3)			Total
	Commodity Price Hedges
	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 December 31, 2014.
		Quantitative Information About Level 3 Fair Value Measurements
	Commodity Price Hedges	Fair Value			Valuation Technique		Unobservable		Range
		(000's)					Input
	Natural gas liquid swaps	$	3,045		Use a discounted cash flow approach using inputs including forward price statements from counterparties		Natural gas liquid futures		$8.09 - $75.52 per barrel
	Natural gas basis swaps	$	(265	)	Use a discounted cash flow approach using inputs including forward price statements from counterparties		Natural gas basis swaps		$(0.11) - $(0.17) per barrel
	Significant increases/decreases in natural gas liquid 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 years ended December 31, 2014 and 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		(1,095	)
	Settlements		(210	)
	Transfers to Level 2		(753	)
	Changes in fair value		2,342
	Balance at December 31, 2013, net		(1,235	)
	Purchases		668
	Settlements		476
	Transfers into Level 3		(265	)
	Transfers to Level 2		332
	Changes in fair value		2,804
	Balance at December 31, 2014, net	$	2,780
	Transfers from Level 3 to Level 2 represent the Company's natural gas basis swaps for which observable forward curve pricing information has become readily available. Purchases represent natural gas liquid swaps that the Company entered into that do not have observable forward curve pricing information. There were no transfers into Level 3 for the years ended December 31, 2014 and 2013.
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	The following table provides the fair value of financial instruments that are not recorded at fair value in the consolidated financial statements:
		December 31, 2014						December 31, 2013
	(in thousands of dollars)	Carrying			Fair Value			Carrying			Fair Value
		Amount						Amount
	Debt:
	Revolver	$	360,000		$	360,000		$	498,000		$	498,000
	Term loan		—			—			160,000			160,000
	2022 Notes		500,000			384,375			—			—
	The Revolver is 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 approximates fair value, as it is subject to short-term floating interest rates that approximate the rates available to the Company for those periods.
	The fair value of the 2022 Notes (as defined in Note 6) is based on pricing that is readily available in the public market. Accordingly, the 2022 Notes are classified as Level 2 in the valuation hierarchy as the pricing is based on quoted market prices for the debt securities.
	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 years ended December 31, 2014 and 2013. During 2012, unamortized capitalized costs of certain properties were higher than their expected undiscounted future cash flows due primarily to downward reserve revisions, drilling of marginal or uneconomic wells, or development dry holes in certain producing fields. As a result, the Company recorded charges of $18.8 million during the year ended December 31, 2012.
	Additionally, the Company reviews its unproved properties for indicators of impairment based on the Company's current exploration plans. In the fourth quarter of 2013, the Company recorded an impairment charge of $14.4 million related to the Southridge properties. As the Company did not drill the required number of wells by October 31, 2013 necessary to keep its joint development agreement with Southridge in effect, the Company lost its right to the undeveloped acreage and associated reserves. The Company incurred no impairment charges related to its unproved properties in 2014 or 2012.
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	12 Months Ended
	Dec. 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 that could affect its future operations as of December 31, 2014 and 2013, as follows:
	Hedging Positions
		December 31, 2014
				Low			High			Weighted			Final
										Average			Expiration
	Oil swaps	Exercise price		$	75.05		$	100.95		$	84.2
		Barrels per month			45,000			184,054			113,852		Dec-18
	Natural gas swaps	Exercise price		$	3.37		$	6.45		$	4.4
		mmbtu per month			710,000			1,772,584			1,175,275		Dec-18
	Basis swaps	Contract differential		$	(0.39	)	$	(0.11	)	$	(0.21	)
		mmbtu per month			320,000			980,000			716,667		Mar-16
	Natural gas liquids swaps	Exercise price		$	8.09		$	95.24		$	42.46
		Barrels per month			2,000			143,000			50,444		Dec-17
		December 31, 2013
				Low			High			Weighted			Final
										Average			Expiration
	Oil swaps	Exercise price		$	81.7		$	102.84		$	89.03
		Barrels per month			29,000			161,613			96,149		Dec-17
	Natural gas swaps	Exercise price		$	3.88		$	6.9		$	4.26
		mmbtu per month			510,000			1,290,000			830,275		Dec-17
	Basis swaps	Contract differential		$	(0.43	)	$	(0.11	)	$	(0.34	)
		mmbtu per month			320,000			690,000			467,037		Mar-16
	Natural gas liquids swaps	Exercise price		$	6.72		$	95.24		$	32.98
		Barrels per month			2,000			118,000			46,646		Dec-17
	The Company recognized a net gain on derivative instruments of $189.6 million for the year ended December 31, 2014, a net loss of $2.6 million for the year ended December 31, 2013, and a net gain of $16.7 million for the year ended December 31, 2012.
	Offsetting Assets and Liabilities
	As of December 31, 2014, the counterparties to our commodity derivative contracts consisted of seven financial institutions. Substantially, all of our counterparties or their affiliates are also lenders under the Revolver. 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 that are netted on our Consolidated Balance Sheet as of December 31, 2014 and December 31, 2013:
	(in thousands of dollars)	Gross Amounts			Gross			Net Amounts			Gross			Net Amount
		of Recognized			Amounts			of Assets /			Amounts
		Assets /			Offset in the			Liabilities			Not
		Liabilities			Balance			Presented in			Offset in the
					Sheet			the Balance			Balance
								Sheet			Sheet
	December 31, 2014
	Commodity derivative contracts
	Assets	$	208,646		$	(72	)	$	208,574		$	—		$	208,574
	Liabilities		(100	)		72			(28	)		—			(28	)
	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	)

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2014
Long-Term Debt
Long-Term Debt
	6. Long-Term Debt
	Senior Notes
	On April 1, 2014, JEH and its wholly-owned subsidiary, Jones Energy Finance Corp. (together the "Issuers"), sold $500.0 million in aggregate principal amount of the Issuers' 6.75% Senior Notes due 2022 (the "2022 Notes"). The Company used the net proceeds from the issuance of the 2022 Notes to repay all outstanding borrowings under the Term Loan ($160.0 million), a portion of the outstanding borrowings under the Revolver ($308.0 million) and for working capital and general corporate purposes. The Company subsequently terminated the Term Loan in accordance with its terms. The 2022 Notes bear interest at a rate of 6.75% per year, payable semi-annually on April 1 and October 1 of each year beginning October 1, 2014. As of December 31, 2014, the Company had $8.4 million in interest accrued related to the 2022 Notes. Total interest expense related to the 2022 Notes amounted to $25.3 million for the year ended December 31, 2014.
	The 2022 Notes are guaranteed on a senior unsecured basis by the Company and by all of its significant subsidiaries. The 2022 Notes will be senior in right of payment to any future subordinated indebtedness of the Issuers.
	The Company may redeem the 2022 Notes at any time on or after April 1, 2017 at a declining redemption price set forth in the indenture, plus accrued and unpaid interest.
	The indenture governing the 2022 Notes contains covenants that, among other things, limit the ability of the Company to incur additional indebtedness or issue certain preferred stock, pay dividends on capital stock, transfer or sell assets, make investments, create certain liens, enter into agreements that restrict dividends or other payments from the Company's restricted subsidiaries to the Company, consolidate, merge or transfer all of the Company's assets, engage in transactions with affiliates or create unrestricted subsidiaries. However, many of these covenants will be suspended if the Notes are rated investment grade by Standard & Poor's or Moody's.
	Other 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"), each of which have been amended periodically. On April 1, 2014, the Term Loan was repaid in full and terminated in connection with the issuance of the 2022 Notes. On November 6, 2014, the Company amended the Revolver to, among other things, increase the borrowing base under the Revolver from $550.0 million to $625.0 million until the next redetermination thereof, and extend the maturity date of the Revolver to November 6, 2019. The Company's oil and gas properties are pledged as collateral to secure its obligations under the Revolver. The borrowing base on the Revolver was subsequently adjusted to $562.5 million in accordance with its terms as a result of the issuance of the 2023 Notes in February 2015.
	The terms of the Revolver require the Company to make periodic payments of interest on the loans outstanding thereunder, with all outstanding principal and interest under the Revolver due on the maturity date thereof. The Revolver is subject to a borrowing base which limits the amount of borrowings which may be drawn thereunder. The borrowing base will be redetermined by the lenders at least semi-annually on or about April 1 and October 1 of each year. Interest on the Revolver is calculated, at the Company's option, at either (a) the LIBO rate for the applicable interest period plus a margin of 1.50% to 2.50% based on the level of borrowing base utilization at such time or (b) the greatest of the federal funds rate plus 0.50%, the one-month adjusted LIBO rate plus 1.00%, or the prime rate announced by Wells Fargo Bank, N.A. in effect on such day, in each case plus a margin of 0.50% to 1.50% based on the level of borrowing base utilization at such time. For the year ended December 31, 2014, the average interest rate under the Revolver was 2.51% on an average outstanding balance of $333.8 million. For the year ended December 31, 2013, the average interest rate under the Revolver was 3.01% on an average outstanding balance of $384.9 million.
	Total interest and commitment fees under the Revolver and Term Loan were $13.0 million, $27.0 million, and $21.2 million for the years ended December 31, 2014, 2013 and 2012, respectively. $3.8 million in unamortized deferred financing costs were charged to interest expense during 2014 in connection with repayment of the Term Loan.
	The Revolver is 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 approximates fair value, as it is subject to short-term floating interest rates that approximate the rates available to the Company for those periods.
	We are subject to certain covenants under the Revolver which include, but are not limited to, restrictions on asset sales, distributions to members, and incurrence of additional indebtedness, and financial covenants which require the maintenance of certain financial ratios, including a maximum leverage ratio, and a minimum current ratio. The Company was in compliance with these covenants at December 31, 2014.

Stockbased_Compensation

Stock-based Compensation	12 Months Ended
	Dec. 31, 2014
Stock-based Compensation
Stock-based Compensation
	7. Stock-based Compensation
	Management Units
	Prior to the IPO, JEH granted management units under a previously existing management incentive plan. 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 December 31, 2014, there were 274,385 unvested JEH Units and shares of Class B common stock under this plan. No new JEH Units and Class B shares are created upon a vesting event. The JEH Units (together with a corresponding number of shares of Class B common stock) will become exchangeable into a like number of shares of Class A common stock upon vesting or forfeiture. The following table summarizes information related to the vesting of JEH Units:
			JEH Units			Weighted Average
						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			(998,032	)	$	9.96
	Unvested at December 31, 2013			457,150		$	12.46
	Granted			21,405		$	6.66
	Forfeited			(21,405	)	$	6.66
	Vested			(182,765	)	$	8.65
	Unvested at December 31, 2014			274,385		$	15
	Stock compensation expense associated with the management units and JEH Units for the years ended December 31, 2014, 2013 and 2012 was $1.6 million, $10.7 million, and $0.6 million, respectively, and is included in general and administrative expenses on the Company's Consolidated Statement of Operations.
	Restricted Stock Awards
	On September 23, 2014, the Company granted restricted stock awards to non-employee members of the Board of Directors. Each of the five directors was awarded 5,486 restricted shares of Class A common stock, contingent on the director serving as a director of the Company for a one-year service period in accordance with the terms of the award. The fair value of the awards was based on the value of the Company's Class A common stock on the date of grant.
	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. These awards are fully vested as of December 31, 2014. The total number of shares awarded to the directors is as follows:
	Director Restricted Stock Awards
			Restricted			Weighted Average
			Stock Awards			Grant Date Fair
						Value per Share
	Unvested at January 1, 2013			—			—
	Granted			26,580		$	15.05
	Forfeited			—			—
	Vested			—			—
	Unvested at December 31, 2013			26,580		$	15.05
	Granted			27,430		$	18.77
	Forfeited			—			—
	Vested			(26,580	)	$	15.05
	Unvested at December 31, 2014			27,430		$	18.77
	Stock compensation expense associated with the Board of Directors awards for the year ended December 31, 2014 was $0.4 million and for the year ended December 31, 2013 was $0.1 million and is included in general and administrative expenses on the Company's Consolidated Statement of Operations.
	Restricted Stock Unit Awards
	During the year ended December 31, 2014, the Company granted 340,001 restricted stock unit awards to certain officers and employees of the Company. The fair value of the restricted stock unit awards 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 applicable three-year vesting period. The total number of units awarded to the officers and employees is as follows:
	Employee Restricted Stock Unit Awards
			Restricted			Weighted Average
			Stock Unit			Grant Date Fair
			Awards			Value per Share
	Unvested at January 1, 2014			—			—
	Granted			340,001		$	17.31
	Forfeited			(13,688	)	$	17.07
	Vested			(1,416	)	$	17.07
	Unvested at December 31, 2014			324,897		$	17.33
	Stock compensation expense associated with the employee restricted stock unit awards for the twelve months ended December 31, 2014 was $1.1 million, and is included in general and administrative expenses on the Company's Consolidated Statement of Operations.
	Performance Unit Awards
	During the twelve months ended December 31, 2014, the Company granted 201,318 performance unit awards to certain officers of the Company. Upon the completion of the applicable three-year performance period, each officer will vest in a number of performance units. The number of performance units in which each officer vests at such time will range from 0% to 200% based on the Company's total shareholder return relative to an industry peer group over the applicable three-year performance period. Each vested performance unit is exchangeable for one share of the Company's Class A common stock. The grant date fair value of the performance units was determined using a Monte Carlo simulation model, which results in an expected percentage of performance units earned. The fair value of the performance units is expensed on a straight-line basis over the applicable three-year performance period.
	The total number of units awarded to the officers is as follows:
	Employee Performance Unit Awards
			Performance			Weighted Average
			Unit Awards			Grant Date Fair
						Value per Share
	Unvested at January 1, 2014			—			—
	Granted			201,318		$	21.65
	Forfeited			(8,320	)	$	21.65
	Vested			—			—
	Unvested at December 31, 2014			192,998		$	21.65
	Stock compensation expense associated with the performance unit awards for the twelve months ended December 31, 2014 was $0.9 million, and is included in general and administrative expenses on the Company's Consolidated Statement of Operations.
	The Monte Carlo simulation process is a generally accepted statistical technique used, in this instance, to simulate future stock prices for the Company and the components of the peer group. The simulation uses a risk-neutral framework along with the risk-free rate of return, the volatility of each entity, and the correlations of each entity with the other entities in the peer group. A stock price path has been simulated for the Company and each peer company and is used to determine the payout percentages and the stock price of the Company's common stock as of the vesting date. The ending stock price is multiplied by the payout percentage to determine the projected payout, which is then discounted with the risk-free rate of return to the grant date to determine the grant date fair value for that simulation. When enough simulations are generated, the resulting distribution gives a reasonable estimate of the range of future expected stock prices.
	The following assumptions were used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense during the twelve months ended December 31, 2014:
	Stock Price(1)		$	17.07
	Beginning Average Stock Price(2)		$	14.78
Expected Volatility(3)			46.95	%
Risk-Free Rate of Return(4)			0.61	%
-1	Based on the closing price of Jones Energy, Inc. Class A common stock on May 20, 2014.
-2	Based on the 10 trading days immediately prior to the beginning of the performance period.
-3	Based on the average historical volatilities over the most recent 2.62-year period for the Company and each peer company using daily stock prices through May 20, 2014. The measurement period reflects the 2.62 years remaining in the performance period as of the grant date.
-4	Based on the yield curve of U.S. Treasury rates as of May 20, 2014.
Based on these assumptions, the Monte Carlo simulation model resulted in a simulated fair value of $21.65 based on an expected percentage of performance units earned of 126.80%.

Earnings_per_Share

Earnings per Share	12 Months Ended
	Dec. 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. Shares of Class B common stock are 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 potential dilutive effect of shares that could be issued by the Company in conjunction with stock awards that have been granted to directors and employees. In accordance with ASC 260, Earnings Per Share, awards of nonvested shares shall be considered outstanding as of the respective grant dates for purposes of computing diluted EPS even though the award is contingent upon vesting. For the twelve months ended December 31, 2014, 27,430 restricted stock shares, 54,656 restricted stock units and 192,998 performance units were excluded from the calculation as they would have had an anti-dilutive effect. The following is a calculation of the basic and diluted weighted-average number of shares of Class A common stock outstanding and EPS. 2014 is calculated using the twelve months ended December 31, 2014. 2013 is calculated for the period from July 29, 2013, the closing date of the IPO, to December 31, 2013.
	Basic Earnings per Share
	(in thousands, except per share data)	2014		2013
	Income (numerator):
	Net income (loss) attributable to controlling interests	$	40,868	$	(2,186	)
	Weighted-average shares (denominator):
	Weighted-average number of shares of Class A common stock		12,526		12,500
	Earnings (loss) per share:
	Basic earnings per share	$	3.26	$	(0.17	)
	Diluted Earnings per Share
	(in thousands, except per share data)	2014		2013
	Income (numerator):
	Net income (loss) attributable to controlling interests	$	40,868	$	(2,186	)
	Weighted-average shares (denominator):
	Weighted-average number of shares of Class A common stock		12,535		12,500
	Earnings (loss) per share:
	Diluted earnings per share	$	3.26	$	(0.17	)
	Anti-dilutive shares of Class A common stock		275		27

Monarch_Investment

Monarch Investment	12 Months Ended
	Dec. 31, 2014
Monarch Investment
Monarch Investment
	9. Monarch Investment
	On May 7, 2013, the Company entered into a marketing agreement with 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%, or $10 million, of the Monarch equity interests to the Company's owners pro rata based on equity contributions and approximately 16% of the interests to a member of management. The remaining approximately 17% of the equity interests were reserved for distribution to management through an incentive plan. During the year ended December 31, 2014, $0.5 million of the equity interests were distributed to management under the incentive plan. The Company recognized expense of $0.8 million during the year ended December 31, 2014 and $0.3 million during the year ended December 31, 2013 in connection with the incentive plan. In addition, the Company recorded deferred revenue of $15.0 million related to the marketing agreement 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 $1.2 million of the deferred revenue balance during the year ended December 31, 2014, and $0.5 million of deferred revenue during the year ended December 31, 2013. This revenue is recorded in other revenues on the Company's Consolidated Statement of Operations.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies
Commitments and Contingencies
	10. Commitments and Contingencies
	Lease obligations
	The Company leases approximately 43,000 square feet of office space in Austin, TX under an operating lease arrangement. Future minimum payments for all noncancellable operating leases extending beyond one year at December 31, 2014 are as follows:
	(in thousands of dollars)
	Years Ending December 31,
	2015	$	944
	2016		954
	2017		1,038
	2018		1,101
	2019		1,122
	Thereafter		377
		$	5,536
	Rent expense under operating leases was $0.9 million, $0.8 million and $0.8 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	Litigation
	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 current matters will not have a material adverse effect on its financial position, results of operations, or liquidity.

Benefit_Plans

Benefit Plans	12 Months Ended
	Dec. 31, 2014
Benefit Plans
Benefit Plans
	11. Benefit Plans
	The Company established a 401(k) tax-deferred savings plan (the "Plan") for the benefit of employees. The Plan is a defined contribution plan and the Company may match a portion of employee contributions. For each of the years ended December 31, 2014 and 2013, $0.3 million was contributed to the Plan.
	In 2013, the Company established a 409A tax-deferred savings plan for the benefit of key employees. This plan is a defined contribution plan, and the Company may match a portion of employee contributions. For each of the years ended December 31, 2014 and 2013, the Company made no contributions to this plan.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Taxes
Income Taxes
	12. Income Taxes
	Following its IPO, the Company began recording a federal and state income tax liability 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 following table summarizes the tax provision for the years ended December 31, 2014, 2013 and 2012:
		Year Ended December 31,
	(in thousands of dollars)	2014			2013			2012
	Current tax expense:
	Federal	$	53		$	85		$	—
	State		—			—			—
	Total current expense		53			85			—
	Deferred tax expense (benefit):
	Federal		21,996			(1,260	)		—
	State		4,025			1,104			473
	Total deferred expense (benefit)		26,021			(156	)		473
	Total tax expense (benefit)	$	26,074		$	(71	)	$	473
	Tax expense (benefit) attributable to controlling interests	$	22,675		$	(1,223	)	$	473
	Tax expense attributable to non-controlling interests		3,399			1,152			—
	Total income tax expense (benefit)	$	26,074		$	(71	)	$	473
	For the pre-IPO period of the year ended December 31, 2013 and for the entire year ended December 31, 2012, the reported taxes in the table above relate solely to the Texas franchise tax liability of JEH.
	A reconciliation of the Company's provision for income taxes as reported and the amount computed by multiplying income before taxes, less non-controlling interest, by the U.S. federal statutory rate of 35%:
	(in thousands of dollars)	2014			2013
	Provision calculated at federal statutory income tax rate:
	Net income before taxes	$	250,217		$	22,334
	Statutory rate		35	%		35	%
	Income tax expense computed at statutory rate	$	87,577		$	7,817
	Less: Non-controlling interests		(65,336	)		(9,009	)
	Income tax expense (benefit) attributable to controlling interests		22,241			(1,192	)
	State and local income taxes, net of federal benefit		626			(49	)
	Other		(192	)		18
	Tax expense (benefit) attributable to controlling interests		22,675			(1,223	)
	Tax expense attributable to non-controlling interests		3,399			1,152
	Total income tax expense (benefit)	$	26,074		$	(71	)
	For the year ended December 31, 2012, the calculation is not applicable as the Company was not subject to federal income taxes prior to the IPO.
	The Company is subject to federal, state, and local income and franchise taxes. As such, deferred income taxes result from temporary differences between the carrying amounts of assets and liabilities of the Company for financial reporting purposes and the amounts used for income tax purposes. Deferred tax assets and liabilities are measured using enacted tax rates in effect in the years in which those temporary differences are expected to reverse.
	Significant components of the Company's deferred tax assets and deferred tax liabilities consisted of the following:
		As of December 31,
	(in thousands of dollars)	2014			2013
	Deferred tax assets
	Investment in consolidated subsidiary JEH	$	—		$	526
	Net operating loss		8,223			649
	Section 754 election tax basis adjustment		945			—
	Alternative minimum tax credits		53			86
	Other deferred tax asset		232			52
	Total deferred tax assets		9,453			1,313
	Deferred tax liabilities
	Current state deferred tax liability		718			—
	Investment in consolidated subsidiary JEH		29,163			—
	Noncurrent state deferred tax liability		6,731			3,093
	Total deferred tax liabilities		36,612			3,093
	Net deferred tax assets (liabilities)		(27,159	)		(1,780	)
	Valuation allowance		—			—
	Net deferred tax assets (liabilities)	$	(27,159	)	$	(1,780	)
	The Company has a federal net operating loss carry-forward totaling $22.4 million and state net operating loss carry-forward of $9.6 million, both of which expire between 2033 and 2034. No valuation allowance has been recorded as management believes that there is sufficient future taxable income to fully utilize its deferred tax assets. This future taxable income will arise from reversing temporary differences due to the excess of the book carrying value of oil and gas properties over their corresponding tax basis. In addition, the Company may elect to capitalize intangible drilling costs, rather than expensing these costs, in order to prevent an operating loss carryforward from expiring unused.
	Separate federal and state income tax returns are filed for Jones Energy, Inc. and Jones Energy Holdings, LLC. JEH's Texas franchise tax returns are subject to audit for 2010 through 2014. The tax years 2011 through 2014 remain open to examination by the major taxing jurisdictions to which the Company is subject. The Company is not currently under audit by the IRS or any state jurisdiction.
	Accounting for uncertainty in income taxes prescribes a recognition threshold and measurement methodology for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. As of December 31, 2014 and December 31, 2013 there was no material liability or expense for the periods then ended recorded for payments of interest and penalties associated with uncertain tax positions or material unrecognized tax positions and the Company's unrecognized tax benefits were not material.
	Tax Receivable Agreement
	JEH intends to make an election under Section 754 of the Internal Revenue Code (the "Code") effective for 2014 and future tax years. As a result, JEH will be required to adjust the tax basis of the assets of JEH at the time of an exchange of JEH units and Class B common stock held by the non-controlling interest members of the Company for Class A common stock. The tax basis adjustments are expected to result in increases in the tax basis of the assets of JEH that would otherwise have not been available. This increase in tax basis allows the Company to reduce the amount of future tax payments to the extent that the Company has future taxable income.
	As a result of the increase in tax basis generated in exchanges made as of December 31, 2014, the Company is entitled to future tax benefits of $0.9 million and has recorded this amount as a deferred tax asset on its consolidated balance sheet. Under the terms of the TRA entered into prior to the IPO, JEI will pay 85% of the amount of cash savings, if any, in U.S. federal, state and local income tax that the Company actually realizes as a result of these increases in tax basis to the exchanging member who generated the increased tax basis. For purposes of making payments under the TRA, actual cash savings in income tax in a given year will be computed by comparing the Company's actual income tax liability to the amount of such taxes the Company would have been required to pay had there been no increase to the tax basis of the assets of JEH as a result of the exchanges.
	While the actual amount and timing of payments under the TRA will depend upon a number of factors, including the amount and timing of taxable income generated in the future, changes in future tax rates, the value of individual assets, and the portion of the Company's payments under the TRA constituting imputed interest, the Company has estimated that the payments that will be made to the pre-IPO members who have exchanged shares as of December 31, 2014 will be $0.8 million and has recorded this obligation as a liability on the consolidated balance sheet. To the extent the Company does not realize all of the tax benefits in future years or in the event of a change in future tax rates, this liability may change.
	As of December 31, 2014, the Company has not made any payments under the TRA to pre-IPO members who have exchanged JEH units and Class B common stock for Class A common stock. The Company does not anticipate making a material payment under the TRA in 2015.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events
Subsequent Events
	13. Subsequent Events
	Public Offering of Class A Common Stock
	On February 17, 2015, the Company completed the issuance and sale of 7,500,000 shares of Class A common stock to the public at a price of $10.25 per share under the Company's registration statement on Form S-3 (the "Public Equity Offering"). The shares of Class A common stock were issued pursuant to an underwriting agreement, dated February 11, 2015, in which the Company granted the underwriters a 30-day option to purchase up to an additional 1,125,000 shares of Class A common stock.
	Private Placement of Class A Common Stock
	On February 23, 2015, the Company completed the sale of an aggregate of $50.0 million of its Class A common stock to certain affiliates of GSO Capital Partners LP and Magnetar Capital LLC in a direct placement of registered shares under the Company's registration statement on Form S-3 (the "Private Equity Offering"). Under the terms of the Private Equity Offering, the Company sold 4,761,905 shares of Class A common stock at a purchase price of $10.50 per share.
	Private Placement of Senior Unsecured Notes
	On February 23, 2015, JEH and Jones Energy Finance Corp., a wholly-owned subsidiary of JEH formed for the sole purpose of co-issuing certain of JEH's debt, completed the sale of $250.0 million in aggregate principal amount of 9.25% senior unsecured notes due 2023 (the "2023 Notes") to certain affiliates of GSO Capital Partners LP and Magnetar Capital LLC in a private placement (the "Notes Offering"). The 2023 Notes rank equally with all of the Company's other senior unsecured indebtedness and are effectively subordinated in right of payment to all of the Company's secured indebtedness (to the extent of the collateral securing such indebtedness). The 2023 Notes are fully and unconditionally guaranteed on a senior unsecured basis by the Company and by all of JEH's existing subsidiaries (other than the co-issuer and two immaterial subsidiaries) and any future subsidiaries that guarantee indebtedness under the Revolver or other debt securities.
	The Company used the net proceeds from the Public Equity Offering, the Private Equity Offering and the Notes Offering for working capital and to repay outstanding borrowings under the Revolver.

Subsidiary_Guarantors

Subsidiary Guarantors	12 Months Ended
	Dec. 31, 2014
Subsidiary Guarantors
Subsidiary Guarantors
	14. Subsidiary Guarantors
	On April 1, 2014, JEH and its wholly-owned subsidiary, Jones Energy Finance Corp. (the "Issuers"), sold $500.0 million in aggregate principal amount of the Issuers' 6.75% Senior Notes due 2022 (the "2022 Notes").
	The 2022 Notes are guaranteed on a senior unsecured basis by the Company and by all of JEH's current subsidiaries (except Jones Energy Finance Corp. and two immaterial subsidiaries) and certain future subsidiaries, including any future subsidiaries that guarantee any indebtedness under the Company's Revolver. Each subsidiary guarantor is 100% owned by JEH, and all guarantees are full, unconditional, and joint and several with all other subsidiary guarantees and the parent guarantee. Any subsidiaries of JEH other than the subsidiary guarantors and Jones Energy Finance Corp. are minor.
	The Company is a holding company and has no independent assets or operations of its own. The Company is the sole managing member of JEH and is responsible for all operational, management and administrative decisions related to JEH's business. In accordance with JEH's limited liability company agreement, the Company may not be removed as the sole managing member of JEH.
	As of December 31, 2014, the Company held approximately 25.6% of the economic interest in JEH, with the remaining 74.4% economic interest held by a group of investors that owned interests in JEH prior to the Company's IPO (the "Existing Owners"). The Existing Owners have no voting rights with respect to their economic interest in JEH.
	The Company has two classes of common stock, Class A common stock, which was sold to investors in the IPO, and Class B common stock. Pursuant to the Company's certificate of incorporation, each share of Class A common stock is entitled to one vote per share, and the shares of Class A common stock are entitled to 100% of the economic interests in the Company. Each share of Class B common stock has no economic rights in the Company, but entitles its holder to one vote on all matters to be voted on by the Company's stockholders generally.
	In connection with a reorganization that occurred immediately prior to the IPO, each Existing Owner was issued a number of shares of Class B common stock that is equal to the number of JEH Units that such Existing Owner holds. Holders of the Company's Class A common stock and Class B common stock generally vote together as a single class on all matters presented to the Company's stockholders for their vote or approval. Accordingly, the Existing Owners collectively have a number of votes in the Company equal to the aggregate number of JEH Units that they hold.
	The Existing Owners have the right, pursuant to the terms of an Exchange Agreement by and among the Company, JEH and each of the Existing Owners, to exchange their JEH Units (together with a corresponding number of shares of Class B common stock) 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, the Company expects that over time the Company will have an increasing economic interest in JEH as Class B common stock and JEH Units are exchanged for Class A common stock. Moreover, any transfers of JEH Units outside of the Exchange Agreement (other than permitted transfers to affiliates) must be approved by the Company. The Company intends to retain full voting and management control over JEH.
	Jones Energy, Inc.
	Condensed Consolidating Balance Sheet
	December 31, 2014
	(in thousands of dollars)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
								Subsidiaries			Guarantor
											Subsidiaries
	Assets
	Current assets
	Cash	$	100		$	1,000		$	12,436		$	30		$	—		$	13,566
	Restricted cash		—			—			149			—			—			149
	Accounts receivable, net
	Oil and gas sales		—			—			49,861			—			—			49,861
	Joint interest owners		—			—			41,761			—			—			41,761
	Other		102			8,788			3,622			—			—			12,512
	Commodity derivative assets		—			121,519			—			—			—			121,519
	Other current assets		—			451			2,923			—			—			3,374
	Intercompany receivable		4,164			1,205,608			—			(2,328	)		(1,207,444	)		—
	Total current assets		4,366			1,337,366			110,752			(2,298	)		(1,207,444	)		242,742
	Oil and gas properties, net, at cost under the successful efforts method		—			—			1,638,860			—			—			1,638,860
	Other property, plant and equipment, net		—			—			3,252			796			—			4,048
	Commodity derivative assets		—			87,055			—			—			—			87,055
	Other assets		—			20,098			254			—			—			20,352
	Deferred tax assets		171			—			—			—			—			171
	Investment in subsidiaries		231,866			—			—			—			(231,866	)		—
	Total assets	$	236,403		$	1,444,519		$	1,753,118		$	(1,502	)	$	(1,439,310	)	$	1,993,228
	Liabilities and Stockholders' Equity
	Current liabilities
	Trade accounts payable	$	—		$	288		$	136,049		$	—		$	—		$	136,337
	Oil and gas sales payable		—			—			70,469			—			—			70,469
	Accrued liabilities		—			8,914			10,487			—			—			19,401
	Deferred tax liabilities		—			718			—			—			—			718
	Asset retirement obligations		—			—			3,074			—			—			3,074
	Intercompany payable		—			—			1,209,630			—			(1,209,630	)		—
	Total current liabilities		—			9,920			1,429,709			—			(1,290,630	)		229,999
	Long-term debt		—			360,000			—			—			—			360,000
	Senior notes		—			500,000			—			—			—			500,000
	Deferred revenue		—			13,377			—			—			—			13,377
	Commodity derivative liabilities		—			28			—			—			—			28
	Asset retirement obligations		—			—			10,536			—			—			10,536
	Liability under tax receivable agreement		803			—			—			—			—			803
	Deferred tax liabilities		20,093			6,519			—			—			—			26,612
	Total liabilities		20,896			889,844			1,440,245			—			(1,209,630	)		1,141,355
	Stockholders' / members' equity
	Members' equity		—			554,675			312,873			(1,502	)		(866,046	)		—
	Class A common stock, $0.001 par value; 12,672,260 shares issued and 12,649,658 shares outstanding		13			—			—			—			—			13
	Class B common stock, $0.001 par value; 36,719,499 shares issued and outstanding		37			—			—			—			—			37
	Treasury stock, at cost; 22,602 shares		(358	)		—			—			—			—			(358	)
	Additional paid-in-capital		177,133			—			—			—			—			177,133
	Retained earnings		38,682			—			—			—			—			38,682
	Stockholders' equity		215,507			554,675			312,873			(1,502	)		(866,046	)		215,507
	Non-controlling interest		—			—			—			—			636,366			636,366
	Total stockholders' equity		215,507			554,675			312,873			(1,502	)		(229,680	)		851,873
	Total liabilities and stockholders' equity	$	236,403		$	1,444,519		$	1,753,118		$	(1,502	)	$	(1,439,310	)	$	1,993,228
	Jones Energy, Inc.
	Condensed Consolidating Balance Sheet
December 31, 2013
(in thousands of dollars)	JEI (Parent)			Issuers			Guarantor			Non-Guarantor			Eliminations			Consolidated
							Subsidiaries			Subsidiaries
Assets
Current assets
Cash	$	100		$	6,000		$	17,650		$	70		$	—		$	23,820
Restricted cash		—			—			45			—			—			45
Accounts receivable, net
Oil and gas sales		—			—			51,233			—			—			51,233
Joint interest owners		—			—			42,481			—			—			42,481
Other		—			—			16,782			—			—			16,782
Commodity derivative assets		—			8,837			—			—			—			8,837
Other current assets		—			387			2,005			—			—			2,392
Deferred tax assets		—			12			—			—			—			12
Intercompany receivable		638			1,051,389			—						(1,052,027	)		—
Total current assets		738			1,066,625			130,196			70			(1,052,027	)		145,602
Oil and gas properties, net, at cost under the successful efforts method		—			—			1,297,228			—			—			1,297,228
Other property, plant and equipment, net		—			—			2,557			887			—			3,444
Commodity derivative assets		—			25,398			—			—			—			25,398
Other assets		—			14,072			934			—			—			15,006
Investment in subsidiaries		169,081			—			—			—			(169,081	)		—
Deferred tax assets		1,301			—			—			—			—			1,301
Total assets	$	171,120		$	1,106,095		$	1,430,915		$	957		$	(1,221,108	)	$	1,487,979
Liabilities and Stockholders' Equity
Current liabilities
Trade accounts payable	$	—		$	230		$	89,200		$	—		$	—		$	89,430
Oil and gas sales payable		—			—			66,179			—			—			66,179
Accrued liabilities		87			1,642			9,076			—			—			10,805
Commodity derivative liabilities		—			10,664			—			—			—			10,664
Asset retirement obligations		—			—			2,590			—			—			2,590
Intercompany payable		—			—			1,051,935			2,279			(1,054,214	)		—
Total current liabilities		87			12,536			1,218,980			2,279			(1,054,214	)		179,668
Long-term debt		—			658,000			—			—			—			658,000
Deferred revenue		—			14,531			—			—			—			14,531
Commodity derivative liabilities		—			190			—			—			—			190
Asset retirement obligations		—			—			8,373			—			—			8,373
Deferred tax liabilities		—			3,093			—			—			—			3,093
Total liabilities		87			688,350			1,227,353			2,279			(1,054,214	)		863,855
Stockholders' / members' equity
Members' equity		—			417,745			203,562			(1,322	)		(619,985	)		—
Class A common stock, $0.001 par value; 12,526,580 shares issued and outstanding		13			—			—			—			—			13
Class B common stock, $0.001 par value; 36,836,333 shares issued and outstanding		37			—			—			—			—			37
Additional paid-in-capital		173,169			—			—			—			—			173,169
Retained earnings (deficit)		(2,186	)		—			—			—			—			(2,186	)
Stockholders' equity		171,033			417,745			203,562			(1,322	)		(619,985	)		171,033
Non-controlling interest		—			—			—			—			453,091			453,091
Total stockholders' equity		171,033			417,745			203,562			(1,322	)		(166,894	)		624,124
Total liabilities and stockholders' equity	$	171,120		$	1,106,095		$	1,430,915		$	957		$	(1,221,108	)	$	1,487,979
Jones Energy, Inc.
Condensed Consolidating Statement of Operations and Comprehensive Income
Year Ended December 31, 2014
(in thousands)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
							Subsidiaries			Guarantor
										Subsidiaries
Operating revenues
Oil and gas sales	$	—		$	—		$	378,401		$	—		$	—		$	378,401
Other revenues		—			1,154			1,042			—			—			2,196
Total operating revenues		—			1,154			379,443			—			—			380,597
Operating costs and expenses
Lease operating		—			—			43,843			—			—			43,843
Production taxes		—			—			18,094			—			—			18,094
Exploration		—			—			3,453			—			—			3,453
Depletion, depreciation and amortization		—			—			181,578			91			—			181,669
Accretion of discount		—			—			770			—			—			770
General and administrative (including non-cash compensation expense)		—			4,494			21,180			89			—			25,763
Total operating expenses		—			4,494			268,918			180			—			273,592
Operating income		—			(3,340	)		110,525			(180	)		—			107,005
Other income (expense)
Interest expense		—			(45,215	)		(1,511	)		—			—			(46,726	)
Net gain on commodity derivatives		—			189,641			—			—			—			189,641
Gain on sales of assets		—			—			297			—			—			297
Other income (expense), net		—			144,426			(1,214	)		—			—			143,212
Income (loss) before income tax		—			141,086			109,311			(180	)		—			250,217
Equity interest in income		62,785												(62,785
					—			—			—				)		—
Income tax provision
Current		53															53
Deferred		21,864			4,157												26,021
Total income tax provision		21,917			4,157			—			—			—			26,074
Net income (loss)		40,868			136,929			109,311			(180	)		(62,785	)		224,143
Net income attributable to non-controlling interests		—			—			—			—			183,275			183,275
Net income attributable to controlling interests	$	40,868			—			—			—			—		$	40,868
Jones Energy, Inc.
Condensed Consolidating Statement of Operations and Comprehensive Income
Year Ended December 31, 2013
(in thousands)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
							Subsidiaries			Guarantor
										Subsidiaries
Operating revenues
Oil and gas sales	$	—		$	—		$	258,063		$	—		$	—		$	258,063
Other revenues		—			469			637			—			—			1,106
Total operating revenues		—			469			258,700			—			—			259,169
Operating costs and expenses
Lease operating		—			—			27,781			—			—			27,781
Production taxes		—			—			12,865			—			—			12,865
Exploration		—			—			1,710			—			—			1,710
Depletion, depreciation and amortization		—			—			114,046			90			—			114,136
Impairment of oil and gas properties		—			—			14,415			—			—			14,415
Accretion of discount		—			—			608			—			—			608
General and administrative (including non-cash compensation expense)		—			4,154			27,490			258			—			31,902
Total operating expenses		—			4,154			198,915			348			—			203,417
Operating income		—			(3,685	)		59,785			(348	)		—			55,752
Other income (expense)
Interest expense		—			(29,653	)		(1,121	)		—			—			(30,774	)
Net gain (loss) on commodity derivatives		—			(2,566	)		—			—			—			(2,566	)
Gain (loss) on sales of assets		—			—			41			(119	)		—			(78	)
Other income (expense), net		—			(32,219	)		(1,080	)		(119	)		—			(33,418	)
Income (loss) before income tax		—			(35,904	)		58,705			(467	)		—			22,334
Equity interest in income		(3,400												3,400
			)		—			—			—						—
Income tax provision (benefit)
Current		85						—			—			—			85
Deferred		(1,299	)		1,143			—			—			—			(156	)
Total income tax provision (benefit)		(1,214	)		1,143			—			—			—			(71	)
Net income (loss)		(2,186	)		(37,047	)		58,705			(467	)		3,400			22,405
Net income attributable to non-controlling interests		—			—			—			—			24,591			24,591
Net income (loss) attributable to controlling interests	$	(2,186	)		—			—			—			—		$	(2,186	)
Jones Energy, Inc.
Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2014
(in thousands of dollars)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
							Subsidiaries			Guarantor
										Subsidiaries
Cash flows from operating activities
Net income (loss)	$	40,868		$	136,929		$	109,311		$	(180	)	$	(62,785	)	$	224,143
Adjustments to reconcile net income (loss) to net cash provided by operating activities		(40,510	)		(326,859	)		345,724			140			62,785			41,280
Net cash (used in) / provided by operations		358			(189,930	)		455,035			(40	)		—			265,423
Cash flows from investing activities
Additions to oil and gas properties		—			—			(474,619	)		—			—			(474,619	)
Net adjustments to purchase price of properties acquired		—			—			15,709			—			—			15,709
Proceeds from sales of assets		—			—			448			—			—			448
Acquisition of other property, plant and equipment		—			—			(1,683	)		—			—			(1,683	)
Current period settlements of matured derivative contracts		—			(3,654	)		—			—			—			(3,654	)
Change in restricted cash		—			—			(104	)		—			—			(104	)
Net cash (used in) / provided by investing		—			(3,654	)		(460,249	)		—			—			(463,903	)
Cash flows from financing activities
Proceeds from issuance of long-term debt		—			170,000			—			—			—			170,000
Repayment under long-term debt		—			(468,000	)		—			—			—			(468,000	)
Proceeds from senior notes		—			500,000			—			—			—			500,000
Payment of debt issuance costs		—			(13,416	)		—			—			—			(13,416	)
Purchase of treasury stock		(358	)		—			—			—			—			(358	)
Net cash (used in) / provided by financing		(358	)		188,584			—			—			—			188,226
Net increase (decrease) in cash		—			(5,000	)		(5,214	)		(40	)		—			(10,254	)
Cash
Beginning of period		100			6,000			17,650			70			—			23,820
End of period	$	100		$	1,000		$	12,436		$	30		$	—		$	13,566
Jones Energy, Inc.
Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2013
(in thousands of dollars)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
							Subsidiaries			Guarantor
										Subsidiaries
Cash flows from operating activities
Net income (loss)	$	(2,186	)	$	(37,047	)	$	58,705		$	(467	)	$	3,400		$	22,405
Adjustments to reconcile net income (loss) to net cash provided by operating activities		2,286			(189,393	)		315,942			733			(3,400	)		126,168
Net cash (used in) / provided by operations		100			(226,440	)		374,647			266			—			148,573
Cash flows from investing activities
Investment in subsidiary		(172,481	)		—			—			—			172,481			—
Additions to oil and gas properties		—			—			(197,618	)		—			—			(197,618	)
Acquisition of properties		—			—			(178,173	)		—			—			(178,173	)
Proceeds from sales of assets		—			—			963			644			—			1,607
Acquisition of other property, plant and equipment		—			—			(724	)		(910	)		—			(1,634	)
Current period settlements of matured derivative contracts		—			7,586			—			—			—			7,586
Change in restricted cash		—			—			(45	)		—			—			(45	)
Net cash (used in) / provided by investing		(172,481	)		7,586			(375,597	)		(266	)		172,481			(368,277	)
Cash flows from financing activities
Proceeds from investment in JEI		—			172,481			—			—			(172,481	)		—
Proceeds from issuance of long-term debt		—			220,000			—			—						220,000
Repayment under long-term debt		—			(172,000	)		—			—						(172,000	)
Payment of debt issuance costs		—			(683	)		—			—						(683	)
Proceeds from sale of common stock, net of expenses of $15.1 million		172,481			—			—			—						172,481
Net cash (used in) / provided by financing		172,481			219,798			—			—			(172,481	)		219,798
Net increase (decrease) in cash		100			944			(950	)		—			—			94
Cash
Beginning of period		—			5,056			18,600			70			—			23,726
End of period	$	100		$	6,000		$	17,650		$	70		$	—		$	23,820

Significant_Accounting_Policie1

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Significant Accounting Policies
Basis of Presentation
	Basis of Presentation
	The accompanying 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 December 31, 2014 and 2013 and the results of the operations and the cash flows for each of the three years in the period ended December 31, 2014 include the Company and all of its subsidiaries.
Segment Information
	Segment Information
	The Company operates in one industry segment, which is the exploration, development and production of oil and natural gas, and all of its operations are conducted in one geographic area of the United States.
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, fair value associated with business combinations, and asset retirement obligations ("ARO").
Financial Instruments
	Financial Instruments
	Cash, accounts receivable and accounts payable are recorded at cost. The fair value of accounts receivable and accounts payable are not materially different from their carrying amounts because of the short-term nature of these instruments. The carrying value of the outstanding balance under the Company's Revolver (as defined in Note 6) represents fair value because the Revolver has variable interest rates, which are reflective of the Company's credit risk. The Company's senior notes have a fixed interest rate and are reported at historical value as of the initial measurement date when issued and their fair value is discussed in Note 4. Derivative instruments are recorded at fair value, as discussed below.
Cash
	Cash
	Cash and cash equivalents include highly liquid investments with a maturity of three months or less. At times, the amount of cash on deposit in financial institutions exceeds federally insured limits. Management monitors the soundness of the financial institutions and believes the Company's risk is not significant.
Accounts Receivable
	Accounts Receivable
	Accounts receivable—Oil and gas sales consist of uncollateralized accrued revenues due under normal trade terms, generally requiring payment within 30 to 60 days of production. Accounts receivable—Joint interest owners consist of uncollateralized joint interest owner obligations due within 30 days of the invoice date. Accounts receivable—Other consists at December 31, 2014 of derivative positions not settled as of the balance sheet date and severance tax refunds due from state agencies and at December 31, 2013 of the adjustments to the purchase price of the Sabine properties purchased in December 2013 and severance tax refunds due from state agencies. No interest is charged on past-due balances. The Company routinely assesses the recoverability of all material trade, joint interest and other receivables to determine their collectability, and reduces the carrying amounts by a valuation allowance that reflects management's best estimate of the amounts that may not be collected. As of December 31, 2014 and 2013, the Company did not have significant allowances for doubtful accounts.
Concentration of Risk
	Concentration of Risk
	Substantially all of the Company's accounts receivable are related to the oil and gas industry. This concentration of entities may affect the Company's overall credit risk in that these entities may be affected similarly by changes in economic and other conditions, including declines in commodity prices. As of December 31, 2014, 70% of Accounts receivable—Oil and gas sales are due from 5 purchasers and 67% of Accounts receivable—Joint interest owners are due from 5 working interest owners. As of December 31, 2013, 79% of Accounts receivable—Oil and gas sales were due from 8 purchasers, and 77% of 2013 Accounts receivable—Joint interest owners were due from 5 working interest owners. If any or all of these significant counterparties were to fail to pay amounts due to the Company, the Company's financial position and results of operations could be materially and adversely affected.
Dependence on Major Customers
	Dependence on Major Customers
	The Company maintains a portfolio of crude oil and natural gas marketing contracts with large, established refiners and oil and gas purchasers. During the year ended December 31, 2014, the largest purchasers were Valero Energy Corp. ("Valero"), NGL Energy Partners LP, PVR Midstream LLC ("PVR Midstream"), Plains Marketing LP ("Plains Marketing"), and Monarch Natural Gas LLC which accounted for approximately 22%, 12%, 12%, 10% and 10% of consolidated oil and gas sales, respectively. During the year ended December 31, 2013, the largest purchasers were PVR Midstream, Unimark LLC, Mercuria Energy Group Ltd. ("Mercuria"), Valero, and Plains Marketing, which accounted for approximately 15%, 13%, 13%, 13% and 6% of consolidated oil and gas sales, respectively. During the year ended December 31, 2012, the largest purchasers were Unimark LLC, Mercuria, PVR Midstream, and Plains Marketing, which accounted for approximately 24%, 18%, 18% and 15% of consolidated oil and gas sales, respectively.
	Management believes that there are alternative purchasers and that it may be necessary to establish relationships with such new purchasers. However, there can be no assurance that the Company can establish such relationships and that those relationships will result in an increased number of purchasers. Although the Company is exposed to a concentration of credit risk, management believes that all of the Company's purchasers are credit worthy.
Dependence on Suppliers
	Dependence on Suppliers
	The Company's industry is cyclical, and from time to time, there can be an imbalance between the supply of and demand for drilling rigs, equipment, services, supplies and qualified personnel. During periods of oversupply, there can be financial pressure on suppliers. If the financial pressure leads to work interruptions or stoppages, the Company could be materially and adversely affected. Management believes that there are adequate alternative providers of drilling and completion services although it may become necessary to establish relationships with new contractors. However, there can be no assurance that the Company can establish such relationships and that those relationships will result in increased availability of drilling rigs or other services, or that they could be obtained on the same terms.
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 December 31, 2014 and 2013:
	(in thousands of dollars)		2014			2013
	Mineral interests in properties
	Unproved		$	94,526		$	99,134
	Proved			1,001,194			958,816
	Wells and equipment and related facilities			1,094,202			609,748
				2,189,922			1,667,698
	Less: Accumulated depletion and impairment			(551,062	)		(370,470	)
	Net oil and gas properties		$	1,638,860		$	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. As of December 31, 2014 and 2013, 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 capitalized less than $0.1 million in interest costs during 2014 for one project. No interest costs were capitalized in 2013. Costs incurred to maintain wells and related equipment are charged to expense as incurred.
	On the sale or retirement of a proved field, the cost and related accumulated depletion, depreciation and amortization are eliminated from the field accounts, and the resultant gain or loss is recognized.
	Capitalized amounts attributable to proved oil and gas properties are depleted by the unit-of-production method over proved reserves, using the unit conversion ratio of six thousand cubic feet of gas to one barrel of oil equivalent. Depletion of the costs of wells and related equipment and facilities, including capitalized asset retirement costs, net of salvage values, is computed using proved developed reserves. The reserve base used to calculate depreciation, depletion, and amortization for leasehold acquisition costs and the cost to acquire proved properties is the sum of proved developed reserves and proved undeveloped reserves. Depletion of oil and gas properties amounted to $180.6 million, $113.3 million and $79.9 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	The Company reviews its proved oil and natural gas properties, including related wells and equipment, for impairment by comparing expected undiscounted future cash flows at a producing field level to the net capitalized cost of the asset. If the future undiscounted cash flows, based on the Company's estimate of future commodity prices, operating costs, and production, are lower than the net capitalized cost, the capitalized cost is reduced to fair value. Fair value is calculated by discounting the future cash flows at an appropriate risk-adjusted discount rate. Due to the significant assumptions associated with the inputs and calculations described, the fair value of oil and gas properties used in estimating impairment represents a nonrecurring Level 3 measurement. No impairments of proved properties were recorded in 2014 or 2013. The Company incurred impairment charges of $18.8 million related to its proved oil and natural gas properties and equipment in 2012.
	The Company evaluates its unproved properties for impairment on a property-by-property basis. The Company's unproved property consists of acquisition costs related to its undeveloped acreage. The Company reviews the unproved property for indicators of impairment based on the Company's current exploration plans with consideration given to results of any drilling and seismic activity during the period and known information regarding exploration and development activity by other companies on adjacent blocks. The Company incurred no impairment charges related to its unproved properties in 2014 or 2012. In the fourth quarter of 2013, the Company recorded an impairment charge of $14.4 million related to its unproved Southridge properties in the Arkoma basin. As the Company did not drill the required number of wells by October 31, 2013 necessary to keep its joint development agreement with Southridge in effect, the Company lost its right to the undeveloped acreage. Impairment of oil and gas properties charges are recorded on the Consolidated Statement of Operations.
	On the sale of an entire interest in an unproved property, gain or loss on the sale is recognized, taking into consideration the amount of any recorded impairment if the property had been assessed individually. If a partial interest in an unproved property is sold, the amount received is treated as a reduction of the cost of the interest retained.
Other Property, Plant and Equipment
	Other Property, Plant and Equipment
	Other property, plant and equipment consisted of the following at December 31, 2014 and 2013:
	(in thousands of dollars)		2014			2013
	Leasehold improvements		$	1,218		$	1,060
	Furniture, fixtures, computers and software			3,727			2,491
	Vehicles			988			835
	Aircraft			910			910
	Other			219			134
				7,062			5,430
	Less: Accumulated depreciation and amortization			(3,014	)		(1,986	)
	Net other property, plant and equipment		$	4,048		$	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 $1.1 million, $0.8 million and $0.8 million during the years ended December 31, 2014, 2013 and 2012, respectively.
Oil and Gas Sales Payable
	Oil and Gas Sales Payable
	Oil and gas sales payable represents amounts collected from purchasers for oil and gas sales, which are due to other revenue interest owners. Generally, the Company is required to remit amounts due under these liabilities within 60 days of receipt.
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 years ended December 31, 2014, 2013 and 2012, 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 ("ARO") consist of future plugging and abandonment expenses on oil and natural gas properties. The Company estimates an ARO for each well in the period in which it is incurred based on estimated present value of plugging and abandonment costs, increased by an inflation factor to the estimated date that the well would be plugged. The resulting liability is recorded by increasing the carrying amount of the related long- lived asset. The liability is then accreted to its then-present value each period and the capitalized cost is depleted over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, a gain or loss is recognized. The ARO is classified as current or noncurrent based on the expect timing of payments. A summary of the Company's ARO for the years ended December 31, 2014 and 2013 is as follows:
	(in thousands of dollars)		2014			2013
	ARO liability at beginning of year		$	10,963		$	9,506
	Liabilities incurred(1)			1,995			1,515
	Accretion of discount			770			608
	Liabilities settled due to sale of related properties			(109	)		(271	)
	Liabilities settled due to plugging and abandonment			(55	)		(702	)
	Change in estimate			46			307
	ARO liability at end of year			13,610			10,963
	Less: Current portion of ARO at end of year			(3,074			(2,590
					)			)
	Total long-term ARO at end of year		$	10,536		$	8,373
	-1	Includes $824 related to wells acquired in 2013 (see Note 3, "Acquisition of Properties").
Revenue Recognition	Revenue Recognition
	Revenues from the sale of crude oil, natural gas, and natural gas liquids are recognized when the product is delivered at a fixed or determinable price, title has transferred, collectability is reasonably assured and evidenced by a contract. The Company follows the "sales method" of accounting for its oil and natural gas revenue, so it recognizes revenue on all crude oil, natural gas, and natural gas liquids sold to purchasers. A receivable or liability is recognized only to the extent that the Company has an imbalance on a specific property greater than the expected remaining proved reserves.
Production Costs
	Production Costs
	Production costs, including compressor rental, pumpers' salaries, saltwater disposal, ad valorem taxes, insurance, repairs and maintenance, expensed workovers and other operating expenses are expensed as incurred and included in lease operating expense on the Consolidated Statement of Operations.
Exploration Expenses
	Exploration Expenses
	Exploration expenses include dry hole costs, lease extensions, delay rentals and geological and geophysical costs.
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.
Liability under Tax Receivable Agreement
	Liability under Tax Receivable Agreement
	In connection with the IPO, the Company entered into a Tax Receivable Agreement (the "TRA") which obligated the Company to make payments to certain current and former owners equal to 85% of the applicable cash savings that the Company realizes as a result of tax attributes arising from exchanges of JEH Units and JEI Class B shares held by those owners for Class A shares of JEI common stock. The Company will retain the benefit of the remaining 15% of these tax savings.
	As a result of exchanges made through December 31, 2014, the Company has accrued future tax benefits of $0.9 million and has recorded this amount as a deferred tax asset on its consolidated balance sheet. As of December 31, 2014, the Company has recorded a liability of $0.8 million associated with its future TRA obligation. The actual amount and timing of payments made under the TRA will depend upon a number of factors, including the amount and timing of taxable income generated in the future, changes in future tax rates, the use of loss carryovers, and the portion of the Company's payments under the TRA constituting imputed interest. To the extent the Company does not realize all of the tax benefits in future years or in the event of a change in future tax rates, this liability may change.
	As of December 31, 2014, the Company has made no payments under the TRA and does not anticipate making a material payment under the TRA in 2015.
Comprehensive Income
	Comprehensive Income
	The Company has no elements of comprehensive income other than net income.
Statement of Cash Flows
	Statement of Cash Flows
	The Company presents its cash flows using the indirect method.
Related Party Transactions
	Related Party Transactions
	In the years ended December 31, 2013 and 2012, the Company paid an annual administration fee to Metalmark of $0.7 million. This amount was charged to expense. As a result of the IPO, this fee is no longer payable to Metalmark.
	On May 7, 2013, the Company entered into a natural gas sale and purchase agreement with Monarch Natural Gas, LLC, ("Monarch"), under which Monarch has the first right to gather the natural gas the Company produces from dedicated properties, process the NGLs from this natural gas production and market the processed natural gas and extracted NGLs. Under the Monarch agreement, the Company is paid a specified percentage of the value of the NGLs extracted and sold by Monarch, based on a set liquids recovery percentage, and the amount received from the sale of the residue gas, after deducting a fixed volume for fuel, lost and unaccounted for gas. The Company produced approximately 1.4 MMBoe of natural gas and NGLs for the year ended December 31, 2014 and 0.8 MMBoe of natural gas and NGLs for the year ended December 31, 2013, from the properties that became subject to the Monarch agreement. The initial term of the agreement runs for 10 years from the effective date of September 1, 2013.
	At the time the Company entered into the agreement, Metalmark Capital owned approximately 81% of the outstanding equity interests of Monarch. In addition, Metalmark Capital beneficially owns in excess of five percent of the Company's outstanding equity interests and two of our directors, Howard I. Hoffen and Gregory D. Myers, are managing directors of Metalmark Capital. In connection with the Company's entering into the Monarch agreement, Monarch issued to JEH equity interests in Monarch having a deemed value of $15 million. JEH assigned $2.4 million of the Monarch equity interests to Jonny Jones, the Company's chief executive officer and chairman of the board, and reserved $2.6 million of the Monarch equity interests to a benefit plan established for certain of the Company's officers, including Mike McConnell, Robert Brooks and Eric Niccum. The remaining $10 million of Monarch equity was distributed to certain of the pre-IPO owners, which include Metalmark Capital, Wells Fargo, the Jones family entities, and certain of the Company's officers and directors, including Jonny Jones, Mike McConnell and Eric Niccum.
	In September 2014, the Company signed a 10-year oil gathering and transportation agreement with Monarch Oil Pipeline LLC, pursuant to which Monarch Oil Pipeline, LLC will build, at its expense, a new oil gathering system and connect to dedicated Company leases in Texas. At the time the Company entered into the agreement, Metalmark Capital owned the majority of the outstanding equity interests of Monarch Oil Pipeline, LLC and/or its parent. The system is expected to begin service during the second quarter of 2015 and provide connectivity to both a regional refinery market as well as the Cushing market hub. The Company has reserved capacity of up to 12,000 barrels per day on the system with the potential to increase throughput at a future date.
Stock Compensation
	Stock Compensation
	JEH implemented a management incentive plan effective January 1, 2010, that provided awards of membership interests in JEH to members of senior management ("management units"). The management unit grants awarded prior to the initial filing of the IPO registration statement in March 2013 had a dual vesting schedule and were fully vested as of December 31, 2014. Grants awarded after the initial IPO registration statement generally 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. At December 31, 2014, there were 274,385 unvested JEH Units and shares of Class B common stock that will become convertible into a like number of shares of Class A common stock upon vesting.
	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.
	During 2014, the Company granted performance unit and restricted stock unit awards to certain officers and employees under the Jones Energy, Inc. 2013 Omnibus Incentive Plan. The fair value of the performance units was based on the grant date fair value (using a Monte Carlo simulation model) and is expensed on a straight-line basis over the applicable three-year performance period. The number of shares of Class A common stock issuable upon vesting of the performance unit awards ranges from zero to 200% based on the Company's total shareholder return relative to an industry peer group over the applicable three-year performance period. The fair value of the restricted stock unit awards 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 applicable three-year vesting period.
	In September 2014 and 2013, the Company granted each of the outside members of the Board of Directors 5,486 and 6,645 shares, respectively, 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 director and employee stock-based compensation awards
Business Combinations
	Business Combinations
	For acquisitions of working interests that are accounted for as business combinations, the results of operations are included in the Consolidated Statement of Operations from the date of acquisition. Purchase prices are allocated to assets acquired based on their estimated fair values at the time of acquisition. 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. The fair value measurement is based on the assumptions of market participants and not those of the reporting entity. Therefore, entity-specific intentions do not impact the measurement of fair value. The fair value of oil and natural gas properties is determined using a risk-adjusted after-tax discounted cash flow analysis based upon significant inputs including: 1) oil and gas prices, 2) projections of estimated quantities of oil and natural gas reserves, including those classified as proved, probable and possible, 3) projections of future rates of production, 4) timing and amount of future development and operating costs, 5) projected reserve recovery factors, and 6) weighted average cost of capital.
Recent Accounting Pronouncements
	Recent Accounting Pronouncements
	In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2014-09, "Revenue from Contracts with Customers," which creates a new topic in the Accounting Standards Codification ("ASC"), topic 606, "Revenue from Contracts with Customers." This ASU sets forth a five-step model for determining when and how revenue is recognized. Under the model, an entity will be required to recognize revenue to depict the transfer of goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods or services. Additional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. The amendments are effective for fiscal years, and interim periods within those years, beginning after December 15, 2016 and may be applied on either a full or modified retrospective basis. Early adoption is not permitted. We do not expect the adoption of these provisions to have a significant impact on the Company's consolidated financial statements. However, we will continue to assess the anticipated impact as further implementation guidance is released from the FASB.
	In August 2014, the FASB issued ASU No. 2014-15, "Presentation of Financial Statements—Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concern." This ASU requires management to evaluate whether there are conditions or events that raise substantial doubt about an entity's ability to continue as a "going concern" and to provide disclosures when certain criteria are met. Substantial doubt exists when relevant conditions and events, considered in the aggregate, indicate that it is probable that the entity will be unable to meet its obligations as they become due within one year after the date that the financial statements are issued (or available to be issued). The amendments are effective for fiscal years, and interim periods within those years, beginning after December 15, 2016. Early adoption is permitted. We do not expect the adoption of these disclosures to have a significant impact on the Company's consolidated financial statements.
	In January 2015, the FASB issued Accounting Standards Update No. 2015-01, Income Statement—Extraordinary and Unusual Items ("ASU 2015-01"). ASU 2015-01 removes the concept of extraordinary items from GAAP. Under existing guidance, an entity is required to separately disclose extraordinary items, net of tax, in the income statement after income from continuing operations if an event or transaction is of an unusual nature and occurs infrequently. This separate, net-of-tax presentation will no longer be allowed. ASU 2015-01 is effective for interim and annual reporting periods beginning after December 15, 2015. The Company does not expect the adoption of this guidance to have a material impact on its financial position, cash flows or results of operations.

Significant_Accounting_Policie2

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Significant Accounting Policies
Schedule of oil and gas properties
	(in thousands of dollars)		2014			2013
	Mineral interests in properties
	Unproved		$	94,526		$	99,134
	Proved			1,001,194			958,816
	Wells and equipment and related facilities			1,094,202			609,748
				2,189,922			1,667,698
	Less: Accumulated depletion and impairment			(551,062	)		(370,470	)
	Net oil and gas properties		$	1,638,860		$	1,297,228
Schedule of other property, plant and equipment
	(in thousands of dollars)		2014			2013
	Leasehold improvements		$	1,218		$	1,060
	Furniture, fixtures, computers and software			3,727			2,491
	Vehicles			988			835
	Aircraft			910			910
	Other			219			134
				7,062			5,430
	Less: Accumulated depreciation and amortization			(3,014	)		(1,986	)
	Net other property, plant and equipment		$	4,048		$	3,444
Summary of the Company's ARO
	(in thousands of dollars)		2014			2013
	ARO liability at beginning of year		$	10,963		$	9,506
	Liabilities incurred(1)			1,995			1,515
	Accretion of discount			770			608
	Liabilities settled due to sale of related properties			(109	)		(271	)
	Liabilities settled due to plugging and abandonment			(55	)		(702	)
	Change in estimate			46			307
	ARO liability at end of year			13,610			10,963
	Less: Current portion of ARO at end of year			(3,074			(2,590
					)			)
	Total long-term ARO at end of year		$	10,536		$	8,373
	-1	Includes $824 related to wells acquired in 2013 (see Note 3, "Acquisition of Properties").

Acquisition_of_Properties_Tabl

Acquisition of Properties (Tables)	12 Months Ended
	Dec. 31, 2014
Sabine acquisition
Acquisition of Properties
Schedule of purchase price allocation
	(in thousands of dollars)
	Oil and gas properties
	Unproved		$	32,964
	Proved			147,024
	Asset retirement obligations			(824	)
	Total purchase price		$	179,164
Schedule of unaudited pro forma results of operations
						Year Ended
						December 31,
			Post			2013
	(in thousands of dollars)		Acquisition(1)			Pro Forma
			(unaudited)			(unaudited)
	Total operating revenue		$	1,365		$	308,773
	Total operating expenses			291			229,648
	Operating income			1,074			79,125
	Net income			1,074			45,778
	-1	Represents revenues and expenses for the post acquisition period of December 18, 2013 to December 31, 2013 included in the Consolidated Statement of Operations.
Chalker acquisition
Acquisition of Properties
Schedule of purchase price allocation
	(in thousands of dollars)
	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
			Year Ended
			December 31,
			2012
	(in thousands of dollars)		Pro Forma
			(unaudited)
	Total operating revenue		$	194,685
	Total operating expenses			161,053
	Operating income			33,632
	Net income			25,713

Fair_Value_Measurement_Tables

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Measurement
Schedule of financial instruments carried at fair value
		December 31, 2014
		Fair Value Measurements Using
	(in thousands of dollars)	(Level 1)			(Level 2)			(Level 3)			Total
	Commodity Price Hedges
	Current assets	$	—		$	120,604		$	915		$	121,519
	Long-term assets		—			85,162			1,893			87,055
	Current liabilities		—			—			—			—
	Long-term liabilities		—			—			28			28
		December 31, 2013
		Fair Value Measurements Using
	(in thousands of dollars)	(Level 1)			(Level 2)			(Level 3)			Total
	Commodity Price Hedges
	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	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 December 31, 2014.
		Quantitative Information About Level 3 Fair Value Measurements
	Commodity Price Hedges	Fair Value			Valuation Technique		Unobservable		Range
		(000's)					Input
	Natural gas liquid swaps	$	3,045		Use a discounted cash flow approach using inputs including forward price statements from counterparties		Natural gas liquid futures		$8.09 - $75.52 per barrel
	Natural gas basis swaps	$	(265	)	Use a discounted cash flow approach using inputs including forward price statements from counterparties		Natural gas basis swaps		$(0.11) - $(0.17) per barrel
Schedule of changes in fair value of Level 3 financial instruments
	(in thousands of dollars)
	Balance at December 31, 2012, net	$	(1,519	)
	Purchases		(1,095	)
	Settlements		(210	)
	Transfers to Level 2		(753	)
	Changes in fair value		2,342
	Balance at December 31, 2013, net		(1,235	)
	Purchases		668
	Settlements		476
	Transfers into Level 3		(265	)
	Transfers to Level 2		332
	Changes in fair value		2,804
	Balance at December 31, 2014, net	$	2,780
Schedule of fair value of financial instruments that are not recorded at fair value in the consolidated financial statements
		December 31, 2014						December 31, 2013
	(in thousands of dollars)	Carrying			Fair Value			Carrying			Fair Value
		Amount						Amount
	Debt:
	Revolver	$	360,000		$	360,000		$	498,000		$	498,000
	Term loan		—			—			160,000			160,000
	2022 Notes		500,000			384,375			—			—

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 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
		December 31, 2014
				Low			High			Weighted			Final
										Average			Expiration
	Oil swaps	Exercise price		$	75.05		$	100.95		$	84.2
		Barrels per month			45,000			184,054			113,852		Dec-18
	Natural gas swaps	Exercise price		$	3.37		$	6.45		$	4.4
		mmbtu per month			710,000			1,772,584			1,175,275		Dec-18
	Basis swaps	Contract differential		$	(0.39	)	$	(0.11	)	$	(0.21	)
		mmbtu per month			320,000			980,000			716,667		Mar-16
	Natural gas liquids swaps	Exercise price		$	8.09		$	95.24		$	42.46
		Barrels per month			2,000			143,000			50,444		Dec-17
		December 31, 2013
				Low			High			Weighted			Final
										Average			Expiration
	Oil swaps	Exercise price		$	81.7		$	102.84		$	89.03
		Barrels per month			29,000			161,613			96,149		Dec-17
	Natural gas swaps	Exercise price		$	3.88		$	6.9		$	4.26
		mmbtu per month			510,000			1,290,000			830,275		Dec-17
	Basis swaps	Contract differential		$	(0.43	)	$	(0.11	)	$	(0.34	)
		mmbtu per month			320,000			690,000			467,037		Mar-16
	Natural gas liquids swaps	Exercise price		$	6.72		$	95.24		$	32.98
		Barrels per month			2,000			118,000			46,646		Dec-17
Schedule of commodity derivative contracts that are netted on Consolidated Balance Sheet
	(in thousands of dollars)	Gross Amounts			Gross			Net Amounts			Gross			Net Amount
		of Recognized			Amounts			of Assets /			Amounts
		Assets /			Offset in the			Liabilities			Not
		Liabilities			Balance			Presented in			Offset in the
					Sheet			the Balance			Balance
								Sheet			Sheet
	December 31, 2014
	Commodity derivative contracts
	Assets	$	208,646		$	(72	)	$	208,574		$	—		$	208,574
	Liabilities		(100	)		72			(28	)		—			(28	)
	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	)

Stockbased_Compensation_Tables

Stock-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Performance Units Awards
Stock-based Compensation
Schedule of assumptions used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense
	The following assumptions were used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense during the twelve months ended December 31, 2014:
	Stock Price(1)		$	17.07
	Beginning Average Stock Price(2)		$	14.78
	Expected Volatility(3)			46.95	%
	Risk-Free Rate of Return(4)			0.61	%
	-1	Based on the closing price of Jones Energy, Inc. Class A common stock on May 20, 2014.
	-2	Based on the 10 trading days immediately prior to the beginning of the performance period.
	-3	Based on the average historical volatilities over the most recent 2.62-year period for the Company and each peer company using daily stock prices through May 20, 2014. The measurement period reflects the 2.62 years remaining in the performance period as of the grant date.
	-4	Based on the yield curve of U.S. Treasury rates as of May 20, 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, 2013			—			—
	Granted			26,580		$	15.05
	Forfeited			—			—
	Vested			—			—
	Unvested at December 31, 2013			26,580		$	15.05
	Granted			27,430		$	18.77
	Forfeited			—			—
	Vested			(26,580	)	$	15.05
	Unvested at December 31, 2014			27,430		$	18.77
Officers and employees | Restricted stock
Stock-based Compensation
Summary of information related to the Units/shares or awards
			Restricted			Weighted Average
			Stock Unit			Grant Date Fair
			Awards			Value per Share
	Unvested at January 1, 2014			—			—
	Granted			340,001		$	17.31
	Forfeited			(13,688	)	$	17.07
	Vested			(1,416	)	$	17.07
	Unvested at December 31, 2014			324,897		$	17.33
Officers and employees | Performance Units Awards
Stock-based Compensation
Summary of information related to the Units/shares or awards
			Performance			Weighted Average
			Unit Awards			Grant Date Fair
						Value per Share
	Unvested at January 1, 2014			—			—
	Granted			201,318		$	21.65
	Forfeited			(8,320	)	$	21.65
	Vested			—			—
	Unvested at December 31, 2014			192,998		$	21.65
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, 2013			710,767		$	3.62
	Granted			911,654		$	15
	Forfeited			(167,239	)	$	3.62
	Vested			(998,032	)	$	9.96
	Unvested at December 31, 2013			457,150		$	12.46
	Granted			21,405		$	6.66
	Forfeited			(21,405	)	$	6.66
	Vested			(182,765	)	$	8.65
	Unvested at December 31, 2014			274,385		$	15

Earnings_per_Share_Tables

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings per Share
Schedule of calculation of the basic and diluted weighted-average shares and EPS
	(in thousands, except per share data)	2014		2013
	Income (numerator):
	Net income (loss) attributable to controlling interests	$	40,868	$	(2,186	)
	Weighted-average shares (denominator):
	Weighted-average number of shares of Class A common stock		12,526		12,500
	Earnings (loss) per share:
	Basic earnings per share	$	3.26	$	(0.17	)
	(in thousands, except per share data)	2014		2013
	Income (numerator):
	Net income (loss) attributable to controlling interests	$	40,868	$	(2,186	)
	Weighted-average shares (denominator):
	Weighted-average number of shares of Class A common stock		12,535		12,500
	Earnings (loss) per share:
	Diluted earnings per share	$	3.26	$	(0.17	)
	Anti-dilutive shares of Class A common stock		275		27

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies
Schedule of future minimum payments for noncancellable operating leases extending beyond one year
	(in thousands of dollars)
	Years Ending December 31,
	2015	$	944
	2016		954
	2017		1,038
	2018		1,101
	2019		1,122
	Thereafter		377
		$	5,536

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Taxes
Schedule of income tax provision
		Year Ended December 31,
	(in thousands of dollars)	2014			2013			2012
	Current tax expense:
	Federal	$	53		$	85		$	—
	State		—			—			—
	Total current expense		53			85			—
	Deferred tax expense (benefit):
	Federal		21,996			(1,260	)		—
	State		4,025			1,104			473
	Total deferred expense (benefit)		26,021			(156	)		473
	Total tax expense (benefit)	$	26,074		$	(71	)	$	473
	Tax expense (benefit) attributable to controlling interests	$	22,675		$	(1,223	)	$	473
	Tax expense attributable to non-controlling interests		3,399			1,152			—
	Total income tax expense (benefit)	$	26,074		$	(71	)	$	473
Schedule of reconciliation of the Company's provision for income taxes as reported and the amount computed by multiplying income before taxes, less non-controlling interest, by the U.S. federal statutory rate
	(in thousands of dollars)	2014			2013
	Provision calculated at federal statutory income tax rate:
	Net income before taxes	$	250,217		$	22,334
	Statutory rate		35	%		35	%
	Income tax expense computed at statutory rate	$	87,577		$	7,817
	Less: Non-controlling interests		(65,336	)		(9,009	)
	Income tax expense (benefit) attributable to controlling interests		22,241			(1,192	)
	State and local income taxes, net of federal benefit		626			(49	)
	Other		(192	)		18
	Tax expense (benefit) attributable to controlling interests		22,675			(1,223	)
	Tax expense attributable to non-controlling interests		3,399			1,152
	Total income tax expense (benefit)	$	26,074		$	(71	)
Schedule of significant components of the Company's deferred tax assets and deferred tax liability
		As of December 31,
	(in thousands of dollars)	2014			2013
	Deferred tax assets
	Investment in consolidated subsidiary JEH	$	—		$	526
	Net operating loss		8,223			649
	Section 754 election tax basis adjustment		945			—
	Alternative minimum tax credits		53			86
	Other deferred tax asset		232			52
	Total deferred tax assets		9,453			1,313
	Deferred tax liabilities
	Current state deferred tax liability		718			—
	Investment in consolidated subsidiary JEH		29,163			—
	Noncurrent state deferred tax liability		6,731			3,093
	Total deferred tax liabilities		36,612			3,093
	Net deferred tax assets (liabilities)		(27,159	)		(1,780	)
	Valuation allowance		—			—
	Net deferred tax assets (liabilities)	$	(27,159	)	$	(1,780	)

Condensed_Consolidating_Financ

Condensed Consolidating Financial Statements (Tables)	12 Months Ended
	Dec. 31, 2014
Subsidiary Guarantors
Condensed Consolidating Balance Sheet
	Condensed Consolidating Balance Sheet
	December 31, 2014
	(in thousands of dollars)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
								Subsidiaries			Guarantor
											Subsidiaries
	Assets
	Current assets
	Cash	$	100		$	1,000		$	12,436		$	30		$	—		$	13,566
	Restricted cash		—			—			149			—			—			149
	Accounts receivable, net
	Oil and gas sales		—			—			49,861			—			—			49,861
	Joint interest owners		—			—			41,761			—			—			41,761
	Other		102			8,788			3,622			—			—			12,512
	Commodity derivative assets		—			121,519			—			—			—			121,519
	Other current assets		—			451			2,923			—			—			3,374
	Intercompany receivable		4,164			1,205,608			—			(2,328	)		(1,207,444	)		—
	Total current assets		4,366			1,337,366			110,752			(2,298	)		(1,207,444	)		242,742
	Oil and gas properties, net, at cost under the successful efforts method		—			—			1,638,860			—			—			1,638,860
	Other property, plant and equipment, net		—			—			3,252			796			—			4,048
	Commodity derivative assets		—			87,055			—			—			—			87,055
	Other assets		—			20,098			254			—			—			20,352
	Deferred tax assets		171			—			—			—			—			171
	Investment in subsidiaries		231,866			—			—			—			(231,866	)		—
	Total assets	$	236,403		$	1,444,519		$	1,753,118		$	(1,502	)	$	(1,439,310	)	$	1,993,228
	Liabilities and Stockholders' Equity
	Current liabilities
	Trade accounts payable	$	—		$	288		$	136,049		$	—		$	—		$	136,337
	Oil and gas sales payable		—			—			70,469			—			—			70,469
	Accrued liabilities		—			8,914			10,487			—			—			19,401
	Deferred tax liabilities		—			718			—			—			—			718
	Asset retirement obligations		—			—			3,074			—			—			3,074
	Intercompany payable		—			—			1,209,630			—			(1,209,630	)		—
	Total current liabilities		—			9,920			1,429,709			—			(1,290,630	)		229,999
	Long-term debt		—			360,000			—			—			—			360,000
	Senior notes		—			500,000			—			—			—			500,000
	Deferred revenue		—			13,377			—			—			—			13,377
	Commodity derivative liabilities		—			28			—			—			—			28
	Asset retirement obligations		—			—			10,536			—			—			10,536
	Liability under tax receivable agreement		803			—			—			—			—			803
	Deferred tax liabilities		20,093			6,519			—			—			—			26,612
	Total liabilities		20,896			889,844			1,440,245			—			(1,209,630	)		1,141,355
	Stockholders' / members' equity
	Members' equity		—			554,675			312,873			(1,502	)		(866,046	)		—
	Class A common stock, $0.001 par value; 12,672,260 shares issued and 12,649,658 shares outstanding		13			—			—			—			—			13
	Class B common stock, $0.001 par value; 36,719,499 shares issued and outstanding		37			—			—			—			—			37
	Treasury stock, at cost; 22,602 shares		(358	)		—			—			—			—			(358	)
	Additional paid-in-capital		177,133			—			—			—			—			177,133
	Retained earnings		38,682			—			—			—			—			38,682
	Stockholders' equity		215,507			554,675			312,873			(1,502	)		(866,046	)		215,507
	Non-controlling interest		—			—			—			—			636,366			636,366
	Total stockholders' equity		215,507			554,675			312,873			(1,502	)		(229,680	)		851,873
	Total liabilities and stockholders' equity	$	236,403		$	1,444,519		$	1,753,118		$	(1,502	)	$	(1,439,310	)	$	1,993,228
	Condensed Consolidating Balance Sheet
	December 31, 2013
	(in thousands of dollars)	JEI (Parent)			Issuers			Guarantor			Non-Guarantor			Eliminations			Consolidated
								Subsidiaries			Subsidiaries
	Assets
	Current assets
	Cash	$	100		$	6,000		$	17,650		$	70		$	—		$	23,820
	Restricted cash		—			—			45			—			—			45
	Accounts receivable, net
	Oil and gas sales		—			—			51,233			—			—			51,233
	Joint interest owners		—			—			42,481			—			—			42,481
Other		—			—			16,782			—			—			16,782
Commodity derivative assets		—			8,837			—			—			—			8,837
Other current assets		—			387			2,005			—			—			2,392
Deferred tax assets		—			12			—			—			—			12
Intercompany receivable		638			1,051,389			—						(1,052,027	)		—
Total current assets		738			1,066,625			130,196			70			(1,052,027	)		145,602
Oil and gas properties, net, at cost under the successful efforts method		—			—			1,297,228			—			—			1,297,228
Other property, plant and equipment, net		—			—			2,557			887			—			3,444
Commodity derivative assets		—			25,398			—			—			—			25,398
Other assets		—			14,072			934			—			—			15,006
Investment in subsidiaries		169,081			—			—			—			(169,081	)		—
Deferred tax assets		1,301			—			—			—			—			1,301
Total assets	$	171,120		$	1,106,095		$	1,430,915		$	957		$	(1,221,108	)	$	1,487,979
Liabilities and Stockholders' Equity
Current liabilities
Trade accounts payable	$	—		$	230		$	89,200		$	—		$	—		$	89,430
Oil and gas sales payable		—			—			66,179			—			—			66,179
Accrued liabilities		87			1,642			9,076			—			—			10,805
Commodity derivative liabilities		—			10,664			—			—			—			10,664
Asset retirement obligations		—			—			2,590			—			—			2,590
Intercompany payable		—			—			1,051,935			2,279			(1,054,214	)		—
Total current liabilities		87			12,536			1,218,980			2,279			(1,054,214	)		179,668
Long-term debt		—			658,000			—			—			—			658,000
Deferred revenue		—			14,531			—			—			—			14,531
Commodity derivative liabilities		—			190			—			—			—			190
Asset retirement obligations		—			—			8,373			—			—			8,373
Deferred tax liabilities		—			3,093			—			—			—			3,093
Total liabilities		87			688,350			1,227,353			2,279			(1,054,214	)		863,855
Stockholders' / members' equity
Members' equity		—			417,745			203,562			(1,322	)		(619,985	)		—
Class A common stock, $0.001 par value; 12,526,580 shares issued and outstanding		13			—			—			—			—			13
Class B common stock, $0.001 par value; 36,836,333 shares issued and outstanding		37			—			—			—			—			37
Additional paid-in-capital		173,169			—			—			—			—			173,169
Retained earnings (deficit)		(2,186	)		—			—			—			—			(2,186	)
Stockholders' equity		171,033			417,745			203,562			(1,322	)		(619,985	)		171,033
Non-controlling interest		—			—			—			—			453,091			453,091
Total stockholders' equity		171,033			417,745			203,562			(1,322	)		(166,894	)		624,124
Total liabilities and stockholders' equity	$	171,120		$	1,106,095		$	1,430,915		$	957		$	(1,221,108	)	$	1,487,979
Condensed Consolidating Statements of Operations
	Condensed Consolidating Statement of Operations and Comprehensive Income
	Year Ended December 31, 2014
	(in thousands)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
								Subsidiaries			Guarantor
											Subsidiaries
	Operating revenues
	Oil and gas sales	$	—		$	—		$	378,401		$	—		$	—		$	378,401
	Other revenues		—			1,154			1,042			—			—			2,196
	Total operating revenues		—			1,154			379,443			—			—			380,597
	Operating costs and expenses
	Lease operating		—			—			43,843			—			—			43,843
	Production taxes		—			—			18,094			—			—			18,094
	Exploration		—			—			3,453			—			—			3,453
	Depletion, depreciation and amortization		—			—			181,578			91			—			181,669
	Accretion of discount		—			—			770			—			—			770
	General and administrative (including non-cash compensation expense)		—			4,494			21,180			89			—			25,763
	Total operating expenses		—			4,494			268,918			180			—			273,592
	Operating income		—			(3,340	)		110,525			(180	)		—			107,005
	Other income (expense)
	Interest expense		—			(45,215	)		(1,511	)		—			—			(46,726	)
	Net gain on commodity derivatives		—			189,641			—			—			—			189,641
	Gain on sales of assets		—			—			297			—			—			297
	Other income (expense), net		—			144,426			(1,214	)		—			—			143,212
	Income (loss) before income tax		—			141,086			109,311			(180	)		—			250,217
	Equity interest in income		62,785												(62,785
						—			—			—				)		—
	Income tax provision
	Current		53															53
	Deferred		21,864			4,157												26,021
	Total income tax provision		21,917			4,157			—			—			—			26,074
	Net income (loss)		40,868			136,929			109,311			(180	)		(62,785	)		224,143
	Net income attributable to non-controlling interests		—			—			—			—			183,275			183,275
	Net income attributable to controlling interests	$	40,868			—			—			—			—		$	40,868
	Condensed Consolidating Statement of Operations and Comprehensive Income
	Year Ended December 31, 2013
	(in thousands)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
								Subsidiaries			Guarantor
											Subsidiaries
	Operating revenues
	Oil and gas sales	$	—		$	—		$	258,063		$	—		$	—		$	258,063
	Other revenues		—			469			637			—			—			1,106
	Total operating revenues		—			469			258,700			—			—			259,169
	Operating costs and expenses
	Lease operating		—			—			27,781			—			—			27,781
	Production taxes		—			—			12,865			—			—			12,865
	Exploration		—			—			1,710			—			—			1,710
	Depletion, depreciation and amortization		—			—			114,046			90			—			114,136
	Impairment of oil and gas properties		—			—			14,415			—			—			14,415
	Accretion of discount		—			—			608			—			—			608
	General and administrative (including non-cash compensation expense)		—			4,154			27,490			258			—			31,902
	Total operating expenses		—			4,154			198,915			348			—			203,417
	Operating income		—			(3,685	)		59,785			(348	)		—			55,752
	Other income (expense)
	Interest expense		—			(29,653	)		(1,121	)		—			—			(30,774	)
	Net gain (loss) on commodity derivatives		—			(2,566	)		—			—			—			(2,566	)
	Gain (loss) on sales of assets		—			—			41			(119	)		—			(78	)
	Other income (expense), net		—			(32,219	)		(1,080	)		(119	)		—			(33,418	)
	Income (loss) before income tax		—			(35,904	)		58,705			(467	)		—			22,334
	Equity interest in income		(3,400												3,400
				)		—			—			—						—
	Income tax provision (benefit)
	Current		85						—			—			—			85
	Deferred		(1,299	)		1,143			—			—			—			(156	)
Total income tax provision (benefit)		(1,214	)		1,143			—			—			—			(71	)
Net income (loss)		(2,186	)		(37,047	)		58,705			(467	)		3,400			22,405
Net income attributable to non-controlling interests		—			—			—			—			24,591			24,591
Net income (loss) attributable to controlling interests	$	(2,186	)		—			—			—			—		$	(2,186	)
Condensed Statements of Cash Flows
	Condensed Consolidating Statement of Cash Flows
	Year Ended December 31, 2014
	(in thousands of dollars)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
								Subsidiaries			Guarantor
											Subsidiaries
	Cash flows from operating activities
	Net income (loss)	$	40,868		$	136,929		$	109,311		$	(180	)	$	(62,785	)	$	224,143
	Adjustments to reconcile net income (loss) to net cash provided by operating activities		(40,510	)		(326,859	)		345,724			140			62,785			41,280
	Net cash (used in) / provided by operations		358			(189,930	)		455,035			(40	)		—			265,423
	Cash flows from investing activities
	Additions to oil and gas properties		—			—			(474,619	)		—			—			(474,619	)
	Net adjustments to purchase price of properties acquired		—			—			15,709			—			—			15,709
	Proceeds from sales of assets		—			—			448			—			—			448
	Acquisition of other property, plant and equipment		—			—			(1,683	)		—			—			(1,683	)
	Current period settlements of matured derivative contracts		—			(3,654	)		—			—			—			(3,654	)
	Change in restricted cash		—			—			(104	)		—			—			(104	)
	Net cash (used in) / provided by investing		—			(3,654	)		(460,249	)		—			—			(463,903	)
	Cash flows from financing activities
	Proceeds from issuance of long-term debt		—			170,000			—			—			—			170,000
	Repayment under long-term debt		—			(468,000	)		—			—			—			(468,000	)
	Proceeds from senior notes		—			500,000			—			—			—			500,000
	Payment of debt issuance costs		—			(13,416	)		—			—			—			(13,416	)
	Purchase of treasury stock		(358	)		—			—			—			—			(358	)
	Net cash (used in) / provided by financing		(358	)		188,584			—			—			—			188,226
	Net increase (decrease) in cash		—			(5,000	)		(5,214	)		(40	)		—			(10,254	)
	Cash
	Beginning of period		100			6,000			17,650			70			—			23,820
	End of period	$	100		$	1,000		$	12,436		$	30		$	—		$	13,566
	Condensed Consolidating Statement of Cash Flows
	Year Ended December 31, 2013
	(in thousands of dollars)	JEI (Parent)			Issuers			Guarantor			Non-			Eliminations			Consolidated
								Subsidiaries			Guarantor
											Subsidiaries
	Cash flows from operating activities
	Net income (loss)	$	(2,186	)	$	(37,047	)	$	58,705		$	(467	)	$	3,400		$	22,405
	Adjustments to reconcile net income (loss) to net cash provided by operating activities		2,286			(189,393	)		315,942			733			(3,400	)		126,168
	Net cash (used in) / provided by operations		100			(226,440	)		374,647			266			—			148,573
	Cash flows from investing activities
	Investment in subsidiary		(172,481	)		—			—			—			172,481			—
	Additions to oil and gas properties		—			—			(197,618	)		—			—			(197,618	)
	Acquisition of properties		—			—			(178,173	)		—			—			(178,173	)
	Proceeds from sales of assets		—			—			963			644			—			1,607
	Acquisition of other property, plant and equipment		—			—			(724	)		(910	)		—			(1,634	)
	Current period settlements of matured derivative contracts		—			7,586			—			—			—			7,586
	Change in restricted cash		—			—			(45	)		—			—			(45	)
	Net cash (used in) / provided by investing		(172,481	)		7,586			(375,597	)		(266	)		172,481			(368,277	)
	Cash flows from financing activities
	Proceeds from investment in JEI		—			172,481			—			—			(172,481	)		—
	Proceeds from issuance of long-term debt		—			220,000			—			—						220,000
	Repayment under long-term debt		—			(172,000	)		—			—						(172,000	)
	Payment of debt issuance costs		—			(683	)		—			—						(683	)
	Proceeds from sale of common stock, net of expenses of $15.1 million		172,481			—			—			—						172,481
	Net cash (used in) / provided by financing		172,481			219,798			—			—			(172,481	)		219,798
	Net increase (decrease) in cash		100			944			(950	)		—			—			94
	Cash
	Beginning of period		—			5,056			18,600			70			—			23,726
	End of period	$	100		$	6,000		$	17,650		$	70		$	—		$	23,820

Organization_and_Description_o1

Organization and Description of Business (Details)	12 Months Ended	0 Months Ended
	Dec. 31, 2014	Jul. 29, 2013	Jul. 29, 2014
	item	item
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
Existing Owners
Organization and description of business
Exchange ratio		1	1
Number of votes for each holder of common stock		1
JEH
Organization and description of business
Economic interest (as a percent)		74.70%

Significant_Accounting_Policie3

Significant Accounting Policies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014
	item
Segment Information
Number of Operating Segments	1
Number of Geographic Areas in which Entity Operates	1
Accounts Receivable
Payment period of oil and gas sales, Minimum	30 days
Payment period of oil and gas sales, Maximum	60 days
Period within which joint interest owner obligations becomes due	30 days
Interest charged on past-due balances	$0

Significant_Accounting_Policie4

Significant Accounting Policies (Details 2) (Credit risk)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
	item	item
Accounts receivable - Oil and gas sales
Concentration of Risk
Concentration risk (as a percent)	70.00%	79.00%
Number of customers	5	8
Accounts receivable - Joint interest owners
Concentration of Risk
Concentration risk (as a percent)	67.00%	77.00%
Number of customers	5	5

Significant_Accounting_Policie5

Significant Accounting Policies (Details 3) (Oil and gas sales)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
PVR Midstream
Dependence on Major Customers
Concentration risk (as a percent)	22.00%	15.00%	18.00%
Unimark LLC
Dependence on Major Customers
Concentration risk (as a percent)	12.00%	13.00%	24.00%
Mercuria
Dependence on Major Customers
Concentration risk (as a percent)	12.00%	13.00%	18.00%
Valero Marketing
Dependence on Major Customers
Concentration risk (as a percent)	10.00%	13.00%
Plains Marketing
Dependence on Major Customers
Concentration risk (as a percent)	10.00%	6.00%	15.00%

Significant_Accounting_Policie6

Significant Accounting Policies (Details 4) (USD $)	3 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
		item	MMBoe	MMBoe
		Boe
Mineral interests in properties
Unproved	$99,134,000	$94,526,000	$94,526,000	$99,134,000
Proved	958,816,000	1,001,194,000	1,001,194,000	958,816,000
Wells and equipment and related facilities	609,748,000	1,094,202,000	1,094,202,000	609,748,000
Gross oil and gas properties	1,667,698,000	2,189,922,000	2,189,922,000	1,667,698,000
Less: Accumulated depletion and impairment	-370,470,000	-551,062,000	-551,062,000	-370,470,000
Net oil and gas properties	1,297,228,000	1,638,860,000	1,638,860,000	1,297,228,000
Costs capitalized in connection with exploratory wells		0	0
Minimum project period for capitalization of interest on expenditures		6 months	6 months
Number of projects for which interest on expenditure is capitalized		0	0
Amount of capitalized interest on expenditures			100,000
Number of cubic feet of gas considered as numerator in calculation of unit conversion ratio		6,000	1.4	0.8
Depletion of oil and gas properties			180,600,000	113,300,000	79,900,000
Impairment of proved properties			0	0	18,800,000
Impairment of unproved properties	$14,400,000		$0		$0

Significant_Accounting_Policie7

Significant Accounting Policies (Details 5) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Other Property, Plant and Equipment
Gross other property, plant and equipment	$7,062,000	$5,430,000
Less: Accumulated depreciation and amortization	-3,014,000	-1,986,000
Net other property, plant and equipment	4,048,000	3,444,000
Depreciation and amortization of other property, plant and equipment	1,100,000	800,000	800,000
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	1,218,000	1,060,000
Furniture, fixtures, computers and software
Other Property, Plant and Equipment
Gross other property, plant and equipment	3,727,000	2,491,000
Vehicles
Other Property, Plant and Equipment
Gross other property, plant and equipment	988,000	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	$219,000	$134,000

Significant_Accounting_Policie8

Significant Accounting Policies (Detail 6) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Oil and Gas Sales Payable
Period of remittance for oil and gas sales payable	60 days
Asset Retirement Obligations
ARO liability at beginning of year	$10,963,000	$10,963,000	$9,506,000
Liabilities incurred	1,995,000	1,516,000	662,000
Accretion of discount	770,000	608,000
Liabilities settled due to sale of related properties	-109,000	-271,000
Liabilities settled due to plugging and abandonment	-55,000	-702,000
Change in estimate	46,000	307,000
ARO liability at end of year	13,610,000	10,963,000	10,963,000
Less: Current portion of ARO at end of year	-3,074,000	-2,590,000
Total long-term ARO at end of year	10,536,000	8,373,000
Liabilities incurred related to wells acquired	824,000
Liability under 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
Future Tax Benefits	900,000
Liability under tax receivable agreement	$800,000

Significant_Accounting_Policie9

Significant Accounting Policies (Details 7) (USD $)	1 Months Ended	12 Months Ended			0 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Sep. 01, 2013	7-May-13
		Boe	MMBoe
Related Party Transactions
Production of natural gas and NGLs from the Chalker properties (in MMBoe)		6,000	0.8
Reserved capacity (in barrels per day)	12,000
Metalmark
Related Party Transactions
Annual administration fee			0.7	$0.70
Number of directors who are managing directors of the related party			2
Metalmark | Minimum
Related Party Transactions
Outstanding equity interests held by the related party (as a percent)			5.00%
Monarch
Related Party Transactions
Initial term of the agreement					10 years
Term of Oil Gathering and Transportation Agreement	10 years
Monarch | Metalmark
Related Party Transactions
Outstanding equity interests held (as a percent)						81.00%
JEH
Related Party Transactions
Value of equity interests assigned to Jonny Jones						2.4
Value of equity interests reserved to a benefit plan established for certain of the entity's officers						2.6
Value of remaining equity interests distributed to certain of the pre-IPO owners						10
JEH | Monarch
Related Party Transactions
Deemed value of equity interests issued						$15

Recovered_Sheet1

Significant Accounting Policies (Details 8)	1 Months Ended	12 Months Ended	0 Months Ended	12 Months Ended
	31-May-14	Dec. 31, 2014	Sep. 23, 2014	Dec. 31, 2013
Performance Units Awards
Stock Compensation
Performance period of shareholder return	3 years
Stock-based Compensation expensed recognition period	3 years
Performance Units Awards | Minimum
Stock Compensation
Number of shares of common stock issuable upon vesting of the performance share awards (as a percent)	0.00%	0.00%
Performance Units Awards | Maximum
Stock Compensation
Number of shares of common stock issuable upon vesting of the performance share awards (as a percent)	200.00%	200.00%
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
2013 Omnibus Incentive Plan | Restricted stock
Stock Compensation
Vesting term		1 year
Awards granted, per outside member of the Board of Directors (in shares)			5,486	6,645

Acquisition_of_Properties_Deta

Acquisition of Properties (Details) (USD $)	12 Months Ended			0 Months Ended			3 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 20, 2012	Dec. 18, 2013	Jun. 30, 2014
	item
Acquisition of Properties
Number of property acquisitions	0
Post Acquisition
Total operating revenues	$380,597,000	$259,169,000	$149,814,000
Total operating expenses	273,592,000	203,417,000	144,974,000
Operating income	107,005,000	55,752,000	4,840,000
Net income	40,868,000	-2,186,000	-3,079,000
Earnings per share, basic (in dollars per share)	$3.26	($0.17)
Earnings per share, diluted (in dollars per share)	$3.26	($0.17)
Sabine acquisition
Oil and gas properties
Unproved							32,964,000
Proved							147,024,000
Asset retirement obligations							-824,000
Total purchase price							179,164,000
Post Acquisition
Total operating revenues				1,365,000
Total operating expenses				291,000
Operating income				1,074,000
Net income	45,778,000			1,074,000
Pro Forma
Total operating revenue	308,773,000
Total operating expenses	229,648,000
Operating income	79,125,000
Chalker acquisition
Acquisition of Properties
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
Pro Forma
Total operating revenue			194,685,000
Total operating expenses			161,053,000
Operating income			33,632,000
Net income			25,713,000
Oil and natural gas properties located in Oklahoma
Acquisition of Properties
Purchase price						193,500,000	179,200,000
JEI (Parent)
Post Acquisition
Net income	$40,868,000	($2,186,000)

Fair_Value_Measurement_Details

Fair Value Measurement (Details) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Fair Value Measurements
Current assets	$121,519	$8,837
Long-term assets	87,055	25,398
Current liabilities		10,664
Long-term liabilities	28	190
Level 2 | Commodity Price Hedges
Fair Value Measurements
Current assets	120,604	8,837
Long-term assets	85,162	25,967
Current liabilities		10,188
Level 3 | Commodity Price Hedges
Fair Value Measurements
Current assets	915
Long-term assets	1,893	-569
Current liabilities		476
Long-term liabilities	28	190
Fair Value | Commodity Price Hedges
Fair Value Measurements
Current assets	121,519	8,837
Long-term assets	87,055	25,398
Current liabilities		10,664
Long-term liabilities	$28	$190

Fair_Value_Measurement_Details1

Fair Value Measurement (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Natural gas liquids | Swaps | Minimum
Quantitative Information About Level 3 Fair Value Measurements
Swap price (in dollars per barrel/mmbtu)	8.09	6.72
Natural gas liquids | Swaps | Maximum
Quantitative Information About Level 3 Fair Value Measurements
Swap price (in dollars per barrel/mmbtu)	95.24	95.24
Commodity Price Hedges
Quantitative Information About Level 3 Fair Value Measurements
Fair Value	$100	$14,347
Discounted cash flow approach | Level 3 | Commodity Price Hedges | Natural gas liquids | Swaps
Quantitative Information About Level 3 Fair Value Measurements
Fair Value	3,045
Discounted cash flow approach | Level 3 | Commodity Price Hedges | Natural gas liquids | Swaps | 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 Price Hedges | Natural gas liquids | Swaps | Maximum
Quantitative Information About Level 3 Fair Value Measurements
Swap price (in dollars per barrel/mmbtu)	75.52
Discounted cash flow approach | Level 3 | Commodity Price Hedges | Natural gas | Basis swaps
Quantitative Information About Level 3 Fair Value Measurements
Fair Value	($265)
Discounted cash flow approach | Level 3 | Commodity Price Hedges | Natural gas | Basis swaps | Minimum
Quantitative Information About Level 3 Fair Value Measurements
Swap price (in dollars per barrel/mmbtu)	-0.11
Discounted cash flow approach | Level 3 | Commodity Price Hedges | Natural gas | Basis swaps | Maximum
Quantitative Information About Level 3 Fair Value Measurements
Swap price (in dollars per barrel/mmbtu)	-0.17

Fair_Value_Measurement_Details2

Fair Value Measurement (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Nonrecurring | Carrying Amount | 2022 Notes | Senior notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	$500,000
Nonrecurring | Carrying Amount | Revolver
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	360,000	498,000
Nonrecurring | Carrying Amount | Term Loan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt		160,000
Nonrecurring | Fair Value | 2022 Notes | Senior notes
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	384,375
Nonrecurring | Fair Value | Revolver
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt	360,000	498,000
Nonrecurring | Fair Value | Term Loan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt		160,000
Level 3
Changes in fair value of Level 3 instruments
Balance at the beginning of the period	-1,235	-1,519
Purchases	668	-1,095
Settlements	476	-210
Transfer to Level 2	332	-753
Transfers to Level 3	0	0
Changes in fair value	2,804	2,342
Balance at the end of the period	$2,780	($1,235)

Fair_Value_Measurement_Details3

Fair Value Measurement (Details 4) (USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Nonfinancial Assets and Liabilities
Impairment of unproved properties	$14.40	$0		$0
Impairment of proved properties		$0	$0	$18.80

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Basis swaps | Minimum
Derivative instruments and hedging activities
Contract differential (in dollars per mmbtu)	-0.39	-0.43
Nonmonetary notional amount	320,000	320,000
Basis swaps | Maximum
Derivative instruments and hedging activities
Contract differential (in dollars per mmbtu)	-0.11	-0.11
Nonmonetary notional amount	980,000	690,000
Basis swaps | Weighted Average
Derivative instruments and hedging activities
Contract differential (in dollars per mmbtu)	-0.21	-0.34
Nonmonetary notional amount	716,667	467,037
Oil | Swaps | Minimum
Derivative instruments and hedging activities
Exercise price (in dollars per barrels)	75.05	81.7
Nonmonetary notional amount	45,000	29,000
Oil | Swaps | Maximum
Derivative instruments and hedging activities
Exercise price (in dollars per barrels)	100.95	102.84
Nonmonetary notional amount	184,054	161,613
Oil | Swaps | Weighted Average
Derivative instruments and hedging activities
Exercise price (in dollars per barrels)	84.2	89.03
Nonmonetary notional amount	113,852	96,149
Natural gas | Swaps | Minimum
Derivative instruments and hedging activities
Exercise price (in dollars per mmbtu)	3.37	3.88
Nonmonetary notional amount	710,000	510,000
Natural gas | Swaps | Maximum
Derivative instruments and hedging activities
Exercise price (in dollars per mmbtu)	6.45	6.9
Nonmonetary notional amount	1,772,584	1,290,000
Natural gas | Swaps | Weighted Average
Derivative instruments and hedging activities
Exercise price (in dollars per mmbtu)	4.4	4.26
Nonmonetary notional amount	1,175,275	830,275
Natural gas liquids | Swaps | Minimum
Derivative instruments and hedging activities
Exercise price (in dollars per barrels)	8.09	6.72
Nonmonetary notional amount	2,000	2,000
Natural gas liquids | Swaps | Maximum
Derivative instruments and hedging activities
Exercise price (in dollars per barrels)	95.24	95.24
Nonmonetary notional amount	143,000	118,000
Natural gas liquids | Swaps | Weighted Average
Derivative instruments and hedging activities
Exercise price (in dollars per barrels)	42.46	32.98
Nonmonetary notional amount	50,444	46,646
Commodity Price Hedges
Derivative instruments and hedging activities
Net gains (Losses) recognized on derivative instruments	$189.60	($2.60)	$16.70

Derivative_Instruments_and_Hed3

Derivative Instruments and Hedging Activities (Details 2) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Offsetting Assets and Liabilities
Number of counterparties to commodity derivative contracts	7
Commodity Price Hedges
Assets
Gross Amounts of Recognized Assets	$208,646	$38,071
Gross Amounts Offset in the Balance Sheet	-72	-6,035
Net Amounts of Assets Presented in the Balance Sheet	208,574	32,036
Gross Amounts Not Offset in the Balance Sheet		2,199
Net Amount	208,574	34,235
Liabilities
Gross Amounts of Recognized Liabilities	-100	-14,347
Gross Amounts Offset in the Balance Sheet	72	6,035
Net Amounts of Liabilities Presented in the Balance Sheet	-28	-8,312
Gross Amounts Not Offset in the Balance Sheet		-2,542
Net Amount	($28)	($10,854)

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	12 Months Ended			0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Apr. 01, 2014	Dec. 31, 2009	Nov. 06, 2014	Nov. 05, 2014
	item				item
Credit agreements
Total interest expense	$46,726,000	$30,774,000	$25,292,000
Number of credit agreements	2				2
Total interest and commitment fees	13,000,000	27,000,000	21,200,000
2022 Notes | Senior notes
Credit agreements
Issuance of debt				500,000,000
Stated interest rate (as a percent)				6.75%
Accrued interest	8,400,000
Total interest expense	25,300,000
Revolver
Credit agreements
Repayment of borrowings		3,800,000		308,000,000
Borrowing base	562,500,000					625,000,000	550,000,000
Average interest rates (as a percent)	333.80%	3.01%
Average outstanding balance		384,900,000
Average interest rate (as a percent)	2.51%
Revolver | London Interbank Offered Rate (LIBOR) | Minimum
Credit agreements
Margin interest rate (as a percent)	1.50%
Revolver | London Interbank Offered Rate (LIBOR) | Maximum
Credit agreements
Margin interest rate (as a percent)	2.50%
Revolver | Federal Funds Effective Swap Rate
Credit agreements
Margin interest rate (as a percent)	0.50%
Revolver | Base rate | Minimum
Credit agreements
Margin interest rate (as a percent)	0.50%
Revolver | Base rate | Maximum
Credit agreements
Margin interest rate (as a percent)	1.50%
Revolver | One Month Adjust LIBO Rate
Credit agreements
Margin interest rate (as a percent)	1.00%
Term Loan
Credit agreements
Repayment of borrowings				$160,000,000

Stockbased_Compensation_Detail

Stock-based Compensation (Details) (USD $)	1 Months Ended	12 Months Ended		0 Months Ended		12 Months Ended
In Millions, except Share data, unless otherwise specified	31-May-14	Dec. 31, 2014	Dec. 31, 2013	Sep. 23, 2014	Sep. 04, 2013	Dec. 31, 2012
Performance Units Awards
Weighted Average Grant Date Fair Value per Share
Stock-based Compensation expensed recognition period	3 years
Performance period of shareholder return	3 years
Assumptions used to determine the grant date fair value and associated compensation expense
Stock Price		$17.07
Beginning Average Stock Price		$14.78
Expected Volatility (as a percent)		46.95%
Risk-Free Rate of Return (as a percent)		0.61%
Number of trading days		10 days
Remaining in the performance period		2 years 7 months 13 days
Simulated fair value		$21.65
Expected percentage of performance units earned		126.80%
Performance Units Awards | Minimum
Weighted Average Grant Date Fair Value per Share
Number of shares of common stock issuable upon vesting of the performance unit awards (as a percent)	0.00%	0.00%
Performance Units Awards | Maximum
Weighted Average Grant Date Fair Value per Share
Number of shares of common stock issuable upon vesting of the performance unit awards (as a percent)	200.00%	200.00%
Restricted Stock Unit Awards
Weighted Average Grant Date Fair Value per Share
Stock-based Compensation expensed recognition period		3 years
Class A common stock | Performance Units Awards
Weighted Average Grant Date Fair Value per Share
Exchangeable ratio of vested performance unit (as a percent)		1.00%
General and administrative expenses | Performance Units Awards
Weighted Average Grant Date Fair Value per Share
Stock compensation expense		$0.90
General and administrative expenses | Restricted Stock Unit Awards
Weighted Average Grant Date Fair Value per Share
Stock compensation expense		1.1
Officers and employees | Performance Units Awards
Units/ Awards
Granted (in shares)		201,318
Forfeited (in shares)		-8,320
Unvested at the end of the period (in shares)		192,998
Weighted Average Grant Date Fair Value per Share
Granted (in dollars per share)		$21.65
Forfeited (in dollars per share)		$21.65
Unvested at the end of the period (in dollars per share)		$21.65
Performance period of shareholder return		3 years
Officers and employees | Restricted Stock Unit Awards
Units/ Awards
Granted (in shares)		340,001
Forfeited (in shares)		-13,688
Vested (in shares)		-1,416
Unvested at the end of the period (in shares)		324,897
Weighted Average Grant Date Fair Value per Share
Granted (in dollars per share)		$17.31
Forfeited (in dollars per share)		$17.07
Vested (in dollars per share)		$17.07
Unvested at the end of the period (in dollars per share)		$17.33
Non-employee members of Board Of Directors | Restricted stock
Units/ Awards
Unvested at the beginning of the period (in shares)		26,580
Granted (in shares)		27,430	26,580
Vested (in shares)		-26,580
Unvested at the end of the period (in shares)		27,430	26,580
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (in dollars per share)		$15.05
Granted (in dollars per share)		$18.77	$15.05
Vested (in dollars per share)		$15.05
Unvested at the end of the period (in dollars per share)		$18.77	$15.05
Stock compensation expense		0.4
Non-employee members of Board Of Directors | Class A common stock | Restricted stock
Weighted Average Grant Date Fair Value per Share
Number of non-employee members of the Board of Directors to whom awards were granted				5	4
Awards granted to each non-employee director (in shares)				5,486	6,645
Service period from date of grant		1 year		1 year
Non-employee members of Board Of Directors | General and administrative expenses | Restricted stock
Weighted Average Grant Date Fair Value per Share
Stock compensation expense			0.1
Management incentive plan | Management units | JEH | Class B common stock
Units/ Awards
Unvested at the end of the period (in shares)		274,385
Management incentive plan | Management units | JEH | General and administrative expenses
Weighted Average Grant Date Fair Value per Share
Stock compensation expense		$1.60	$10.70			$0.60
Management incentive plan | Management units | JEH | Management
Units/ Awards
Unvested at the beginning of the period (in shares)		457,150	710,767
Granted (in shares)		21,405	911,654
Forfeited (in shares)		-21,405	-167,239
Vested (in shares)		-182,765	-998,032
Unvested at the end of the period (in shares)		274,385	457,150
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (in dollars per share)		$12.46	$3.62
Granted (in dollars per share)		$6.66	$15
Forfeited (in dollars per share)		$6.66	$3.62
Vested (in dollars per share)		$8.65	$9.96
Unvested at the end of the period (in dollars per share)		$15	$12.46

Earnings_per_Share_Details

Earnings per Share (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	275	27
Restricted stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	27,430
Restricted Stock Unit Awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	54,656
Performance Units Awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	192,998

Earnings_per_Share_Details_2

Earnings per Share (Details 2) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income (numerator):
Net income attributable to controlling interests	$40,868	($2,186)	($3,079)
Weighted-average shares (denominator):
Weighted-average number of shares of Class A common stock - basic	12,526	12,500
Weighted-average number of shares of Class A common stock - diluted	12,535	12,500
Earnings per share:
Basic	$3.26	($0.17)
Diluted	$3.26	($0.17)
JEI (Parent)
Income (numerator):
Net income attributable to controlling interests	$40,868	($2,186)

Monarch_Investment_Details

Monarch Investment (Details) (USD $)	12 Months Ended		0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	7-May-13
Monarch Investment
Deferred revenue recorded	$13,377,000	$14,531,000
Equity interests issued to the Company in connection with the marketing agreement
Monarch Investment
Compensation expense recognized under management distributions and incentive plan	800,000	300,000
Deferred revenue recorded		15,000,000
Equity interests issued to the Company in connection with the marketing agreement | Equity interests | Monarch Natural Gas Holdings, LLC
Monarch Investment
Equity interests distributed to the entity's owners (as a percent)			67.00%
Equity interests distributed to the entity's owners			10,000,000
Equity interests distributed to a member of management (as a percent)			16.00%
Equity Interests Distributed Management	500,000
Equity interests reserved for distribution to management through incentive plan (as a percent)			17.00%
Monarch
Monarch Investment
Amortization of deferred revenue	1,200,000	500,000
Monarch | Equity interests issued to the Company in connection with the marketing agreement | Equity interests | Monarch Natural Gas Holdings, LLC
Monarch Investment
Estimated fair value of equity interests issued to the entity			$15,000,000

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
	sqft
Commitments and Contingencies
Leased area of office space in Austin, TX (in square feet)	43,000
Future minimum payments for noncancellable operating leases
2015	$944,000
2016	954,000
2017	1,038,000
2018	1,101,000
2019	1,122,000
Thereafter	377,000
Total	5,536,000
Rent expense under operating leases	$900,000	$800,000	$800,000

Benefit_Plans_Details

Benefit Plans (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
401(k)
Benefit Plans
Amount contributed to the Plan	$300,000	$300,000
409A
Benefit Plans
Amount contributed to the Plan	$0	$0

Income_Taxes_Details

Income Taxes (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Current tax expense
Federal	$53	$85
Total current expense	53	85
Deferred tax expense (benefit)
Federal	21,996	-1,260
State	4,025	1,104	473
Total deferred expense (benefit)	26,021	-156	473
Total income tax provision	26,074	-71	473
Tax benefit attributable to controlling interests	22,675	-1,223	473
Tax expense attributable to non-controlling interests	3,399	1,152
Provision calculated at federal statutory income tax rate:
Net income before taxes	250,217	22,334	-2,606
Statutory rate (as a percent)	35.00%	35.00%
Income tax expense computed at statutory rate	87,577	7,817
Less: Noncontrolling interests	-65,336	-9,009
Income tax benefit attributable to Jones Energy, Inc.	22,241	-1,192
State and local income taxes, net of federal benefit	626	-49
Other	-192	18
Tax benefit attributable to Jones Energy, Inc.	22,675	-1,223	473
Tax expense attributable to non-controlling interests	3,399	1,152
Total income tax provision	26,074	-71	473
Deferred tax assets
Investment in consolidated Subsidiary JEH		526
Net operating loss	8,223	649
Section 754 election tax basis adjustment	945
Alternative minimum tax credits	53	86
State deferred tax asset	232	52
Total deferred tax assets	9,453	1,313
Deferred tax liabilities
State deferred tax liability	718
Investment in consolidated subsidiary JEH	29,163
Noncurrent state deferred tax liability	6,731	3,093
Total deferred tax liabilities	36,612	3,093
Net deferred tax assets (liabilities)	-27,159	-1,780
Net deferred tax assets (liabilities)	-27,159	-1,780
JEI (Parent)
Current tax expense
Total current expense	53	85
Deferred tax expense (benefit)
Total deferred expense (benefit)	21,864	-1,299
Total income tax provision	21,917	-1,214
Provision calculated at federal statutory income tax rate:
Total income tax provision	$21,917	($1,214)

Income_Taxes_Details_2

Income Taxes (Details 2) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Federal
Operating loss carry-forward
Net operating loss carry-forward	$22.40
State
Operating loss carry-forward
Net operating loss carry-forward	$9.60

Income_Taxes_Details_3

Income Taxes (Details 3) (USD $)	Dec. 31, 2014
In Millions, unless otherwise specified
Income Taxes
Future Tax Benefits	$0.90
Tax Savings Receivable in Connection with Tax Receivable Agreement (as a percent)	85.00%
Liability under tax receivable agreement	$0.80

Subsequent_Events_Details

Subsequent Events (Details) (Subsequent event, USD $)	0 Months Ended
	Feb. 17, 2015	Feb. 23, 2015
Class A common stock | Follow-on offering
Subsequent events
Issuance of common stock (in shares)	7,500,000
Price (in dollars per shares)	$10.25
Underwriter option period	30 days
Underwriter option (in shares)	1,125,000
Class A common stock | Private placement
Subsequent events
Issuance of common stock		$50,000,000
Issuance of common stock (in shares)		4,761,905
Price (in dollars per shares)		$10.50
2023 Notes | Senior notes
Subsequent events
Issuance of debt		$250,000,000
Stated interest rate (as a percent)		9.25%

Subsidiary_Guarantors_Details

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

Subsidiary_Guarantors_Details_

Subsidiary Guarantors (Details 2)	12 Months Ended
	Dec. 31, 2014
	item
Subsidiary Guarantors
Classes of stock, number	2
Class A common stock
Subsidiary Guarantors
Economic interests	100.00%
Votes per share entitled to stockholders	1
Class B common stock
Subsidiary Guarantors
Economic interests	0.00%
Votes per share entitled to stockholders	1
Issuers
Subsidiary Guarantors
Economic interest	25.60%
Existing Owners | Class A common stock
Subsidiary Guarantors
Ratio in which JEH Units and Class B common stock is exchanged for Class A common stock	1
Issuers | Guarantor Subsidiaries
Subsidiary Guarantors
Ownership percentage in subsidiary guarantors	100.00%
Existing Owners | Issuers
Subsidiary Guarantors
Economic interest (as a percent)	74.40%

Subsidiary_Guarantors_Details_1

Subsidiary Guarantors (Details 3) (USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, except Share data, unless otherwise specified
Current assets
Cash	$13,566	$23,820
Restricted Cash	149	45
Accounts receivable, net
Oil and gas sales	49,861	51,233
Joint interest owners	41,761	42,481
Other	12,512	16,782
Commodity derivative assets	121,519	8,837
Other current assets	3,374	2,392
Deferred tax assets		12
Total current assets	242,742	145,602
Oil and gas properties, net, at cost under the successful efforts method	1,638,860	1,297,228
Other property, plant and equipment, net	4,048	3,444
Commodity derivative assets	87,055	25,398
Other assets	20,352	15,006
Deferred tax assets	171	1,301
Total assets	1,993,228	1,487,979
Current liabilities
Trade accounts payable	136,337	89,430
Oil and gas sales payable	70,469	66,179
Accrued liabilities	19,401	10,805
Commodity derivative liabilities		10,664
Deferred tax liabilities	718
Asset retirement obligations	3,074	2,590
Total current liabilities	229,999	179,668
Long-term debt	360,000	658,000
Senior notes	500,000
Deferred revenue	13,377	14,531
Commodity derivative liabilities	28	190
Asset retirement obligations	10,536	8,373
Liability under tax receivable agreement	803
Deferred tax liabilities	26,612	3,093
Total liabilities	1,141,355	863,855
Commitments and contingencies (Note 10)
Stockholders' / members' equity
Treasury stock, at cost; 22,602 shares at December 31, 2014 and 0 shares at December 31, 2013	-358
Additional paid-in-capital	177,133	173,169
Retained earnings (deficit)	38,682	-2,186
Stockholders' equity	215,507	171,033
Non-controlling interest	636,366	453,091
Total stockholders' equity	851,873	624,124	428,400	345,909
Total liabilities and stockholders' equity	1,993,228	1,487,979
Treasury stock, shares	22,602	0
Class A common stock
Stockholders' / members' equity
Common Stock	13	13
Common Stock, par value (in dollars per share)	$0.00	$0.00
Common Stock, shares issued	12,672,260	12,526,580
Common Stock, shares outstanding	12,649,658	12,526,580
Class B common stock
Stockholders' / members' equity
Common Stock	37	37
Common Stock, par value (in dollars per share)	$0.00	$0.00
Common Stock, shares issued	36,719,499	36,836,333
Common Stock, shares outstanding	36,719,499	36,836,333
Eliminations
Accounts receivable, net
Intercompany receivable	-1,207,444	-1,052,027
Total current assets	-1,207,444	-1,052,027
Investment in Subsidiaries	-231,866	-169,081
Total assets	-1,439,310	-1,221,108
Current liabilities
Intercompany payable	-1,209,630	-1,054,214
Total current liabilities	-1,209,630	-1,054,214
Total liabilities	-1,209,630	-1,054,214
Stockholders' / members' equity
Members' equity	-866,046	-619,985
Stockholders' equity	-866,046	-619,985
Non-controlling interest	636,366	453,091
Total stockholders' equity	-229,680	-166,894
Total liabilities and stockholders' equity	-1,439,310	-1,221,108
JEI (Parent)
Current assets
Cash	100	100
Accounts receivable, net
Other	102
Intercompany receivable	4,164	638
Total current assets	4,366	738
Investment in Subsidiaries	231,866	169,081
Deferred tax assets	171	1,301
Total assets	236,403	171,120
Current liabilities
Accrued liabilities		87
Total current liabilities		87
Liability under tax receivable agreement	803
Deferred tax liabilities	20,093
Total liabilities	20,896	87
Stockholders' / members' equity
Treasury stock, at cost; 22,602 shares at December 31, 2014 and 0 shares at December 31, 2013	-358
Additional paid-in-capital	177,133	173,169
Retained earnings (deficit)	38,682	-2,186
Stockholders' equity	215,507	171,033
Total stockholders' equity	215,507	171,033
Total liabilities and stockholders' equity	236,403	171,120
Treasury stock, shares	22,602
JEI (Parent) | Class A common stock
Stockholders' / members' equity
Common Stock	13	13
Common Stock, par value (in dollars per share)	$0.00	$0.00
Common Stock, shares issued	12,672,260	12,526,580
Common Stock, shares outstanding	12,649,658	12,526,580
JEI (Parent) | Class B common stock
Stockholders' / members' equity
Common Stock	37	37
Common Stock, par value (in dollars per share)	$0.00	$0.00
Common Stock, shares issued	36,719,499	36,836,333
Common Stock, shares outstanding	36,719,499	36,836,333
Issuers
Current assets
Cash	1,000	6,000
Accounts receivable, net
Other	8,788
Commodity derivative assets	121,519	8,837
Other current assets	451	387
Deferred tax assets		12
Intercompany receivable	1,205,608	1,051,389
Total current assets	1,337,366	1,066,625
Commodity derivative assets	87,055	25,398
Other assets	20,098	14,072
Total assets	1,444,519	1,106,095
Current liabilities
Trade accounts payable	288	230
Accrued liabilities	8,914	1,642
Commodity derivative liabilities		10,664
Deferred tax liabilities	718
Total current liabilities	9,920	12,536
Long-term debt	360,000	658,000
Senior notes	500,000
Deferred revenue	13,377	14,531
Commodity derivative liabilities	28	190
Deferred tax liabilities	6,519	3,093
Total liabilities	889,844	688,350
Stockholders' / members' equity
Members' equity	554,675	417,745
Stockholders' equity	554,675	417,745
Total stockholders' equity	554,675	417,745
Total liabilities and stockholders' equity	1,444,519	1,106,095
Guarantor Subsidiaries
Current assets
Cash	12,436	17,650
Restricted Cash	149	45
Accounts receivable, net
Oil and gas sales	49,861	51,233
Joint interest owners	41,761	42,481
Other	3,622	16,782
Other current assets	2,923	2,005
Total current assets	110,752	130,196
Oil and gas properties, net, at cost under the successful efforts method	1,638,860	1,297,228
Other property, plant and equipment, net	3,252	2,557
Other assets	254	934
Total assets	1,753,118	1,430,915
Current liabilities
Trade accounts payable	136,049	89,200
Oil and gas sales payable	70,469	66,179
Accrued liabilities	10,487	9,076
Asset retirement obligations	3,074	2,590
Intercompany payable	1,209,630	1,051,935
Total current liabilities	1,429,709	1,218,980
Asset retirement obligations	10,536	8,373
Total liabilities	1,440,245	1,227,353
Stockholders' / members' equity
Members' equity	312,873	203,562
Stockholders' equity	312,873	203,562
Total stockholders' equity	312,873	203,562
Total liabilities and stockholders' equity	1,753,118	1,430,915
Non-Guarantor Subsidiaries
Current assets
Cash	30	70
Accounts receivable, net
Intercompany receivable	-2,328
Total current assets	-2,298	70
Other property, plant and equipment, net	796	887
Total assets	-1,502	957
Current liabilities
Intercompany payable		2,279
Total current liabilities		2,279
Total liabilities		2,279
Stockholders' / members' equity
Members' equity	-1,502	-1,322
Stockholders' equity	-1,502	-1,322
Total stockholders' equity	-1,502	-1,322
Total liabilities and stockholders' equity	($1,502)	$957

Subsidiary_Guarantors_Details_2

Subsidiary Guarantors (Details 4) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating revenues
Oil and gas sales	$378,401	$258,063	$148,967
Other revenues	2,196	1,106	847
Total operating revenues	380,597	259,169	149,814
Operating costs and expenses
Lease operating	43,843	27,781	23,097
Production taxes	18,094	12,865	5,583
Exploration	3,453	1,710	356
Depletion, depreciation and amortization	181,669	114,136	80,709
Impairment of oil and gas properties		14,415	18,821
Accretion of discount	770	608	533
General and administrative (including non-cash compensation expense)	25,763	31,902	15,875
Total operating expenses	273,592	203,417	144,974
Operating income	107,005	55,752	4,840
Other income (expense)
Interest expense	-46,726	-30,774	-25,292
Net gain (loss) on commodity derivatives	189,641	-2,566	16,684
Gain (loss) on sales of assets	297	-78	1,162
Other income (expense), net	143,212	-33,418	-7,446
Income (loss) before income tax	250,217	22,334	-2,606
Income tax provision (benefit)
Current	53	85
Deferred	26,021	-156	473
Total income tax provision	26,074	-71	473
Net income (loss)	224,143	22,405	-3,079
Net income attributable to non-controlling interests	183,275	24,591
Net income (loss) attributable to controlling interests	40,868	-2,186	-3,079
Eliminations
Other income (expense)
Equity interest in income	-62,785	3,400
Income tax provision (benefit)
Net income (loss)	-62,785	3,400
Net income attributable to non-controlling interests	183,275	24,591
JEI (Parent)
Other income (expense)
Equity interest in income	62,785	-3,400
Income tax provision (benefit)
Current	53	85
Deferred	21,864	-1,299
Total income tax provision	21,917	-1,214
Net income (loss)	40,868	-2,186
Net income (loss) attributable to controlling interests	40,868	-2,186
Issuers
Operating revenues
Other revenues	1,154	469
Total operating revenues	1,154	469
Operating costs and expenses
General and administrative (including non-cash compensation expense)	4,494	4,154
Total operating expenses	4,494	4,154
Operating income	-3,340	-3,685
Other income (expense)
Interest expense	-45,215	-29,653
Net gain (loss) on commodity derivatives	189,641	-2,566
Other income (expense), net	144,426	-32,219
Income (loss) before income tax	141,086	-35,904
Income tax provision (benefit)
Deferred	4,157	1,143
Total income tax provision	4,157	1,143
Net income (loss)	136,929	-37,047
Guarantor Subsidiaries
Operating revenues
Oil and gas sales	378,401	258,063
Other revenues	1,042	637
Total operating revenues	379,443	258,700
Operating costs and expenses
Lease operating	43,843	27,781
Production taxes	18,094	12,865
Exploration	3,453	1,710
Depletion, depreciation and amortization	181,578	114,046
Impairment of oil and gas properties		14,415
Accretion of discount	770	608
General and administrative (including non-cash compensation expense)	21,180	27,490
Total operating expenses	268,918	198,915
Operating income	110,525	59,785
Other income (expense)
Interest expense	-1,511	-1,121
Gain (loss) on sales of assets	297	41
Other income (expense), net	-1,214	-1,080
Income (loss) before income tax	109,311	58,705
Income tax provision (benefit)
Net income (loss)	109,311	58,705
Non-Guarantor Subsidiaries
Operating costs and expenses
Depletion, depreciation and amortization	91	90
General and administrative (including non-cash compensation expense)	89	258
Total operating expenses	180	348
Operating income	-180	-348
Other income (expense)
Gain (loss) on sales of assets		-119
Other income (expense), net		-119
Income (loss) before income tax	-180	-467
Income tax provision (benefit)
Net income (loss)	($180)	($467)

Subsidiary_Guarantors_Details_3

Subsidiary Guarantors (Details 5) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows from operating activities
Net income (loss)	$224,143,000	$22,405,000	($3,079,000)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	41,280,000	126,168,000
Net cash provided by operations	265,423,000	148,573,000	84,550,000
Cash flows from investing activities
Additions to oil and gas properties	-474,619,000	-197,618,000	-125,493,000
Acquisition of properties		-178,173,000	-249,007,000
Net adjustments to purchase price of properties acquired	15,709,000
Proceeds from sales of assets	448,000	1,607,000	9,158,000
Acquisition of other property, plant and equipment	-1,683,000	-1,634,000	-969,000
Current period settlements of matured derivative contracts	-3,654,000	7,586,000	28,675,000
Change in restricted cash	-104,000	-45,000
Net cash (used in) investing	-463,903,000	-368,277,000	-337,636,000
Cash flows from financing activities
Proceeds from issuance of long-term debt	170,000,000	220,000,000	233,243,000
Repayment under long-term debt	-468,000,000	-172,000,000	-38,243,000
Proceeds from senior notes	500,000,000
Payment of debt issuance costs	-13,416,000	-683,000	-9,324,000
Proceeds from sale of common stock, net of expenses of $15.1 million		172,481,000
Purchases of treasury stock	358,000
Net cash provided by financing	188,226,000	219,798,000	270,676,000
Net increase (decrease) in cash	-10,254,000	94,000	17,590,000
Cash
Beginning of period	23,820,000	23,726,000	6,136,000
End of period	13,566,000	23,820,000	23,726,000
Payments of Stock Issuance Costs		15,100,000
Eliminations
Cash flows from operating activities
Net income (loss)	-62,785,000	3,400,000
Adjustments to reconcile net income (loss) to net cash provided by operating activities	62,785,000	-3,400,000
Cash flows from investing activities
Investment in subsidiary		172,481,000
Net cash (used in) investing		172,481,000
Cash flows from financing activities
Proceeds from investment by JEI		172,481,000
Net cash provided by financing		-172,481,000
JEI (Parent)
Cash flows from operating activities
Net income (loss)	40,868,000	-2,186,000
Adjustments to reconcile net income (loss) to net cash provided by operating activities	-40,510,000	2,286,000
Net cash provided by operations	358,000	100,000
Cash flows from investing activities
Investment in subsidiary		-172,481,000
Net cash (used in) investing		-172,481,000
Cash flows from financing activities
Proceeds from sale of common stock, net of expenses of $15.1 million		172,481,000
Purchases of treasury stock	358,000
Net cash provided by financing	-358,000	172,481,000
Net increase (decrease) in cash		100,000
Cash
Beginning of period	100,000
End of period	100,000	100,000
Payments of Stock Issuance Costs		15,100,000
Issuers
Cash flows from operating activities
Net income (loss)	136,929,000	-37,047,000
Adjustments to reconcile net income (loss) to net cash provided by operating activities	-326,859,000	-189,393,000
Net cash provided by operations	-189,930,000	-226,440,000
Cash flows from investing activities
Current period settlements of matured derivative contracts	-3,654,000	7,586,000
Net cash (used in) investing	-3,654,000	7,586,000
Cash flows from financing activities
Proceeds from investment by JEI		-172,481,000
Proceeds from issuance of long-term debt	170,000,000	220,000,000
Repayment under long-term debt	-468,000,000	-172,000,000
Proceeds from senior notes	500,000,000
Payment of debt issuance costs	-13,416,000	-683,000
Net cash provided by financing	188,584,000	219,798,000
Net increase (decrease) in cash	-5,000,000	944,000
Cash
Beginning of period	6,000,000	5,056,000
End of period	1,000,000	6,000,000
Guarantor Subsidiaries
Cash flows from operating activities
Net income (loss)	109,311,000	58,705,000
Adjustments to reconcile net income (loss) to net cash provided by operating activities	345,724,000	315,942,000
Net cash provided by operations	455,035,000	374,647,000
Cash flows from investing activities
Additions to oil and gas properties	-474,619,000	-197,618,000
Acquisition of properties		-178,173,000
Net adjustments to purchase price of properties acquired	15,709,000
Proceeds from sales of assets	448,000	963,000
Acquisition of other property, plant and equipment	-1,683,000	-724,000
Change in restricted cash	-104,000	-45,000
Net cash (used in) investing	-460,249,000	-375,597,000
Cash flows from financing activities
Net increase (decrease) in cash	-5,214,000	-950,000
Cash
Beginning of period	17,650,000	18,600,000
End of period	12,436,000	17,650,000
Non-Guarantor Subsidiaries
Cash flows from operating activities
Net income (loss)	-180,000	-467,000
Adjustments to reconcile net income (loss) to net cash provided by operating activities	140,000	733,000
Net cash provided by operations	-40,000	266,000
Cash flows from investing activities
Proceeds from sales of assets		644,000
Acquisition of other property, plant and equipment		-910,000
Net cash (used in) investing		-266,000
Cash flows from financing activities
Net increase (decrease) in cash	-40,000
Cash
Beginning of period	70,000	70,000
End of period	$30,000	$70,000