Jones Energy (JONEQ) 10-K 28 Feb 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Feb. 21, 2018	Jun. 30, 2017
Document Information [Line Items]
Entity Registrant Name	Jones Energy, Inc.
Entity Central Index Key	1,573,166
Document Type	10-K
Document Period End Date	Dec. 31, 2017
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Entity Public Float			$ 102.4
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	FY
Class A common stock
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		92,030,282
Class B common stock
Document Information [Line Items]
Entity Common Stock, Shares Outstanding		9,627,821

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Current assets
Cash	$ 19,472	$ 34,642
Accounts receivable, net
Oil and gas sales	34,492	26,568
Joint interest owners	31,651	5,267
Other	1,236	6,061
Commodity derivative assets	3,474	24,100
Other current assets	14,376	2,684
Total current assets	104,701	99,322
Oil and gas properties, net, at cost under the successful efforts method	1,597,040	1,743,588
Other property, plant and equipment, net	2,719	2,996
Commodity derivative assets	172	34,744
Other assets	5,431	6,050
Total assets	1,710,063	1,886,700
Current liabilities
Trade accounts payable	72,663	36,527
Oil and gas sales payable	31,462	28,339
Accrued liabilities	21,604	25,707
Commodity derivative liabilities	36,709	14,650
Other current liabilities	4,049	2,584
Total current liabilities	166,487	107,807
Long-term debt	759,316	724,009
Deferred revenue	5,457	7,049
Commodity derivative liabilities	8,788	1,209
Asset retirement obligations	19,652	19,458
Liability under tax receivable agreement	59,596	43,045
Other liabilities	811	792
Deferred tax liabilities	14,281	2,905
Total liabilities	1,034,388	906,274
Commitments and contingencies (Note 15)
Mezzanine equity
Series A preferred stock, $0.001 par value; 1,839,995 shares issued and outstanding at December 31, 2017 and 1,840,000 shares issued and outstanding at December 31, 2016	89,539	88,975
Stockholders' equity
Treasury stock, at cost: 22,602 shares at December 31, 2017 and December 31, 2016	(358)	(358)
Additional paid-in-capital	606,319	447,137
Retained (deficit) / earnings	(136,274)	(8,652)
Stockholders' equity	469,787	438,214
Non-controlling interest	116,349	453,237
Total stockholders’ equity	586,136	891,451
Total liabilities and stockholders' equity	1,710,063	1,886,700
Class A common stock
Stockholders' equity
Common stock	90	57
Class B common stock
Stockholders' equity
Common stock	$ 10	$ 30

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2017	Dec. 31, 2016
Mezzanine equity
Series A preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Series A preferred stock, shares issued	1,839,995	1,840,000
Series A preferred stock, shares outstanding	1,839,995	1,840,000
Treasury stock
Treasury stock, shares	22,602	22,602
Class A common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	90,139,840	57,048,076
Common stock, shares outstanding	90,117,238	57,025,474
Class B common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	9,627,821	29,832,098
Common stock, shares outstanding	9,627,821	29,832,098

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating revenues
Oil and gas sales		$ 186,393	$ 124,877	$ 194,555
Other revenues		2,180	2,970	2,844
Total operating revenues		188,573	127,847	197,399
Operating costs and expenses
Lease operating		36,636	32,640	41,027
Production and ad valorem taxes		6,874	7,768	12,130
Exploration		14,145	6,673	6,551
Depletion, depreciation and amortization		167,224	153,930	205,498
Impairment of oil and gas properties		149,648
Accretion of ARO liability		960	1,263	1,087
General and administrative		29,892	29,640	33,388
Other operating			199	4,188
Total operating expenses		405,379	232,113	303,869
Operating income (loss)		(216,806)	(104,266)	(106,470)
Other income (expense)
Interest expense		(51,651)	(53,127)	(64,458)
Gain on debt extinguishment			99,530
Net gain (loss) on commodity derivatives		(17,985)	(51,264)	158,753
Other income (expense)		56,952	536	317
Other income (expense), net		(12,684)	(4,325)	94,612
Income (loss) before income tax		(229,490)	(108,591)	(11,858)
Income tax provision (benefit)
Current		(3,585)	3,981	113
Deferred		(47,082)	(27,767)	(2,894)
Total income tax provision (benefit)		(50,667)	(23,786)	(2,781)
Net income (loss)		(178,823)	(84,805)	(9,077)
Net income (loss) attributable to non-controlling interests		(77,331)	(42,253)	(6,696)
Net income (loss) attributable to controlling interests		(101,492)	(42,552)	(2,381)
Dividends and accretion on preferred stock		(7,924)	(2,669)
Net income (loss) attributable to common shareholders		$ (109,416)	$ (45,221)	$ (2,381)
Earnings (loss) per share:
Basic - Net income (loss) attributable to common shareholders (in dollars per share)	[1]	$ (1.51)	$ (1.04)	$ (0.08)
Diluted - Net income (loss) attributable to common shareholders (in dollars per share)	[1]	$ (1.51)	$ (1.04)	$ (0.08)
Weighted average Class A shares outstanding (1) :
Basic (in shares)	[1]	72,411	43,506	29,161
Diluted (in shares)	[1]	72,411	43,506	29,161
[1]	All share and earnings per share information presented has been recast to retrospectively adjust for the effects of the 0.087423 per share Special Stock Dividend, as defined in Note 12, “Stockholders’ and Mezzanine equity”, distributed on March 31, 2017.

Consolidated Statements of Ope5

Consolidated Statements of Operations (Parenthetical)	Mar. 31, 2017shares
Class A common stock
Weighted average Class A shares outstanding (1) :
Special stock dividend declared per share (in shares)	0.087423

Statement of Changes in Stockho

Statement of Changes in Stockholders' Equity - USD ($) shares in Thousands, $ in Thousands	Common StockClass A common stock	Common StockClass B common stock	Treasury StockClass A common stock	Additional Paid-in-Capital	Retained Earnings	Non-controlling Interest	Class A common stock	Total
Balance at Dec. 31, 2014	$ 13	$ 37	$ (358)	$ 178,763	$ 38,950	$ 635,945		$ 853,350
Balance (in shares) at Dec. 31, 2014	12,622	36,719	23
Increase (Decrease) Stockholders' Equity
Stock-compensation expense				7,562				7,562
Stock-compensation expense (in shares)	67
Vested restricted shares (in shares)	153
Sale of common stock	$ 12			123,189				123,201
Sale of common stock (in shares)	12,263
Exchange of Class B Shares for Class A Shares	$ 6	$ (6)		54,209		(92,393)		(38,184)
Exchange of Class B shares for Class A shares (in shares)	5,446	(5,446)
Net income (loss)					(2,381)	(6,696)		(9,077)
Balance at Dec. 31, 2015	$ 31	$ 31	$ (358)	363,723	36,569	536,856		936,852
Balance (in shares) at Dec. 31, 2015	30,551	31,273	23
Increase (Decrease) Stockholders' Equity
Stock-compensation expense				7,425				7,425
Vested restricted shares (in shares)	385
Distributions paid to JEH unitholders						(17,319)		(17,319)
Sale of common stock	$ 25			65,421				65,446
Sale of common stock (in shares)	24,648
Exchange of Class B Shares for Class A Shares	$ 1	$ (1)		10,568		(24,047)		(13,479)
Exchange of Class B shares for Class A shares (in shares)	1,441	(1,441)
Dividends and accretion on preferred stock					(2,669)			(2,669)
Net income (loss)					(42,552)	(42,253)		(84,805)
Balance at Dec. 31, 2016	$ 57	$ 30	$ (358)	447,137	(8,652)	453,237		891,451
Balance (in shares) at Dec. 31, 2016	57,025	29,832	23
Increase (Decrease) Stockholders' Equity
Cumulative effect of adoption of ASU 2016-09				706	(706)
Stock-compensation expense	$ 1			5,797				5,798
Stock-compensation expense (in shares)	763
Distributions paid to JEH unitholders						(562)		(562)
Sale of common stock	$ 4			8,329				8,333
Sale of common stock (in shares)	3,716						3,700
Stock dividends on common stock	$ 5			17,495	(17,500)
Stock dividends on common stock (in shares)	5,000
Exchange of Class B Shares for Class A Shares	$ 20	$ (20)		122,865		(258,995)		(136,130)
Exchange of Class B shares for Class A shares (in shares)	20,204	(20,204)
Dividends and accretion on preferred stock	$ 3			3,990	(7,924)			(3,931)
Dividends and accretion on preferred stock (in shares)	3,409
Net income (loss)					(101,492)	(77,331)		(178,823)
Balance at Dec. 31, 2017	$ 90	$ 10	$ (358)	$ 606,319	$ (136,274)	$ 116,349		$ 586,136
Balance (in shares) at Dec. 31, 2017	90,117	9,628	23

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities
Net income (loss)	$ (178,823)	$ (84,805)	$ (9,077)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, and amortization	167,224	153,930	205,498
Exploration (dry hole and lease abandonment)	11,017	6,261	5,250
Impairment of oil and gas properties	149,648
Accretion of ARO liability	960	1,263	1,087
Amortization of debt issuance costs	3,955	4,060	6,043
Stock compensation expense	6,260	7,425	7,562
Deferred and other non-cash compensation expense	208	804	455
Amortization of deferred revenue	(1,854)	(2,384)	(1,960)
(Gain) loss on commodity derivatives	17,985	51,264	(158,753)
(Gain) loss on sales of assets	127	(14)	3
(Gain) on debt extinguishment		(99,530)
Deferred income tax provision	(47,082)	(27,767)	(2,892)
Change in liability under tax receivable agreement	(59,492)
Other - net	2,044	418	(961)
Changes in operating assets and liabilities
Accounts receivable	(34,615)	2,276	64,510
Other assets	(12,330)	(675)	(432)
Accrued interest expense	(1,422)	(4,727)	7,050
Accounts payable and accrued liabilities	35,198	17,901	(54,534)
Net cash provided by operations	59,008	25,700	68,849
Cash flows from investing activities
Additions to oil and gas properties	(245,364)	(264,462)	(311,305)
Net adjustments to purchase price of properties acquired	2,391
Proceeds from sales of assets	61,290	1,645	41
Acquisition of other property, plant and equipment	(586)	(310)	(1,101)
Current period settlements of matured derivative contracts	72,265	132,265	144,145
Net cash (used in) investing	(110,004)	(130,862)	(168,220)
Cash flows from financing activities
Proceeds from issuance of long-term debt	162,000	130,000	85,000
Repayment of long-term debt	(129,000)	(62,000)	(335,000)
Proceeds from senior notes			236,475
Purchase of senior notes		(84,589)
Payment of debt issuance costs	(1,115)		(1,556)
Payment of cash dividends on preferred stock	(3,368)	(1,615)
Net distributions paid to JEH unitholders	(562)	(17,319)
Net payments for share based compensation	(462)
Proceeds from sale of common stock	8,333	65,446	122,779
Proceeds from sale of preferred stock		87,988
Net cash provided by financing	35,826	117,911	107,698
Net increase (decrease) in cash	(15,170)	12,749	8,327
Cash
Beginning of period	34,642	21,893	13,566
End of period	19,472	34,642	21,893
Supplemental disclosure of cash flow information
Cash paid for interest, net of capitalized interest	49,101	53,816	52,796
Cash paid for income taxes	2,318		(155)
Change in accrued additions to oil and gas properties	3,921	9,325	(111,210)
Asset retirement obligations incurred, including changes in estimate	$ 924	$ (1,276)	$ 6,371

Organization and Description of

Organization and Description of Business	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Organization and Description of Business	1. Organization and Description of Busines 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, certain members of management and through private equity funds managed by Metalmark Capital, among others. 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 remaining owners of JEH prior to the initial public offering (“IPO”) of the Company (collectively, the “Class B shareholders”) and can be exchanged (together with a corresponding number of common 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 holders to one vote on all matters to be voted on by the Company’s stockholders generally. As of December 31, 2017, the Company held 90,117,238 JEH Units and all of the preferred units representing membership interests in JEH, and the remaining 9,627,821 JEH Units are held by the Class B shareholders. The Class B shareholders have no voting rights with respect to their economic interest in JEH, resulting in the Company reporting this ownership interest as a non-controlling interest. The Company’s certificate of incorporation also authorizes the Board of Directors of the Company to establish one or more series of preferred stock. Unless required by law or by any stock exchange on which our common stock is listed, the authorized shares of preferred stock will be available for issuance without further action. Rights and privileges associated with shares of preferred stock are subject to authorization by the Board of Directors of the Company and may differ from those of any and all other series at any time outstanding. On August 25, 2016, the Company issued 1,840,000 shares of its 8.0% Series A Perpetual Convertible Preferred Stock, par value $0.001 per share (the “Series A preferred stock”), pursuant to a registered public offering at $50 per share, of which 1,839,995 remained issued and outstanding as of December 31, 2017. See Note 12, “Stockholders’ and Mezzanine equity”. Description of Business The Company is engaged in the exploration, development, production and acquisition of oil and natural gas properties in the mid-continent United States, spanning areas of Oklahoma and Texas. The Company’s assets are located within the Eastern Anadarko Basin, targeting the liquids rich Woodford shale and Meramec formations in the Merge area of the STACK/SCOOP plays, and the Western Anadarko Basin, targeting the liquids rich Cleveland, Granite Wash, Tonkawa and Marmaton formations, and are owned by JEH and its operating subsidiaries. The Company is headquartered in Austin, Texas.

Significant Accounting Policies

Significant Accounting Policies	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Significant Accounting Policies	2. Significant Accounting Policies Basis of Presentation The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission. All significant intercompany transactions and balances have been eliminated in consolidation. The Company’s financial position as of December 31, 2017 and 2016 and the financial statements reported for each of the three years in the period ended December 31, 2017 include the Company and all of its subsidiaries Certain prior period amounts have been reclassified to conform to the current presentation. 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 and unproved 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”). 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 it does business with, 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, 2017 and at December 31, 2016 of derivative positions not settled as of the balance sheet date. 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, 2017 and 2016, 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, 2017, 71% of Accounts receivable—Oil and gas sales were due from three purchasers and 59% of Accounts receivable‑Joint interest owners were due from five working interest owners. As of December 31, 2016, 77% of Accounts receivable—Oil and gas sales were due from four purchasers and 48% of Accounts receivable‑Joint interest owners were due from five working interest owners. As of December 31, 2015, 68% of Accounts receivable—Oil and gas sales are due from four purchasers and 80% of Accounts receivable—Joint interest owners are due from five 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, 2017, the largest purchasers of our production were Plains Marketing LP (“Plains Marketing”) and ETC Field Services LLC, which accounted for approximately 40% and 22% of consolidated oil and gas sales, respectively. During the year ended December 31, 2016, the largest purchasers of our production were Plains Marketing LP (“Plains Marketing”) and ETC Field Services LLC, which accounted for approximately 37% and 24% of consolidated oil and gas sales, respectively. During the year ended December 31, 2015, the largest purchasers of our production were Valero Energy Corp. (“Valero”), ETC Field Services LLC, Plains Marketing LP, and NGL Energy Partners LP, which accounted for approximately 18%, 17%, 16%, 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. 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. 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. 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 the life of 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. 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. 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 commodity prices, lease expiration dates, results of any drilling and geo science activity during the period, and known information regarding exploration and development activity by other companies on adjacent blocks. 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 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. 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. Accrued Liabilities Accrued liabilities consisted of the following at December 31, 2017 and 2016: December 31, December 31, (in thousands of dollars) 2017 2016 Accrued interest $ 12,109 $ 13,531 Other accrued liabilities 9,495 12,176 Total accrued liabilities $ 21,604 $ 25,707 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, 2017, 2016 and 2015, 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 7, “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. Revenue Recognition Revenues from the sale of crude oil, natural gas, and natural gas liquids are valued at the estimated sales price and 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. The Company had no significant imbalances as of December 31, 2017, 2016, and 2015. Income Taxes The Company records a federal and state income tax liability associated with its status as a corporation. The Company recognizes a tax liability on its share of pre-tax book income, exclusive of the non-controlling interest. 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. On December 22, 2017, the US Congress enacted the Tax Cuts and Jobs Act (Tax Reform Legislation), which made significant changes to US federal income tax law affecting us. See Note 11. “Income Taxes.” 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 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. Comprehensive Income The Company has no elements of comprehensive income other than net income. Recent Accounting Pronouncements Adopted in the current year: In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-09, “Compensation—Stock Compensation” (Topic 718). This amendment is intended to simplify the accounting for share-based payment awards to employees, specifically in regard to (1) the income tax consequences, (2) classification of awards as either equity or liabilities, and (3) classification on the statement of cash flows. The amendments are effective for interim and annual reporting periods beginning after December 15, 2016. Therefore, the Company has adopted ASU 2016-09 effective as of January 1, 2017. Upon adoption of ASU 2016-09, the Company elected to change its accounting policy to account for forfeitures as they occur. The change was applied on a modified retrospective basis with a cumulative effect adjustment to retained earnings for forfeitures of $0.7 million as of January 1, 2017. As a result of the valuation allowance against the Company’s deferred tax assets, there was no net adjustment to retained earnings for the change in accounting for unrecognized windfall tax benefits. In May 2017, the FASB issued ASU 2017-09, “Scope of Modification Accounting” as it relates to “Compensation—Stock Compensation” (Topic 718). This amendment clarifies when changes to the terms or conditions of a share-based payment award must be accounted for as modifications. The new guidance is expected to reduce diversity in practice and result in fewer changes to the terms of an award being accounted for as modifications. Under ASU 2017-09, an entity will not apply modification accounting to a share-based payment award if the award’s fair value, vesting conditions and classification as an equity or liability instrument are the same immediately before and after the change. The amendments are effective for interim and annual reporting periods beginning after December 15, 2017. Early adoption is permitted and the Company chose to early adopt ASU 2017-09 beginning April 1, 2017. The change was applied prospectively to awards modified on or after the adoption date. Adoption did not have a material impact on the financial position, cash flows or results of operations. To be adopted in a future period: In May 2014, the FASB issued ASU 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 standard 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. In August 2015, the FASB issued ASU 2015-14, which deferred the effective date of ASU 2014-09 by one year. The amendments are now effective for interim and annual reporting periods beginning after December 15, 2017 and may be applied on either a full or modified retrospective basis. Early adoption is permitted. During 2017, the Company performed a comparison of our current revenue recognition policies in effect through December 31, 2017 to the new requirements upon adoption of ASU 2014-09 and ASU 2015-14 for each of our revenue categories based upon review of our current contracts by product category and homogenous groupings. Upon completion of the assessment, the analysis of these homogenous groupings did not indicate any material change to our current revenue recognition methodology, although we do expect some changes in presentation of gross revenues and expenses upon adoption of the standard; such costs are currently offset against revenues. The Company adopted ASU 2014-09 and ASU 2015-14 effective as of January 1, 2018 applied on a modified retrospective basis, which did not result in a material cumulative effect adjustment as of the date of adoption. Adoption did not have a material impact on the financial position, cash flows or results of operations. In addition to changes in the presentation of the Company’s Consolidated Statement of Operations, we expect to expand disclosures related to revenue recognition. The Company will continue to further evaluate the effect that the adoption of ASU 2014-09 and ASU 2015-14 will have on our disclosures as we prepare for our first quarter 2018 Form 10-Q filing. In February 2016, the FASB issued ASU 2016-02, “Leases” (Topic 842). This amendment requires, among other things, that lessees recognize the following for all leases (with the exception of short-term leases) at the commencement date: (1) a lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis; and (2) a right-of-use asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term. Lessees and lessors must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The amendments are effective for interim and annual reporting periods beginning after December 15, 2018. Early adoption is permitted. The Company is currently evaluating the impacts of the amendments to our financial statements and accounting practices for leases. We anticipate adoption of ASU 2016-02 effective as of January 1, 2019. In January 2017, the FASB issued ASU 2017-01, “Business Combinations” (Topic 805). The amendments under this ASU provide guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (disposals) or business combinations by providing a screen to determine when an integrated set of assets and activities is not a business. The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business, therefore reducing the number of transactions that need to be further evaluated for treatment as a business combination. This new guidance is effective for annual periods beginning after December 15, 2017. Early adoption is permitted. The Company adopted ASU 2017-01 effective as of January 1, 2018 applied prospectively, which did not have a material impact on our financial statements; however these amendments could result in the recording of fewer business combinations in future periods. In August 2017, the FASB issued ASU 2017-12, “Derivatives and Hedging” (Topic 815). The amendments in this update apply to any entity that elects to apply hedge accounting in accordance with current GAAP. This standard expands an entity’s ability to apply hedge accounting for nonfinancial and financial risk components and allows for a simplified approach for fair value hedging of interest rate risk. The standard also eliminates the need to separately measure and report hedge ineffectiveness and generally requires the entire change in fair value of a hedging instrument to be presented in the same income statement line as the hedged item. Additionally, the standard simplifies the hedge documentation and effectiveness assessment requirements under the previous guidance. The amendments are effective for interim and annual reporting periods beginning after December 15, 2018. Early adoption is permitted. Historically, the Company has elected not to designate any of its commodity price risk management activities as cash flow or fair value hedges. After concluding our assessment of the amendments in this update, Management has determined we will continue not to designate any of our commodity price risk management activities as cash flow or fair value hedges. Therefore, adoption is not expected to have a material impact on the financial position, cash flows or results of operations. We anticipate adoption of ASU 2017-12 effective as of January 1, 2019.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Acquisitions	3. Acquisitions and Divestitures During the three year period ended December 31, 2017, the Company entered into several purchase and sale agreements (as described below). One business combination occurred during the twelve months ended December 31, 2016. However, no business combinations occurred during the twelve months ended December 31, 2017 and 2015. Merge Acquisition On September 22, 2016, JEH acquired oil and gas properties located in the Merge area of the STACK/SCOOP plays (the “Merge”) in Central Oklahoma (the “Merge Acquisition”) from SCOOP Energy Company, LLC for cash consideration of $134.4 million, net of the final working capital settlement of $2.4 million received in the first quarter of 2017. The oil and gas properties acquired in the Merge Acquisition, on a closed and funded basis, principally consist of 16,975 undeveloped net acres in Canadian, Grady and McClain Counties, Oklahoma. This transaction has been accounted for as an asset acquisition. The Company used proceeds from our equity offerings to fund the purchase. See Note 12, “Stockholders’ and Mezzanine equity”. Anadarko Acquisition On August 25, 2016, JEH acquired producing and undeveloped oil and gas assets in the Western Anadarko Basin (the “Anadarko Acquisition”) for final consideration of $25.9 million. This transaction was accounted for as a business combination. The Company allocated $32.3 million to “Oil and gas properties,” with $3.0 million allocated to “Unproved” properties, $17.0 million allocated to “Proved” properties, and $12.3 million allocated to “Wells and equipment and related facilities”, based on the respective fair values of the assets acquired. Additionally, the Company allocated $6.4 million to our ARO liability associated with those proved properties. As of December 31, 2017, the measurement-period has closed. The Anadarko Acquisition did not result in a significant impact to revenues or net income and as such, pro forma financial information is not included. The Company funded the Anadarko Acquisition with cash on hand. The assets acquired in the Anadarko Acquisition included interests in 174 wells, 59% of which were operated by the company, and approximately 25,000 net acres in Lipscomb and Ochiltree Counties in the Texas Panhandle. As of the closing date, the acquired acreage was producing approximately 900 barrels of oil equivalent per day. Arkoma Divestiture As of June 30, 2017, the Arkoma Assets and related liabilities (the “Held for sale assets”) were classified as held for sale due to the pending Arkoma Divestiture. Upon the classification change occurring on June 30, 2017, the Company ceased recording depletion on the Held for sale assets. Based on the Company’s sales price, the Company recognized an estimated impairment charge of $148.0 million at June 30, 2017 which has been included in Impairment of oil and gas properties on the Company’s Consolidated Statement of Operations. On August 1, 2017, JEH closed its previously announced agreement to sell its Arkoma Basin properties (the “Arkoma Assets”) for a sale price of $65.0 million, prior to customary effective date adjustments of $7.3 million, and subject to customary post-close adjustments (the “Arkoma Divestiture”). JEH may also receive up to $2.5 million in contingent payments based on natural gas prices. No amounts have been recorded related to this contingent payment as of December 31, 2017.

Properties, Plant and Equipment

Properties, Plant and Equipment	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Properties, Plant and Equipment	4. Properties, Plant and Equipment 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, 2017 and 2016: December 31, December 31, (in thousands of dollars) 2017 2016 Mineral interests in properties Unproved $ 164,087 $ 213,153 Proved 893,246 1,054,683 Wells and equipment and related facilities 1,434,383 1,395,291 2,491,716 2,663,127 Less: Accumulated depletion and impairment (894,676) (919,539) Net oil and gas properties $ 1,597,040 $ 1,743,588 There were no exploratory wells drilled during the year ended December 31, 2017 and, as such, no associated costs were capitalized. One exploratory well was drilled during the year ended December 31, 2016, for which associated costs of $1.3 million were capitalized. No exploratory wells resulted in exploration expense during either year. 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. During the year ended December 31, 2017, the Company capitalized $0.4 million associated with such in progress projects. The Company did not capitalize any interest during the year ended December 31, 2016 as no projects lasted more than six months. Costs incurred to maintain wells and related equipment are charged to expense as incurred. Depletion of oil and gas properties amounted to $166.2 million, $152.7 million, and $204.2 million for the years ended December 31, 2017, 2016, and 2015, respectively. The Company continues to monitor its proved and unproved properties for impairment. During the year ended December 31, 2017, the Company recognized an impairment charge of $1.6 million related to minor properties, which we are not currently developing. Additionally, as noted in Note 3, “Acquisitions and Divestitures - Arkoma Divestiture,” the Company recognized an impairment charge of $148.0 million during the second quarter of 2017 based on the Company’s negotiated selling price of the Arkoma Basin oil and gas property assets and related liabilities. No impairments of proved or unproved properties were recorded during the years ended December 31, 2016 and 2015. Other Property, Plant and Equipment Other property, plant and equipment consisted of the following at December 31, 2017 and 2016: December 31, December 31, (in thousands of dollars) 2017 2016 Leasehold improvements $ 1,186 $ 1,213 Furniture, fixtures, computers and software 4,410 4,170 Vehicles 1,922 1,677 Aircraft 910 910 Other 210 284 8,638 8,254 Less: Accumulated depreciation and amortization (5,919) (5,258) Net other property, plant and equipment $ 2,719 $ 2,996 Depreciation and amortization of other property, plant and equipment amounted to $1.0 million, $1.2 million, and $1.3 million during the years ended December 31, 2017, 2016 and 2015, respectively.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Long-Term Debt	5. Long‑Term Debt Long-term debt consisted of the following at December 31, 2017 and 2016: (in thousands of dollars) December 31, 2017 December 31, 2016 Revolver $ 211,000 $ 178,000 2022 Notes 409,148 409,148 2023 Notes 150,000 150,000 Total principal amount 770,148 737,148 Less: unamortized discount (5,228) (6,240) Less: debt issuance costs, net (5,604) (6,899) Total carrying amount $ 759,316 $ 724,009 Senior Unsecured Notes On April 1, 2014, JEH and Jones Energy Finance Corp., JEH’s wholly owned subsidiary formed for the sole purpose of co-issuing certain of JEH’s debt (collectively, 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 certain indebtedness and for working capital and general corporate purposes. 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. The 2022 Notes were registered in March 2015. The 2022 Notes mature on April 1, 2022. On February 23, 2015, the Issuers sold $250.0 million in aggregate principal amount of 9.25% senior notes due 2023 (the “2023 Notes”) in a private placement to affiliates of GSO Capital Partners LP and Magnetar Capital LLC. The 2023 Notes were issued at a discounted price equal to 94.59% of the principal amount. The Company used the $236.5 million net proceeds from the issuance of the 2023 Notes to repay outstanding borrowings under the Revolver (as defined below) and for working capital and general corporate purposes. The 2023 Notes bear interest at a rate of 9.25% per year, payable semi-annually on March 15 and September 15 of each year beginning September 15, 2015. The 2023 Notes were registered in February 2016. The 2023 Notes mature on March 15, 2023. During 2016, the Company purchased an aggregate principal amount of $190.9 million of its senior unsecured notes through several open-market and privately negotiated purchases. The Company purchased $90.9 million principal amount of its 2022 Notes for $38.1 million, and $100.0 million principal amount of its 2023 Notes for $46.5 million, in each case excluding accrued interest and including any associated fees. The Company used cash on hand and borrowings from its Revolver to fund the note purchases. In conjunction with the extinguishment of this debt, JEH recognized cancellation of debt income of $99.5 million during the year ended December 31, 2016, on a pre-tax basis. This income is recorded in Gain on debt extinguishment on the Company’s Consolidated Statement of Operations. Of the Company’s total repurchases, $20.3 million principal amount of its 2022 Notes were not cancelled and are available for future reissuance, subject to applicable securities laws. No additional purchases were made during 2017. The 2022 Notes and 2023 Notes are guaranteed on a senior unsecured basis by the Company and by all of its significant subsidiaries. The 2022 Notes and 2023 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 and the 2023 Notes at any time on or after March 15, 2018 at a declining redemption price set forth in the respective indentures, plus accrued and unpaid interest. The indentures governing the 2022 Notes and 2023 Notes are substantially identical and contain 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. If at any time when the 2022 Notes or 2023 Notes are rated investment grade and no default or event of default (as defined in the indenture) has occurred and is continuing, many of the foregoing covenants pertaining to the 2022 Notes or 2023 Notes, as applicable, will be suspended. If the ratings on the 2022 Notes or 2023 Notes, as applicable, were to decline subsequently to below investment grade, the suspended covenants would be reinstated. As of December 31, 2017, the Company was in compliance with the indentures governing the 2022 Notes and 2023 Notes. Senior Secured First Lien Notes due 2023 On February 14, 2018, the Issuers sold $450.0 million of 9.25% senior secured first lien notes due 2023 (the “2023 First Lien Notes”) at an offering price equal to 97.526% of par in an offering exempt from registration under the Securities Act. See Note 16, “Subsequent Events.” Other Long-Term Debt The Company has a Senior Secured Revolving Credit Facility (the “Revolver”) with a syndicate of banks. At the beginning of 2017, the borrowing base under the Revolver was $425.0 million, which was reaffirmed on May 15, 2017 during the semi-annual borrowing base re-determination. Upon closing of the Arkoma Divestiture on August 1, 2017, the Company’s borrowing base was reduced to $375.0 million. Effective November 26, 2017, the borrowing base was further reduced to $350.0 million during the semi-annual borrowing base re-determination. The Company’s oil and gas properties are pledged as collateral to secure its obligations under the Revolver. The Revolver matures on November 6, 2019. On November 26, 2017, the Company entered into an amendment to the Revolver to, among other things (a) modify certain financial ratio covenants, which are more fully described below, (b) reduce the borrowing base to $350.0 million until the next redetermination thereof, (c) increase the margin applicable to borrowings under the Revolver by 0.75% if the total leverage ratio is at or below 4.00 to 1.00 and 1.25% if the total leverage ratio is above 4.00 to 1.00, in each case determined as of the last day of the most recently ended fiscal quarter, (d) add a covenant limiting the ability of JEH and its subsidiaries to repurchase or redeem certain indebtedness prior to maturity thereof, subject to certain exceptions, (e) permit JEH to raise up to $350.0 million of junior lien debt, subject to covenant compliance and other customary conditions and (f) increase the Company’s hedge limits to permit, at any time, hedging of up to (i) 100% of projected production from proved reserves over the period of 24 months following such time and (ii) 85% of projected production from proved reserves for the subsequent period of 36 months thereafter. On February 14, 2018, the Company further amended the Revolver in connection with the offering of the 2023 First Lien Notes. Please see Note 16, “Subsequent Events.” 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. The Revolver is subject to a borrowing base, which limits the amount of borrowings which may be drawn thereunder. The borrowing base will be re-determined by the lenders at least semi-annually on or about April 1 and October 1 of each year, with such re-determination based primarily on reserve reports using lender commodity price expectations at such time. Any reduction in the borrowing base will reduce our liquidity, and, if the reduction results in the outstanding amount under our Revolver exceeding the borrowing base, we will be required to repay the deficiency within a short period of time. Interest on the Revolver is calculated, at the Company’s option, at either (a) the London Interbank Offered (“LIBO”) rate for the applicable interest period plus a margin of (i) 2.25% to 3.25% if the Company’s total leverage ratio is less than or equal to 4.00 to 1.00 as of the last day of the previous fiscal quarter or (ii) 2.75% to 3.75% if the Company’s total leverage ratio is greater than 4.00 to 1.00 as of the last day of the previous fiscal quarter, in each case 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 (x) 1.25% to 2.25% if the Company’s total leverage ratio is less than or equal to 4.00 to 1.00 as of the last day of the previous fiscal quarter or (y) 1.75% to 2.75% if the Company’s total leverage ratio is greater than 4.00 to 1.00 as of the last day of the previous fiscal quarter, in each case based on the level of borrowing base utilization at such time. For the year ended December 31, 2017, the average interest rate under the Revolver was 3.04% on an average outstanding balance of $189.0 million. For the year ended December 31, 2016, the average interest rate under the Revolver was 2.40% on an average outstanding balance of $172.3 million. Total interest and commitment fees under the Revolver were $6.6 million, $5.3 million, and $5.1 million for the years ended December 31, 2017, 2016 and 2015, respectively. Jones Energy, Inc. and its consolidated subsidiaries are subject to certain covenants under the Revolver, including the requirement to maintain the following financial ratios: · commencing with the fiscal quarter ending March 31, 2019, a senior secured leverage ratio, consisting of consolidated secured funded debt to EBITDAX, of not greater than 2.25 to 1.00 as of the last day of any fiscal quarter; · commencing with the fiscal quarter ending March 31, 2019, a total leverage ratio, consisting of consolidated debt to EBITDAX, of not greater than (i) 5.25 to 1.00 as of March 31, 2019, (ii) 5.00 to 1.00 as of June 30, 2019, (iii) 4.75 to 1.00 as of September 30, 2019, (iv) 4.50 to 1.00 as of December 31, 2019 and (v) 4.00 to 1.00 as of the last day of each fiscal quarter ending thereafter; and · a current ratio, consisting of consolidated current assets, including the unused amounts of the total commitments, to consolidated current liabilities, of not less than 1.00 to 1.00 as of the last day of any fiscal quarter. As of December 31, 2017, our senior secured leverage ratio was approximately 1.18x, our total leverage ratio was approximately 4.29x and our current ratio was approximately 1.85x, as calculated based on the requirements in our indenture. We were in compliance with all terms of our Revolver at December 31, 2017, and we expect to maintain compliance throughout 2018. However, factors including those outside of our control, such as commodity price declines, may prevent us from maintaining compliance with these covenants, at future measurement dates in 2018 and beyond. In the event it were to become necessary, we believe we have the ability to take actions that would prevent us from failing to comply with our covenants, such as paying off and terminating the Revolver. If an event of default exists under the Revolver, the lenders will be able to accelerate the obligations outstanding under the Revolver and exercise other rights and remedies. Our Revolver contains customary events of default, including the occurrence of a change of control, as defined in the Revolver.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Derivative Instruments and Hedging Activities	6. Derivative Instruments and Hedging Activities The Company uses derivative instruments to mitigate volatility in commodity prices. While the use of these instruments limits the downside risk of adverse price changes, their use may also limit future revenues from favorable price changes. Depending on changes in oil and gas futures markets and management’s view of underlying supply and demand trends, we may increase or decrease our hedging positions. The following tables summarize our hedging positions as of December 31, 2017: Hedging Positions December 31, 2017 Weighted Final Low High Average Expiration Oil swaps Exercise price $ 49.70 $ 54.18 $ 50.64 December 2020 Net barrels per month 55,000 216,000 112,333 Natural gas swaps Exercise price $ 2.76 $ 3.10 $ 2.89 December 2020 Net MMbtu per month 700,000 1,890,000 1,118,889 Natural gas liquids swaps Exercise price $ 22.89 $ 45.26 $ 29.79 December 2018 Barrels per month 130,000 145,000 138,750 Natural gas basis swaps Exercise price $ (0.50) $ (0.30) $ (0.41) October 2018 Net MMbtu per month 800,000 800,000 800,000 Oil collars Puts (floors) $ 45.00 $ 50.00 $ 48.52 December 2019 Calls (ceilings) $ 56.60 $ 61.00 $ 59.64 Net barrels per month 65,000 73,000 67,500 Natural gas collars Puts (floors) $ 2.55 $ 2.55 $ 2.55 December 2019 Calls (ceilings) $ 3.08 $ 3.41 $ 3.19 Net barrels per month 950,000 1,050,000 990,833 The Company recognized net losses on derivative instruments of $18.0 million and $51.3 million for the years ended December 31, 2017 and 2016, respectively. The Company recognized net gains on derivative instruments of $158.8 million for the year ended December 31, 2015. The Company routinely enters into oil and natural gas swap contracts as seller, thus resulting in a fixed price. During 2016 and 2017, the Company realized certain mark-to-market gains associated with oil and natural gas hedges the Company had in place for years 2018 and 2019. The gains were effectively realized by purchasing, as opposed to selling, oil and natural gas swap contracts for an equal volume that was associated with the initial hedge transaction. Therefore, as prices fluctuate, the loss (or gain) on any single contract in 2018 and 2019 will be offset by an equal gain (or loss). This essentially left the underlying production open to fluctuations in market prices prior to the point when the Company began to re-hedge the unhedged production. Based on the original contract terms of these purchased swaps, the gains would have been recognized as the hedge contracts mature in 2018 and 2019. However, during the year ended December 31, 2017, the Company unwound all of its realized 2018 and 2019 hedges resulting in approximately $42.8 million, respectively, of recognized gains which have been included in Net gain (loss) on commodity derivatives on the Company’s Consolidated Statement of Operations. Offsetting Assets and Liabilities As of December 31, 2017, the counterparties to our commodity derivative contracts consisted of six financial institutions. 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. The following table presents information about our commodity derivative contracts that are netted on our Consolidated Balance Sheet as of December 31, 2017 and 2016: Net Amounts Gross of Assets / Gross Amounts Gross Amounts Amounts Liabilities Not of Recognized Offset in the Presented in Offset in the Assets / Balance the Balance Balance (in thousands of dollars) Liabilities Sheet Sheet Sheet Net Amount December 31, 2017 Commodity derivative contracts Assets $ 8,572 $ (4,926) $ 3,646 $ — $ 3,646 Liabilities (50,423) 4,926 (45,497) — (45,497) December 31, 2016 Commodity derivative contracts Assets $ 79,649 $ (20,805) $ 58,844 $ — $ 58,844 Liabilities (36,664) 20,805 (15,859) — (15,859)

Fair Value Measurement

Fair Value Measurement	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Fair Value Measurement	7. 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 high 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. 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, 2017 and 2016, by consolidated balance sheet caption and by valuation hierarchy, as described above are as follows: (in thousands of dollars) December 31, 2017 Fair Value Measurements Using Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ 3,474 $ — $ 3,474 Long-term assets — 56 116 172 Current liabilities — 28,946 7,763 36,709 Long-term liabilities — 7,860 928 8,788 (in thousands of dollars) December 31, 2016 Fair Value Measurements Using Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ 24,100 $ — $ 24,100 Long-term assets (1) — 36,384 (1,640) 34,744 Current liabilities — 13,636 1,014 14,650 Long-term liabilities — 892 317 1,209 (1) Level 3 long-term assets are negative as a result of the netting of our commodity derivatives reflected on our Consolidated Balance Sheet as of December 31, 2016. Our agreements include set-off provisions, as noted in Note 6, “Derivative Instruments and Hedging Activities - Offsetting Assets and Liabilities”. 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, 2017. Quantitative Information About Level 3 Fair Value Measurements Fair Value Unobservable Commodity Price Hedges (000’s) Valuation Technique Input Range Natural gas liquid swaps $ (7,763) Use a discounted cash flow approach using inputs including forward price statements from counterparties Natural gas liquid futures $27.93 - $44.00 per barrel Crude oil collars $ (654) Use a discounted option model approach using inputs including interpolated volatilities for certain settlement months where market volatility quotes were unavailable for the option strike price Market volatility quotes at the option strike for certain settlement months in 2019 $45.00 - $61.00 per barrel Natural gas collars $ (158) Use a discounted option model approach using inputs including interpolated volatilities for certain settlement months where market volatility quotes were unavailable for the option strike price Market volatility quotes at the option strike for certain settlement months in 2019 $2.55 - $3.41 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, 2017 and 2016. 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. The following table summarizes the Company’s commodity derivative contract activity involving Level 3 instruments, by year, is as follows: (in thousands of dollars) Balance at December 31, 2015, net $ 1,428 Purchases (5,208) Settlements (171) Transfers to Level 2 — Transfers to Level 3 2,363 Changes in fair value (1,383) Balance at December 31, 2016, net $ (2,971) Purchases (1,236) Settlements 1,606 Transfers to Level 2 — Transfers to Level 3 (6,527) Changes in fair value 553 Balance at December 31, 2017, net $ (8,575) 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, 2017 December 31, 2016 Principal Principal (in thousands of dollars) Amount Fair Value Amount Fair Value Debt: Revolver $ 211,000 $ 211,000 $ 178,000 $ 178,000 2022 Notes 409,148 305,404 409,148 393,150 2023 Notes 150,000 114,750 150,000 153,375 The Revolver (as defined in Note 5) 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 5) is based on pricing that is readily available in the public market. Accordingly, the 2022 Notes are classified as Level 1 in the valuation hierarchy as the pricing is based on quoted market prices for the debt securities and is actively traded. The fair value of the 2023 Notes (as defined in Note 5) is based on indicative pricing that is available in the public market. Accordingly, the 2023 Notes are classified as Level 2 in the valuation hierarchy as the pricing is based on quoted market prices for the debt securities but is not actively traded. 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.

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Asset Retirement Obligations	8. Asset Retirement Obligations A summary of the Company’s ARO for the years ended December 31, 2017 and 2016 is as follows: (in thousands of dollars) 2017 2016 ARO liability at beginning of year $ 20,058 $ 20,980 Liabilities incurred (1) 1,062 6,947 Accretion of ARO liability 960 1,263 Liabilities settled due to sale of related properties (1,231) (446) Liabilities settled due to plugging and abandonment (339) (463) Change in estimate (2) (138) (8,223) ARO liability at end of year 20,372 20,058 Less: Current portion of ARO at end of year (720) (600) Total long-term ARO at end of year $ 19,652 $ 19,458 (1) The 2016 amount includes $6.4 million related to wells acquired in the Anadarko Acquisition. See Note 3, “Acquisitions and Divestitures—Anadarko Acquisition”. (2) The 2016 amount reflects a reduction in the estimated cost per well, consistent with the decline in actual costs experienced by the Company.

Stock-based Compensation

Stock-based Compensation	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Stock-based Compensation	9. Stock‑based Compensation Management Unit Awards Effective January 1, 2010, JEH implemented a management incentive plan that provided indirect awards of membership interests in JEH to members of senior management (“Management Units”). These awards had various vesting schedules, and a portion of the Management Units vested in a lump sum at the IPO date. In connection with the IPO, both the vested and unvested Management Units were converted into the right to receive JEH Units and shares of Class B common stock. The JEH Units (together with a corresponding number of shares of Class B common stock) will become exchangeable under this plan into a like number of shares of Class A common stock upon vesting or forfeiture. No new Management Units have been awarded since the IPO and no new JEH Units or shares of Class B common stock are created upon a vesting event. Grants listed below reflect the transfer of JEH Units that occurred upon forfeiture. The following table summarizes information related to the vesting of Management Units as of December 31, 2017: Weighted Average Grant Date Fair Value JEH Units per Share Unvested at December 31, 2016 90,762 $ 15.00 Granted 13,066 15.00 Forfeited (13,066) 15.00 Vested (58,447) 15.00 Unvested at December 31, 2017 32,315 $ 15.00 Stock compensation expense associated with the Management Units for the years ended December 31, 2017, 2016 and 2015 was $0.6 million, $1.2 million, and $1.3 million, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. The weighted average grant date fair value of management units was $15.00 per share for the years ended December 31, 2017 and 2016. Unrecognized expense as of December 31, 2017 for all outstanding management units was $0.1 million and will be recognized over a weighted-average remaining period of 0.3 years. 2013 Omnibus Incentive Plan Under the Amended and Restated Jones Energy, Inc. 2013 Omnibus Incentive Plan (the “LTIP”), established in conjunction with the Company’s IPO and restated on May 4, 2016 following approval by the Company’s stockholders, the Company has reserved a total of 8,340,211 shares of Class A common stock for non-employee director, consultant, and employee stock-based compensation awards, as adjusted for the effects of the Special Stock Dividend and the preferred stock dividends paid in shares, as described in Note 12 “Stockholders’ and Mezzanine equity”. The Company granted (i) performance share unit and restricted stock unit awards to certain officers and employees and (ii) restricted shares of Class A common stock to the Company’s non-employee directors under the LTIP during 2015, 2016 and 2017. During 2016 and 2017, the Company also granted performance unit awards to certain members of the senior management team under the LTIP. All share and earnings per share information presented for awards made under the LTIP has been recast to retrospectively adjust for the effects of the 0.087423 per share Special Stock Dividend, as defined in Note 12, “Stockholders’ and Mezzanine equity”, distributed on March 31, 2017. Restricted Stock Unit Awards The Company has outstanding restricted stock unit awards granted to certain officers and employees of the Company under the LTIP. The fair value of the restricted stock unit awards is 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 vesting period, which is typically three years. The following table summarizes information related to the total number of units awarded to officers and employees as of December 31, 2017: Restricted Weighted Average Stock Unit Grant Date Fair Value Awards per Share Unvested at December 31, 2016 1,359,142 $ 5.60 Adjustment (1) 130,871 — Granted 2,394,290 2.32 Forfeited (543,803) 3.00 Vested (577,729) 6.62 Unvested at December 31, 2017 2,762,771 $ 2.79 (1) Increase of 0.002195 units for each unvested restricted stock unit awards at the time of the Company’s May 15, 2017 preferred stock dividend for the portion of such dividend paid in shares of the Company’s Class A common stock and of 0.021931 units for each unvested restricted stock unit award at the time of the Company’s August 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock and of 0.018867 units for each unvested restricted stock unit award at the time of the Company’s November 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock, as described in Note 12 “Stockholders’ and Mezzanine equity,” in accordance with the terms of the original awards. This increase is in addition to the adjustment for the effects of the Special Stock Dividend previously disclosed in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2017. Stock compensation expense associated with the employee restricted stock unit awards for the years ended December 31, 2017, 2016, and 2015 was $3.8 million, $3.0 million, and $3.1 million, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. The weighted average grant date fair value of restricted stock units was $2.32 per share, $3.67 per share, and $8.81 per share for the years ended December 31, 2017, 2016, and 2015, respectively. Unrecognized expense as of December 31, 2017 for all outstanding restricted stock unit awards was $5.3 million and will be recognized over a weighted-average remaining period of 2.0 years. Performance Share Unit Awards The Company has outstanding performance share unit awards granted to certain members of the senior management team of the Company under the LTIP. Prior to the second quarter of 2016, the performance share unit awards were described in the Company’s filings as performance unit awards. During the second quarter of 2016, the Company created a new class of equity award, described below as a performance unit award, that is settled in cash rather than shares of the Company’s Class A common stock. As a result, references to performance unit awards in the Company’s filings prior to the second quarter of 2016 refer to this description of performance share unit awards. Upon the completion of the applicable three-year performance period, each recipient may vest in a number of performance share units. The percent of awarded performance share units in which each recipient vests at such time, if any, 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 share unit is exchangeable for one share of the Company’s Class A common stock. The grant date fair value of the performance share units was determined using a Monte Carlo simulation model, which results in an estimated percentage of performance share units earned. The fair value of the performance share units is expensed on a straight-line basis over the applicable three-year performance period. The following table summarizes information related to the total number of performance share units awarded to the senior management team as of December 31, 2017: Performance Weighted Average Share Unit Grant Date Fair Value Awards per Share Unvested at December 31, 2016 942,073 $ 6.25 Adjustment (1) 63,712 — Granted 519,562 2.24 Forfeited (274,524) 5.29 Vested (293,645) 8.22 Unvested at December 31, 2017 957,178 $ 4.64 (1) Increase of 0.002195 units for each unvested performance share unit awards at the time of the Company’s May 15, 2017 preferred stock dividend for the portion of such dividend paid in shares of the Company’s Class A common stock and of 0.021931 units for each unvested performance share unit award at the time of the Company’s August 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock and of 0.018867 units for each unvested performance share unit award at the time of the Company’s November 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock, as described in Note 12 “Stockholders’ and Mezzanine equity,” in accordance with the terms of the original awards. This increase is in addition to the adjustment for the effects of the Special Stock Dividend previously disclosed in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2017. At the time the performance share units vest, the results of the the Company’s total share return relative to the industry peer group must be certified by the compensation committee of the board of directors before the corresponding shares of Class A common stock are issued. As of December 31, 2017 the 293,645 performance share units that vested during 2017 were awaiting certification by the compensation committee. The Class A shares corresponding to these uncertified awards are not included in the Company’s total outstanding Class A shares reported within stockholder’s equity on the Company’s Consolidated Balance Sheets. The estimated fair value of performance share units vested during the year ended December 31, 2017 was $0.2 million, which will be distributed to recipients during the first quarter of 2018. The fair value of performance share units vested during the year ended December 31, 2016 was $0.8 million, the shares of which were distributed to recipients during the first quarter of 2017. No performance share units vested during the year ended December 31, 2015. Stock compensation expense associated with the performance share unit awards for the years ended December 31, 2017, 2016, and 2015 was $1.5 million, $2.7 million, and $2.6 million, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. The weighted average grant date fair value of performance share unit awards was $2.24 per share, $4.37 per share, and $9.51 per share for the years ended December 31, 2017, 2016, and 2015, respectively. Unrecognized expense as of December 31, 2017 for all outstanding performance share unit awards was $1.5 million and will be recognized over a weighted-average remaining period of 1.5 years. 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 stock price trading correlations of each entity with the other entities in the peer group. A stock price path has been simulated for the Company and the industry peer group 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 using 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 stock-based compensation expense during the periods presented: Performance Share Unit Awards 2017 2016 2015 Forecast period (years) Risk-free interest rate % % % Jones stock price volatility % % % The average historical combined volatilities for the Company and the peer group was 39.97%, 70.45%, and 55.13% for the awards made in 2017, 2016, and 2015, respectively. Based on these assumptions, the Monte Carlo simulation model resulted in an expected percentage of performance share units earned of 97.25%, 123.84%, and 101.61% for the 2017, 2016, and 2015 awards, respectively. Performance Unit Awards The Company has outstanding performance unit awards, granted initially in 2016, to certain members of the senior management team of the Company under the LTIP. References to performance unit awards in prior filings do not correspond to these newly created performance unit awards. Upon the completion of the applicable three-year performance period, each recipient may vest in a number of performance units. The value of awarded performance units in which each recipient vests at such time, if any, will range from $0.00 to $200.00 per performance unit based on the Company’s total shareholder return relative to an industry peer group over the applicable three-year performance period. For accounting purposes, the performance units are treated as a liability award with the liability being re-measured at the end of each reporting period. Therefore, the expense associated with these awards is subject to volatility until the payout is finally determined at the end of the performance period. The value of the performance units was determined at award using a Monte Carlo simulation model, as of the grant date, which resulted in an estimated final value upon vesting of $0.3 million and $1.1 million for the awards made in 2017 and 2016, respectively, as adjusted for forfeitures. The fair value measured as of December 31, 2017 was $0.1 million and $0.1 million for the awards made in 2017 and 2016, respectively. The following assumptions were used for the Monte Carlo model to determine the grant date fair value and associated stock-based compensation expense of the performance unit awards granted during the periods presented: Performance Unit Awards 2017 2016 Forecast period (years) Risk-free interest rate % % Jones stock price volatility % % For the performance units granted during the years ended December 31, 2017 and 2016, the Monte Carlo simulation model resulted in an expected payout of $28.25 per performance unit and $67.38 per performance unit as of the grant date. Stock compensation expense associated with the performance unit awards was an income position of $0.2 million and expense of $0.3 million for the years ended December 31, 2017 and 2016, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. As of December 31, 2017, $0.1 million of unrecognized compensation expense related to all the performance unit awards, subject to re-measurement and adjustment for the change in estimated final value as of the end of each reporting period, is expected to be recognized over the remaining weighted-average remaining period of 1.4 years. Restricted Stock Awards The Company has outstanding restricted stock awards granted to the non-employee members of the Board of Directors of the Company under the LTIP. The restricted stock will vest upon 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 price of the Company’s Class A common stock on the date of grant. The following table summarizes information related to the total value of the awards to the Board of Directors as of December 31, 2017: Weighted Average Restricted Grant Date Fair Value Stock Awards per Share Unvested at December 31, 2016 152,050 $ 3.68 Adjustment (1) 7,749 — Granted 180,000 2.25 Forfeited — — Vested (152,380) 3.67 Unvested at December 31, 2017 187,419 $ 2.16 (1) Increase of 0.002195 units for each unvested share of restricted stock at the time of the Company’s May 15, 2017 preferred stock dividend for the portion of such dividend paid in shares of the Company’s Class A common stock and of 0.021931 units for each unvested share of restricted stock at the time of the Company’s August 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock and of 0.018867 units for each unvested share of restricted stock at the time of the Company’s November 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock, as described in Note 12 “Stockholders’ and Mezzanine equity,” in accordance with the terms of the original awards. This increase is in addition to the adjustment for the effects of the Special Stock Dividend previously disclosed in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2017. Stock compensation expense associated with awards to the members of the Board of Directors for the years ended December 31, 2017, 2016 and 2015 was $0.4 million, $0.6 million, and $0.6 million, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. The weighted average grant date fair value of restricted stock awards was $2.25 per share, $3.68 per share, and $6.71 per share for the years ended December 31, 2017, 2016, and 2015. Unrecognized expense as of December 31, 2017 for all outstanding restricted stock awards was $0.2 million and will be recognized over the remaining vesting period of 0.4 years. For the years ended December 31, 2017, 2016, and 2015, the Company had an associated tax benefit of $1.6 million, $1.4 million, and $1.1 million, respectively, related to all stock-based compensation, calculated at the federal statutory rate after adjusting for the non-controlling interest.

Benefit Plans

Benefit Plans	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Benefit Plans	10. Benefit Plans The Company maintains a tax-qualified 401(k) 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 to the Plan. In addition, since 2013, the Company has maintained a non-qualified deferred compensation plan for the benefit of key employees. The non-qualified deferred compensation plan is an unfunded, account-based plan under which key employees of the Company may elect to defer a portion of their base salary and/or bonus. For the years ended December 31, 2017, 2016, and 2015, our total expense relating to these plans was $0.4 million, $0.4 million, and $0.5 million, respectively.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Income Taxes	11. Income Taxes The Company records federal and state income tax liabilities associated with its status as a corporation. The Company recognizes 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. On December 22, 2017, the US Congress enacted the Tax Reform Legislation, which made significant changes to US federal income tax law, including a reduction of the federal corporate tax rate to 21% effective January 1, 2018. We are required to recognize the effect of a rate change on deferred tax assets and liabilities in the period in which the tax rate change is enacted. Therefore, the rate change enacted by the Tax Reform Legislation resulted in the recognition of a tax benefit of $17.2 million along with a benefit from the reduction of the liability under the Tax Receivable Agreement of $59.5 million. The Tax Reform Legislation is a comprehensive bill containing other provisions, such as limitations on the deductibility of interest expense and certain executive compensation, that are not expected to materially affect us. The ultimate impact of Tax Reform Legislation may differ from our estimates due to changes in interpretations and assumptions made by us, as well as additional regulatory guidance that may be issued. The impact on our deferred tax assets and liabilities may be adjusted in future periods, as an adjustment to income tax expense or benefit, in the period in which the final amounts are determined. The following table summarizes the tax provision for the years ended December 31, 2017, 2016, and 2015: Year Ended December 31, (in thousands of dollars) 2017 2016 2015 Current tax expense (benefit): Federal $ (3,555) $ 3,758 $ — State (30) 223 113 Total current expense (benefit) (3,585) 3,981 113 Deferred tax expense (benefit): Federal (46,917) (27,245) (1,137) State (165) (522) (1,757) Total deferred expense (benefit) (47,082) (27,767) (2,894) Total tax expense (benefit) $ (50,667) $ (23,786) $ (2,781) Tax benefit attributable to controlling interests (50,422) (23,263) (1,160) Tax benefit attributable to non-controlling interests (245) (523) (1,621) Total income tax expense (benefit) $ (50,667) $ (23,786) $ (2,781) 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) 2017 2016 2015 Provision calculated at federal statutory income tax rate: Net income before taxes $ (229,490) $ (108,591) $ (11,858) Statutory rate (1) 35 % 35 % 35 % Income tax expense (benefit) computed at statutory rate $ (80,322) $ (38,007) $ (4,150) Less: Non-controlling interests 27,152 14,972 2,911 Income tax expense (benefit) attributable to controlling interests (53,170) (23,035) (1,239) State and local income taxes, net of federal benefit (4,692) (622) (1,011) IRC Section 382 limitation 41,653 — — Reduction of TRA liability — (282) (694) Equity compensation, shortfall — — 338 Change in enacted rate (1) (38,040) — (650) Change in valuation allowance 4,302 950 2,333 Other (475) (274) (237) Tax expense (benefit) attributable to controlling interests (50,422) (23,263) (1,160) Tax expense attributable to non-controlling interests (245) (523) (1,621) Total income tax expense (benefit) $ $ $ (1) Statutory rate will decrease to 21% for fiscal year 2018. The effect of the rate change on deferred tax assets and liabilities is recognized in the period in which the tax rate change is enacted, which also results in the reduction of the TRA liability. 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. In 2017, the United States enacted legislation that reduced the federal corporate tax rate from 35% to 21% for tax years beginning on or after January 1, 2018. The Company is required to recognize the effect of this rate change on its deferred tax assets and liabilities in the period the tax rate change is enacted. We recorded tax benefit of $17.2 million, net of valuation allowance, as a result of revaluing our deferred tax assets and liabilities at the newly enacted rate. The Company also recognized non-taxable income from the reduction of the liability under the Tax Receivable Agreement as a result of remeasuring the liability to reflect the revised federal statutory rate that had an impact on the effective rate of $20.8 million. In 2015, Texas enacted legislation that reduced the Texas franchise tax rate from 1.0% to 0.75%. We recorded a tax benefit of $1.7 million as a result of revaluing our deferred tax assets and liabilities at the newly enacted rate, of which $1.0 million was attributable to the non-controlling interest. 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) 2017 2016 Deferred tax assets Net operating loss $ 13,381 $ 8,687 Section 754 election tax basis adjustment 78,623 51,154 Other deferred tax asset 220 — Total deferred tax assets 92,224 59,841 Deferred tax liabilities Investment in consolidated subsidiary JEH 93,974 56,888 Noncurrent state deferred tax liability 2,281 2,703 Total deferred tax liabilities 96,255 59,591 Net deferred tax assets (liabilities) (4,031) 250 Valuation allowance (10,250) (3,155) Net deferred tax assets (liabilities) $ (14,281) $ (2,905) Internal Revenue Code ("IRC") Section 382 limits a corporation’s utilization of federal net operating loss carryforwards and certain other tax attributes on an annual basis following an ownership change of the corporation. The Company has a federal net operating loss carry-forward totaling $53.0 million and state net operating loss carry-forward of $47.4 million, after giving effect to an IRC Section 382 limitation. These federal and state net operating loss carryforwards expire between 2033 and 2037. Net operating losses generated in 2018 and future years will have an indefinite carryforward as a result of Tax Reform Legislation. The tax benefits of carryforwards are recorded as an asset to the extent that management assesses the utilization of such carryforwards to be more likely than not. When the future utilization of some portion of the carryforwards is determined not to be more likely than not, a valuation allowance is provided to reduce the recorded tax benefits from such assets. As of December 31, 2017 and 2016, we had a valuation allowance of $10.2 million and $3.2 million, respectively as a result of management’s assessment of the realizability of federal and state deferred tax assets. Management believes that there will be sufficient future taxable income based on the reversal of temporary differences to enable utilization of substantially all other tax carryforwards. The Company experienced ownership changes within the meaning of IRC Section 382 during 2017 and 2015 that subject a portion of its federal net operating loss carryforwards to IRC Section 382 limitations. The Company estimates that the IRC Section 382 limitation that applies to the Company’s 2017 ownership change will result in a permanent loss of federal and state deferred tax assets totaling $13.8 net operating loss carryforwards and other tax attributes, as measured at the 21% enacted rate and adjusted for the modified loss carryforward provisions of Tax Reform Legislation. The reduction in state net operating loss carryforwards is off-set by a corresponding $2.4 million adjustment to the valuation allowance. 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 2013 through 2016. The tax years 2014 through 2016 remain open to examination by the major taxing jurisdictions to which the Company is subject, however net operating losses originating in prior years are subject to examination when utilized. The Internal Revenue Service is currently examining the 2013 federal partnership income tax return for JEH, but has indicated that the audit will be concluded with no change. The Company’s other income tax returns have not been audited by the Internal Revenue Service 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, 2017, 2016 and 2015 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 In connection with the IPO, the Company entered into a Tax Receivable Agreement (the “TRA”) which obligates 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 shares of the Company’s Class B common stock held by those owners for shares of the Company’s Class A common stock. The Company will retain the benefit of the remaining 15% of these tax savings. At the time of an exchange, the company records a liability to reflect the future payments under the TRA. The TRA liability is recorded based upon the projected tax savings at the time of an exchange. As a result of the tax reform legislation, the amount of the TRA liability was remeasured to reflect the reduction of the federal corporate tax rate from 35% to 21%. We recorded a benefit for the reduction of the TRA liability of $59.5 million as a result of the newly enacted rate. The amount is included in other income (expense) on the Company’s Consolidated Statement of Operations. The actual amount and timing of payments to be 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. As of December 31, 2017 and December 31, 2016, the Company had a gross TRA liability of $69.9 million and $45.7 million, respectively. As a result of the valuation allowance recorded against its deferred tax assets associated with prior exchanges, the TRA liability was reduced, as the payment of the TRA liability is dependent upon the realizability of the associated deferred tax assets. As of December 31, 2017 and 2016, the amount of the TRA liability was reduced by $8.7 million, and $2.7 million, respectively, as a result of the valuation allowance recorded against the Company’s deferred tax assets. 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, 2017, and 2016 the Company had recorded a net TRA liability of $61.2 million and $43.0 million, respectively, for the estimated payments that will be made to the Class B shareholders who have exchanged shares, after adjusting for the TRA liability reduction. As of December 31, 2017, of the $61.2 million net TRA liability, $1.6 million was recorded within other current liabilities on the Company’s Consolidated Balance Sheet. As of December 31, 2017 and 2016 there were corresponding deferred tax assets, net of valuation allowance, of $72.3 million, and $50.6 million, respectively, as a result of the increase in tax basis generated arising from such exchanges. As of December 31, 2017, the Company had not made any payments under the TRA to Class B shareholders who have exchanged JEH units and Class B common stock for Class A common stock. The Company made a payment of $1.6 million of the TRA liability with respect to cash savings that the Company realized on its 2016 tax return as a result of tax attributes arising from prior exchanges in the first quarter of 2018. The Company does not anticipate it will realize cash savings on its 2017 tax return as a result of tax attributes arising from prior exchanges, and therefore does not anticipate a payment under the TRA for the 2017 tax year. Cash Tax Distributions The holders of JEH Units, including Jones Energy, Inc., incur U.S. federal, state and local income taxes on their share of any taxable income of JEH. Under the terms of its operating agreement, JEH is generally required to make quarterly pro-rata cash tax distributions to its unitholders (including us) based on income allocated to its unitholders through the end of each relevant quarter, as adjusted to take into account good faith projections by the Company of taxable income or loss for the remainder of the calendar year, to the extent JEH has cash available for such distributions and subject to certain other restrictions. A Special Committee of the Board of Directors comprised solely of directors who do not have a direct or indirect interest in such distribution approved, and JEH made, aggregate cash tax distributions during 2017 and 2016 of $1.7 million and $41.0 million, respectively, (including distributions to us) to its unitholders towards its total 2016 projected tax distribution obligation. Distributions during 2017 were made pro-rata to all members of JEH, and included a $1.1 million payment to the Company and a $0.6 million payment to JEH unitholders other than the Company. Distributions during 2016 were made pro-rata to all members of JEH, and included a $23.7 million payment to the Company and a $17.3 million payment to Class B shareholders. The 2016 tax distributions are the result of taxable income generated by JEH’s operations and debt extinguishment. All tax distributions were paid as a result of JEH’s 2016 taxable income.

Stockholders' and Mezzanine equ

Stockholders' and Mezzanine equity	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Stockholders’ and Mezzanine equity	12. Stockholders’ and Mezzanine equity Stockholders’ equity is comprised of 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 IPO and can be exchanged (together with a corresponding number of units representing membership interests in 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 holders to one vote on all matters to be voted on by the Company’s stockholders generally. The Company has classified the Series A preferred stock as mezzanine equity based upon the terms and conditions that contain various redemption and conversion features. For a description of these features, please see below under “—Offering of 8.0% Series A Perpetual Convertible Preferred Stock.” Equity Distribution Agreement On May 24, 2016, the Company and JEH entered into an Equity Distribution Agreement (“Equity Distribution Agreement”) with Citigroup Global Markets Inc. and Wells Fargo Securities, LLC (each, a “Manager” and collectively, the “Managers”). Pursuant to the terms of the Equity Distribution Agreement, the Company may sell from time to time through the Managers, as the Company’s sales agents, the Company’s Class A common stock having an aggregate offering price of up to $73.0 million (the “Class A Shares”). Under the terms of the Equity Distribution Agreement, the Company may also sell Class A Shares from time to time to any Manager as principal for its own account at a price to be agreed upon at the time of sale. Any sale of Class A Shares to a Manager as principal would be pursuant to the terms of a separate terms agreement between the Company and such Manager. Sales of the Class A Shares, if any, will be made by means of ordinary brokers’ transactions, to or through a market maker or directly on or through an electronic communication network, a “dark pool” or any similar market venue, or as otherwise agreed by the Company and one or more of the Managers. During the year ended December 31, 2017, the Company sold approximately 3.7 million Class A Shares under the Equity Distribution Agreement for net proceeds of approximately $8.4 million ($8.7 million gross proceeds, net of approximately $0.3 million in commissions and professional services expenses). The Company used the net proceeds for general corporate purposes. As of December 31, 2017, approximately $62.2 million in aggregate offering proceeds remained available to be issued and sold under the Equity Distribution Agreement. Offering of Class A Common Stock On August 26, 2016, the Company issued 21,000,000 shares of Class A common stock pursuant to an underwritten public offering, and on September 12, 2016 the Company issued an additional 3,150,000 shares of Class A common stock in connection with the exercise of the underwriters’ over-allotment option. The total net proceeds (after underwriters’ discounts and commissions, but before estimated expenses) of the offering, including the exercise of the over-allotment option, was $64.0 million. Offering of 8.0% Series A Perpetual Convertible Preferred Stock On August 26, 2016, the Company issued 1,840,000 shares of Series A preferred stock pursuant to an underwritten public offering for total net proceeds (after underwriters’ discounts and commissions but before expenses) of $88.3 million. Holders of Series A preferred stock are entitled to receive, when as and if declared by the Company’s Board of Directors, cumulative dividends at the rate of 8.0% per annum (the “dividend rate”) per share on the $50.00 liquidation preference per share of the Series A Preferred Stock, payable quarterly in arrears on February 15, May 15, August 15 and November 15 of each year, beginning on November 15, 2016. Dividends may be paid in cash or, subject to certain limitations, in Class A common stock, or a combination thereof. Under the terms of the Series A preferred stock, the Company’s ability to declare or pay dividends or make distributions on, or purchase, redeem or otherwise acquire for consideration, shares of the Company’s Class A common stock, or any junior stock or parity stock currently outstanding or issued in the future, will be subject to certain restrictions in the event that the Company does not pay in full or declare and set aside for payment in full all accrued and unpaid dividends on the Series A preferred stock (including certain unpaid excess cash payment amounts excused from payment as a dividend due to restrictions in credit facilities or other indebtedness or legal requirements (“Unpaid Excess Cash Payment Amounts”)). Each share of Series A preferred stock has a liquidation preference of $50.00 per share and is convertible, at the holder’s option at any time, into approximately 17.0683 shares of Class A common stock after adjusting the conversion ratio for the effects of the Special Stock Dividend, as defined in Note 12, “Stockholders’ and Mezzanine equity”, (which is equivalent to a conversion price of approximately $2.93 per share after adjusting for the effects of the Special Stock Dividend), subject to specified further adjustments and limitations as set forth in the certificate of designations for the Series A preferred stock. Based on the adjusted conversion rate and the full exercise of the Preferred Stock Underwriters’ over-allotment option, approximately 31.4 million shares of Class A common stock would be issuable upon conversion of all the Series A preferred stock. On or after August 15, 2021, the Company may, at its option, give notice of its election to cause all outstanding shares of Series A preferred stock to be automatically converted into shares of Class A common stock at the conversion rate, if the closing sale price of the Class A common stock equals or exceeds 175% of the conversion price for at least 20 trading days in a period of 30 consecutive trading days. On August 15, 2024 (the “designated redemption date”), each holder of Series A preferred stock may require us to redeem any or all Series A preferred stock held by such holder outstanding on the designated redemption date at a redemption price equal to a liquidation preference of $50.00 per share plus all accrued dividends on the shares up to but excluding the designated redemption date that have not been paid plus any Unpaid Excess Cash Payment Amounts (the “redemption price”). At our option, the redemption price may be paid in cash or, subject to certain limitations, in Class A common stock, or a combination thereof. Except as required by law or the Company’s certificate of incorporation, which includes the certificate of designations for the Series A preferred stock, the holders of Series A preferred stock have no voting rights (other than with respect to certain matters regarding the Series A preferred stock or when dividends payable on the Series A preferred stock have not been paid for an aggregate of six quarterly dividend periods, or more, whether or not consecutive, as provided in the certificate of designations for the Series A preferred stock). The Series A preferred stock is classified as mezzanine equity on the Company’s Consolidated Balance Sheet and is not listed on a national stock exchange. A summary of the Company’s Mezzanine equity for the year ended December 31, 2017 is as follows: (in thousands of dollars) Mezzanine equity at December 31, 2016 $ 88,975 Dividends on preferred stock, net — Accretion on preferred stock 564 Mezzanine equity at December 31, 2017 $ 89,539 Preferred Stock Dividends On January 19, 2017, the Company’s Board of Directors declared a quarterly cash dividend per share equal to 8.0% based on the liquidation preference of $50.00 per share on an annualized basis, or $1.00 per share, on the Series A preferred stock. This dividend is for the period beginning on the last payment date of November 15, 2016 through February 14, 2017 and was paid in cash on February 15, 2017 to shareholders of record as of February 1, 2017. On April 17, 2017, the Company’s Board of Directors declared a quarterly dividend per share equal to 8.0% based on the liquidation preference of $50.00 per share on an annualized basis, or $1.00 per share, on the Series A preferred stock. On May 15, 2017, the dividend was paid in a combination of cash and the Company’s Class A common stock, with the cash component equal to $0.83 per share and the stock component equal to $0.17 per share. The price per share of the Class A common stock used to determine the number of shares issued was equal to 95% of the average volume-weighted average price per share for each day during the five-consecutive day trading period ending immediately prior to the payment date. This dividend was for the period beginning on the last payment date of February 15, 2017 through May 14, 2017 to shareholders of record as of May 1, 2017. On July 13, 2017, the Company’s Board of Directors declared a quarterly dividend per share equal to 8.0% based on the liquidation preference of $50.00 per share on an annualized basis, or $1.00 per share, on the Series A preferred stock. On August 15, 2017, the dividend was paid entirely in shares of Class A common stock. The price per share of the Class A common stock used to determine the number of shares issued was equal to 95% of the average volume-weighted average price per share for each day during the five-consecutive day trading period ending immediately prior to the payment date. This dividend was for the period beginning on the last payment date of May 15, 2017 through August 14, 2017 to shareholders of record as of August 1, 2017. On October 9, 2017, the Company’s Board of Directors declared a quarterly dividend per share equal to 8.0% based on the liquidation preference of $50.00 per share on an annualized basis, or $1.00 per share, on the Series A preferred stock. On November 15, 2017, the dividend was paid entirely in shares of Class A common stock. The price per share of the Class A common stock used to determine the number of shares issued will equal 95% of the average volume-weighted average price per share for each day during the five-consecutive day trading period ending immediately prior to the payment date. This dividend was for the period beginning on the last payment date of August 15, 2017 through November 14, 2017 to shareholders of record as of November 1, 2017 Special Stock Dividend On March 31, 2017, the Company paid a stock dividend (the “Special Stock Dividend”) of 0.087423 shares of the Class A common stock to holders of record as of March 15, 2017. From time-to-time, JEH makes cash distributions to the holders of JEH Units to cover tax obligations that may occur as a result of any net taxable income of JEH allocable to holders of JEH Units. As a holder of JEH Units, the Company has received such cash distributions from JEH in excess of the amount required to satisfy the Company’s associated tax obligations. As a result, the Company used the excess cash of approximately $17.5 million in the aggregate to acquire newly-issued JEH Units from JEH. The Special Stock Dividend was distributed in order to equalize the number of shares of Class A common stock outstanding to the number of JEH Units held by the Company, and the aggregate number of shares of Class A common stock issued in the Special Stock Dividend equaled the number of additional JEH Units the Company purchased from JEH. The Company purchased 4,999,927 JEH Units at a price of $3.50 per share, which is the volume weighted average price per share of the Class A common stock for the five trading days ended February 28, 2017. Immaterial cash payments were made in lieu of fractional shares. The comparative earnings per share information has been recast to retrospectively adjust for the effects of the Special Stock Dividend.

Earnings per Share

Earnings per Share	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Earnings per Share	13. 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 the Series A preferred stock and from stock awards that have been granted to directors and employees. Awards of non-vested shares are considered outstanding as of the respective grant dates for purposes of computing diluted EPS even though the award is contingent upon vesting. For the year ended December 31, 2017, 2,762,738 restricted stock units, and 1,250,822 performance share units, and 31,405,587 shares from the convertible Class A preferred stock were excluded from the calculation as they would have had an anti-dilutive effect. For the year ended December 31, 2016, 1,359,088 restricted stock units, and 1,125,706 performance share units, and 31,405,762 shares from the convertible Class A preferred stock were excluded from the calculation as they would have had an anti-dilutive effect. For the year ended December 31, 2015, 823,446 restricted stock units, and 586,325 performance share 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: Earnings per Share Year Ended December 31, (in thousands, except per share data) 2017 2016 2015 Income (numerator): Net income (loss) attributable to controlling interests $ (101,492) $ (42,552) $ (2,381) Less: Dividends and accretion on preferred stock (7,924) (2,669) — Net income (loss) attributable to common shareholder $ (109,416) $ (45,221) $ (2,381) Weighted-average shares (denominator): (1) Weighted-average number of shares of Class A common stock - basic 72,411 43,506 29,161 Weighted-average number of shares of Class A common stock - diluted 72,411 43,506 29,161 Earnings (loss) per share: (1) Basic - Net income (loss) attributable to common shareholders $ (1.51) $ (1.04) $ (0.08) Diluted - Net income (loss) attributable to common shareholders $ (1.51) $ (1.04) $ (0.08) (1) All share and earnings per share information presented has been recast to retrospectively adjust for the effects of the 0.087423 per share Special Stock Dividend, as defined in Note 12, “Stockholders’ and Mezzanine equity”, distributed on March 31, 2017.

Related Parties

Related Parties	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Related Parties	14. Related Parties Related Party Transactions Transactions with Our Executive Officers, Directors and 5% Stockholders Monarch Natural Gas Holdings, LLC Natural Gas Sale and Purchase Agreement 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, from the properties that became subject to the Monarch agreement. During the year ended December 31, 2014, the Company recognized $37.0 million of revenue associated with the aforementioned natural gas and NGL production. Effective May 1, 2015, the rights to gather natural gas under the sale and purchase agreement transferred from Monarch to Enable Midstream Partners LP, (“Enable”), an unaffiliated third-party. Prior to closing of the transfer of these rights, the Company produced approximately 1.0 MMBoe of natural gas and NGLs for the year ended December 31, 2015 from the properties that became subject to the Monarch agreement for which the Company recognized $10.6 million of revenue. The revenue, for all years mentioned, is recorded in Oil and gas sales on the Company’s Consolidated Statement of Operations. The initial term of the agreement, which remains unchanged by the transfer to Enable, runs for 10 years from the effective date of September 1, 2013. At the time the Company entered into the 2013 Monarch 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 former directors, Howard I. Hoffen and Gregory D. Myers, are managing directors of Metalmark Capital and were directors at the time the Company entered into the 2013 Monarch agreement. In connection with the Company’s entering into the 2013 Monarch agreement, Monarch issued to JEH equity interests in Monarch, having an estimated fair value of $15.0 million, in return for marketing services to be provided throughout the term of the agreement. The Company recorded this amount as deferred revenue which is being amortized on an estimated units-of-production basis commencing in September 2013, the first month of product sales to Monarch. During the years ended December 31, 2017, 2016 and 2015, the Company amortized $1.9 million, $2.4 million, and $2.0 million, respectively, of the deferred revenue balance. This revenue is recorded in Other revenues on the Company’s Consolidated Statement of Operations. Following the issuance of $15.0 million Monarch equity interests to JEH, JEH assigned $2.4 million of the equity interests to Jonny Jones, the Company’s chief executive officer and chairman of the Board of Directors, and reserved $2.6 million of the equity interests for future distribution through an incentive plan to certain of the Company’s officers, including Mike McConnell and Robert Brooks. The remaining $10.0 million of Monarch equity interests was distributed to certain of the Class B shareholders, which included, among others, Metalmark Capital, the Jones family entities, and certain of the Company’s officers and directors, including Jonny Jones and Mike McConnell. As of December 31, 2017, equity interests in Monarch of $0.4 million are included in Other assets on the Company’s Consolidated Balance Sheet. During the years ended December 31, 2017, 2016 and 2015, equity interests of $0.3 million, $0.6 million, and $0.8 million, respectively, were distributed to management under the incentive plan. The Company recognized expense of $0.4 million, $0.5 million, and $0.5 million during the years ended December 31, 2017, 2016 and 2015, respectively, in connection with the incentive plan. 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 built, at its expense, a new oil gathering system and connected the gathering system 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 began service during the fourth quarter of 2015 and provides connectivity to both a regional refinery market as well as the Cushing market hub. The Company incurred gathering fees, which were paid to Monarch Oil Pipeline LLC, of $2.3 million, $2.7 million and $0.4 million associated with the approximately 1.1 MMBoe, 1.3 MMBoe and 0.2 MMBoe of oil production transported under the agreement for the years ended December 31, 2017, 2016 and 2015, respectively. These costs are recorded as an offset to Oil and gas sales in the Company’s Consolidated Statement of Operations. The aforementioned production was recognized as Oil and gas sales on the Company’s Consolidated Statement of Operations at the time it was sold to the purchasers, who are unaffiliated third-parties, after passing through the gathering and transportation system. The audit committee of the Board of Directors reviewed and approved the terms of the agreement with Monarch Oil Pipeline LLC. In May 2015, the Company received a $0.7 million cash distribution associated with its equity interests in Monarch, which was accounted for following the cost method. The initial cash distribution from Monarch was treated as dividend income and is recorded in Other income (expense). Purchases of Senior Unsecured Notes On February 29, 2016, JEH and Jones Energy Finance Corp. purchased $50.0 million principal amount of their outstanding 2023 Notes from investment funds managed by Magnetar Capital and its affiliates, which investment funds collectively then owned more than 5% of a class of voting securities of the Company, for approximately $23.3 million excluding accrued interest and including any associated fees. On the same day, JEH and Jones Energy Finance Corp. purchased an additional $50.0 million principal amount of their outstanding 2023 Notes from investment funds managed by Blackstone Group Management L.L.C. and its affiliates, which investment funds collectively then owned more than 5% of a class of voting securities of the Company, for approximately $23.3 million excluding accrued interest and including any associated fees. In conjunction with the extinguishment of this $100.0 million principal amount of debt, JEH recognized cancellation of debt income of $48.3 million on a pre-tax basis. This income is recorded in Gain on debt extinguishment on the Company’s Consolidated Statement of Operations. Issuance of Class A Shares In connection with the August 2016 issuance of Class A common stock pursuant to an underwritten public offering as described in Note 12, “Stockholders’ and Mezzanine equity—Offering of Class A Common Stock,” affiliates of JVL Advisors, L.L.C. (“JVL”), who then owned more than 5% of a class of voting securities of the Company, purchased 9,025,270 shares of Class A common stock, prior to adjustment for the effects of the 0.087423 per share Special Stock Dividend, as defined in Note 12, “Stockholders’ and Mezzanine equity”, in the offering, for gross proceeds to the Company of $25.0 million, before underwriting discounts and commissions of $1.1 million. Following its purchase in the offering, JVL owned in excess of 15% of our outstanding voting stock. As a result, the Company entered into a letter agreement with JVL (the “JVL Letter Agreement”) in connection with the offering. The JVL Letter Agreement approved, pursuant to Section 203 of the Delaware General Corporation Law (“Section 203”), the purchase of shares of Class A common stock in the offering by JVL. This approval resulted in JVL not being subject to the restrictions on “business combinations” contained in Section 203. In consideration of such approval, JVL agreed that, among other things: · it will not acquire any material assets of the Company; · it will not become the owner of more than 19.9% of the Company’s outstanding voting stock (other than as a result of actions taken solely by the Company) without the prior approval of the Company’s independent directors who are not affiliated with JVL; and · it will not engage in any “business combination” (as defined in the JVL Letter Agreement). On May 3, 2017, the Company amended and restated its registration rights agreement dated August 29, 2013 (as amended and restated, the “Restated Registration Rights Agreement”) to add JVL as a party in order to facilitate an orderly distribution of JVL’s shares of Class A common stock in the future, a copy of which was filed on the Company’s Current Report on Form 8-K filed with the Securities and Exchange Commission on May 3, 2017. Issuance of Series A Preferred Stock In connection with the August 2016 issuance of Series A preferred stock pursuant to an underwritten public offering as described in Note 12, “Stockholders’ and Mezzanine equity—Offering of 8.0% Series A Perpetual Convertible Preferred Stock,” affiliates of Metalmark, who then owned more than 5% of a class of voting securities of the Company and had two representatives on our Board of Directors, purchased 200,000 shares of Series A preferred stock in the offering, for gross proceeds to the Company of $10.0 million, before underwriting discounts and commissions of $400,000. Amended and Restated Registration Rights and Stockholders Agreement On May 2, 2017, we entered into an Amended and Restated Registration Rights and Stockholders Agreement (the “Restated Agreement”) with certain entities affiliated with the Jones family (the “Jones Family Entities”), Metalmark and JVL. The Restated Agreement amends and restates in its entirety that certain Registration Rights and Stockholders Agreement, dated July 29, 2013 (the “Original Agreement”), by and among the Company, Metalmark and the Jones Family Entities, to, among other things, provide JVL with certain rights, in addition to those rights granted to Metalmark and the Jones Family Entities in the Original Agreement, to require the Company to register the sale of any number of JVL’s shares of Class A common stock. JVL shall have the right to cause no more than one such required or “demand” registration, which shall be requested by a majority in interest of the JVL holders who hold certain equity securities of the Company or securities convertible or exchangeable into equity securities of the Company. The Company is not obligated to affect any demand registration in which the anticipated aggregate offering price included in such offering is equal to or less than $50,000,000 ($25,000,000 where the registration is on a Form S-3). Furthermore, if, at any time, the Company proposes to register an offering of Class A common stock (subject to certain exceptions) for the Company’s own account, then it must give prompt notice to Metalmark, JVL and the Jones Family Entities to allow them to include a specified number of their shares in that registration statement. These registration rights are subject to certain conditions and limitations, including the right of the underwriters to limit the number of shares to be included in a registration and the Company’s right to delay or withdraw a registration statement under certain circumstances. The Company will generally be obligated to pay all registration expenses in connection with the registration obligations, regardless of whether a registration statement is filed or becomes effective. The Restated Agreement also includes customary provisions dealing with indemnification, contribution and allocation of expenses.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Commitments and Contingencies	15. Commitments and Contingencies Lease obligations The Company leases approximately 43,000 square feet of office space in Austin, TX under an operating lease arrangement. We also lease approximately 9,000 square feet of office space in Oklahoma City, Oklahoma. Future minimum payments for all noncancellable operating leases extending beyond one year at December 31, 2017 are as follows: (in thousands of dollars) Years Ending December 31, 2018 $ 1,300 2019 1,311 2020 562 2021 — 2022 — Thereafter — $ 3,173 Rent expense under operating leases was $1.8 million, $1.6 million, and $1.6 million for the years ended December 31, 2017, 2016 and 2015, respectively. Litigation The Company is subject to legal proceedings and claims that arise in the ordinary course of its business. When applicable, we record accruals for contingencies when it is probable that a liability will be incurred and the amount of loss can be reasonably estimated. While the outcome of lawsuits and other proceedings against us cannot be predicted with certainty, in the opinion of management, individually or in the aggregate, no such lawsuits are expected to have a material effect on our financial position, results of operations, or liquidity. In an action filed on June 12, 2015 in the 31 st District Court of Hemphill County, Texas, Donna Kim Flowers and Mitchell Kirk Flowers v. Jones Energy, LLC f/k/a Jones Energy Limited, LLC f/k/a Jones Energy, Ltd. (Case No. 7225), the Company was sued by Donna Kim Flowers and Mitchell Kirk Flowers (the “plaintiffs”). The plaintiffs own surface rights to property located in Hemphill County, Texas. The mineral rights are leased to third parties, and the Company is the operator of the Oil and Gas Mineral Lease. On May 28, 2010, the plaintiffs and the Company entered into a Surface Use Agreement concerning the Company’s operations on the property, which require the Company to minimize disruption and damage to the plaintiffs’ surface rights. The plaintiffs allege that the Company is in breach of such contract, and seek monetary damages. In June 2016, the Company presented a settlement offer to the plaintiffs. As a result of this settlement offer, the Company accrued $1.5 million related to its estimated obligation under this settlement offer. This accrual was included in accrued liabilities on the Company’s Consolidated Balance Sheet as of December 31, 2016, and the charge was recorded as general and administrative expense on the Company’s Consolidated Statement of Operations during the second quarter of 2016. In June 2017, the Company presented a revised settlement offer to the plaintiffs and the plaintiff accepted. The settlement was paid in cash during June 2017. Upon settlement, the Company recognized an additional charge of $1.4 million which was recorded as general and administrative expense on the Company’s Consolidated Statement of Operations during the second quarter of 2017.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Subsequent Events	16. Subsequent Events Preferred Stock Dividend Declared On January 11, 2018, the Company’s Board of Directors declared a quarterly dividend per share equal to 8.0% based on the liquidation preference of $50.00 per share on an annualized basis, or $1.00 per share, on the Series A preferred stock, to be paid entirely in shares of Class A common stock (the “February Preferred Dividend”). The price per share of the Class A common stock used to determine the number of shares issued will equal to 95% of the average volume-weighted average price per share for each day during the five-consecutive day trading period ending immediately prior to the payment date. The February Preferred Dividend will be paid on February 15, 2018 for the period beginning on the last payment date of November 15, 2017 through February 14, 2018 to shareholders of record as of February 1, 2018. Senior Secured First Lien Notes due 2023 On February 14, 2018, JEH and Jones Energy Finance Corp. issued the 2023 First Lien Notes at an offering price equal to 97.526% of par in an offering exempt from registration under the Securities Act. The 2023 First Lien Notes are senior secured first lien obligations of JEH and Jones Energy Finance Corp. and are guaranteed on a senior secured first lien basis by the Company and each of the existing and future restricted subsidiaries of JEH and Jones Energy Finance Corp. The Company used the net proceeds from the offering to repay all but $25.0 million of the outstanding borrowings under the Revolver, to fund drilling and completion activities, and for other general corporate purposes. An affiliate of Q Investments, LP, one of our principal stockholders and an affiliate of Scott McCarty, one of our directors, purchased $45.0 million of 2023 First Lien Notes in the offering. Amendment of Revolving Credit Facility In connection with the offering of the 2023 First Lien Notes JEH amended the Revolver to, among other things, (i) permit the issuance of the 2023 First Lien Notes and additional senior secured notes in an aggregate principal amount, together with the notes issued pursuant to this offering, not to exceed $700.0 million, (ii) permit the incurrence of liens securing the 2023 First Lien Notes pursuant to the terms of a collateral trust agreement, (iii) reduce the borrowing base under the Revolver to $50.0 million and (iv) suspend testing of our senior secured leverage ratio until March 31, 2019. Continued efforts to sell non-core asset We continue to seek opportunities to reduce leverage through non-core asset sales. However, we have no assurance that we will be successful in closing any such divestitures.

Subsidiary Guarantors

Subsidiary Guarantors	12 Months Ended
	Dec. 31, 2017
Disclosure Text Block
Subsidiary Guarantors	17. Subsidiary Guarantors The 2022 Notes and the 2023 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 Revolver. Each subsidiary guarantor is 100% owned by JEH, and all guarantees are full and unconditional, subject to customary exceptions pursuant to the indentures governing our 2022 Notes and 2023 Notes, as discussed below, 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 immaterial. As of December 31, 2016, the 2022 Notes and the 2023 Notes were guaranteed on a senior unsecured basis by the Company and by all of its significant subsidiaries, other than Nosley SCOOP, LLC and Nosley Acquisition, LLC. These subsidiaries have since become guarantors during the first quarter of 2017 and are therefore presented accordingly in the accompanying condensed consolidated guarantor financial information. Guarantees of the 2022 Notes and 2023 Notes will be released under certain circumstances, including (i) in connection with any sale or other disposition of (a) all or substantially all of the properties or assets of a guarantor (including by way of merger or consolidation) or (b) all of the capital stock of such guarantor, in each case, to a person that is not the Company or a restricted subsidiary of the Company, (ii) if the Company designates any restricted subsidiary that is a guarantor as an unrestricted subsidiary, (iii) upon legal defeasance, covenant defeasance or satisfaction and discharge of the applicable indenture, or (iv) at such time as such guarantor ceases to guarantee any other indebtedness of the Company or any other guarantor. The Company is a holding company whose sole material asset is an equity interest in JEH. 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. During the preparation of the condensed consolidating financial information of Jones Energy, Inc. and Subsidiaries in the second quarter of 2017, it was determined that the Issuer Investment in subsidiaries and the related Eliminations at December 31, 2016 as filed in the Company’s 2016 Form 10-K were improperly calculated and understated by $453.2 million. Additionally, it was determined that the Guarantor Subsidiaries Intercompany payable balances and the related Eliminations and the Issuer Intercompany receivable and the related Eliminations at December 31, 2016 as filed in the Company’s 2016 Form 10-K were improperly calculated and overstated by $453.2 million and $80.0 million, respectively. In addition, it was determined that the Issuer Equity interest in income (loss) and the related Eliminations for the year ended December 31, 2016 as filed in the Company’s 2016 Form 10-K were improperly calculated and understated by $42.6 million. It was also determined that the Issuer Adjustments to reconcile net income (loss) to net cash provided by operating activities and the related Eliminations for the year ended December 31, 2016 as filed in the Company’s 2016 Form 10-K were improperly calculated and overstated by $42.6 million. In addition, it was determined that the Issuer Equity interest in income (loss) and the related Eliminations for the year ended December 31, 2015 as filed in the Company’s 2015 Form 10-K were improperly calculated and understated by $9.1 million. Lastly, it was determined that the Issuer Adjustments to reconcile net income (loss) to net cash provided by operating activities and the related Eliminations for the year ended December 31, 2015 as filed in the Company’s 2015 Form 10-K were improperly calculated and overstated by $9.1 million. The errors, which the Company has determined are not material to this disclosure, had no impact on the total assets of the Parent or the Guarantor Subsidiaries and are eliminated upon consolidation, and therefore have no impact on the Company’s consolidated financial condition, results of operations or cash flows. The Company has revised the Condensed Consolidating Balance Sheets for the Issuer, Guarantor Subsidiaries and Eliminations as of December 31, 2016, the Condensed Consolidating Income Statements for the Issuer and Eliminations for the years ended December 31, 2016 and 2015 and the Condensed Consolidating Statement of Cash Flows for the years ended December 31, 2016 and 2015 to correct for these errors. Jones Energy, Inc. Condensed Consolidating Balance Sheet December 31, 2017 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Assets Current assets Cash $ 5,248 $ 1,180 $ 13,024 $ 20 $ — $ 19,472 Accounts receivable, net Oil and gas sales — — 34,492 — — 34,492 Joint interest owners — — 31,651 — — 31,651 Other — — 1,236 — — 1,236 Commodity derivative assets — 3,474 — — — 3,474 Other current assets 1,866 358 12,152 — — 14,376 Intercompany receivable 383,849 1,146,647 — — (1,530,496) — Total current assets 390,963 1,151,659 92,555 20 (1,530,496) 104,701 Oil and gas properties, net, at cost under the successful efforts method — — 1,597,040 — — 1,597,040 Other property, plant and equipment, net — — 2,192 527 — 2,719 Commodity derivative assets — 172 — — — 172 Other assets — 4,427 1,004 — — 5,431 Investment in subsidiaries 242,617 116,349 — — (358,966) — Total assets $ 633,580 $ 1,272,607 $ 1,692,791 $ 547 $ (1,889,462) $ 1,710,063 Liabilities and Stockholders’ Equity Current liabilities Trade accounts payable $ 138 $ 247 $ 72,278 $ — $ — $ 72,663 Oil and gas sales payable — — 31,462 — — 31,462 Accrued liabilities 62 11,363 10,172 7 — 21,604 Commodity derivative liabilities — 36,709 — — — 36,709 Other current liabilities 1,606 1,723 720 — — 4,049 Intercompany payable — — 1,527,418 3,078 (1,530,496) — Total current liabilities 1,806 50,042 1,642,050 3,085 (1,530,496) 166,487 Long-term debt — 759,316 — — — 759,316 Deferred revenue — 5,457 — — — 5,457 Commodity derivative liabilities — 8,788 — — — 8,788 Asset retirement obligations — — 19,652 — — 19,652 Liability under tax receivable agreement 59,596 — — — — 59,596 Other liabilities — 68 743 — — 811 Deferred tax liabilities 12,852 1,429 — — — 14,281 Total liabilities 74,254 825,100 1,662,445 3,085 (1,530,496) 1,034,388 Mezzanine equity Series A preferred stock, $0.001 par value; 1,839,995 shares issued and outstanding at December 31, 2017 89,539 — — — — 89,539 Stockholders’/ members' equity (deficit) Members' equity — 447,507 30,346 (2,538) (475,315) — Class A common stock, $0.001 par value; 90,139,840 shares issued and 90,117,238 shares outstanding at December 31, 2017 90 — — — — 90 Class B common stock, $0.001 par value; 9,627,821 shares issued and outstanding at December 31, 2017 10 — — — — 10 Treasury stock, at cost: 22,602 shares at December 31, 2017 (358) — — — — (358) Additional paid-in-capital 606,319 — — — — 606,319 Retained earnings (deficit) (136,274) — — — — (136,274) Stockholders' equity (deficit) 469,787 447,507 30,346 (2,538) (475,315) 469,787 Non-controlling interest — — — — 116,349 116,349 Total stockholders’ equity 469,787 447,507 30,346 (2,538) (358,966) 586,136 Total liabilities and stockholders’ equity $ 633,580 $ 1,272,607 $ 1,692,791 $ 547 $ (1,889,462) $ 1,710,063 Jones Energy, Inc. Condensed Consolidating Balance Sheet December 31, 2016 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Assets Current assets Cash $ 27,164 $ 1,975 $ 5,483 $ 20 $ — $ 34,642 Accounts receivable, net Oil and gas sales — — 26,568 — — 26,568 Joint interest owners — — 5,267 — — 5,267 Other — 5,434 627 — — 6,061 Commodity derivative assets — 24,100 — — — 24,100 Other current assets — 422 2,262 — — 2,684 Intercompany receivable 15,666 1,100,834 — — (1,116,500) — Total current assets 42,830 1,132,765 40,207 20 (1,116,500) 99,322 Oil and gas properties, net, at cost under the successful efforts method — — 1,743,588 — — 1,743,588 Other property, plant and equipment, net — — 2,378 618 — 2,996 Commodity derivative assets — 34,744 — — — 34,744 Other assets — 5,265 785 — — 6,050 Investment in subsidiaries 531,363 453,237 — — (984,600) — Total assets $ 574,193 $ 1,626,011 $ 1,786,958 $ 638 $ (2,101,100) $ 1,886,700 Liabilities and Stockholders’ Equity Current liabilities Trade accounts payable $ — $ 13 $ 36,514 $ — $ — $ 36,527 Oil and gas sales payable — — 28,339 — — 28,339 Accrued liabilities 3,874 11,227 10,597 9 — 25,707 Commodity derivative liabilities — 14,650 — — — 14,650 Other current liabilities — 1,984 600 — — 2,584 Intercompany payable — — 1,113,704 2,796 (1,116,500) — Total current liabilities 3,874 27,874 1,189,754 2,805 (1,116,500) 107,807 Long-term debt — 724,009 — — — 724,009 Deferred revenue — 7,049 — — — 7,049 Commodity derivative liabilities — 1,209 — — — 1,209 Asset retirement obligations — — 19,458 — — 19,458 Liability under tax receivable agreement 43,045 — — — — 43,045 Other liabilities — 269 523 — — 792 Deferred tax liabilities 85 2,820 — — — 2,905 Total liabilities 47,004 763,230 1,209,735 2,805 (1,116,500) 906,274 Mezzanine equity Series A preferred stock, $0.001 par value; 1,840,000 shares issued and outstanding at December 31, 2016 88,975 — — — — 88,975 Stockholders’/ members' equity (deficit) Members' equity — 862,781 577,223 (2,167) (1,437,837) — Class A common stock, $0.001 par value; 57,048,076 shares issued and 57,025,474 shares outstanding at December 31, 2016 57 — — — — 57 Class B common stock, $0.001 par value; 29,832,098 shares issued and outstanding at December 31, 2016 30 — — — — 30 Treasury stock, at cost: 22,602 shares at December 31, 2016 (358) — — — — (358) Additional paid-in-capital 447,137 — — — — 447,137 Retained earnings (deficit) (8,652) — — — — (8,652) Stockholders' equity (deficit) 438,214 862,781 577,223 (2,167) (1,437,837) 438,214 Non-controlling interest — — — — 453,237 453,237 Total stockholders’ equity 438,214 862,781 577,223 (2,167) (984,600) 891,451 Total liabilities and stockholders’ equity $ 574,193 $ 1,626,011 $ 1,786,958 $ 638 $ (2,101,100) $ 1,886,700 Jones Energy, Inc. Condensed Consolidating Statement of Operations Year Ended December 31, 2017 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Operating revenues Oil and gas sales $ — $ — $ 186,393 $ — $ — $ 186,393 Other revenues — 1,854 326 — — 2,180 Total operating revenues — 1,854 186,719 — — 188,573 Operating costs and expenses Lease operating — — 36,636 — — 36,636 Production and ad valorem taxes — — 6,874 — — 6,874 Exploration — — 14,145 — — 14,145 Depletion, depreciation and amortization — — 167,133 91 — 167,224 Impairment of oil and gas properties — — 149,648 — — 149,648 Accretion of ARO liability — — 960 — — 960 General and administrative 237 10,146 19,226 283 — 29,892 Total operating expenses 237 10,146 394,622 374 — 405,379 Operating income (loss) (237) (8,292) (207,903) (374) — (216,806) Other income (expense) Interest expense — (52,016) 365 — — (51,651) Net gain (loss) on commodity derivatives — (17,985) — — — (17,985) Other income (expense) 59,492 (93) (2,447) — — 56,952 Other income (expense), net 59,492 (70,094) (2,082) — — (12,684) Income (loss) before income tax 59,255 (78,386) (209,985) (374) — (229,490) Equity interest in income (loss) (211,217) (77,527) — — 288,744 — Income tax provision (benefit) (50,470) (197) — — — (50,667) Net income (loss) (101,492) (155,716) (209,985) (374) 288,744 (178,823) Net income (loss) attributable to non-controlling interests — — — — (77,331) (77,331) Net income (loss) attributable to controlling interests $ (101,492) $ (155,716) $ (209,985) $ (374) $ 366,075 $ (101,492) Dividends and accretion on preferred stock (7,924) — — — — (7,924) Net income (loss) attributable to common shareholders $ (109,416) $ (155,716) $ (209,985) $ (374) $ 366,075 $ (109,416) Jones Energy, Inc. Condensed Consolidating Statement of Operations Year Ended December 31, 2016 Guarantor Non‑Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Operating revenues Oil and gas sales $ — $ — $ 124,877 $ — $ — $ 124,877 Other revenues — 2,384 586 — — 2,970 Total operating revenues — 2,384 125,463 — — 127,847 Operating costs and expenses Lease operating — — 32,640 — — 32,640 Production and ad valorem taxes — — 7,768 — — 7,768 Exploration — — 6,673 — — 6,673 Depletion, depreciation and amortization — — 153,843 87 — 153,930 Accretion of ARO liability — — 1,263 — — 1,263 General and administrative — 12,028 17,244 368 — 29,640 Other operating — 199 — 199 Total operating expenses — 12,028 219,630 455 — 232,113 Operating income (loss) — (9,644) (94,167) (455) — (104,266) Other income (expense) Interest expense — (53,080) (47) — — (53,127) Gain on debt extinguishment — 99,530 — — — 99,530 Net gain (loss) on commodity derivatives — (51,264) — — — (51,264) Other income (expense) 784 (321) 73 — — 536 Other income (expense), net 784 (5,135) 26 — — (4,325) Income (loss) before income tax 784 (14,779) (94,141) (455) — (108,591) Equity interest in income (loss) (66,804) (42,571) — — 109,375 — Income tax provision (benefit) (23,468) (318) — — — (23,786) Net income (loss) (42,552) (57,032) (94,141) (455) 109,375 (84,805) Net income (loss) attributable to non-controlling interests — — — — (42,253) (42,253) Net income (loss) attributable to controlling interests $ (42,552) $ (57,032) $ (94,141) $ (455) $ 151,628 $ (42,552) Dividends and accretion on preferred stock (2,669) — — — — (2,669) Net income (loss) attributable to common shareholders $ (45,221) $ (57,032) $ (94,141) $ (455) $ 151,628 $ (45,221) Jones Energy, Inc. Condensed Consolidating Statement of Operations Year Ended December 31, 2015 Guarantor Non‑Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Operating revenues Oil and gas sales $ — $ — $ 194,555 $ — $ — $ 194,555 Other revenues — 1,960 884 — — 2,844 Total operating revenues — 1,960 195,439 — — 197,399 Operating costs and expenses Lease operating — — 41,027 — — 41,027 Production and ad valorem taxes — — 12,130 — — 12,130 Exploration — — 6,551 — — 6,551 Depletion, depreciation and amortization — — 205,407 91 — 205,498 Accretion of ARO liability — — 1,087 — — 1,087 General and administrative — 13,565 19,707 116 — 33,388 Other operating — — 4,188 — — 4,188 Total operating expenses — 13,565 290,097 207 — 303,869 Operating income (loss) — (11,605) (94,658) (207) — (106,470) Other income (expense) Interest expense — (63,160) (1,298) — — (64,458) Net gain (loss) on commodity derivatives — 158,753 — — — 158,753 Other income (expense) 1,984 (1,663) (4) — — 317 Other income (expense), net 1,984 93,930 (1,302) — — 94,612 Income (loss) before income tax 1,984 82,325 (95,960) (207) — (11,858) Equity interest in income (loss) (4,728) (9,114) — — 13,842 — Income tax provision (benefit) (363) (2,418) — — — (2,781) Net income (loss) (2,381) 75,629 (95,960) (207) 13,842 (9,077) Net income (loss) attributable to non-controlling interests — — — — (6,696) (6,696) Net income (loss) attributable to controlling interests $ (2,381) $ 75,629 $ (95,960) $ (207) $ 20,538 $ (2,381) Dividends and accretion on preferred stock — — — — — — Net income (loss) attributable to common shareholders $ (2,381) $ 75,629 $ (95,960) $ (207) $ 20,538 $ (2,381) Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2017 Non- Guarantor Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ (101,492) $ (155,716) $ (209,985) $ (374) $ 288,744 $ (178,823) Adjustments to reconcile net income (loss) to net cash provided by operating activities 73,536 52,870 399,795 374 (288,744) 237,831 Net cash (used in) / provided by operations (27,956) (102,846) 189,810 — — 59,008 Cash flows from investing activities Additions to oil and gas properties — — (245,364) — — (245,364) Net adjustments to purchase price of properties acquired — — 2,391 — — 2,391 Proceeds from sales of assets — — 61,290 — — 61,290 Acquisition of other property, plant and equipment — — (586) — — (586) Current period settlements of matured derivative contracts — 72,265 — — — 72,265 Net cash (used in) / provided by investing — 72,265 (182,269) — — (110,004) Cash flows from financing activities Proceeds from issuance of long-term debt — 162,000 — — — 162,000 Repayment of long-term debt — (129,000) — — — (129,000) Payment of debt issuance costs — (1,115) — — — (1,115) Payment of cash dividends on preferred stock (3,368) — — — — (3,368) Net distributions paid to JEH unitholders 1,075 (1,637) — — — (562) Net payments for share based compensation — (462) — — — (462) Proceeds from sale of common stock 8,333 — — — — 8,333 Net cash (used in) / provided by financing 6,040 29,786 — — — 35,826 Net increase (decrease) in cash (21,916) (795) 7,541 — — (15,170) Cash Beginning of period 27,164 1,975 5,483 20 — 34,642 End of period $ 5,248 $ 1,180 $ 13,024 $ 20 $ — $ 19,472 Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2016 Non- Guarantor Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ (42,552) $ (57,032) $ (94,141) $ (455) $ 109,375 $ (84,805) Adjustments to reconcile net income (loss) to net cash provided by operating activities (105,877) (28,124) 353,426 455 (109,375) 110,505 Net cash (used in) / provided by operations (148,429) (85,156) 259,285 — — 25,700 Cash flows from investing activities Additions to oil and gas properties — — (264,462) — — (264,462) Proceeds from sales of assets — — 1,645 — — 1,645 Acquisition of other property, plant and equipment — — (310) — — (310) Current period settlements of matured derivative contracts — 132,265 — — — 132,265 Net cash (used in) / provided by investing — 132,265 (263,127) — — (130,862) Cash flows from financing activities Proceeds from issuance of long-term debt — 130,000 — — — 130,000 Repayment under long-term debt — (62,000) — — — (62,000) Purchase of senior notes — (84,589) — — — (84,589) Payment of dividends on preferred stock (1,615) — — — — (1,615) Net distributions paid to JEH unitholders 23,674 (40,993) — — — (17,319) Proceeds from sale of common stock 65,446 — — — — 65,446 Proceeds from sale of preferred stock 87,988 — — — — 87,988 Net cash (used in) / provided by financing 175,493 (57,582) — — — 117,911 Net increase (decrease) in cash 27,064 (10,473) (3,842) — — 12,749 Cash Beginning of period 100 12,448 9,325 20 — 21,893 End of period $ 27,164 $ 1,975 $ 5,483 $ 20 $ — $ 34,642 Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2015 Non- Guarantor Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ (2,381) $ 75,629 $ (95,960) $ (207) $ 13,842 $ (9,077) Adjustments to reconcile net income (loss) to net cash provided by operating activities (120,398) (193,245) 405,214 197 (13,842) 77,926 Net cash (used in) / provided by operations (122,779) (117,616) 309,254 (10) — 68,849 Cash flows from investing activities Additions to oil and gas properties — — (311,305) — — (311,305) Proceeds from sales of assets — — 41 — — 41 Acquisition of other property, plant and equipment — — (1,101) — — (1,101) Current period settlements of matured derivative contracts — 144,145 — — — 144,145 Net cash (used in) / provided by investing — 144,145 (312,365) — — (168,220) Cash flows from financing activities Proceeds from issuance of long-term debt — 85,000 — — — 85,000 Repayment under long-term debt — (335,000) — — — (335,000) Proceeds from senior notes — 236,475 — — — 236,475 Payment of debt issuance costs — (1,556) — — — (1,556) Proceeds from sale of common stock 122,779 — — — — 122,779 Net cash (used in) / provided by financing 122,779 (15,081) — — — 107,698 Net increase (decrease) in cash — 11,448 (3,111) (10) — 8,327 Cash Beginning of period 100 1,000 12,436 30 — 13,566 End of period $ 100 $ 12,448 $ 9,325 $ 20 $ — $ 21,893

Significant Accounting Polici25

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
Policy Text Blocks
Basis of Presentation	Basis of Presentation The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and in accordance with the rules and regulations of the Securities and Exchange Commission. All significant intercompany transactions and balances have been eliminated in consolidation. The Company’s financial position as of December 31, 2017 and 2016 and the financial statements reported for each of the three years in the period ended December 31, 2017 include the Company and all of its subsidiaries Certain prior period amounts have been reclassified to conform to the current presentation.
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 and unproved 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”).
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 it does business with, 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, 2017 and at December 31, 2016 of derivative positions not settled as of the balance sheet date. 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, 2017 and 2016, 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, 2017, 71% of Accounts receivable—Oil and gas sales were due from three purchasers and 59% of Accounts receivable‑Joint interest owners were due from five working interest owners. As of December 31, 2016, 77% of Accounts receivable—Oil and gas sales were due from four purchasers and 48% of Accounts receivable‑Joint interest owners were due from five working interest owners. As of December 31, 2015, 68% of Accounts receivable—Oil and gas sales are due from four purchasers and 80% of Accounts receivable—Joint interest owners are due from five 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, 2017, the largest purchasers of our production were Plains Marketing LP (“Plains Marketing”) and ETC Field Services LLC, which accounted for approximately 40% and 22% of consolidated oil and gas sales, respectively. During the year ended December 31, 2016, the largest purchasers of our production were Plains Marketing LP (“Plains Marketing”) and ETC Field Services LLC, which accounted for approximately 37% and 24% of consolidated oil and gas sales, respectively. During the year ended December 31, 2015, the largest purchasers of our production were Valero Energy Corp. (“Valero”), ETC Field Services LLC, Plains Marketing LP, and NGL Energy Partners LP, which accounted for approximately 18%, 17%, 16%, 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. 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. 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. 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 the life of 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. 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. 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 commodity prices, lease expiration dates, results of any drilling and geo science activity during the period, and known information regarding exploration and development activity by other companies on adjacent blocks. 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 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.
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.
Accrued Liabilities	Accrued Liabilities Accrued liabilities consisted of the following at December 31, 2017 and 2016: December 31, December 31, (in thousands of dollars) 2017 2016 Accrued interest $ 12,109 $ 13,531 Other accrued liabilities 9,495 12,176 Total accrued liabilities $ 21,604 $ 25,707
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, 2017, 2016 and 2015, 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 7, “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.
Revenue Recognition	Revenue Recognition Revenues from the sale of crude oil, natural gas, and natural gas liquids are valued at the estimated sales price and 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. The Company had no significant imbalances as of December 31, 2017, 2016, and 2015.
Income Taxes	Income Taxes The Company records a federal and state income tax liability associated with its status as a corporation. The Company recognizes a tax liability on its share of pre-tax book income, exclusive of the non-controlling interest. 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. On December 22, 2017, the US Congress enacted the Tax Cuts and Jobs Act (Tax Reform Legislation), which made significant changes to US federal income tax law affecting us. See Note 11. “Income Taxes.” 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 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.
Comprehensive Income	Comprehensive Income The Company has no elements of comprehensive income other than net income.
Recent Accounting Pronouncements	Recent Accounting Pronouncements Adopted in the current year: In March 2016, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2016-09, “Compensation—Stock Compensation” (Topic 718). This amendment is intended to simplify the accounting for share-based payment awards to employees, specifically in regard to (1) the income tax consequences, (2) classification of awards as either equity or liabilities, and (3) classification on the statement of cash flows. The amendments are effective for interim and annual reporting periods beginning after December 15, 2016. Therefore, the Company has adopted ASU 2016-09 effective as of January 1, 2017. Upon adoption of ASU 2016-09, the Company elected to change its accounting policy to account for forfeitures as they occur. The change was applied on a modified retrospective basis with a cumulative effect adjustment to retained earnings for forfeitures of $0.7 million as of January 1, 2017. As a result of the valuation allowance against the Company’s deferred tax assets, there was no net adjustment to retained earnings for the change in accounting for unrecognized windfall tax benefits. In May 2017, the FASB issued ASU 2017-09, “Scope of Modification Accounting” as it relates to “Compensation—Stock Compensation” (Topic 718). This amendment clarifies when changes to the terms or conditions of a share-based payment award must be accounted for as modifications. The new guidance is expected to reduce diversity in practice and result in fewer changes to the terms of an award being accounted for as modifications. Under ASU 2017-09, an entity will not apply modification accounting to a share-based payment award if the award’s fair value, vesting conditions and classification as an equity or liability instrument are the same immediately before and after the change. The amendments are effective for interim and annual reporting periods beginning after December 15, 2017. Early adoption is permitted and the Company chose to early adopt ASU 2017-09 beginning April 1, 2017. The change was applied prospectively to awards modified on or after the adoption date. Adoption did not have a material impact on the financial position, cash flows or results of operations. To be adopted in a future period: In May 2014, the FASB issued ASU 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 standard 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. In August 2015, the FASB issued ASU 2015-14, which deferred the effective date of ASU 2014-09 by one year. The amendments are now effective for interim and annual reporting periods beginning after December 15, 2017 and may be applied on either a full or modified retrospective basis. Early adoption is permitted. During 2017, the Company performed a comparison of our current revenue recognition policies in effect through December 31, 2017 to the new requirements upon adoption of ASU 2014-09 and ASU 2015-14 for each of our revenue categories based upon review of our current contracts by product category and homogenous groupings. Upon completion of the assessment, the analysis of these homogenous groupings did not indicate any material change to our current revenue recognition methodology, although we do expect some changes in presentation of gross revenues and expenses upon adoption of the standard; such costs are currently offset against revenues. The Company adopted ASU 2014-09 and ASU 2015-14 effective as of January 1, 2018 applied on a modified retrospective basis, which did not result in a material cumulative effect adjustment as of the date of adoption. Adoption did not have a material impact on the financial position, cash flows or results of operations. In addition to changes in the presentation of the Company’s Consolidated Statement of Operations, we expect to expand disclosures related to revenue recognition. The Company will continue to further evaluate the effect that the adoption of ASU 2014-09 and ASU 2015-14 will have on our disclosures as we prepare for our first quarter 2018 Form 10-Q filing. In February 2016, the FASB issued ASU 2016-02, “Leases” (Topic 842). This amendment requires, among other things, that lessees recognize the following for all leases (with the exception of short-term leases) at the commencement date: (1) a lease liability, which is a lessee’s obligation to make lease payments arising from a lease, measured on a discounted basis; and (2) a right-of-use asset, which is an asset that represents the lessee’s right to use, or control the use of, a specified asset for the lease term. Lessees and lessors must apply a modified retrospective transition approach for leases existing at, or entered into after, the beginning of the earliest comparative period presented in the financial statements. The amendments are effective for interim and annual reporting periods beginning after December 15, 2018. Early adoption is permitted. The Company is currently evaluating the impacts of the amendments to our financial statements and accounting practices for leases. We anticipate adoption of ASU 2016-02 effective as of January 1, 2019. In January 2017, the FASB issued ASU 2017-01, “Business Combinations” (Topic 805). The amendments under this ASU provide guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (disposals) or business combinations by providing a screen to determine when an integrated set of assets and activities is not a business. The screen requires that when substantially all of the fair value of the gross assets acquired (or disposed of) is concentrated in a single identifiable asset or a group of similar identifiable assets, the set is not a business, therefore reducing the number of transactions that need to be further evaluated for treatment as a business combination. This new guidance is effective for annual periods beginning after December 15, 2017. Early adoption is permitted. The Company adopted ASU 2017-01 effective as of January 1, 2018 applied prospectively, which did not have a material impact on our financial statements; however these amendments could result in the recording of fewer business combinations in future periods. In August 2017, the FASB issued ASU 2017-12, “Derivatives and Hedging” (Topic 815). The amendments in this update apply to any entity that elects to apply hedge accounting in accordance with current GAAP. This standard expands an entity’s ability to apply hedge accounting for nonfinancial and financial risk components and allows for a simplified approach for fair value hedging of interest rate risk. The standard also eliminates the need to separately measure and report hedge ineffectiveness and generally requires the entire change in fair value of a hedging instrument to be presented in the same income statement line as the hedged item. Additionally, the standard simplifies the hedge documentation and effectiveness assessment requirements under the previous guidance. The amendments are effective for interim and annual reporting periods beginning after December 15, 2018. Early adoption is permitted. Historically, the Company has elected not to designate any of its commodity price risk management activities as cash flow or fair value hedges. After concluding our assessment of the amendments in this update, Management has determined we will continue not to designate any of our commodity price risk management activities as cash flow or fair value hedges. Therefore, adoption is not expected to have a material impact on the financial position, cash flows or results of operations. We anticipate adoption of ASU 2017-12 effective as of January 1, 2019.

Significant Accounting Polici26

Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Schedule of accrued liabilities	December 31, December 31, (in thousands of dollars) 2017 2016 Accrued interest $ 12,109 $ 13,531 Other accrued liabilities 9,495 12,176 Total accrued liabilities $ 21,604 $ 25,707

Properties, Plant and Equipme27

Properties, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Schedule of oil and gas properties	December 31, December 31, (in thousands of dollars) 2017 2016 Mineral interests in properties Unproved $ 164,087 $ 213,153 Proved 893,246 1,054,683 Wells and equipment and related facilities 1,434,383 1,395,291 2,491,716 2,663,127 Less: Accumulated depletion and impairment (894,676) (919,539) Net oil and gas properties $ 1,597,040 $ 1,743,588
Schedule of other property, plant and equipment	December 31, December 31, (in thousands of dollars) 2017 2016 Leasehold improvements $ 1,186 $ 1,213 Furniture, fixtures, computers and software 4,410 4,170 Vehicles 1,922 1,677 Aircraft 910 910 Other 210 284 8,638 8,254 Less: Accumulated depreciation and amortization (5,919) (5,258) Net other property, plant and equipment $ 2,719 $ 2,996

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Summary of long-term debt	(in thousands of dollars) December 31, 2017 December 31, 2016 Revolver $ 211,000 $ 178,000 2022 Notes 409,148 409,148 2023 Notes 150,000 150,000 Total principal amount 770,148 737,148 Less: unamortized discount (5,228) (6,240) Less: debt issuance costs, net (5,604) (6,899) Total carrying amount $ 759,316 $ 724,009

Derivative Instruments and He29

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Schedule of various commodity derivatives in place to offset uncertain price fluctuations that could affect the entity's future operations	December 31, 2017 Weighted Final Low High Average Expiration Oil swaps Exercise price $ 49.70 $ 54.18 $ 50.64 December 2020 Net barrels per month 55,000 216,000 112,333 Natural gas swaps Exercise price $ 2.76 $ 3.10 $ 2.89 December 2020 Net MMbtu per month 700,000 1,890,000 1,118,889 Natural gas liquids swaps Exercise price $ 22.89 $ 45.26 $ 29.79 December 2018 Barrels per month 130,000 145,000 138,750 Natural gas basis swaps Exercise price $ (0.50) $ (0.30) $ (0.41) October 2018 Net MMbtu per month 800,000 800,000 800,000 Oil collars Puts (floors) $ 45.00 $ 50.00 $ 48.52 December 2019 Calls (ceilings) $ 56.60 $ 61.00 $ 59.64 Net barrels per month 65,000 73,000 67,500 Natural gas collars Puts (floors) $ 2.55 $ 2.55 $ 2.55 December 2019 Calls (ceilings) $ 3.08 $ 3.41 $ 3.19 Net barrels per month 950,000 1,050,000 990,833
Schedule of commodity derivative contracts that are netted on Consolidated Balance Sheet	Net Amounts Gross of Assets / Gross Amounts Gross Amounts Amounts Liabilities Not of Recognized Offset in the Presented in Offset in the Assets / Balance the Balance Balance (in thousands of dollars) Liabilities Sheet Sheet Sheet Net Amount December 31, 2017 Commodity derivative contracts Assets $ 8,572 $ (4,926) $ 3,646 $ — $ 3,646 Liabilities (50,423) 4,926 (45,497) — (45,497) December 31, 2016 Commodity derivative contracts Assets $ 79,649 $ (20,805) $ 58,844 $ — $ 58,844 Liabilities (36,664) 20,805 (15,859) — (15,859)

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Schedule of financial instruments carried at fair value	(in thousands of dollars) December 31, 2017 Fair Value Measurements Using Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ 3,474 $ — $ 3,474 Long-term assets — 56 116 172 Current liabilities — 28,946 7,763 36,709 Long-term liabilities — 7,860 928 8,788 (in thousands of dollars) December 31, 2016 Fair Value Measurements Using Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ 24,100 $ — $ 24,100 Long-term assets (1) — 36,384 (1,640) 34,744 Current liabilities — 13,636 1,014 14,650 Long-term liabilities — 892 317 1,209 (1) Level 3 long-term assets are negative as a result of the netting of our commodity derivatives reflected on our Consolidated Balance Sheet as of December 31, 2016. Our agreements include set-off provisions, as noted in Note 6, “Derivative Instruments and Hedging Activities - Offsetting Assets and Liabilities”.
Schedule of quantitative information about Level 3 inputs used in the fair value measurement, assets	Quantitative Information About Level 3 Fair Value Measurements Fair Value Unobservable Commodity Price Hedges (000’s) Valuation Technique Input Range Natural gas liquid swaps $ (7,763) Use a discounted cash flow approach using inputs including forward price statements from counterparties Natural gas liquid futures $27.93 - $44.00 per barrel Crude oil collars $ (654) Use a discounted option model approach using inputs including interpolated volatilities for certain settlement months where market volatility quotes were unavailable for the option strike price Market volatility quotes at the option strike for certain settlement months in 2019 $45.00 - $61.00 per barrel Natural gas collars $ (158) Use a discounted option model approach using inputs including interpolated volatilities for certain settlement months where market volatility quotes were unavailable for the option strike price Market volatility quotes at the option strike for certain settlement months in 2019 $2.55 - $3.41 per barrel
Schedule of changes in fair value of Level 3 financial instruments	(in thousands of dollars) Balance at December 31, 2015, net $ 1,428 Purchases (5,208) Settlements (171) Transfers to Level 2 — Transfers to Level 3 2,363 Changes in fair value (1,383) Balance at December 31, 2016, net $ (2,971) Purchases (1,236) Settlements 1,606 Transfers to Level 2 — Transfers to Level 3 (6,527) Changes in fair value 553 Balance at December 31, 2017, net $ (8,575)
Schedule of fair value of financial instruments that are not recorded at fair value in the consolidated financial statements	December 31, 2017 December 31, 2016 Principal Principal (in thousands of dollars) Amount Fair Value Amount Fair Value Debt: Revolver $ 211,000 $ 211,000 $ 178,000 $ 178,000 2022 Notes 409,148 305,404 409,148 393,150 2023 Notes 150,000 114,750 150,000 153,375

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Summary of the Company's ARO	(in thousands of dollars) 2017 2016 ARO liability at beginning of year $ 20,058 $ 20,980 Liabilities incurred (1) 1,062 6,947 Accretion of ARO liability 960 1,263 Liabilities settled due to sale of related properties (1,231) (446) Liabilities settled due to plugging and abandonment (339) (463) Change in estimate (2) (138) (8,223) ARO liability at end of year 20,372 20,058 Less: Current portion of ARO at end of year (720) (600) Total long-term ARO at end of year $ 19,652 $ 19,458 (1) The 2016 amount includes $6.4 million related to wells acquired in the Anadarko Acquisition. See Note 3, “Acquisitions and Divestitures—Anadarko Acquisition”. (2) The 2016 amount reflects a reduction in the estimated cost per well, consistent with the decline in actual costs experienced by the Company.

Stock-based Compensation (Table

Stock-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2017
Management Unit Awards
Table Text Blocks
Summary of information related to the units/shares or awards	Weighted Average Grant Date Fair Value JEH Units per Share Unvested at December 31, 2016 90,762 $ 15.00 Granted 13,066 15.00 Forfeited (13,066) 15.00 Vested (58,447) 15.00 Unvested at December 31, 2017 32,315 $ 15.00
Restricted Stock Unit Awards
Table Text Blocks
Summary of information related to the units/shares or awards	Restricted Weighted Average Stock Unit Grant Date Fair Value Awards per Share Unvested at December 31, 2016 1,359,142 $ 5.60 Adjustment (1) 130,871 — Granted 2,394,290 2.32 Forfeited (543,803) 3.00 Vested (577,729) 6.62 Unvested at December 31, 2017 2,762,771 $ 2.79 (1) Increase of 0.002195 units for each unvested restricted stock unit awards at the time of the Company’s May 15, 2017 preferred stock dividend for the portion of such dividend paid in shares of the Company’s Class A common stock and of 0.021931 units for each unvested restricted stock unit award at the time of the Company’s August 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock and of 0.018867 units for each unvested restricted stock unit award at the time of the Company’s November 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock, as described in Note 12 “Stockholders’ and Mezzanine equity,” in accordance with the terms of the original awards. This increase is in addition to the adjustment for the effects of the Special Stock Dividend previously disclosed in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2017.
Performance Share Unit Awards
Table Text Blocks
Summary of information related to the units/shares or awards	Performance Weighted Average Share Unit Grant Date Fair Value Awards per Share Unvested at December 31, 2016 942,073 $ 6.25 Adjustment (1) 63,712 — Granted 519,562 2.24 Forfeited (274,524) 5.29 Vested (293,645) 8.22 Unvested at December 31, 2017 957,178 $ 4.64 (1) Increase of 0.002195 units for each unvested performance share unit awards at the time of the Company’s May 15, 2017 preferred stock dividend for the portion of such dividend paid in shares of the Company’s Class A common stock and of 0.021931 units for each unvested performance share unit award at the time of the Company’s August 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock and of 0.018867 units for each unvested performance share unit award at the time of the Company’s November 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock, as described in Note 12 “Stockholders’ and Mezzanine equity,” in accordance with the terms of the original awards. This increase is in addition to the adjustment for the effects of the Special Stock Dividend previously disclosed in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2017.
Schedule of assumptions used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense	Performance Share Unit Awards 2017 2016 2015 Forecast period (years) Risk-free interest rate % % % Jones stock price volatility % % %
Performance Unit Awards
Table Text Blocks
Schedule of assumptions used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense	Performance Unit Awards 2017 2016 Forecast period (years) Risk-free interest rate % % Jones stock price volatility % %
Restricted Stock Awards
Table Text Blocks
Summary of information related to the units/shares or awards	Weighted Average Restricted Grant Date Fair Value Stock Awards per Share Unvested at December 31, 2016 152,050 $ 3.68 Adjustment (1) 7,749 — Granted 180,000 2.25 Forfeited — — Vested (152,380) 3.67 Unvested at December 31, 2017 187,419 $ 2.16 (1) Increase of 0.002195 units for each unvested share of restricted stock at the time of the Company’s May 15, 2017 preferred stock dividend for the portion of such dividend paid in shares of the Company’s Class A common stock and of 0.021931 units for each unvested share of restricted stock at the time of the Company’s August 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock and of 0.018867 units for each unvested share of restricted stock at the time of the Company’s November 15, 2017 preferred stock dividend paid entirely in shares of the Company’s Class A common stock, as described in Note 12 “Stockholders’ and Mezzanine equity,” in accordance with the terms of the original awards. This increase is in addition to the adjustment for the effects of the Special Stock Dividend previously disclosed in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2017.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Schedule of income tax provision	Year Ended December 31, (in thousands of dollars) 2017 2016 2015 Current tax expense (benefit): Federal $ (3,555) $ 3,758 $ — State (30) 223 113 Total current expense (benefit) (3,585) 3,981 113 Deferred tax expense (benefit): Federal (46,917) (27,245) (1,137) State (165) (522) (1,757) Total deferred expense (benefit) (47,082) (27,767) (2,894) Total tax expense (benefit) $ (50,667) $ (23,786) $ (2,781) Tax benefit attributable to controlling interests (50,422) (23,263) (1,160) Tax benefit attributable to non-controlling interests (245) (523) (1,621) Total income tax expense (benefit) $ (50,667) $ (23,786) $ (2,781)
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) 2017 2016 2015 Provision calculated at federal statutory income tax rate: Net income before taxes $ (229,490) $ (108,591) $ (11,858) Statutory rate (1) 35 % 35 % 35 % Income tax expense (benefit) computed at statutory rate $ (80,322) $ (38,007) $ (4,150) Less: Non-controlling interests 27,152 14,972 2,911 Income tax expense (benefit) attributable to controlling interests (53,170) (23,035) (1,239) State and local income taxes, net of federal benefit (4,692) (622) (1,011) IRC Section 382 limitation 41,653 — — Reduction of TRA liability — (282) (694) Equity compensation, shortfall — — 338 Change in enacted rate (1) (38,040) — (650) Change in valuation allowance 4,302 950 2,333 Other (475) (274) (237) Tax expense (benefit) attributable to controlling interests (50,422) (23,263) (1,160) Tax expense attributable to non-controlling interests (245) (523) (1,621) Total income tax expense (benefit) $ $ $ (1) Statutory rate will decrease to 21% for fiscal year 2018. The effect of the rate change on deferred tax assets and liabilities is recognized in the period in which the tax rate change is enacted, which also results in the reduction of the TRA liability.
Schedule of components of the Company's deferred tax assets and deferred tax liabilities	As of December 31, (in thousands of dollars) 2017 2016 Deferred tax assets Net operating loss $ 13,381 $ 8,687 Section 754 election tax basis adjustment 78,623 51,154 Other deferred tax asset 220 — Total deferred tax assets 92,224 59,841 Deferred tax liabilities Investment in consolidated subsidiary JEH 93,974 56,888 Noncurrent state deferred tax liability 2,281 2,703 Total deferred tax liabilities 96,255 59,591 Net deferred tax assets (liabilities) (4,031) 250 Valuation allowance (10,250) (3,155) Net deferred tax assets (liabilities) $ (14,281) $ (2,905)

Stockholders' and Mezzanine e34

Stockholders' and Mezzanine equity (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Schedule of Mezzanine equity	(in thousands of dollars) Mezzanine equity at December 31, 2016 $ 88,975 Dividends on preferred stock, net — Accretion on preferred stock 564 Mezzanine equity at December 31, 2017 $ 89,539

Earnings per Share (Tables)

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Schedule of calculation of the basic and diluted weighted-average shares and EPS	Year Ended December 31, (in thousands, except per share data) 2017 2016 2015 Income (numerator): Net income (loss) attributable to controlling interests $ (101,492) $ (42,552) $ (2,381) Less: Dividends and accretion on preferred stock (7,924) (2,669) — Net income (loss) attributable to common shareholder $ (109,416) $ (45,221) $ (2,381) Weighted-average shares (denominator): (1) Weighted-average number of shares of Class A common stock - basic 72,411 43,506 29,161 Weighted-average number of shares of Class A common stock - diluted 72,411 43,506 29,161 Earnings (loss) per share: (1) Basic - Net income (loss) attributable to common shareholders $ (1.51) $ (1.04) $ (0.08) Diluted - Net income (loss) attributable to common shareholders $ (1.51) $ (1.04) $ (0.08) (1) All share and earnings per share information presented has been recast to retrospectively adjust for the effects of the 0.087423 per share Special Stock Dividend, as defined in Note 12, “Stockholders’ and Mezzanine equity”, distributed on March 31, 2017.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Schedule of future minimum payments for noncancellable operating leases extending beyond one year	(in thousands of dollars) Years Ending December 31, 2018 $ 1,300 2019 1,311 2020 562 2021 — 2022 — Thereafter — $ 3,173

Subsidiary Guarantors (Tables)

Subsidiary Guarantors (Tables)	12 Months Ended
	Dec. 31, 2017
Table Text Blocks
Condensed Consolidating Balance Sheet	Condensed Consolidating Balance Sheet December 31, 2017 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Assets Current assets Cash $ 5,248 $ 1,180 $ 13,024 $ 20 $ — $ 19,472 Accounts receivable, net Oil and gas sales — — 34,492 — — 34,492 Joint interest owners — — 31,651 — — 31,651 Other — — 1,236 — — 1,236 Commodity derivative assets — 3,474 — — — 3,474 Other current assets 1,866 358 12,152 — — 14,376 Intercompany receivable 383,849 1,146,647 — — (1,530,496) — Total current assets 390,963 1,151,659 92,555 20 (1,530,496) 104,701 Oil and gas properties, net, at cost under the successful efforts method — — 1,597,040 — — 1,597,040 Other property, plant and equipment, net — — 2,192 527 — 2,719 Commodity derivative assets — 172 — — — 172 Other assets — 4,427 1,004 — — 5,431 Investment in subsidiaries 242,617 116,349 — — (358,966) — Total assets $ 633,580 $ 1,272,607 $ 1,692,791 $ 547 $ (1,889,462) $ 1,710,063 Liabilities and Stockholders’ Equity Current liabilities Trade accounts payable $ 138 $ 247 $ 72,278 $ — $ — $ 72,663 Oil and gas sales payable — — 31,462 — — 31,462 Accrued liabilities 62 11,363 10,172 7 — 21,604 Commodity derivative liabilities — 36,709 — — — 36,709 Other current liabilities 1,606 1,723 720 — — 4,049 Intercompany payable — — 1,527,418 3,078 (1,530,496) — Total current liabilities 1,806 50,042 1,642,050 3,085 (1,530,496) 166,487 Long-term debt — 759,316 — — — 759,316 Deferred revenue — 5,457 — — — 5,457 Commodity derivative liabilities — 8,788 — — — 8,788 Asset retirement obligations — — 19,652 — — 19,652 Liability under tax receivable agreement 59,596 — — — — 59,596 Other liabilities — 68 743 — — 811 Deferred tax liabilities 12,852 1,429 — — — 14,281 Total liabilities 74,254 825,100 1,662,445 3,085 (1,530,496) 1,034,388 Mezzanine equity Series A preferred stock, $0.001 par value; 1,839,995 shares issued and outstanding at December 31, 2017 89,539 — — — — 89,539 Stockholders’/ members' equity (deficit) Members' equity — 447,507 30,346 (2,538) (475,315) — Class A common stock, $0.001 par value; 90,139,840 shares issued and 90,117,238 shares outstanding at December 31, 2017 90 — — — — 90 Class B common stock, $0.001 par value; 9,627,821 shares issued and outstanding at December 31, 2017 10 — — — — 10 Treasury stock, at cost: 22,602 shares at December 31, 2017 (358) — — — — (358) Additional paid-in-capital 606,319 — — — — 606,319 Retained earnings (deficit) (136,274) — — — — (136,274) Stockholders' equity (deficit) 469,787 447,507 30,346 (2,538) (475,315) 469,787 Non-controlling interest — — — — 116,349 116,349 Total stockholders’ equity 469,787 447,507 30,346 (2,538) (358,966) 586,136 Total liabilities and stockholders’ equity $ 633,580 $ 1,272,607 $ 1,692,791 $ 547 $ (1,889,462) $ 1,710,063 Jones Energy, Inc. Condensed Consolidating Balance Sheet December 31, 2016 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Assets Current assets Cash $ 27,164 $ 1,975 $ 5,483 $ 20 $ — $ 34,642 Accounts receivable, net Oil and gas sales — — 26,568 — — 26,568 Joint interest owners — — 5,267 — — 5,267 Other — 5,434 627 — — 6,061 Commodity derivative assets — 24,100 — — — 24,100 Other current assets — 422 2,262 — — 2,684 Intercompany receivable 15,666 1,100,834 — — (1,116,500) — Total current assets 42,830 1,132,765 40,207 20 (1,116,500) 99,322 Oil and gas properties, net, at cost under the successful efforts method — — 1,743,588 — — 1,743,588 Other property, plant and equipment, net — — 2,378 618 — 2,996 Commodity derivative assets — 34,744 — — — 34,744 Other assets — 5,265 785 — — 6,050 Investment in subsidiaries 531,363 453,237 — — (984,600) — Total assets $ 574,193 $ 1,626,011 $ 1,786,958 $ 638 $ (2,101,100) $ 1,886,700 Liabilities and Stockholders’ Equity Current liabilities Trade accounts payable $ — $ 13 $ 36,514 $ — $ — $ 36,527 Oil and gas sales payable — — 28,339 — — 28,339 Accrued liabilities 3,874 11,227 10,597 9 — 25,707 Commodity derivative liabilities — 14,650 — — — 14,650 Other current liabilities — 1,984 600 — — 2,584 Intercompany payable — — 1,113,704 2,796 (1,116,500) — Total current liabilities 3,874 27,874 1,189,754 2,805 (1,116,500) 107,807 Long-term debt — 724,009 — — — 724,009 Deferred revenue — 7,049 — — — 7,049 Commodity derivative liabilities — 1,209 — — — 1,209 Asset retirement obligations — — 19,458 — — 19,458 Liability under tax receivable agreement 43,045 — — — — 43,045 Other liabilities — 269 523 — — 792 Deferred tax liabilities 85 2,820 — — — 2,905 Total liabilities 47,004 763,230 1,209,735 2,805 (1,116,500) 906,274 Mezzanine equity Series A preferred stock, $0.001 par value; 1,840,000 shares issued and outstanding at December 31, 2016 88,975 — — — — 88,975 Stockholders’/ members' equity (deficit) Members' equity — 862,781 577,223 (2,167) (1,437,837) — Class A common stock, $0.001 par value; 57,048,076 shares issued and 57,025,474 shares outstanding at December 31, 2016 57 — — — — 57 Class B common stock, $0.001 par value; 29,832,098 shares issued and outstanding at December 31, 2016 30 — — — — 30 Treasury stock, at cost: 22,602 shares at December 31, 2016 (358) — — — — (358) Additional paid-in-capital 447,137 — — — — 447,137 Retained earnings (deficit) (8,652) — — — — (8,652) Stockholders' equity (deficit) 438,214 862,781 577,223 (2,167) (1,437,837) 438,214 Non-controlling interest — — — — 453,237 453,237 Total stockholders’ equity 438,214 862,781 577,223 (2,167) (984,600) 891,451 Total liabilities and stockholders’ equity $ 574,193 $ 1,626,011 $ 1,786,958 $ 638 $ (2,101,100) $ 1,886,700
Condensed Consolidating Statement of Operations	Condensed Consolidating Statement of Operations Year Ended December 31, 2017 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Operating revenues Oil and gas sales $ — $ — $ 186,393 $ — $ — $ 186,393 Other revenues — 1,854 326 — — 2,180 Total operating revenues — 1,854 186,719 — — 188,573 Operating costs and expenses Lease operating — — 36,636 — — 36,636 Production and ad valorem taxes — — 6,874 — — 6,874 Exploration — — 14,145 — — 14,145 Depletion, depreciation and amortization — — 167,133 91 — 167,224 Impairment of oil and gas properties — — 149,648 — — 149,648 Accretion of ARO liability — — 960 — — 960 General and administrative 237 10,146 19,226 283 — 29,892 Total operating expenses 237 10,146 394,622 374 — 405,379 Operating income (loss) (237) (8,292) (207,903) (374) — (216,806) Other income (expense) Interest expense — (52,016) 365 — — (51,651) Net gain (loss) on commodity derivatives — (17,985) — — — (17,985) Other income (expense) 59,492 (93) (2,447) — — 56,952 Other income (expense), net 59,492 (70,094) (2,082) — — (12,684) Income (loss) before income tax 59,255 (78,386) (209,985) (374) — (229,490) Equity interest in income (loss) (211,217) (77,527) — — 288,744 — Income tax provision (benefit) (50,470) (197) — — — (50,667) Net income (loss) (101,492) (155,716) (209,985) (374) 288,744 (178,823) Net income (loss) attributable to non-controlling interests — — — — (77,331) (77,331) Net income (loss) attributable to controlling interests $ (101,492) $ (155,716) $ (209,985) $ (374) $ 366,075 $ (101,492) Dividends and accretion on preferred stock (7,924) — — — — (7,924) Net income (loss) attributable to common shareholders $ (109,416) $ (155,716) $ (209,985) $ (374) $ 366,075 $ (109,416) Jones Energy, Inc. Condensed Consolidating Statement of Operations Year Ended December 31, 2016 Guarantor Non‑Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Operating revenues Oil and gas sales $ — $ — $ 124,877 $ — $ — $ 124,877 Other revenues — 2,384 586 — — 2,970 Total operating revenues — 2,384 125,463 — — 127,847 Operating costs and expenses Lease operating — — 32,640 — — 32,640 Production and ad valorem taxes — — 7,768 — — 7,768 Exploration — — 6,673 — — 6,673 Depletion, depreciation and amortization — — 153,843 87 — 153,930 Accretion of ARO liability — — 1,263 — — 1,263 General and administrative — 12,028 17,244 368 — 29,640 Other operating — 199 — 199 Total operating expenses — 12,028 219,630 455 — 232,113 Operating income (loss) — (9,644) (94,167) (455) — (104,266) Other income (expense) Interest expense — (53,080) (47) — — (53,127) Gain on debt extinguishment — 99,530 — — — 99,530 Net gain (loss) on commodity derivatives — (51,264) — — — (51,264) Other income (expense) 784 (321) 73 — — 536 Other income (expense), net 784 (5,135) 26 — — (4,325) Income (loss) before income tax 784 (14,779) (94,141) (455) — (108,591) Equity interest in income (loss) (66,804) (42,571) — — 109,375 — Income tax provision (benefit) (23,468) (318) — — — (23,786) Net income (loss) (42,552) (57,032) (94,141) (455) 109,375 (84,805) Net income (loss) attributable to non-controlling interests — — — — (42,253) (42,253) Net income (loss) attributable to controlling interests $ (42,552) $ (57,032) $ (94,141) $ (455) $ 151,628 $ (42,552) Dividends and accretion on preferred stock (2,669) — — — — (2,669) Net income (loss) attributable to common shareholders $ (45,221) $ (57,032) $ (94,141) $ (455) $ 151,628 $ (45,221) Jones Energy, Inc. Condensed Consolidating Statement of Operations Year Ended December 31, 2015 Guarantor Non‑Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Operating revenues Oil and gas sales $ — $ — $ 194,555 $ — $ — $ 194,555 Other revenues — 1,960 884 — — 2,844 Total operating revenues — 1,960 195,439 — — 197,399 Operating costs and expenses Lease operating — — 41,027 — — 41,027 Production and ad valorem taxes — — 12,130 — — 12,130 Exploration — — 6,551 — — 6,551 Depletion, depreciation and amortization — — 205,407 91 — 205,498 Accretion of ARO liability — — 1,087 — — 1,087 General and administrative — 13,565 19,707 116 — 33,388 Other operating — — 4,188 — — 4,188 Total operating expenses — 13,565 290,097 207 — 303,869 Operating income (loss) — (11,605) (94,658) (207) — (106,470) Other income (expense) Interest expense — (63,160) (1,298) — — (64,458) Net gain (loss) on commodity derivatives — 158,753 — — — 158,753 Other income (expense) 1,984 (1,663) (4) — — 317 Other income (expense), net 1,984 93,930 (1,302) — — 94,612 Income (loss) before income tax 1,984 82,325 (95,960) (207) — (11,858) Equity interest in income (loss) (4,728) (9,114) — — 13,842 — Income tax provision (benefit) (363) (2,418) — — — (2,781) Net income (loss) (2,381) 75,629 (95,960) (207) 13,842 (9,077) Net income (loss) attributable to non-controlling interests — — — — (6,696) (6,696) Net income (loss) attributable to controlling interests $ (2,381) $ 75,629 $ (95,960) $ (207) $ 20,538 $ (2,381) Dividends and accretion on preferred stock — — — — — — Net income (loss) attributable to common shareholders $ (2,381) $ 75,629 $ (95,960) $ (207) $ 20,538 $ (2,381)
Condensed Consolidating Statement of Cash Flows	Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2017 Non- Guarantor Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ (101,492) $ (155,716) $ (209,985) $ (374) $ 288,744 $ (178,823) Adjustments to reconcile net income (loss) to net cash provided by operating activities 73,536 52,870 399,795 374 (288,744) 237,831 Net cash (used in) / provided by operations (27,956) (102,846) 189,810 — — 59,008 Cash flows from investing activities Additions to oil and gas properties — — (245,364) — — (245,364) Net adjustments to purchase price of properties acquired — — 2,391 — — 2,391 Proceeds from sales of assets — — 61,290 — — 61,290 Acquisition of other property, plant and equipment — — (586) — — (586) Current period settlements of matured derivative contracts — 72,265 — — — 72,265 Net cash (used in) / provided by investing — 72,265 (182,269) — — (110,004) Cash flows from financing activities Proceeds from issuance of long-term debt — 162,000 — — — 162,000 Repayment of long-term debt — (129,000) — — — (129,000) Payment of debt issuance costs — (1,115) — — — (1,115) Payment of cash dividends on preferred stock (3,368) — — — — (3,368) Net distributions paid to JEH unitholders 1,075 (1,637) — — — (562) Net payments for share based compensation — (462) — — — (462) Proceeds from sale of common stock 8,333 — — — — 8,333 Net cash (used in) / provided by financing 6,040 29,786 — — — 35,826 Net increase (decrease) in cash (21,916) (795) 7,541 — — (15,170) Cash Beginning of period 27,164 1,975 5,483 20 — 34,642 End of period $ 5,248 $ 1,180 $ 13,024 $ 20 $ — $ 19,472 Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2016 Non- Guarantor Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ (42,552) $ (57,032) $ (94,141) $ (455) $ 109,375 $ (84,805) Adjustments to reconcile net income (loss) to net cash provided by operating activities (105,877) (28,124) 353,426 455 (109,375) 110,505 Net cash (used in) / provided by operations (148,429) (85,156) 259,285 — — 25,700 Cash flows from investing activities Additions to oil and gas properties — — (264,462) — — (264,462) Proceeds from sales of assets — — 1,645 — — 1,645 Acquisition of other property, plant and equipment — — (310) — — (310) Current period settlements of matured derivative contracts — 132,265 — — — 132,265 Net cash (used in) / provided by investing — 132,265 (263,127) — — (130,862) Cash flows from financing activities Proceeds from issuance of long-term debt — 130,000 — — — 130,000 Repayment under long-term debt — (62,000) — — — (62,000) Purchase of senior notes — (84,589) — — — (84,589) Payment of dividends on preferred stock (1,615) — — — — (1,615) Net distributions paid to JEH unitholders 23,674 (40,993) — — — (17,319) Proceeds from sale of common stock 65,446 — — — — 65,446 Proceeds from sale of preferred stock 87,988 — — — — 87,988 Net cash (used in) / provided by financing 175,493 (57,582) — — — 117,911 Net increase (decrease) in cash 27,064 (10,473) (3,842) — — 12,749 Cash Beginning of period 100 12,448 9,325 20 — 21,893 End of period $ 27,164 $ 1,975 $ 5,483 $ 20 $ — $ 34,642 Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2015 Non- Guarantor Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ (2,381) $ 75,629 $ (95,960) $ (207) $ 13,842 $ (9,077) Adjustments to reconcile net income (loss) to net cash provided by operating activities (120,398) (193,245) 405,214 197 (13,842) 77,926 Net cash (used in) / provided by operations (122,779) (117,616) 309,254 (10) — 68,849 Cash flows from investing activities Additions to oil and gas properties — — (311,305) — — (311,305) Proceeds from sales of assets — — 41 — — 41 Acquisition of other property, plant and equipment — — (1,101) — — (1,101) Current period settlements of matured derivative contracts — 144,145 — — — 144,145 Net cash (used in) / provided by investing — 144,145 (312,365) — — (168,220) Cash flows from financing activities Proceeds from issuance of long-term debt — 85,000 — — — 85,000 Repayment under long-term debt — (335,000) — — — (335,000) Proceeds from senior notes — 236,475 — — — 236,475 Payment of debt issuance costs — (1,556) — — — (1,556) Proceeds from sale of common stock 122,779 — — — — 122,779 Net cash (used in) / provided by financing 122,779 (15,081) — — — 107,698 Net increase (decrease) in cash — 11,448 (3,111) (10) — 8,327 Cash Beginning of period 100 1,000 12,436 30 — 13,566 End of period $ 100 $ 12,448 $ 9,325 $ 20 $ — $ 21,893

Organization and Description 38

Organization and Description of Business - Common Stock (Details)	12 Months Ended
	Dec. 31, 2017classshares
Common Stock
Number of classes of common stock | class	2
Class B common stock
Common Stock
Economic interests/rights (as a percent)	0.00%
Votes per share entitled to holders	1
Pre-IPO owners of JEH
Common Stock
Ratio in which JEH Units and Class B common stock are exchanged for Class A common stock	1
JEH | Jones Energy, Inc.
Common Stock
Number of units held (in shares)	90,117,238
JEH | Pre-IPO owners of JEH
Common Stock
Number of units held (in shares)	9,627,821

Organization and Description 39

Organization and Description of Business - Series A Perpetual Convertible Preferred Stock (Details) - $ / shares	Oct. 09, 2017	Jul. 13, 2017	Apr. 17, 2017	Jan. 19, 2017	Aug. 25, 2016	Dec. 31, 2017	Dec. 31, 2016
Series A Perpetual Convertible Preferred Stock
Series A preferred stock, par value (in dollars per share)						$ 0.001	$ 0.001
Series A preferred stock, shares issued						1,839,995	1,840,000
Series A preferred stock, shares outstanding						1,839,995	1,840,000
Series A preferred stock
Series A Perpetual Convertible Preferred Stock
Shares issued (in shares)					1,840,000
Dividend rate (as a percent)	8.00%	8.00%	8.00%	8.00%	8.00%
Series A preferred stock, par value (in dollars per share)					$ 0.001
Preferred stock, share price (in dollars per share)					$ 50

Significant Accounting Polici40

Significant Accounting Policies - Segment Information (Details)	12 Months Ended
	Dec. 31, 2017segmentarea
Segment Information
Number of industry segments | segment	1
Number of Geographic Areas in which Entity Operates | area	1

Significant Accounting Polici41

Significant Accounting Policies - Accounts Receivable (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)
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 Polici42

Significant Accounting Policies - Concentration of Risk (Details) - Credit risk	12 Months Ended
	Dec. 31, 2017customerOwner	Dec. 31, 2016customerOwner	Dec. 31, 2015customerOwner
Accounts receivable - Oil and gas sales
Concentration of Risk
Concentration risk (as a percent)	71.00%	77.00%	68.00%
Number of customers | customer	3	4	4
Accounts receivable - Joint interest owners
Concentration of Risk
Concentration risk (as a percent)	59.00%	48.00%	80.00%
Number of customers | Owner	5	5	5

Significant Accounting Polici43

Significant Accounting Policies - Dependence on Major Customers (Details) - Oil and gas sales - Customer concentration	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Valero Energy Corp.
Dependence on Major Customers
Concentration risk (as a percent)			18.00%
ETC Field Services LLC
Dependence on Major Customers
Concentration risk (as a percent)	22.00%	24.00%	17.00%
NGL Energy Partners LP
Dependence on Major Customers
Concentration risk (as a percent)			15.00%
Plains Marketing
Dependence on Major Customers
Concentration risk (as a percent)	40.00%	37.00%	16.00%

Significant Accounting Polici44

Significant Accounting Policies - Oil and Gas Properties (Details)	12 Months Ended
	Dec. 31, 2017ft³ / Boe
Oil and Gas Properties
Minimum project period for capitalization of interest on expenditures	6 months
Unit conversion ratio	6,000

Significant Accounting Polici45

Significant Accounting Policies - Other Property, Plant and Equipment (Details)	12 Months Ended
	Dec. 31, 2017
Minimum
Other Property, Plant and Equipment
Estimated useful lives	3 years
Maximum
Other Property, Plant and Equipment
Estimated useful lives	10 years

Significant Accounting Polici46

Significant Accounting Policies - Oil and Gas Sales Payable (Details)	12 Months Ended
	Dec. 31, 2017
Oil and Gas Sales Payable
Period of remittance for oil and gas sales payable	60 days

Significant Accounting Polici47

Significant Accounting Policies - Accrued Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Accrued Liabilities
Accrued interest	$ 12,109	$ 13,531
Other accrued liabilities	9,495	12,176
Total accrued liabilities	$ 21,604	$ 25,707

Significant Accounting Polici48

Significant Accounting Policies - Recent Accounting Pronouncements (Details) $ in Millions	Jan. 01, 2017USD ($)
Accounting Standards Update 2016-09
Recent Accounting Pronouncements
Cumulative effect of adoption of ASU 2016-09	$ 0.7

Acquisitions and Divestitures -

Acquisitions and Divestitures - Merge Acquisition (Details) - Merge Acquisition $ in Millions	Sep. 22, 2016USD ($)a	Mar. 31, 2017USD ($)
Acquisitions
Purchase consideration	$ 134.4
Proceeds from final working capital settlement		$ 2.4
Number of net acres | a	16,975

Acquisitions and Divestitures50

Acquisitions and Divestitures - Anadarko Acquisition - General Information (Details) $ in Millions	Aug. 25, 2016USD ($)
Anadarko Acquisition
Acquisitions
Purchase consideration	$ 25.9

Acquisitions and Divestitures51

Acquisitions and Divestitures - Anadarko Acquisition - Purchase Price Allocation (Details) - Anadarko Acquisition $ in Millions	Aug. 25, 2016USD ($)
Oil and gas properties
Purchase consideration	$ 25.9
Total assets	32.3
Oil and gas properties	32.3
Unproved	3
Proved	17
Wells and equipment and related facilities	12.3
Total liabilities	6.4
Asset retirement obligations	$ 6.4

Acquisitions and Divestitures52

Acquisitions and Divestitures - Anadarko Acquisition - Additional Information (Details) - Anadarko Acquisition	Aug. 25, 2016abbl / ditem
Acquisitions
Number of wells | item	174
Wells operated by entity (as a percent)	59.00%
Number of net acres | a	25,000
Production per day (in barrels per day) | bbl / d	900

Acquisitions and Divestitures53

Acquisitions and Divestitures - Arkoma Divestiture - Assets Held for Sale - Impairment (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2017	Dec. 31, 2017
Divestitures
Impairment charges		$ 148
Arkoma Assets | Disposal Group, Held-for-sale, Not Discontinued Operations
Divestitures
Impairment charges	$ 148

Acquisitions and Divestitures54

Acquisitions and Divestitures - Arkoma Divestiture - General Information (Details) - Arkoma Assets - USD ($) $ in Millions	Sep. 30, 2017	Aug. 01, 2017
Disposal Group, Disposed of by Sale, Not Discontinued Operations
Divestitures
Consideration, purchase price		$ 65
Contingent payments based on natural gas prices		2.5
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Scenario, Adjustment
Divestitures
Consideration, purchase price		$ 7.3
Disposal Group, Held-for-sale, Not Discontinued Operations
Divestitures
Contingent payments based on natural gas prices	$ 0

Properties, Plant and Equipme55

Properties, Plant and Equipment - Oil and Gas Properties - Tabular Information (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Mineral interests in properties
Unproved	$ 164,087	$ 213,153
Proved	893,246	1,054,683
Wells and equipment and related facilities	1,434,383	1,395,291
Gross oil and gas properties	2,491,716	2,663,127
Less: Accumulated depletion and impairment	(894,676)	(919,539)
Net oil and gas properties	$ 1,597,040	$ 1,743,588

Properties, Plant and Equipme56

Properties, Plant and Equipment - Oil and Gas Properties - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)project	Dec. 31, 2016USD ($)project	Dec. 31, 2015USD ($)
Oil and Gas Properties
Number of exploratory wells for which costs were capitalized | project	0	1
Costs capitalized in connection with exploratory wells		$ 1.3
Exploration expense on exploratory wells	$ 0	0
Amount of capitalized interest on expenditures	0.4	0
Depletion of oil and gas properties	166.2	152.7	$ 204.2
Impairments of proved or unproved oil and gas properties	1.6	$ 0	$ 0
Impairment charges	$ 148

Properties, Plant and Equipme57

Properties, Plant and Equipment - Other Property, Plant and Equipment - Tabular Information (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Other Property, Plant and Equipment
Gross other property, plant and equipment	$ 8,638	$ 8,254
Less: Accumulated depreciation and amortization	(5,919)	(5,258)
Net other property, plant and equipment	2,719	2,996
Leasehold improvements
Other Property, Plant and Equipment
Gross other property, plant and equipment	1,186	1,213
Furniture, fixtures, computers and software
Other Property, Plant and Equipment
Gross other property, plant and equipment	4,410	4,170
Vehicles
Other Property, Plant and Equipment
Gross other property, plant and equipment	1,922	1,677
Aircraft
Other Property, Plant and Equipment
Gross other property, plant and equipment	910	910
Other
Other Property, Plant and Equipment
Gross other property, plant and equipment	$ 210	$ 284

Properties, Plant and Equipme58

Properties, Plant and Equipment - Other Property, Plant and Equipment - Depreciation and Amortization (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Other Property, Plant and Equipment
Depreciation and amortization of other property, plant and equipment	$ 1	$ 1.2	$ 1.3

Long-Term Debt - Tabular Disclo

Long-Term Debt - Tabular Disclosure (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Long-Term Debt
Total principal amount	$ 770,148	$ 737,148
Less: unamortized discount	(5,228)	(6,240)
Less: debt issuance costs, net	(5,604)	(6,899)
Total carrying amount	759,316	724,009
2022 Notes | Senior notes
Long-Term Debt
Total principal amount	409,148	409,148
2023 Notes | Senior notes
Long-Term Debt
Total principal amount	150,000	150,000
Revolving credit facility | Revolver | Line of credit
Long-Term Debt
Total principal amount	$ 211,000	$ 178,000

Long-Term Debt - Senior Unsecur

Long-Term Debt - Senior Unsecured Notes (Details) - USD ($) $ in Thousands	Feb. 29, 2016	Feb. 23, 2015	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Feb. 14, 2018	Apr. 01, 2014
Senior Unsecured Notes
Notes proceeds from issuance					$ 236,475
Repayment under long-term debt			$ 129,000	$ 62,000	$ 335,000
Purchased amount				84,589
Gain on debt extinguishment				99,530
Senior notes
Senior Unsecured Notes
Aggregate principal amount repurchased				190,900
Gain on debt extinguishment				99,500
2022 Notes | Senior notes
Senior Unsecured Notes
Aggregate principal amount							$ 500,000
Stated interest rate (as a percent)							6.75%
Aggregate principal amount repurchased				90,900
Purchased amount				38,100
Aggregate principle amount repurchased and available for reissuance				20,300
2023 Notes | Senior notes
Senior Unsecured Notes
Aggregate principal amount		$ 250,000
Stated interest rate (as a percent)		9.25%
Discount of principal amount (as a percent)		94.59%
Notes proceeds from issuance		$ 236,500
Beneficial owner | 2023 Notes | Senior notes
Senior Unsecured Notes
Aggregate principal amount repurchased	$ 100,000
Purchased amount				$ 46,500
Gain on debt extinguishment	$ 48,300
Subsequent Event | 2023 Notes | Senior notes
Senior Unsecured Notes
Aggregate principal amount						$ 450,000
Stated interest rate (as a percent)						9.25%
Discount of principal amount (as a percent)						97.526%

Long-Term Debt - Other Long-Ter

Long-Term Debt - Other Long-Term Debt (Details) - Revolver $ in Millions	Nov. 26, 2017USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Aug. 01, 2017USD ($)	May 15, 2017USD ($)
Minimum | Line of credit
Other Long-Term Debt
Total leverage ratio	4
Maximum
Other Long-Term Debt
Leverage ratio, last day of quarter		1
Maximum | Line of credit
Other Long-Term Debt
Second lien debt	$ 350
Total leverage ratio	4
Revolving credit facility | Line of credit
Other Long-Term Debt
Borrowing base	$ 350				$ 375	$ 425
Average interest rate (as a percent)		3.04%	2.40%
Average outstanding balance		$ 189	$ 172.3
Total interest and commitment fees		$ 6.6	$ 5.3	$ 5.1
Leverage ratio, I Quarter		5.25
Leverage ratio, II Quarter		5
Leverage ratio, III Quarter		4.75
Leverage ratio, IV Quarter		4.50
Leverage ratio, last day of quarter		4
Leverage ratio, Senior secured debt to EBIDTA		1.18
Percentage of projected production over 24 months	100.00%
Percentage of projected production over 36 months	85.00%
Total leverage ratio		4.29
Current ratio		1.85
Revolving credit facility | London Interbank Offered Rate (LIBOR) | Minimum | Line of credit
Other Long-Term Debt
Leverage ratio, last day of quarter		4
Revolving credit facility | London Interbank Offered Rate (LIBOR) | Maximum | Line of credit
Other Long-Term Debt
Leverage ratio, last day of quarter		4
Revolving credit facility | Federal Funds Effective Swap Rate | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		0.50%
Margin		0.50%
Revolving credit facility | Federal Funds Effective Swap Rate | Minimum | Line of credit
Other Long-Term Debt
Leverage ratio, last day of quarter		4
Revolving credit facility | Federal Funds Effective Swap Rate | Maximum | Line of credit
Other Long-Term Debt
Leverage ratio, last day of quarter		4
Revolving credit facility | One Month Adjust LIBO Rate | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		1.00%
Margin		1.00%
After December 31, 2018 | Revolving credit facility | Line of credit
Other Long-Term Debt
Leverage ratio, Senior secured debt to EBIDTA		2.25
Leverage Ratio is Less than or Equal to 4.00 | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)	0.75%
Margin	0.75%
Leverage Ratio is Less than or Equal to 4.00 | Revolving credit facility | London Interbank Offered Rate (LIBOR) | Minimum | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		2.25%
Margin		2.25%
Leverage Ratio is Less than or Equal to 4.00 | Revolving credit facility | London Interbank Offered Rate (LIBOR) | Maximum | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		3.25%
Margin		3.25%
Leverage Ratio is Less than or Equal to 4.00 | Revolving credit facility | Federal Funds Effective Swap Rate | Minimum | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		1.25%
Margin		1.25%
Leverage Ratio is Less than or Equal to 4.00 | Revolving credit facility | Federal Funds Effective Swap Rate | Maximum | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		2.25%
Margin		2.25%
Leverage Ratio is Greater than 4.00 | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)	1.25%
Margin	1.25%
Leverage Ratio is Greater than 4.00 | Revolving credit facility | London Interbank Offered Rate (LIBOR) | Minimum | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		2.75%
Margin		2.75%
Leverage Ratio is Greater than 4.00 | Revolving credit facility | London Interbank Offered Rate (LIBOR) | Maximum | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		3.75%
Margin		3.75%
Leverage Ratio is Greater than 4.00 | Revolving credit facility | Federal Funds Effective Swap Rate | Minimum | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		1.75%
Margin		1.75%
Leverage Ratio is Greater than 4.00 | Revolving credit facility | Federal Funds Effective Swap Rate | Maximum | Line of credit
Other Long-Term Debt
Margin interest rate (as a percent)		2.75%
Margin		2.75%

Derivative Instruments and He62

Derivative Instruments and Hedging Activities - Hedging Positions (Details)	12 Months Ended
	Dec. 31, 2017$ / bblbbl / moMMBTU / mo$ / MMBTU
Oil | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per barrel)	49.70
Net barrels per month (in barrels per month) | bbl / mo	55,000
Oil | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per barrel)	54.18
Net barrels per month (in barrels per month) | bbl / mo	216,000
Oil | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel)	50.64
Net barrels per month (in barrels per month) | bbl / mo	112,333
Oil | Collars | Minimum
Hedging Positions
Net barrels per month (in barrels per month) | bbl / mo	65,000
Oil | Collars | Maximum
Hedging Positions
Net barrels per month (in barrels per month) | bbl / mo	73,000
Oil | Collars | Weighted Average
Hedging Positions
Net barrels per month (in barrels per month) | bbl / mo	67,500
Natural gas | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU	2.76
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	700,000
Natural gas | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU	3.10
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	1,890,000
Natural gas | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU	2.89
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	1,118,889
Natural gas | Collars | Minimum
Hedging Positions
Net barrels per month (in barrels per month) | bbl / mo	950,000
Natural gas | Collars | Maximum
Hedging Positions
Net barrels per month (in barrels per month) | bbl / mo	1,050,000
Natural gas | Collars | Weighted Average
Hedging Positions
Net barrels per month (in barrels per month) | bbl / mo	990,833
Natural gas | Basis swaps | Minimum
Hedging Positions
Offset exercise price (in dollars per mmbtu)	(0.50)
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	800,000
Natural gas | Basis swaps | Maximum
Hedging Positions
Offset exercise price (in dollars per mmbtu)	(0.30)
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	800,000
Natural gas | Basis swaps | Weighted Average
Hedging Positions
Offset exercise price (in dollars per mmbtu)	(0.41)
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	800,000
Natural gas liquids | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per barrel)	22.89
Net barrels per month (in barrels per month) | bbl / mo	130,000
Natural gas liquids | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per barrel)	45.26
Net barrels per month (in barrels per month) | bbl / mo	145,000
Natural gas liquids | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel)	29.79
Net barrels per month (in barrels per month) | bbl / mo	138,750
Puts (floors) | Oil | Collars | Minimum
Hedging Positions
Exercise price (in dollars per barrel)	45
Puts (floors) | Oil | Collars | Maximum
Hedging Positions
Exercise price (in dollars per barrel)	50
Puts (floors) | Oil | Collars | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel)	48.52
Puts (floors) | Natural gas | Collars | Minimum
Hedging Positions
Exercise price (in dollars per mmbtu)	2.55
Puts (floors) | Natural gas | Collars | Maximum
Hedging Positions
Exercise price (in dollars per mmbtu)	2.55
Puts (floors) | Natural gas | Collars | Weighted Average
Hedging Positions
Exercise price (in dollars per mmbtu)	2.55
Calls (ceilings) | Oil | Collars | Minimum
Hedging Positions
Exercise price (in dollars per barrel)	56.60
Calls (ceilings) | Oil | Collars | Maximum
Hedging Positions
Exercise price (in dollars per barrel)	61
Calls (ceilings) | Oil | Collars | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel)	59.64
Calls (ceilings) | Natural gas | Collars | Minimum
Hedging Positions
Exercise price (in dollars per mmbtu)	3.08
Calls (ceilings) | Natural gas | Collars | Maximum
Hedging Positions
Exercise price (in dollars per mmbtu)	3.41
Calls (ceilings) | Natural gas | Collars | Weighted Average
Hedging Positions
Exercise price (in dollars per mmbtu)	3.19

Derivative Instruments and He63

Derivative Instruments and Hedging Activities - Recognized Gain (Loss) on Derivative Instruments (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Recognized Net Gain (Loss) on Derivative Instruments
Gain (Loss) on Sale of Derivatives	$ (17,985)	$ (51,264)	$ 158,753
Net gain (loss) on commodity derivatives
Recognized Net Gain (Loss) on Derivative Instruments
Gain (Loss) on Sale of Derivatives	42,800
Commodity derivatives
Recognized Net Gain (Loss) on Derivative Instruments
Net (losses) gains recognized on derivative instruments	$ (18,000)	$ (51,300)	$ 158,800

Derivative Instruments and He64

Derivative Instruments and Hedging Activities - Offsetting Assets and Liabilities - Counterparties (Details)	Dec. 31, 2017Counterparty
Offsetting Assets and Liabilities
Number of counterparties to commodity derivative contracts	6

Derivative Instruments and He65

Derivative Instruments and Hedging Activities - Offsetting Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Assets
Gross Amounts of Recognized Assets	$ 8,572	$ 79,649
Gross Amounts Offset in the Balance Sheet	(4,926)	(20,805)
Net Amounts of Assets Presented in the Balance Sheet	3,646	58,844
Net Amount	$ 3,646	$ 58,844

Derivative Instruments and He66

Derivative Instruments and Hedging Activities - Offsetting Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Liabilities
Gross Amounts of Recognized Liabilities	$ (50,423)	$ (36,664)
Gross Amounts Offset in the Balance Sheet	4,926	20,805
Net Amounts of Liabilities Presented in the Balance Sheet	(45,497)	(15,859)
Net Amount	$ (45,497)	$ (15,859)

Fair Value Measurement - Financ

Fair Value Measurement - Financial Instruments Carried at Fair Value by Consolidated Balance Sheet Caption and by Valuation Hierarchy (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Valuation Hierarchy
Current assets	$ 3,474	$ 24,100
Long-term assets	172	34,744
Current liabilities	36,709	14,650
Long-term liabilities	8,788	1,209
Recurring | Commodity derivatives
Valuation Hierarchy
Current assets	3,474	24,100
Long-term assets	172	34,744
Current liabilities	36,709	14,650
Long-term liabilities	8,788	1,209
Recurring | Level 2 | Commodity derivatives
Valuation Hierarchy
Current assets	3,474	24,100
Long-term assets	56	36,384
Current liabilities	28,946	13,636
Long-term liabilities	7,860	892
Recurring | Level 3 | Commodity derivatives
Valuation Hierarchy
Long-term assets	116	(1,640)
Current liabilities	7,763	1,014
Long-term liabilities	$ 928	$ 317

Fair Value Measurement - Quanti

Fair Value Measurement - Quantitative Information about Level 3 Inputs (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)$ / bbl
Natural gas liquids | Swaps | Minimum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	22.89
Natural gas liquids | Swaps | Maximum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	45.26
Oil | Swaps | Minimum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	49.70
Oil | Swaps | Maximum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	54.18
Discounted cash flow approach | Level 3 | Natural gas liquids | Swaps
Commodity Derivative Instruments - Assets
Fair Value | $	$ (7,763)
Discounted cash flow approach | Level 3 | Natural gas liquids | Swaps | Minimum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	27.93
Discounted cash flow approach | Level 3 | Natural gas liquids | Swaps | Maximum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	44
Discounted cash flow approach | Level 3 | Natural gas | Collars | Minimum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	2.55
Discounted cash flow approach | Level 3 | Natural gas | Collars | Maximum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	3.41
Discounted option model approach | Level 3 | Oil | Collars
Commodity Derivative Instruments - Assets
Fair Value | $	$ (654)
Discounted option model approach | Level 3 | Oil | Collars | Minimum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	45
Discounted option model approach | Level 3 | Oil | Collars | Maximum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	61
Discounted option model approach | Level 3 | Natural gas | Collars
Commodity Derivative Instruments - Assets
Fair Value | $	$ (158)

Fair Value Measurement - Change

Fair Value Measurement - Changes in Level 3 Financial Instruments (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Changes in fair value of Level 3 instruments
Balance at the beginning of the period	$ (2,971)	$ 1,428
Purchases	(1,236)	(5,208)
Settlements	1,606	(171)
Transfers to Level 3	6,527	(2,363)
Changes in fair value	553	(1,383)
Balance at the end of the period	$ (8,575)	$ (2,971)

Fair Value Measurement - Assets

Fair Value Measurement - Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis (Details) - Nonrecurring - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Principal Amount | 2022 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	$ 409,148	$ 409,148
Principal Amount | 2023 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	150,000	150,000
Principal Amount | Revolving credit facility | Revolver | Line of credit
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	211,000	178,000
Level 3 | Total | Revolving credit facility | Revolver | Line of credit
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	211,000	178,000
Level 1 | Total | 2022 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	305,404	393,150
Level 2 | Total | 2023 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	$ 114,750	$ 153,375

Asset Retirement Obligations -

Asset Retirement Obligations - Roll Forward (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligations
ARO liability at beginning of year	$ 20,058	$ 20,980
Liabilities incurred	1,062	6,947
Accretion of ARO liability	960	1,263	$ 1,087
Liabilities settled due to sale of related properties	(1,231)	(446)
Liabilities settled due to plugging and abandonment	(339)	(463)
Change in estimate	(138)	(8,223)
ARO liability at end of year	$ 20,372	$ 20,058	$ 20,980

Asset Retirement Obligations 72

Asset Retirement Obligations - Liability at Period End (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligations
ARO liability at end of year	$ 20,372	$ 20,058	$ 20,980
Less: Current portion of ARO at end of year	(720)	(600)
Total long-term ARO at end of year	$ 19,652	$ 19,458

Asset Retirement Obligations 73

Asset Retirement Obligations - Related to Acquisition (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Asset Retirement Obligations
Liabilities incurred	$ 1,062	$ 6,947
Anadarko Acquisition
Asset Retirement Obligations
Liabilities incurred		$ 6,400

Stock-based Compensation - Mana

Stock-based Compensation - Management Unit Awards - New Awards (Details) - shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Management Unit Awards
Stock-based Compensation
Awards (in shares)	0	0	0

Stock-based Compensation - Ma75

Stock-based Compensation - Management Unit Awards - Activity (Details) - Management Unit Awards	12 Months Ended
	Dec. 31, 2017$ / sharesshares
JEH Units
Unvested at the beginning (in shares) | shares	90,762
Granted (in shares) | shares	13,066
Forfeited (in shares) | shares	(13,066)
Vested (in shares) | shares	(58,447)
Unvested at the end (in shares) | shares	32,315
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning (in dollars per share) | $ / shares	$ 15
Granted (in dollars per share) | $ / shares	15
Forfeited (in dollars per share) | $ / shares	15
Vested (in dollars per share) | $ / shares	15
Unvested at the end (in dollars per share) | $ / shares	$ 15

Stock-based Compensation - Ma76

Stock-based Compensation - Management Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
General and administrative expenses | Management Unit Awards
Stock compensation expense
Stock compensation expense	$ 0.6	$ 1.2	$ 1.3

Stock-based Compensation - Ma77

Stock-based Compensation - Management Unit Awards - Additional Disclosures (Details) - Management Unit Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Stock-based Compensation
Weighted average grant date fair value (in dollars per share)	$ 15	$ 15
Unrecognized expenses	$ 0.1
Weighted-average remaining recognition period (in years)	3 months 18 days

Stock-based Compensation - 2013

Stock-based Compensation - 2013 Omnibus Incentive Plan (Details) - Class A common stock - shares	Dec. 31, 2017	Mar. 31, 2017
Stock-based Compensation
Special stock dividend declared per share (in shares)		0.087423
2013 Omnibus Incentive Plan
Stock-based Compensation
Shares reserved (in shares)	8,340,211

Stock-based Compensation - Rest

Stock-based Compensation - Restricted Stock Unit Awards - General Information (Details)	12 Months Ended
	Dec. 31, 2017
Restricted Stock Unit Awards
Stock-based Compensation
Vesting term	3 years

Stock-based Compensation - Re80

Stock-based Compensation - Restricted Stock Unit Awards - Activity (Details) - Restricted Stock Unit Awards - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Awards
Unvested at the beginning (in shares)	1,359,142
Adjustment (in shares)	130,871
Granted (in shares)	2,394,290
Forfeited (in shares)	(543,803)
Vested (in shares)	(577,729)
Unvested at the end (in shares)	2,762,771	1,359,142
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning (in dollars per share)	$ 5.60
Granted (in dollars per share)	2.32	$ 3.67	$ 8.81
Forfeited (in dollars per share)	3
Vested (in dollars per share)	6.62
Unvested at the end (in dollars per share)	$ 2.79	$ 5.60

Stock-based Compensation - Re81

Stock-based Compensation - Restricted Stock Unit Awards - Preferred Stock Dividends (Details) - shares	Nov. 15, 2017	Aug. 15, 2017	May 15, 2017
Restricted Stock Unit Awards
Stock-based Compensation
Dividends Preferred Stock Stock Shares Declared Per Unvested LTIP Unit	0.018867	0.021931	0.002195

Stock-based Compensation - Re82

Stock-based Compensation - Restricted Stock Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
General and administrative expenses | Restricted Stock Unit Awards
Stock compensation expense
Stock compensation expense	$ 3.8	$ 3	$ 3.1

Stock-based Compensation - Re83

Stock-based Compensation - Restricted Stock Unit Awards - Additional Disclosures (Details) - Restricted Stock Unit Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock-based Compensation
Weighted average grant date fair value (in dollars per share)	$ 2.32	$ 3.67	$ 8.81
Awards (in shares)	2,394,290
Unrecognized expenses	$ 5.3
Weighted-average remaining recognition period (in years)	2 years

Stock-based Compensation - Perf

Stock-based Compensation - Performance Share Unit Awards - General Information (Details) - Performance Share Unit Awards	12 Months Ended
	Dec. 31, 2017
Stock-based Compensation
Vesting term	3 years
Class A common stock
Stock-based Compensation
Exchangeable ratio of vested performance unit (as a percent)	1
Class A common stock | Minimum
Stock-based Compensation
Number of shares of common stock issuable upon vesting of the performance unit awards (as a percent)	0.00%
Class A common stock | Maximum
Stock-based Compensation
Number of shares of common stock issuable upon vesting of the performance unit awards (as a percent)	200.00%

Stock-based Compensation - Pe85

Stock-based Compensation - Performance Share Unit Awards - Activity (Details) - Performance Share Unit Awards - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Awards
Unvested at the beginning (in shares)	942,073
Adjustment (in shares)	63,712
Granted (in shares)	519,562
Forfeited (in shares)	(274,524)
Vested (in shares)	(293,645)
Unvested at the end (in shares)	957,178	942,073
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning (in dollars per share)	$ 6.25
Granted (in dollars per share)	2.24	$ 4.37	$ 9.51
Forfeited (in dollars per share)	5.29
Vested (in dollars per share)	8.22
Unvested at the end (in dollars per share)	$ 4.64	$ 6.25

Stock-based Compensation - Pe86

Stock-based Compensation - Performance Share Unit Awards - Preferred Stock Dividends (Details) - shares	Nov. 15, 2017	Aug. 15, 2017	May 15, 2017
Performance Share Unit Awards
Stock-based Compensation
Dividends Preferred Stock Stock Shares Declared Per Unvested LTIP Unit	0.018867	0.021931	0.002195

Stock-based Compensation - Pe87

Stock-based Compensation - Performance Share Unit Awards - Vesting (Details) - Performance Share Unit Awards - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock-based Compensation
Vested restricted shares (in shares)	293,645
Estimated final value upon vesting	$ 0.2	$ 0.8	$ 0

Stock-based Compensation - Pe88

Stock-based Compensation - Performance Share Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
General and administrative expenses | Performance Share Unit Awards
Stock compensation expense
Stock compensation expense	$ 1.5	$ 2.7	$ 2.6

Stock-based Compensation - Pe89

Stock-based Compensation - Performance Share Unit Awards - Additional Disclosures (Details) - Performance Share Unit Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock-based Compensation
Weighted average grant date fair value (in dollars per share)	$ 2.24	$ 4.37	$ 9.51
Unrecognized expenses	$ 1.5
Weighted-average remaining recognition period (in years)	1 year 6 months

Stock-based Compensation - Pe90

Stock-based Compensation - Performance Share Unit Awards - Assumptions - Tabular Disclosure (Details) - Performance Share Unit Awards	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock-based Compensation
Forecast period (years)	2 years 8 months 16 days	2 years 7 months 6 days	2 years 8 months 1 day
Risk-free interest rate (as a percent)	1.34%	1.00%	0.79%
Jones stock price volatility (as a percent)	78.93%	71.47%	52.87%

Stock-based Compensation - Pe91

Stock-based Compensation - Performance Share Unit Awards - Assumptions - Additional Information(Details) - Performance Share Unit Awards	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock-based Compensation
Average historical combined volatilities for the Company and each peer company (as a percent)	39.97%	70.45%	55.13%
Expected percentage of performance share units earned (as a percent)	97.25%	123.84%	101.61%

Stock-based Compensation - Pe92

Stock-based Compensation - Performance Unit Awards - General Information (Details) - Performance Unit Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Stock-based Compensation
Performance period (in years)	3 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grant Date Fair Value Adjusted for Forfeitures	$ 0.3	$ 1.1
Fair value	$ 0.1	$ 0.1
Minimum
Stock-based Compensation
Vested (in dollars per share)	$ 0
Maximum
Stock-based Compensation
Vested (in dollars per share)	$ 200

Stock-based Compensation - Pe93

Stock-based Compensation - Performance Unit Awards - Assumptions (Details) - Performance Unit Awards	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Stock-based Compensation
Forecast period (years)	2 years 8 months 16 days	2 years 7 months 6 days
Risk-free interest rate (as a percent)	1.34%	1.00%
Jones stock price volatility (as a percent)	78.93%	71.47%

Stock-based Compensation - Pe94

Stock-based Compensation - Performance Unit Awards - Expected Payout (Details) - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Performance Unit Awards
Stock-based Compensation
Expected payout per unit as of the grant date (in dollars per share)	$ 28.25	$ 67.38

Stock-based Compensation - Pe95

Stock-based Compensation - Performance Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Performance Unit Awards | General and administrative expenses
Stock-based Compensation
Stock compensation expense	$ 0.2	$ 0.3

Stock-based Compensation - Pe96

Stock-based Compensation - Performance Unit Awards - Additional Disclosures (Details) - Performance Unit Awards $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)
Stock-based Compensation
Unrecognized expenses	$ 0.1
Weighted-average remaining recognition period (in years)	1 year 4 months 24 days

Stock-based Compensation - Re97

Stock-based Compensation - Restricted Stock Awards - General Information (Details)	12 Months Ended
	Dec. 31, 2017
Restricted Stock Awards
Stock-based Compensation
Service period from date of grant	1 year

Stock-based Compensation - Re98

Stock-based Compensation - Restricted Stock Awards - Activity (Details) - Restricted Stock Awards - $ / shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Awards
Unvested at the beginning (in shares)	152,050
Adjustment (in shares)	7,749
Granted (in shares)	180,000
Vested (in shares)	(152,380)
Unvested at the end (in shares)	187,419	152,050
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning (in dollars per share)	$ 3.68
Granted (in dollars per share)	2.25	$ 3.68	$ 6.71
Vested (in dollars per share)	3.67
Unvested at the end (in dollars per share)	$ 2.16	$ 3.68

Stock-based Compensation - Re99

Stock-based Compensation - Restricted Stock Awards - Preferred Stock Dividends (Details) - shares	Nov. 15, 2017	Aug. 15, 2017	May 15, 2017
Restricted Stock Awards
Stock-based Compensation
Dividends Preferred Stock Stock Shares Declared Per Unvested LTIP Unit	0.018867	0.021931	0.002195

Stock-based Compensation - R100

Stock-based Compensation - Restricted Stock Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
General and administrative expenses | Restricted Stock Awards
Stock compensation expense
Stock compensation expense	$ 0.4	$ 0.6	$ 0.6

Stock-based Compensation - R101

Stock-based Compensation - Restricted Stock Awards - Additional Disclosures (Details) - Restricted Stock Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock-based Compensation
Weighted average grant date fair value (in dollars per share)	$ 2.25	$ 3.68	$ 6.71
Unrecognized expenses	$ 0.2
Weighted-average remaining recognition period (in years)	4 months 24 days

Stock-based Compensation - Tax

Stock-based Compensation - Tax Benefit (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Associated tax benefit	$ 1.6	$ 1.4	$ 1.1

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Benefit Plans
Total expense relating to plans	$ 0.4	$ 0.4	$ 0.5

Income Taxes - Tax Reform Legis

Income Taxes - Tax Reform Legislation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes
Statutory rate (as a percent)		35.00%	35.00%	35.00%
Tax benefit		$ 17.2
Reduction of the TRA liability		$ 59.5
Forecast
Income Taxes
Statutory rate (as a percent)	21.00%

Income Taxes - Tax Provision -

Income Taxes - Tax Provision - Current and Deferred (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Current tax expense (benefit):
Federal	$ (3,555)	$ 3,758
State	(30)	223	$ 113
Total current expense (benefit)	(3,585)	3,981	113
Deferred tax expense (benefit):
Federal	(46,917)	(27,245)	(1,137)
State	(165)	(522)	(1,757)
Total deferred expense (benefit)	(47,082)	(27,767)	(2,894)
Total income tax provision (benefit)	$ (50,667)	$ (23,786)	$ (2,781)

Income Taxes - Tax Provision106

Income Taxes - Tax Provision - Attributable to Controlling Interests and Non-controlling Interests (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Tax provision
Income tax provision (benefit)	$ (50,667)	$ (23,786)	$ (2,781)
Jones Energy, Inc.
Tax provision
Income tax provision (benefit)	(50,422)	(23,263)	(1,160)
Non-controlling Interest
Tax provision
Income tax provision (benefit)	$ (245)	$ (523)	$ (1,621)

Income Taxes - Statutory Rate (

Income Taxes - Statutory Rate (Details)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes
Statutory rate (as a percent)	35.00%	35.00%	35.00%

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of the Provision for Income Taxes - Tabular Disclosure (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Provision calculated at federal statutory income tax rate:
Net income before taxes	$ (229,490)	$ (108,591)	$ (11,858)
Statutory rate (as a percent)	35.00%	35.00%	35.00%
Income tax expense (benefit) computed at statutory rate	$ (80,322)	$ (38,007)	$ (4,150)
Less: Non-controlling interests	27,152	14,972	2,911
Income tax expense (benefit) attributable to controlling interests	(53,170)	(23,035)	(1,239)
State and local income taxes, net of federal benefit	(4,692)	(622)	(1,011)
IRC Section 382 limitation	41,653
Reduction of TRA liability		(282)	(694)
Equity compensation, shortfall			338
Change in enacted rate	(38,040)		(650)
Change in valuation allowance	4,302	950	2,333
Other	(475)	(274)	(237)
Tax expense (benefit) attributable to controlling interests	(50,422)	(23,263)	(1,160)
Tax expense attributable to non-controlling interests	(245)	(523)	(1,621)
Total income tax provision (benefit)	$ (50,667)	$ (23,786)	$ (2,781)

Income Taxes - Reconciliatio109

Income Taxes - Reconciliation of the Provision for Income Taxes - Additional Information (Details)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes
Statutory rate (as a percent)		35.00%	35.00%	35.00%
Forecast
Income Taxes
Statutory rate (as a percent)	21.00%

Income Taxes - Tax Reform Le110

Income Taxes - Tax Reform Legislation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes
Statutory rate (as a percent)		35.00%	35.00%	35.00%
Tax benefit, net of valuation allowance		$ 17.2
Tax benefit, Tax Receivable Agreement		$ 20.8
Forecast
Income Taxes
Statutory rate (as a percent)	21.00%

Income Taxes - State Tax Rate (

Income Taxes - State Tax Rate (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Income Taxes
Texas franchise tax rate (as a percent)	0.75%	1.00%
Benefit from revaluing deferred tax assets at the newly enacted rate	$ 1.7
Benefit from revaluing deferred tax assets at the newly enacted rate, non-controlling interest	$ 1

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Deferred Tax Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Deferred tax assets
Net operating loss	$ 13,381	$ 8,687
Section 754 election tax basis adjustment	78,623	51,154
State deferred tax asset	220
Total deferred tax assets	92,224	59,841
Deferred tax liabilities
Investment in consolidated subsidiary JEH	93,974	56,888
Noncurrent state deferred tax liability	2,281	2,703
Total deferred tax liabilities	96,255	59,591
Net deferred tax assets (liabilities)	(4,031)	250
Valuation allowance	(10,250)	(3,155)
Net deferred tax assets (liabilities)	$ (14,281)	$ (2,905)

Income Taxes - Net Operating Lo

Income Taxes - Net Operating Loss Carry-forward (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes
Valuation allowance		$ 10.2	$ 3.2
Deferred tax assets, net operating loss carryforwards		$ 13.8
Statutory rate (as a percent)		35.00%	35.00%	35.00%
Federal
Income Taxes
Net operating loss carry-forward		$ 53
Operating loss carryforward, valuation allowance		2.4
State
Income Taxes
Net operating loss carry-forward		47.4
Operating loss carryforward, valuation allowance		$ 2.4
Forecast
Income Taxes
Statutory rate (as a percent)	21.00%

Income Taxes - Tax Receivable A

Income Taxes - Tax Receivable Agreement (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Tax Receivable Agreement
Cash savings percentage (as a percent)		85.00%
Benefits of cash savings retained under tax receivable agreement (as a percent)		15.00%
Statutory rate (as a percent)		35.00%	35.00%	35.00%
Reduction of the TRA liability		$ 59,500
Gross liability under tax receivable agreement		69,900	$ 45,700
Increase (decrease) in TRA liability due to valuation allowance recorded		(8,700)	(2,700)
Liability under tax receivable agreement		59,596	43,045
Valuation allowance		72,300	$ 50,600
TRA liability cash savings, payment		1,600
Other current liabilities
Tax Receivable Agreement
Liability under tax receivable agreement		$ 1,600
Forecast
Tax Receivable Agreement
Statutory rate (as a percent)	21.00%

Income Taxes - Cash Tax Distrib

Income Taxes - Cash Tax Distributions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Cash Tax Distributions
Cash tax distributions	$ 1.7	$ 41
Cash tax distributions, JEH to the Company	1.1	23.7
Cash tax distributions, JEH to Class B shareholders	$ 0.6	$ 17.3

Stockholders' and Mezzanine 116

Stockholders' and Mezzanine equity - Common Stock (Details)	12 Months Ended
	Dec. 31, 2017class
Common Stock
Number of classes of common stock	2
Pre-IPO owners of JEH
Common Stock
Ratio in which JEH Units and Class B common stock are exchanged for Class A common stock	1
Class B common stock
Common Stock
Economic interests/rights (as a percent)	0.00%
Votes per share entitled to holders	1

Stockholders' and Mezzanine 117

Stockholders' and Mezzanine equity - Series A Perpetual Convertible Preferred Stock (Details)	Oct. 09, 2017	Jul. 13, 2017	Apr. 17, 2017	Jan. 19, 2017	Aug. 25, 2016
Series A preferred stock
Series A Perpetual Convertible Preferred Stock
Dividend rate (as a percent)	8.00%	8.00%	8.00%	8.00%	8.00%

Stockholders' and Mezzanine 118

Stockholders' and Mezzanine equity - Equity Distribution Agreement (Details) - USD ($) $ in Thousands, shares in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	May 24, 2016
Common Stock
Proceeds from sale of common stock	$ 8,333	$ 65,446	$ 122,779
Class A common stock
Common Stock
Offering price to sell common stock shares under Equity Distribution Agreement				$ 73,000
Sale of common stock (in shares)	3.7
Proceeds from sale of common stock	$ 8,400
Gross proceeds from sale of common stock	8,700
Commissions and professional services expenses	300
Aggregate offering proceeds remained available to be issued and sold under the Equity Distribution Agreement	$ 62,200

Stockholders' and Mezzanine 119

Stockholders' and Mezzanine equity - Offering of Class A Common Stock (Details) - USD ($) $ in Thousands	Sep. 12, 2016	Aug. 25, 2016	Sep. 12, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Common Stock
Proceeds from sale of common stock				$ 8,333	$ 65,446	$ 122,779
Class A common stock
Common Stock
Shares issued				3,700,000
Proceeds from sale of common stock				$ 8,400
Class A common stock | Common stock underwriting agreement
Common Stock
Shares issued		21,000,000
Proceeds from sale of common stock			$ 64,000
Class A common stock | Over-Allotment Option
Common Stock
Shares issued	3,150,000

Stockholders' and Mezzanine 120

Stockholders' and Mezzanine equity - Mezzanine Equity - General Information (Details) $ / shares in Units, $ in Thousands	Oct. 09, 2017$ / shares	Jul. 13, 2017$ / shares	Apr. 17, 2017$ / shares	Jan. 19, 2017$ / shares	Aug. 25, 2016USD ($)$ / sharesshares	Dec. 31, 2017item	Dec. 31, 2016USD ($)
Series A Perpetual Convertible Preferred Stock
Net proceeds from offering | $							$ 87,988
Series A preferred stock
Series A Perpetual Convertible Preferred Stock
Shares issued (in shares) | shares					1,840,000
Net proceeds from offering | $					$ 88,300
Dividend rate (as a percent)	8.00%	8.00%	8.00%	8.00%	8.00%
Liquidation preference (in dollars per share) | $ / shares	$ 50	$ 50	$ 50	$ 50	$ 50
Conversion ratio					17.0683
Equivalent conversion price (in dollars per share) | $ / shares					$ 2.93
Shares issuable upon conversion | shares					31,400,000
Conversion threshold (as a percent)						175.00%
Minimum number of trading days | item						20
Consecutive trading days						30 days

Stockholders' and Mezzanine 121

Stockholders' and Mezzanine equity - Mezzanine Equity - Tabular Disclosure (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)
Mezzanine equity
Mezzanine equity at the beginning of period	$ 88,975
Accretion on preferred stock	564
Mezzanine equity at the end of period	$ 89,539

Stockholders' and Mezzanine 122

Stockholders' and Mezzanine equity - Preferred Stock Dividend and Special Stock Dividend (Details) - USD ($) $ / shares in Units, $ in Millions	Oct. 09, 2017	Jul. 13, 2017	Apr. 17, 2017	Jan. 19, 2017	Aug. 25, 2016	Mar. 31, 2017	Dec. 31, 2017
Special Stock Dividend Declared
Distributions from JEH						$ 17.5
Series A preferred stock
Preferred Stock Dividend Declared
Dividend rate (as a percent)	8.00%	8.00%	8.00%	8.00%	8.00%
Liquidation preference (in dollars per share)	$ 50	$ 50	$ 50	$ 50	$ 50
Dividend declared (in dollars per share)	$ 1	$ 1	1	$ 1
Dividend declared, cash portion (in dollars per share)			0.83
Dividend declared, common stock portion (in dollars per share)			$ 0.17
Average volume-weighted price per share percentage (as a percent)	95.00%	95.00%	95.00%
Average volume-weighted price per share percentage, consecutive days	5 days	5 days	5 days
Class A common stock
Special Stock Dividend Declared
Special stock dividend declared per share (in shares)						0.087423
Volume weighted average price per share, period							5 days
JEH
Special Stock Dividend Declared
Number of additional common units purchased							4,999,927
JEH
Special Stock Dividend Declared
Share price (in dollars per share)							$ 3.50

Earnings per Share - Anti-dilut

Earnings per Share - Anti-dilutive Securities (Details) - shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Restricted Stock Unit Awards
Earnings per Share
Antidilutive securities (in shares)	2,762,738	1,359,088	823,446
Performance Share Unit Awards
Earnings per Share
Antidilutive securities (in shares)	1,250,822	1,125,706	586,325
Class B common stock
Earnings per Share
Economic interests/rights (as a percent)	0.00%
Series A preferred stock
Earnings per Share
Antidilutive securities (in shares)	31,405,587	31,405,762

Earnings per Share - Basic Earn

Earnings per Share - Basic Earnings per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income (numerator):
Net income (loss) attributable to controlling interests		$ (101,492)	$ (42,552)	$ (2,381)
Less: Dividends and accretion on preferred stock		(7,924)	(2,669)
Net income (loss) attributable to common shareholders		$ (109,416)	$ (45,221)	$ (2,381)
Weighted-average shares (denominator):
Weighted-average number of shares of Class A common stock - basic (in shares)	[1]	72,411	43,506	29,161
Weighted-average number of shares of Class A common stock - diluted (in shares)	[1]	72,411	43,506	29,161
Earnings (loss) per share:
Basic - Net income (loss) attributable to common shareholders (in dollars per share)	[1]	$ (1.51)	$ (1.04)	$ (0.08)
Diluted - Net income (loss) attributable to common shareholders (in dollars per share)	[1]	$ (1.51)	$ (1.04)	$ (0.08)
[1]	All share and earnings per share information presented has been recast to retrospectively adjust for the effects of the 0.087423 per share Special Stock Dividend, as defined in Note 12, “Stockholders’ and Mezzanine equity”, distributed on March 31, 2017.

Earnings per Share - Additional

Earnings per Share - Additional Information (Details)	Mar. 31, 2017shares
Class A common stock
Special Stock Dividend Declared
Special stock dividend declared per share (in shares)	0.087423

Related Parties - Natural Gas S

Related Parties - Natural Gas Sale and Purchase Agreement with Monarch Natural Gas, LLC (Details) $ in Thousands	Sep. 01, 2013	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)MMBoe	Dec. 31, 2014USD ($)MMBoe
Related Party Transactions
Oil and gas sales		$ 186,393	$ 124,877	$ 194,555
Enable Midstream Partners LP
Related Party Transactions
Initial term of the agreement (in years)	10 years
Investee | Monarch Natural Gas, LLC
Related Party Transactions
Production of natural gas and NGLs (in MMBoe) | MMBoe				1	1.4
Oil and gas sales				$ 10,600	$ 37,000

Related Parties - Metalmark Cap

Related Parties - Metalmark Capital and Monarch Natural Gas, LLC (Details) - director	May 07, 2013	Dec. 31, 2017
Monarch Natural Gas, LLC | Investee | Metalmark
Related Party Transactions
Metalmark Capital's ownership percentage in Monarch (as a percent)	81.00%
Metalmark | Beneficial owner
Related Party Transactions
Number of directors who are managing directors of the related party		2
Minimum | Metalmark | Beneficial owner
Related Party Transactions
Beneficial ownership interest (as a percent)		5.00%

Related Parties - Monarch Natur

Related Parties - Monarch Natural Gas, LLC Equity Interests (Details) - Monarch Natural Gas, LLC - Investee - USD ($) $ in Millions	May 07, 2013	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Related Party Transactions
Estimated fair value of equity interests issued to the entity	$ 15
Amortization of deferred revenue		$ 1.9	$ 2.4	$ 2
Value of equity interests from related party	15
Value of equity interests assigned to Jonny Jones	2.4
Value of equity interests reserved for future distribution through an incentive 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
Equity interests distributed to management		0.3	0.6	0.8
Stock compensation expense		0.4	$ 0.5	$ 0.5
Other assets
Related Party Transactions
Estimated fair value of equity interests issued to the entity		$ 0.4

Related Parties - Transportatio

Related Parties - Transportation Agreement with Monarch Oil Pipeline LLC (Details) $ in Thousands	Sep. 01, 2013	May 07, 2013	May 31, 2015USD ($)	Sep. 30, 2014	Mar. 31, 2017USD ($)	Dec. 31, 2017USD ($)MMBoedirector	Dec. 31, 2016USD ($)MMBoe	Dec. 31, 2015USD ($)MMBoe	Dec. 31, 2014USD ($)MMBoe
Related Party Transactions
Oil and gas sales						$ 186,393	$ 124,877	$ 194,555
Cash distributions associated with equity interests					$ 17,500
Monarch Oil Pipeline LLC | Investee
Related Party Transactions
Oil production transported (in MMBoe) | MMBoe						1.1	1.3	0.2
Term of Oil Gathering and Transportation Agreement (in years)				10 years
Gathering fees						$ 2,300	$ 2,700	$ 400
Monarch Natural Gas, LLC | Investee
Related Party Transactions
Oil production transported (in MMBoe) | MMBoe								1	1.4
Oil and gas sales								$ 10,600	$ 37,000
Cash distributions associated with equity interests			$ 700
Enable Midstream Partners LP
Related Party Transactions
Initial term of the agreement (in years)	10 years
Metalmark | Beneficial owner
Related Party Transactions
Number of directors who are managing directors of the related party | director						2
Metalmark | Monarch Natural Gas, LLC | Investee
Related Party Transactions
Metalmark Capital's ownership percentage in Monarch (as a percent)		81.00%
Minimum | Metalmark | Beneficial owner
Related Party Transactions
Beneficial ownership interest (as a percent)						5.00%

Related Parties - Purchase of S

Related Parties - Purchase of Senior Notes (Details) - USD ($) $ in Thousands	Feb. 29, 2016	Dec. 31, 2016
Senior Unsecured Notes
Purchased amount		$ 84,589
Gain on debt extinguishment		99,530
Magnetar Capital and Affiliates | Minimum | Beneficial owner
Senior Unsecured Notes
Beneficial ownership interest (as a percent)	5.00%
Blackstone Group Management L.L.C. and Affiliates | Minimum | Beneficial owner
Senior Unsecured Notes
Beneficial ownership interest (as a percent)	5.00%
Senior notes
Senior Unsecured Notes
Aggregate principal amount repurchased		190,900
Gain on debt extinguishment		99,500
2023 Notes | Senior notes | Beneficial owner
Senior Unsecured Notes
Aggregate principal amount repurchased	$ 100,000
Purchased amount		$ 46,500
Gain on debt extinguishment	48,300
2023 Notes | Senior notes | Magnetar Capital and Affiliates | Beneficial owner
Senior Unsecured Notes
Aggregate principal amount repurchased	50,000
Purchased amount	23,300
2023 Notes | Senior notes | Blackstone Group Management L.L.C. and Affiliates | Beneficial owner
Senior Unsecured Notes
Aggregate principal amount repurchased	50,000
Purchased amount	$ 23,300

Related Parties - Issuance of C

Related Parties - Issuance of Class A Shares (Details) - Class A common stock - USD ($) $ in Millions	Aug. 25, 2016	Dec. 31, 2017	Mar. 31, 2017
Common Stock
Sale of common stock (in shares)		3,700,000
Special stock dividend declared per share (in shares)			0.087423
Gross proceeds from sale of common stock		$ 8.7
JVL | Beneficial owner
Common Stock
Sale of common stock (in shares)	9,025,270
Gross proceeds from sale of common stock	$ 25
Underwriting discounts and commissions	$ 1.1
Minimum | JVL | Beneficial owner
Common Stock
Beneficial ownership interest (as a percent)	5.00%
Ownership percentage (as a percent)	15.00%
Maximum | Beneficial owner
Common Stock
Ownership percentage (as a percent)	19.90%

Related Parties - Issuance of S

Related Parties - Issuance of Series A Preferred Stock (Details)	Oct. 09, 2017	Jul. 13, 2017	Apr. 17, 2017	Jan. 19, 2017	Aug. 25, 2016USD ($)directorshares	Dec. 31, 2016USD ($)
Series A Perpetual Convertible Preferred Stock
Proceeds from sale of preferred stock						$ 87,988,000
Minimum | Metalmark | Beneficial owner
Series A Perpetual Convertible Preferred Stock
Beneficial ownership interest (as a percent)					5.00%
Series A preferred stock
Series A Perpetual Convertible Preferred Stock
Dividend rate (as a percent)	8.00%	8.00%	8.00%	8.00%	8.00%
Shares issued (in shares) | shares					1,840,000
Proceeds from sale of preferred stock					$ 88,300,000
Series A preferred stock | Director
Series A Perpetual Convertible Preferred Stock
Number of directors who are managing directors of the related party | director					2
Shares issued (in shares) | shares					200,000
Proceeds from sale of preferred stock					$ 10,000,000
Underwriting discounts and commissions					$ 400,000

Related Parties - Amended and R

Related Parties - Amended and Restated Registration Rights and Stockholders Agreement (Details)	Dec. 31, 2017USD ($)
Related Party Transactions
Anticipated aggregate maximum offering price	$ 50,000,000
Anticipated aggregate maximum offering price for S3 registration	$ 25,000,000

Commitments and Contingencies -

Commitments and Contingencies - Leased Space (Details)	Dec. 31, 2017ft²
Office space in Austin, TX
Lease obligations
Leased area of office space (in square feet)	43,000
Office space in Oklahoma City, Oklahoma
Lease obligations
Leased area of office space (in square feet)	9,000

Commitments and Contingencie135

Commitments and Contingencies - Future Minimum Payments (Details) $ in Thousands	Dec. 31, 2017USD ($)
Future minimum payments for noncancellable operating leases
2,018	$ 1,300
2,019	1,311
2,020	562
Total	$ 3,173

Commitments and Contingencie136

Commitments and Contingencies - Rent Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Commitments and Contingencies Disclosure [Abstract]
Rent expense under operating leases	$ 1.8	$ 1.6	$ 1.6

Commitments and Contingencie137

Commitments and Contingencies - Litigation (Details) - Surface Rights Use Violation Case - USD ($) $ in Millions	3 Months Ended
	Jun. 30, 2017	Jun. 30, 2016
Litigation
Accrued liability on settlement offer		$ 1.5
General and administrative expenses
Litigation
Additional charge	$ 1.4

Subsequent Events - Preferred S

Subsequent Events - Preferred Stock Dividend Declared (Details) - Series A preferred stock - $ / shares	Jan. 11, 2018	Oct. 09, 2017	Jul. 13, 2017	Apr. 17, 2017	Jan. 19, 2017	Aug. 25, 2016
Preferred Stock Dividend Declared
Dividend rate (as a percent)		8.00%	8.00%	8.00%	8.00%	8.00%
Liquidation preference (in dollars per share)		$ 50	$ 50	$ 50	$ 50	$ 50
Dividend declared (in dollars per share)		$ 1	$ 1	$ 1	$ 1
Average volume-weighted price per share percentage (as a percent)		95.00%	95.00%	95.00%
Average volume-weighted price per share percentage, consecutive days		5 days	5 days	5 days
Subsequent Event
Preferred Stock Dividend Declared
Dividend rate (as a percent)	8.00%
Liquidation preference (in dollars per share)	$ 50
Dividend declared (in dollars per share)	$ 1
Average volume-weighted price per share percentage (as a percent)	95.00%
Average volume-weighted price per share percentage, consecutive days	5 days

Subsequent Events - Senior Secu

Subsequent Events - Senior Secured First Lien Notes Due 2023 (Details) - USD ($) $ in Millions	Feb. 14, 2018	Feb. 23, 2015
2023 Notes | Senior notes
Senior Secured Notes
Discount of principal amount (as a percent)		94.59%
Issuance of debt		$ 250
2023 Notes | Subsequent Event | Senior notes
Senior Secured Notes
Discount of principal amount (as a percent)	97.526%
Issuance of debt	$ 450
Revolver | Subsequent Event | Line of credit | Revolving credit facility
Senior Secured Notes
Outstanding borrowings under the Revolver	25
Investee | 2023 Notes | Subsequent Event | Senior notes
Senior Secured Notes
Issuance of debt	$ 45

Subsequent Events - Amendment t

Subsequent Events - Amendment to Revolving Credit Facility (Details) - Revolver - Line of credit - Revolving credit facility - USD ($) $ in Millions	Feb. 14, 2018	Nov. 26, 2017	Aug. 01, 2017	May 15, 2017
Other Long-Term Debt
Borrowing base		$ 350	$ 375	$ 425
Subsequent Event
Other Long-Term Debt
Debt issuance principal permitted under terms of revolver	$ 700
Borrowing base	$ 50

Subsidiary Guarantors - General

Subsidiary Guarantors - General Information (Details) - JEH	12 Months Ended
	Dec. 31, 2017subsidiary
Subsidiary Guarantors
Immaterial subsidiaries	2
Guarantor Subsidiaries
Subsidiary Guarantors
Ownership percentage in subsidiary guarantors (as a percent)	100.00%

Subsidiary Guarantors - Imprope

Subsidiary Guarantors - Improper Calculation - Condensed Consolidating Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Eliminations
Current assets
Intercompany receivable	$ (1,530,496)	$ (1,116,500)
Investment in subsidiaries	(358,966)	(984,600)
Current liabilities
Intercompany payable	(1,530,496)	(1,116,500)
Improper Calculation | Adjustment | Eliminations
Current assets
Intercompany receivable		80,000
Investment in subsidiaries		(453,200)
Current liabilities
Intercompany payable		453,200
Issuers
Current assets
Intercompany receivable	1,146,647	1,100,834
Investment in subsidiaries	116,349	453,237
Issuers | Improper Calculation | Adjustment
Current assets
Intercompany receivable		(80,000)
Investment in subsidiaries		453,200
Guarantor Subsidiaries
Current liabilities
Intercompany payable	$ 1,527,418	1,113,704
Guarantor Subsidiaries | Improper Calculation | Adjustment
Current liabilities
Intercompany payable		$ (453,200)

Subsidiary Guarantors - Impr143

Subsidiary Guarantors - Improper Calculation - Condensed Consolidating Statement of Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Eliminations
Condensed Consolidating Statement of Operations
Equity interest in income (loss)	$ 288,744	$ 109,375	$ 13,842
Improper Calculation | Adjustment | Eliminations
Condensed Consolidating Statement of Operations
Equity interest in income (loss)		(42,600)	(9,100)
Issuers
Condensed Consolidating Statement of Operations
Equity interest in income (loss)	$ (77,527)	(42,571)	(9,114)
Issuers | Improper Calculation | Adjustment
Condensed Consolidating Statement of Operations
Equity interest in income (loss)		$ 42,600	$ 9,100

Subsidiary Guarantors - Impr144

Subsidiary Guarantors - Improper Calculation - Condensed Consolidating Statement of Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities
Adjustments to reconcile net income (loss) to net cash provided by operating activities	$ 237,831	$ 110,505	$ 77,926
Eliminations
Cash flows from operating activities
Adjustments to reconcile net income (loss) to net cash provided by operating activities	(288,744)	(109,375)	(13,842)
Improper Calculation | Adjustment | Eliminations
Cash flows from operating activities
Adjustments to reconcile net income (loss) to net cash provided by operating activities		(42,600)	(9,100)
Issuers
Cash flows from operating activities
Adjustments to reconcile net income (loss) to net cash provided by operating activities	$ 52,870	(28,124)	(193,245)
Issuers | Improper Calculation | Adjustment
Cash flows from operating activities
Adjustments to reconcile net income (loss) to net cash provided by operating activities		$ 42,600	$ 9,100

Subsidiary Guarantors - Condens

Subsidiary Guarantors - Condensed Consolidating Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current assets
Cash	$ 19,472	$ 34,642
Accounts receivable, net
Oil and gas sales	34,492	26,568
Joint interest owners	31,651	5,267
Other	1,236	6,061
Commodity derivative assets	3,474	24,100
Other current assets	14,376	2,684
Total current assets	104,701	99,322
Oil and gas properties, net, at cost under the successful efforts method	1,597,040	1,743,588
Other property, plant and equipment, net	2,719	2,996
Commodity derivative assets	172	34,744
Other assets	5,431	6,050
Total assets	1,710,063	1,886,700
Current liabilities
Trade accounts payable	72,663	36,527
Oil and gas sales payable	31,462	28,339
Accrued liabilities	21,604	25,707
Commodity derivative liabilities	36,709	14,650
Other current liabilities	4,049	2,584
Total current liabilities	166,487	107,807
Long-term debt	759,316	724,009
Deferred revenue	5,457	7,049
Commodity derivative liabilities	8,788	1,209
Asset retirement obligations	19,652	19,458
Liability under tax receivable agreement	59,596	43,045
Other liabilities	811	792
Deferred tax liabilities	14,281	2,905
Total liabilities	1,034,388	906,274
Mezzanine equity
Series A preferred stock, $0.001 par value; 1,839,995 shares issued and outstanding at December 31, 2017 and 1,840,000 shares issued and outstanding at December 31, 2016	89,539	88,975
Stockholders' / members' equity
Treasury stock, at cost: 22,602 shares at December 31, 2017 and December 31, 2016	(358)	(358)
Additional paid-in-capital	606,319	447,137
Retained earnings (deficit)	(136,274)	(8,652)
Stockholders' equity	469,787	438,214
Non-controlling interest	116,349	453,237
Total stockholders’ equity	586,136	891,451	$ 936,852	$ 853,350
Total liabilities and stockholders' equity	1,710,063	1,886,700
Class A common stock
Stockholders' / members' equity
Common stock	90	57
Class B common stock
Stockholders' / members' equity
Common stock	10	30
Eliminations
Accounts receivable, net
Intercompany receivable	(1,530,496)	(1,116,500)
Total current assets	(1,530,496)	(1,116,500)
Investment in subsidiaries	(358,966)	(984,600)
Total assets	(1,889,462)	(2,101,100)
Current liabilities
Intercompany payable	(1,530,496)	(1,116,500)
Total current liabilities	(1,530,496)	(1,116,500)
Total liabilities	(1,530,496)	(1,116,500)
Stockholders' / members' equity
Members' equity	(475,315)	(1,437,837)
Stockholders' equity	(475,315)	(1,437,837)
Non-controlling interest	116,349	453,237
Total stockholders’ equity	(358,966)	(984,600)
Total liabilities and stockholders' equity	(1,889,462)	(2,101,100)
JEI (Parent)
Current assets
Cash	5,248	27,164
Accounts receivable, net
Other current assets	1,866
Intercompany receivable	383,849	15,666
Total current assets	390,963	42,830
Investment in subsidiaries	242,617	531,363
Total assets	633,580	574,193
Current liabilities
Trade accounts payable	138
Accrued liabilities	62	3,874
Other current liabilities	1,606
Total current liabilities	1,806	3,874
Liability under tax receivable agreement	59,596	43,045
Deferred tax liabilities	12,852	85
Total liabilities	74,254	47,004
Mezzanine equity
Series A preferred stock, $0.001 par value; 1,839,995 shares issued and outstanding at December 31, 2017 and 1,840,000 shares issued and outstanding at December 31, 2016	89,539	88,975
Stockholders' / members' equity
Treasury stock, at cost: 22,602 shares at December 31, 2017 and December 31, 2016	(358)	(358)
Additional paid-in-capital	606,319	447,137
Retained earnings (deficit)	(136,274)	(8,652)
Stockholders' equity	469,787	438,214
Total stockholders’ equity	469,787	438,214
Total liabilities and stockholders' equity	633,580	574,193
JEI (Parent) | Class A common stock
Stockholders' / members' equity
Common stock	90	57
JEI (Parent) | Class B common stock
Stockholders' / members' equity
Common stock	10	30
Issuers
Current assets
Cash	1,180	1,975
Accounts receivable, net
Other		5,434
Commodity derivative assets	3,474	24,100
Other current assets	358	422
Intercompany receivable	1,146,647	1,100,834
Total current assets	1,151,659	1,132,765
Commodity derivative assets	172	34,744
Other assets	4,427	5,265
Investment in subsidiaries	116,349	453,237
Total assets	1,272,607	1,626,011
Current liabilities
Trade accounts payable	247	13
Accrued liabilities	11,363	11,227
Commodity derivative liabilities	36,709	14,650
Other current liabilities	1,723	1,984
Total current liabilities	50,042	27,874
Long-term debt	759,316	724,009
Deferred revenue	5,457	7,049
Commodity derivative liabilities	8,788	1,209
Other liabilities	68	269
Deferred tax liabilities	1,429	2,820
Total liabilities	825,100	763,230
Stockholders' / members' equity
Members' equity	447,507	862,781
Stockholders' equity	447,507	862,781
Total stockholders’ equity	447,507	862,781
Total liabilities and stockholders' equity	1,272,607	1,626,011
Guarantor Subsidiaries
Current assets
Cash	13,024	5,483
Accounts receivable, net
Oil and gas sales	34,492	26,568
Joint interest owners	31,651	5,267
Other	1,236	627
Other current assets	12,152	2,262
Total current assets	92,555	40,207
Oil and gas properties, net, at cost under the successful efforts method	1,597,040	1,743,588
Other property, plant and equipment, net	2,192	2,378
Other assets	1,004	785
Total assets	1,692,791	1,786,958
Current liabilities
Trade accounts payable	72,278	36,514
Oil and gas sales payable	31,462	28,339
Accrued liabilities	10,172	10,597
Other current liabilities	720	600
Intercompany payable	1,527,418	1,113,704
Total current liabilities	1,642,050	1,189,754
Asset retirement obligations	19,652	19,458
Other liabilities	743	523
Total liabilities	1,662,445	1,209,735
Stockholders' / members' equity
Members' equity	30,346	577,223
Stockholders' equity	30,346	577,223
Total stockholders’ equity	30,346	577,223
Total liabilities and stockholders' equity	1,692,791	1,786,958
Non-Guarantor Subsidiaries
Current assets
Cash	20	20
Accounts receivable, net
Total current assets	20	20
Other property, plant and equipment, net	527	618
Total assets	547	638
Current liabilities
Accrued liabilities	7	9
Intercompany payable	3,078	2,796
Total current liabilities	3,085	2,805
Total liabilities	3,085	2,805
Stockholders' / members' equity
Members' equity	(2,538)	(2,167)
Stockholders' equity	(2,538)	(2,167)
Total stockholders’ equity	(2,538)	(2,167)
Total liabilities and stockholders' equity	$ 547	$ 638

Subsidiary Guarantors - Cond146

Subsidiary Guarantors - Condensed Consolidating Balance Sheet - Additional Information (Details) - $ / shares	Dec. 31, 2017	Dec. 31, 2016
Mezzanine equity
Series A preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Series A preferred stock, shares issued	1,839,995	1,840,000
Series A preferred stock, shares outstanding	1,839,995	1,840,000
Treasury stock
Treasury stock, shares	22,602	22,602
Class A common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	90,139,840	57,048,076
Common stock, shares outstanding	90,117,238	57,025,474
Class B common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	9,627,821	29,832,098
Common stock, shares outstanding	9,627,821	29,832,098
JEI (Parent)
Mezzanine equity
Series A preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Series A preferred stock, shares issued	1,839,995	1,840,000
Series A preferred stock, shares outstanding	1,839,995	1,840,000
Treasury stock
Treasury stock, shares	22,602	22,602
JEI (Parent) | Class A common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	90,139,840	57,048,076
Common stock, shares outstanding	90,117,238	57,025,474
JEI (Parent) | Class B common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	9,627,821	29,832,098
Common stock, shares outstanding	9,627,821	29,832,098

Subsidiary Guarantors - Cond147

Subsidiary Guarantors - Condensed Consolidating Statement of Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating revenues
Oil and gas sales	$ 186,393	$ 124,877	$ 194,555
Other revenues	2,180	2,970	2,844
Total operating revenues	188,573	127,847	197,399
Operating costs and expenses
Lease operating	36,636	32,640	41,027
Production and ad valorem taxes	6,874	7,768	12,130
Exploration	14,145	6,673	6,551
Depletion, depreciation and amortization	167,224	153,930	205,498
Impairment of oil and gas properties	149,648
Accretion of ARO liability	960	1,263	1,087
General and administrative	29,892	29,640	33,388
Other operating		199	4,188
Total operating expenses	405,379	232,113	303,869
Operating income (loss)	(216,806)	(104,266)	(106,470)
Other income (expense)
Interest expense	(51,651)	(53,127)	(64,458)
Gain on debt extinguishment		99,530
Net gain (loss) on commodity derivatives	(17,985)	(51,264)	158,753
Other income (expense)	56,952	536	317
Other income (expense), net	(12,684)	(4,325)	94,612
Income (loss) before income tax	(229,490)	(108,591)	(11,858)
Income tax provision (benefit)	(50,667)	(23,786)	(2,781)
Net income (loss)	(178,823)	(84,805)	(9,077)
Net income (loss) attributable to non-controlling interests	(77,331)	(42,253)	(6,696)
Net income (loss) attributable to controlling interests	(101,492)	(42,552)	(2,381)
Dividends and accretion on preferred stock	(7,924)	(2,669)
Net income (loss) attributable to common shareholders	(109,416)	(45,221)	(2,381)
Eliminations
Other income (expense)
Equity interest in income (loss)	288,744	109,375	13,842
Net income (loss)	288,744	109,375	13,842
Net income (loss) attributable to non-controlling interests	(77,331)	(42,253)	(6,696)
Net income (loss) attributable to controlling interests	366,075	151,628	20,538
Net income (loss) attributable to common shareholders	366,075	151,628	20,538
JEI (Parent)
Operating costs and expenses
General and administrative	237
Total operating expenses	237
Operating income (loss)	(237)
Other income (expense)
Other income (expense)	59,492	784	1,984
Other income (expense), net	59,492	784	1,984
Income (loss) before income tax	59,255	784	1,984
Equity interest in income (loss)	(211,217)	(66,804)	(4,728)
Income tax provision (benefit)	(50,470)	(23,468)	(363)
Net income (loss)	(101,492)	(42,552)	(2,381)
Net income (loss) attributable to controlling interests	(101,492)	(42,552)	(2,381)
Dividends and accretion on preferred stock	(7,924)	(2,669)
Net income (loss) attributable to common shareholders	(109,416)	(45,221)	(2,381)
Issuers
Operating revenues
Other revenues	1,854	2,384	1,960
Total operating revenues	1,854	2,384	1,960
Operating costs and expenses
General and administrative	10,146	12,028	13,565
Total operating expenses	10,146	12,028	13,565
Operating income (loss)	(8,292)	(9,644)	(11,605)
Other income (expense)
Interest expense	(52,016)	(53,080)	(63,160)
Gain on debt extinguishment		99,530
Net gain (loss) on commodity derivatives	(17,985)	(51,264)	158,753
Other income (expense)	(93)	(321)	(1,663)
Other income (expense), net	(70,094)	(5,135)	93,930
Income (loss) before income tax	(78,386)	(14,779)	82,325
Equity interest in income (loss)	(77,527)	(42,571)	(9,114)
Income tax provision (benefit)	(197)	(318)	(2,418)
Net income (loss)	(155,716)	(57,032)	75,629
Net income (loss) attributable to controlling interests	(155,716)	(57,032)	75,629
Net income (loss) attributable to common shareholders	(155,716)	(57,032)	75,629
Guarantor Subsidiaries
Operating revenues
Oil and gas sales	186,393	124,877	194,555
Other revenues	326	586	884
Total operating revenues	186,719	125,463	195,439
Operating costs and expenses
Lease operating	36,636	32,640	41,027
Production and ad valorem taxes	6,874	7,768	12,130
Exploration	14,145	6,673	6,551
Depletion, depreciation and amortization	167,133	153,843	205,407
Impairment of oil and gas properties	149,648
Accretion of ARO liability	960	1,263	1,087
General and administrative	19,226	17,244	19,707
Other operating		199	4,188
Total operating expenses	394,622	219,630	290,097
Operating income (loss)	(207,903)	(94,167)	(94,658)
Other income (expense)
Interest expense	365	(47)	(1,298)
Other income (expense)	(2,447)	73	(4)
Other income (expense), net	(2,082)	26	(1,302)
Income (loss) before income tax	(209,985)	(94,141)	(95,960)
Net income (loss)	(209,985)	(94,141)	(95,960)
Net income (loss) attributable to controlling interests	(209,985)	(94,141)	(95,960)
Net income (loss) attributable to common shareholders	(209,985)	(94,141)	(95,960)
Non-Guarantor Subsidiaries
Operating costs and expenses
Depletion, depreciation and amortization	91	87	91
General and administrative	283	368	116
Total operating expenses	374	455	207
Operating income (loss)	(374)	(455)	(207)
Other income (expense)
Income (loss) before income tax	(374)	(455)	(207)
Net income (loss)	(374)	(455)	(207)
Net income (loss) attributable to controlling interests	(374)	(455)	(207)
Net income (loss) attributable to common shareholders	$ (374)	$ (455)	$ (207)

Subsidiary Guarantors - Cond148

Subsidiary Guarantors - Condensed Consolidating Statement of Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities
Net income (loss)	$ (178,823)	$ (84,805)	$ (9,077)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	237,831	110,505	77,926
Net cash provided by operations	59,008	25,700	68,849
Cash flows from investing activities
Additions to oil and gas properties	(245,364)	(264,462)	(311,305)
Net adjustments to purchase price of properties acquired	2,391
Proceeds from sales of assets	61,290	1,645	41
Acquisition of other property, plant and equipment	(586)	(310)	(1,101)
Current period settlements of matured derivative contracts	72,265	132,265	144,145
Net cash (used in) investing	(110,004)	(130,862)	(168,220)
Cash flows from financing activities
Proceeds from issuance of long-term debt	162,000	130,000	85,000
Repayment of long-term debt	(129,000)	(62,000)	(335,000)
Proceeds from senior notes			236,475
Purchase of senior notes		(84,589)
Payment of debt issuance costs	(1,115)		(1,556)
Payment of cash dividends on preferred stock	(3,368)	(1,615)
Net distributions paid to JEH unitholders	(562)	(17,319)
Net payments for share based compensation	(462)
Proceeds from sale of common stock	8,333	65,446	122,779
Proceeds from sale of preferred stock		87,988
Net cash provided by financing	35,826	117,911	107,698
Net increase (decrease) in cash	(15,170)	12,749	8,327
Cash
Beginning of period	34,642	21,893	13,566
End of period	19,472	34,642	21,893
Eliminations
Cash flows from operating activities
Net income (loss)	288,744	109,375	13,842
Adjustments to reconcile net income (loss) to net cash provided by operating activities	(288,744)	(109,375)	(13,842)
JEI (Parent)
Cash flows from operating activities
Net income (loss)	(101,492)	(42,552)	(2,381)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	73,536	(105,877)	(120,398)
Net cash provided by operations	(27,956)	(148,429)	(122,779)
Cash flows from financing activities
Payment of cash dividends on preferred stock	(3,368)	(1,615)
Net distributions paid to JEH unitholders	1,075	23,674
Proceeds from sale of common stock	8,333	65,446	122,779
Proceeds from sale of preferred stock		87,988
Net cash provided by financing	6,040	175,493	122,779
Net increase (decrease) in cash	(21,916)	27,064
Cash
Beginning of period	27,164	100	100
End of period	5,248	27,164	100
Issuers
Cash flows from operating activities
Net income (loss)	(155,716)	(57,032)	75,629
Adjustments to reconcile net income (loss) to net cash provided by operating activities	52,870	(28,124)	(193,245)
Net cash provided by operations	(102,846)	(85,156)	(117,616)
Cash flows from investing activities
Current period settlements of matured derivative contracts	72,265	132,265	144,145
Net cash (used in) investing	72,265	132,265	144,145
Cash flows from financing activities
Proceeds from issuance of long-term debt	162,000	130,000	85,000
Repayment of long-term debt	(129,000)	(62,000)	(335,000)
Proceeds from senior notes			236,475
Purchase of senior notes		(84,589)
Payment of debt issuance costs	(1,115)		(1,556)
Net distributions paid to JEH unitholders	(1,637)	(40,993)
Net payments for share based compensation	(462)
Net cash provided by financing	29,786	(57,582)	(15,081)
Net increase (decrease) in cash	(795)	(10,473)	11,448
Cash
Beginning of period	1,975	12,448	1,000
End of period	1,180	1,975	12,448
Guarantor Subsidiaries
Cash flows from operating activities
Net income (loss)	(209,985)	(94,141)	(95,960)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	399,795	353,426	405,214
Net cash provided by operations	189,810	259,285	309,254
Cash flows from investing activities
Additions to oil and gas properties	(245,364)	(264,462)	(311,305)
Net adjustments to purchase price of properties acquired	2,391
Proceeds from sales of assets	61,290	1,645	41
Acquisition of other property, plant and equipment	(586)	(310)	(1,101)
Net cash (used in) investing	(182,269)	(263,127)	(312,365)
Cash flows from financing activities
Net increase (decrease) in cash	7,541	(3,842)	(3,111)
Cash
Beginning of period	5,483	9,325	12,436
End of period	13,024	5,483	9,325
Non-Guarantor Subsidiaries
Cash flows from operating activities
Net income (loss)	(374)	(455)	(207)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	374	455	197
Net cash provided by operations			(10)
Cash flows from financing activities
Net increase (decrease) in cash			(10)
Cash
Beginning of period	20	20	30
End of period	$ 20	$ 20	$ 20