Jones Energy (JONEQ) 10-K 10 Mar 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Mar. 01, 2017	Jun. 30, 2016
Entity Registrant Name	Jones Energy, Inc.
Entity Central Index Key	1,573,166
Document Type	10-K
Document Period End Date	Dec. 31, 2016
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			$ 126.4
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Class A common stock
Entity Common Stock, Shares Outstanding		57,193,106
Class B common stock
Entity Common Stock, Shares Outstanding		29,832,098

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current assets
Cash	$ 34,642	$ 21,893
Accounts receivable, net
Oil and gas sales	26,568	19,292
Joint interest owners	5,267	11,314
Other	6,061	15,170
Commodity derivative assets	24,100	124,207
Other current assets	2,684	2,298
Total current assets	99,322	194,174
Oil and gas properties, net, at cost under the successful efforts method	1,743,588	1,635,766
Other property, plant and equipment, net	2,996	3,873
Commodity derivative assets	34,744	93,302
Other assets	6,050	8,039
Total assets	1,886,700	1,935,154
Current liabilities
Trade accounts payable	36,527	7,467
Oil and gas sales payable	28,339	32,408
Accrued liabilities	25,707	27,011
Commodity derivative liabilities	14,650	11
Other current liabilities	2,584	679
Total current liabilities	107,807	67,576
Long-term debt	724,009	837,654
Deferred revenue	7,049	11,417
Commodity derivative liabilities	1,209
Asset retirement obligations	19,458	20,301
Liability under tax receivable agreement	43,045	38,052
Other liabilities	792	330
Deferred tax liabilities	2,905	22,972
Total liabilities	906,274	998,302
Mezzanine equity
Series A preferred stock, $0.001 par value; 1,840,000 shares issued and outstanding at December 31, 2016 and no shares issued and outstanding at December 31, 2015	88,975
Stockholders' equity
Treasury stock, at cost: 22,602 shares at December 31, 2016 and December 31, 2015	(358)	(358)
Additional paid-in-capital	447,137	363,723
Retained (deficit) / earnings	(8,652)	36,569
Stockholders' equity	438,214	399,996
Non-controlling interest	453,237	536,856
Total stockholders' equity	891,451	936,852	$ 853,350	$ 624,124
Total liabilities and stockholders' equity	1,886,700	1,935,154
Class A common stock
Current liabilities
Total liabilities		998,302
Stockholders' equity
Common stock	57	31
Class B common stock
Stockholders' equity
Common stock	$ 30	$ 31

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2016	Dec. 31, 2015
Mezzanine equity
Series A preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Series A preferred stock, shares issued	1,840,000	0
Series A preferred stock, shares outstanding	1,840,000	0
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	57,048,076	30,573,509
Common stock, shares outstanding	57,025,474	30,550,907
Class B common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	29,832,098	31,273,130
Common stock, shares outstanding	29,832,098	31,273,130

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating revenues
Oil and gas sales	$ 124,877	$ 194,555	$ 378,401
Other revenues	2,970	2,844	2,196
Total operating revenues	127,847	197,399	380,597
Operating costs and expenses
Lease operating	32,640	41,027	37,760
Production and ad valorem taxes	7,768	12,130	22,556
Exploration	6,673	6,551	3,453
Depletion, depreciation and amortization	153,930	205,498	181,669
Accretion of ARO liability	1,263	1,087	770
General and administrative	29,640	33,388	25,763
Other operating	199	4,188
Total operating expenses	232,113	303,869	271,971
Operating income (loss)	(104,266)	(106,470)	108,626
Other income (expense)
Interest expense	(53,127)	(64,458)	(41,875)
Gain on debt extinguishment	99,530
Net gain (loss) on commodity derivatives	(51,264)	158,753	189,641
Other income (expense)	536	317	(4,554)
Other income (expense), net	(4,325)	94,612	143,212
Income (loss) before income tax	(108,591)	(11,858)	251,838
Income tax provision (benefit)
Current	3,981	113	53
Deferred	(27,767)	(2,894)	26,165
Total income tax provision (benefit)	(23,786)	(2,781)	26,218
Net income (loss)	(84,805)	(9,077)	225,620
Net income (loss) attributable to non-controlling interests	(42,253)	(6,696)	184,484
Net income (loss) attributable to controlling interests	(42,552)	(2,381)	41,136
Dividends and accretion on preferred stock	(2,669)
Net income (loss) attributable to common shareholders	$ (45,221)	$ (2,381)	$ 41,136
Earnings (loss) per share:
Basic - Net income (loss) attributable to common shareholders	$ (1.13)	$ (0.09)	$ 3.28
Diluted - Net income (loss) attributable to common shareholders	$ (1.13)	$ (0.09)	$ 3.28
Weighted average Class A shares outstanding:
Basic (in shares)	40,009	26,816	12,526
Diluted (in shares)	40,009	26,816	12,535
Class A common stock
Weighted average Class A shares outstanding:
Basic (in shares)	40,009	26,816	12,526
Diluted (in shares)	40,009	26,816	12,535

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 (Deficit)/ Earnings	Non-controlling Interest	Total
Balance at Dec. 31, 2013	$ 13	$ 37		$ 173,169	$ (2,186)	$ 453,091	$ 624,124
Balance (in shares) at Dec. 31, 2013	12,500	36,836
Increase (Decrease) Stockholders' Equity
Treasury Stock			$ (358)				(358)
Treasury Stock (in shares)	(23)		23
Stock-compensation expense				4,040			4,040
Vested restricted shares (in shares)	(28)
Exchange of Class B Shares for Class A Shares				1,554		(1,630)	(76)
Exchange of Class B shares for Class A shares (in shares)	117	(117)
Net income (loss)					41,136	184,484	225,620
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	$ 67			7,562			7,562
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
Cash tax distribution						(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

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash flows from operating activities
Net income (loss)	$ (84,805)	$ (9,077)	$ 225,620
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, and amortization	153,930	205,498	181,669
Exploration (dry hole and lease abandonment)	6,261	5,250	2,952
Accretion of ARO liability	1,263	1,087	770
Amortization of debt issuance costs	4,060	6,043	6,878
Stock compensation expense	7,425	7,562	4,040
Deferred and other non-cash compensation expense	804	455	758
Amortization of deferred revenue	(2,384)	(1,960)	(1,154)
(Gain) loss on commodity derivatives	51,264	(158,753)	(189,641)
(Gain) loss on sales of assets	(14)	3	(297)
(Gain) on debt extinguishment	(99,530)
Deferred income tax provision	(27,767)	(2,892)	26,165
Other - net	418	(961)	376
Changes in operating assets and liabilities
Accounts receivable	2,276	64,510	(2,453)
Other assets	(675)	(432)	(669)
Accrued interest expense	(4,727)	7,050	7,823
Accounts payable and accrued liabilities	17,901	(54,534)	2,482
Net cash provided by operations	25,700	68,849	265,319
Cash flows from investing activities
Additions to oil and gas properties	(264,462)	(311,305)	(474,619)
Net adjustments to purchase price of properties acquired			15,709
Proceeds from sales of assets	1,645	41	448
Acquisition of other property, plant and equipment	(310)	(1,101)	(1,683)
Current period settlements of matured derivative contracts	132,265	144,145	(3,654)
Net cash (used in) investing	(130,862)	(168,220)	(463,799)
Cash flows from financing activities
Proceeds from issuance of long-term debt	130,000	85,000	170,000
Repayment under long-term debt	(62,000)	(335,000)	(468,000)
Proceeds from senior notes		236,475	500,000
Purchase of senior notes	(84,589)
Payment of debt issuance costs		(1,556)	(13,416)
Payment of dividends on preferred stock	(1,615)
Net distributions paid to JEH unitholders	(17,319)
Proceeds from sale of common stock	65,446	122,779
Proceeds from sale of preferred stock	87,988
Purchase of treasury stock			(358)
Net cash provided by financing	117,911	107,698	188,226
Net increase (decrease) in cash	12,749	8,327	(10,254)
Cash
Beginning of period	21,893	13,566	23,820
End of period	34,642	21,893	13,566
Supplemental disclosure of cash flow information
Cash paid for interest	53,816	52,796	29,560
Cash paid for income taxes		(155)	155
Change in accrued additions to oil and gas properties	9,325	(111,210)	49,025
Asset retirement obligations incurred, including changes in estimate	$ (1,276)	$ 6,371	$ 2,041

Organization and Description of

Organization and Description of Business	12 Months Ended
	Dec. 31, 2016
Organization and Description of Business
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 and through private equity funds managed by Metalmark Capital and Wells Fargo Energy Capital (collectively, the “Class B shareholders”). JEH acts as a holding company of operating subsidiaries that own and operate assets that are used in the exploration, development, production and acquisition of oil and natural gas properties. The Company’s certificate of incorporation authorizes two classes of common stock, Class A common stock and Class B common stock. The Class B common stock is held by the owners of JEH prior to the Company’s initial public offering (“IPO”) and can be exchanged (together with a corresponding number of 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, 2016, the Company held 57,025,474 JEH Units and all of the preferred units representing membership interests in JEH, and the remaining 29,832,098 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 1.84 million 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, for gross proceeds of approximately $92 million, before underwriting discounts and commissions of $3.68 million. 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 Texas and Oklahoma. The Company’s assets are located within the Anadarko and Arkoma basins, 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, 2016
Significant Accounting Policies
Significant Accounting Policies	2. Significant Accounting Policies Basis of Presentation The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) 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, 2016 and 2015 and the financial statements reported for each of the three years in the period ended December 31, 2016 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, 2016 and at December 31, 2015 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, 2016 and 2015, 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, 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. As of December 31, 2014, 70% of Accounts receivable—Oil and gas sales were due from five purchasers and 67% of Accounts receivable—Joint interest owners were 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, 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. During the year ended December 31, 2014, the largest purchasers of our production were Valero Energy Corp. (“Valero”), NGL Energy Partners LP, PVR Midstream LLC (“PVR Midstream”), Plains Marketing LP (“Plains Marketing”), and Monarch Natural Gas LLC which accounted for approximately 22%, 12%, 12%, 10% and 10% of consolidated oil and gas sales, respectively. 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 results of any drilling and seismic 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. 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, 2016, 2015 and 2014, 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. Any such imbalances were not significant as of December 31, 2016, 2015, and 2014. 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. 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 August 2014, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) 2014-15, “Presentation of Financial Statements—Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern.” This ASU requires management to evaluate whether there are conditions or events that raise substantial doubt about an entity’s ability to continue as a “going concern” and to provide disclosures when certain criteria are met. Substantial doubt exists when relevant conditions and events, considered in the aggregate, indicate that it is probable that the entity will be unable to meet its obligations as they become due within one year after the date that the financial statements are issued (or available to be issued). The amendments are effective for interim and annual reporting periods beginning after December 15, 2016. Early adoption is permitted and the Company chose to early adopt ASU 2014-15 beginning October 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In January 2015, the FASB issued ASU 2015-01, “Income Statement—Extraordinary and Unusual Items.” This ASU removes the concept of extraordinary items from GAAP. Under existing guidance, an entity is required to separately disclose extraordinary items, net of tax, in the income statement after income from continuing operations if an event or transaction is of an unusual nature and occurs infrequently. This separate, net of tax presentation will no longer be allowed. The amendments are effective for interim and annual reporting periods beginning after December 15, 2015. Therefore, the Company adopted ASU 2015-01 beginning January 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In April 2015, the FASB issued ASU 2015-03, “Interest—Imputation of Interest” (Subtopic 835-30): “Simplifying the Presentation of Debt Issuance Costs.” Entities that have historically presented debt issuance costs as an asset, related to a recognized debt liability, will be required to present those costs as a direct deduction from the carrying amount of that debt liability. The ASU does not change the recognition, measurement, or subsequent measurement guidance for debt issuance costs. Adoption of this ASU will be applied retrospectively. In August 2015, the FASB issued ASU 2015-15, “Interest—Imputation of Interest” (Subtopic 835-30), which addresses the presentation or subsequent measurement of debt issuance costs related to line-of-credit arrangements, given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements. The amendments are effective for interim and annual reporting periods beginning after December 15, 2015. Therefore, the Company adopted ASU 2015-03 beginning January 1, 2016. Changes to the balance sheet have been applied on a retrospective basis. This resulted in the reclassification of debt issuance costs of $10.3 million associated with our Senior Unsecured Notes from Other assets to Long-term debt in the Consolidated Balance Sheet for the period ended December 31, 2015. Adoption did not have a material impact on the financial position, cash flows or results of operations. In September 2015, the FASB issued ASU 2015-16, “Business Combinations” (Topic 805): “Simplifying the Measurement-Period Adjustments.” The new standard eliminates the requirement that an acquirer in a business combination account for measurement-period adjustments retrospectively. Instead, an acquirer will recognize a measurement-period adjustment during the period in which it determines the amount of the adjustment. The standard is effective for interim and annual reporting periods beginning after December 15, 2015. Therefore, the Company adopted ASU 2015-16 beginning January 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In August 2016, the FASB issued ASU 2016‑15, “Statement of Cash Flows” (Topic 230). This amendment is intended to reduce diversity in practice in how certain transactions are classified in the statement of cash flows, specifically in regard to (1) debt prepayment or debt extinguishment costs, (2) settlement of zero­coupon debt instruments, (3) contingent consideration payments made after a business combination, (4) proceeds from the settlement of insurance claims, (5) proceeds from the settlement of corporate­owned life insurance policies, including bank­owned life insurance policies, (6) distributions received from equity method investments, (7) beneficial interests in securitization transactions, and (8) separately identifiable cash flows and application of the predominance principle. 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 2016-15 beginning October 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In November 2016, the FASB issued ASU 2016‑18, “Statement of Cash Flows: Restricted Cash” (Topic 230). The new standard requires that the statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. This standard also requires entities to reconcile such total to amounts on the balance sheet and disclose the nature of the restrictions. The standard is effective for interim and annual reporting periods beginning after December 15, 2017. Early adoption is permitted and the Company chose to early adopt ASU 2016-18 beginning October 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In January 2017, the FASB issued ASU 2017‑01, “Business Combinations” (Topic 805). This amendment is intended to clarify the definition of a business. The standard is effective for interim and annual reporting periods beginning after December 15, 2017. Early adoption is permitted and the Company chose to early adopt ASU 2017-01 beginning October 1, 2016. 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 ASU sets forth a five‑step model for determining when and how revenue is recognized. Under the model, an entity will be required to recognize revenue to depict the transfer of goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods or services. Additional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. 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. The Company is in the early stages of evaluating the effect that the adoption of Update 2014‑09 and Update 2015‑14 will have on our financial statements. At this time, we are performing a review on a sample of revenue contracts to determine the impact of adoption. The Company will continue to further evaluate the effect that the adoption of Update 2014-09 and Update 2015-14 will have on our financial statements. We anticipate adoption of Update 2014‑09 and Update 2015‑14 effective as of January 1, 2018. 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. 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, 2018. In March 2016, the FASB issued ASU 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. Adoption did not have a material impact on the financial position, cash flows or results of operations.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2016
Acquisitions
Acquisitions	3. Acquisitions During the year ended December 31, 2016, the Company entered into several purchase and sale agreements (as described below). No business combinations occurred during the twelve months ended December 31, 2015 and 2014. Merge Acquisition On August 18, 2016, JEH entered into a definitive purchase and sale agreement with SCOOP Energy Company, LLC, an Oklahoma limited liability company, to acquire oil and gas properties located in the Merge area of the STACK/SCOOP (the “Merge”) play in Central Oklahoma (the “Merge Acquisition”). The oil and gas properties acquired in the Merge Acquisition principally consist of approximately 18,000 undeveloped net acres in Canadian, Grady and McClain Counties, Oklahoma. The Company closed the Merge Acquisition on September 22, 2016, for cash consideration of $136.8 million. This transaction has been accounted for as an asset acquisition. The Company used proceeds from our equity offerings to fund a portion of the purchase. See Note 12, “Stockholders’ and Mezzanine equity”. Anadarko Acquisition On August 3, 2016, JEH entered into a definitive agreement to acquire producing and undeveloped oil and gas assets in the Western Anadarko basin (the “Anadarko Acquisition”) for $27.1 million, subject to customary closing adjustments. Upon final closing, which occurred October 24, 2016, the transaction closed for $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, 2016, the measurement-period remains open. The Anadarko Acquisition did not result in a significant impact to revenues or net income and as such, pro forma financial information was 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. The Company closed the Anadarko Acquisition on August 25, 2016, at which time, the acquired acreage was producing approximately 900 barrels of oil equivalent per day.

Properties, Plant and Equipment

Properties, Plant and Equipment	12 Months Ended
	Dec. 31, 2016
Properties, Plant and Equipment
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, 2016 and 2015: December 31, December 31, (in thousands of dollars) 2016 2015 Mineral interests in properties Unproved $ $ Proved Wells and equipment and related facilities Less: Accumulated depletion and impairment Net oil and gas properties $ $ One exploratory well was drilled during the year ended December 31, 2016, for which associated costs of $1.3 million were capitalized. There were no exploratory wells drilled during the year ended December 31, 2015 and, as such, no associated costs were capitalized. No exploratory wells resulted in exploration expense during either year. The Company did not capitalize any interest during the years ended December 31, 2016 and 2015 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 $152.7 million, $204.2 million, and $180.6 million for the years ended December 31, 2016, 2015, and 2014, respectively. Due to recent fluctuations in forward commodity prices, the Company continued to monitor its proved and unproved properties for impairment. No impairments of proved or unproved properties were recorded in 2016, 2015, or 2014. Other Property, Plant and Equipment Other property, plant and equipment consisted of the following at December 31, 2016 and 2015: December 31, December 31, (in thousands of dollars) 2016 2015 Leasehold improvements $ $ Furniture, fixtures, computers and software Vehicles Aircraft Other Less: Accumulated depreciation and amortization Net other property, plant and equipment $ $ Depreciation and amortization of other property, plant and equipment amounted to $1.2 million, $1.3 million, and $1.1 million during the years ended December 31, 2016, 2015 and 2014, respectively.

Long-Term Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2016
Long-Term Debt
Long-Term Debt	5. Long‑Term Debt Long-term debt consisted of the following at December 31, 2016 and 2015: (in thousands of dollars) December 31, 2016 December 31, 2015 Revolver $ $ 2022 Notes 2023 Notes Total principal amount Less: unamortized discount Less: debt issuance costs, net Total carrying amount $ $ 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 all outstanding borrowings under the Term Loan (as defined below) ($160.0 million), a portion of the outstanding borrowings under the Revolver (as defined below) ($308.0 million) and for working capital and general corporate purposes. The Company subsequently terminated the Term Loan in accordance with its terms. The 2022 Notes bear interest at a rate of 6.75% per year, payable semi-annually on April 1 and October 1 of each year beginning October 1, 2014. The 2022 Notes were registered in March 2015. 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 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. During the year ended December 31, 2016, through several open market and privately negotiated purchases, the Company purchased an aggregate principal amount of $190.9 million of its senior unsecured notes. As of December 31, 2016, the Company had 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. The 2022 Notes and 2023 Notes are guaranteed on a senior unsecured basis by the Company and by all of its significant subsidiaries other than the new subsidiary formed to acquire the properties in the Merge Acquisition, which was required to become a guarantor no later than January 31, 2017. 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, 2016, the Company was in compliance with the indentures governing the 2022 Notes and 2023 Notes. Other Long-Term Debt The Company entered into two credit agreements dated December 31, 2009, with Wells Fargo Bank N.A, the Senior Secured Revolving Credit Facility (the “Revolver”) and the Second Lien Term Loan (the “Term Loan”). On April 1, 2014, the Term Loan was repaid in full and terminated in connection with the issuance of the 2022 Notes. On November 6, 2014, the Company amended the Revolver to, among other things, extend the maturity date of the Revolver to November 6, 2019. The Company’s oil and gas properties are pledged as collateral to secure its obligations under the Revolver. The borrowing base on the Revolver was subsequently adjusted to $562.5 million in accordance with its terms as a result of the issuance of the 2023 Notes in February 2015 and was reaffirmed at this level effective April 1, 2015. Effective October 8, 2015, the borrowing base was reduced to $510.0 million during the semi-annual borrowing base re-determination. On August 1, 2016, the Company entered into an amendment to the Revolver to, among other things (i) require that the Company's deposit accounts and securities accounts (subject to certain exclusions) become subject to control agreements, (ii) restrict the Company from borrowing or receiving Letters of Credit under the Revolver if the Company has, or, after giving effect to such borrowing or issuance of Letter of Credit, will have, a Consolidated Cash Balance (as defined in the Revolver) in excess of $30.0 million (in each case giving effect to the anticipated use of proceeds thereof) and (iii) set the borrowing base under the Revolver at $425.0 million. The borrowing base was reaffirmed at this level during the semi-annual borrowing base re-determination effective October 24, 2016. 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 revolving credit facility 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 1.50% to 2.50% based on the level of borrowing base utilization at such time or (b) the greatest of the federal funds rate plus 0.50%, the one month adjusted LIBO rate plus 1.00%, or the prime rate announced by Wells Fargo Bank, N.A. in effect on such day, in each case plus a margin of 0.50% to 1.50% based on the level of borrowing base utilization at such time. For the year ended December 31, 2016, the average interest rate under the Revolver was 2.40% on an average outstanding balance of $172.3 million. For the year ended December 31, 2015, the average interest rate under the Revolver was 2.39% on an average outstanding balance of $144.9 million. Total interest and commitment fees under the Revolver were $5.3 million, $5.1 million, and $9.5 million for the years ended December 31, 2016, 2015 and 2014, respectively. Total interest and commitment fees under the Term Loan were $3.6 million for the year ended December 31, 2014. Jones Energy, Inc. and its consolidated subsidiaries are subject to certain covenants under the Revolver, including the requirement to maintain the following financial ratios: · a total leverage ratio, consisting of consolidated debt to EBITDAX, of not greater than 4.0x to 1.0x as of the last day of any fiscal quarter; 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 1.0x to 1.0x as of the last day of any fiscal quarter. As of December 31, 2016, our total leverage ratio is approximately 3.9x and our current ratio is approximately 3.5x, as calculated based on the requirements in our covenants. We are in compliance with all terms of our Revolver at December 31, 2016, and we expect to maintain compliance throughout 2017. 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 2017 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 hedge restructuring or seeking a waiver of such covenants. 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, 2016
Derivative Instruments and Hedging Activities
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, 2016 and 2015: Hedging Positions December 31, 2016 Weighted Final Low High Average Expiration Oil swaps Exercise price $ $ $ June 2019 Offset exercise price $ $ $ Net barrels per month — Natural gas swaps Exercise price $ $ $ June 2019 Offset exercise price $ $ $ Net mmbtu per month — Natural gas liquids swaps Exercise price $ $ $ December 2017 Barrels per month Oil collars Puts (floors) $ $ $ December 2019 Calls (ceilings) $ $ $ Net barrels per month Natural gas collars Puts (floors) $ $ $ December 2019 Calls (ceilings) $ $ $ Net barrels per month December 31, 2015 Weighted Final Low High Average Expiration Oil swaps Exercise price $ $ $ June 2019 Barrels per month Natural gas swaps Exercise price $ $ $ June 2019 mmbtu per month Natural gas basis swaps Contract differential $ $ $ December 2016 mmbtu per month Natural gas liquids swaps Exercise price $ $ $ December 2017 Barrels per month The Company recognized net losses on derivative instruments of $51.3 million for the year ended December 31, 2016. The Company recognized net gains on derivative instruments of $158.8 million and $189.6 million for the years ended December 31, 2015 and 2014, respectively. The Company routinely enters into oil and natural gas swap contracts as seller, thus resulting in a fixed price. In early 2016, 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 the 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 leaves the underlying production open to fluctuations in market prices. Based on current contract terms, the gains will be recognized as the hedge contracts mature in 2018 and 2019. Information related to these purchased oil and natural gas swap contracts is presented in the table above as the “offset exercise price”, and the volumes in the table above are presented “net” of such purchased oil and natural gas swap contracts. Offsetting Assets and Liabilities As of December 31, 2016, 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, 2016 and 2015: 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, 2016 Commodity derivative contracts Assets $ $ $ $ — $ Liabilities — December 31, 2015 Commodity derivative contracts Assets $ $ $ $ — $ Liabilities —

Fair Value Measurement

Fair Value Measurement	12 Months Ended
	Dec. 31, 2016
Fair Value Measurement
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, 2016 and 2015, by consolidated balance sheet caption and by valuation hierarchy, as described above are as follows: (in thousands of dollars) December 31, 2016 Fair Value Measurements Using Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ $ — $ Long-term assets (1) — Current liabilities — Long-term liabilities — (in thousands of dollars) December 31, 2015 Fair Value Measurements Using Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ $ $ Long-term assets — — Current liabilities — — Long-term liabilities — — — — (1) Level 3 long-term assets are negative as a result of the netting of our commodity derivative 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, 2016. Quantitative Information About Level 3 Fair Value Measurements Fair Value Unobservable Commodity Price Hedges (000’s) Valuation Technique Input Range Natural gas liquid swaps $ Use a discounted cash flow approach using inputs including forward price statements from counterparties Natural gas liquid futures $23.94 per barrel Crude oil collars $ 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 $ 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, 2016 and 2015. 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. Transfers from Level 3 to Level 2 represent the Company’s natural gas basis swaps for which observable forward curve pricing information has become readily available. A summary of the Company’s commodity derivative contract activity, by year, is as follows: (in thousands of dollars) Balance at December 31, 2014, net $ Purchases Settlements Transfers into Level 3 — Transfers to Level 2 Changes in fair value Balance at December 31, 2015, net $ Purchases Settlements Transfers to Level 2 Transfers to Level 3 — Changes in fair value Balance at December 31, 2016, net $ 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, 2016 December 31, 2015 Principal Principal (in thousands of dollars) Amount Fair Value Amount Fair Value Debt: Revolver $ $ $ $ 2022 Notes 2023 Notes 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, 2016
Asset Retirement Obligations
Asset Retirement Obligations	8. Asset Retirement Obligations A summary of the Company’s ARO for the years ended December 31, 2016 and 2015 is as follows: (in thousands of dollars) 2016 2015 ARO liability at beginning of year $ $ Liabilities incurred (1) Accretion of ARO liability Liabilities settled due to sale of related properties Liabilities settled due to plugging and abandonment Change in estimate (2) ARO liability at end of year Less: Current portion of ARO at end of year Total long-term ARO at end of year $ $ (1) 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, 2016
Stock-based Compensation
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, 2016: Weighted Average Grant Date Fair Value JEH Units per Share Unvested at December 31, 2015 $ Granted Forfeited Vested Unvested at December 31, 2016 $ Stock compensation expense associated with the Management Units for the years ended December 31, 2016, 2015 and 2014 was $1.2 million, $1.3 million, and $1.6 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 management units was $15.00 per share for the years ended December 31, 2016 and 2015. Unrecognized expense as of December 31, 2016 for all outstanding management units was $0.9 million and will be recognized over a weighted-average remaining period of 1.3 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 amended on May 4, 2016 following approval by the Company’s stockholders, the Company has reserved a total of 7,350,000 shares of Class A common stock for non-employee director, consultant, and employee stock-based compensation awards. 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 2014, 2015 and 2016. During 2016, the Company also granted performance unit awards to certain members of the senior management team under the LTIP. 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, 2016: Restricted Weighted Average Stock Unit Grant Date Fair Value Awards per Share Unvested at December 31, 2015 $ Granted Forfeited Vested Unvested at December 31, 2016 $ Stock compensation expense associated with the employee restricted stock unit awards for the years ended December 31, 2016, 2015, and 2014 was $3.0 million, $3.1 million, and $1.1 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 $3.99 per share, $9.58 per share, and $17.31 per share for the years ended December 31, 2016, 2015, and 2014, respectively. Unrecognized expense as of December 31, 2016 for all outstanding restricted stock unit awards was $4.4 million and will be recognized over a weighted-average remaining period of 1.8 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, 2016: Performance Weighted Average Share Unit Grant Date Fair Value Awards per Share Unvested at December 31, 2015 $ Granted Forfeited Vested Unvested at December 31, 2016 $ 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, 2016 the 168,877 performance share units that vested during 2016 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. Stock compensation expense associated with the performance share unit awards for the years ended December 31, 2016, 2015, and 2014 was $2.7 million, $2.6 million, and $0.9 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 $4.75 per share, $10.27 per share, and $21.65 per share for the years ended December 31, 2016, 2015, and 2014, respectively. Unrecognized expense as of December 31, 2016 for all outstanding performance share unit awards was $2.7 million and will be recognized over a weighted-average remaining period of 1.6 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 each peer company and is used to determine the payout percentages and the stock price of the Company’s common stock as of the vesting date. The ending stock price is multiplied by the payout percentage to determine the projected payout, which is then discounted 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 2016 2015 2014 Forecast period (years) Risk-free interest rate % % % Jones stock price volatility % % % The average historical combined volatilities for the Company and each peer company was 70.45%, 55.13%, and 46.95% for the awards made in 2016, 2015, and 2014, respectively. Based on these assumptions, the Monte Carlo simulation model resulted in an expected percentage of performance share units earned of 123.84%, 101.61%, and 126.80% for the 2016, 2015, and 2014 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 $1.3 million. The fair value measured as of December 31, 2016 was $1.2 million. 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 year ended December 31, 2016: 2016 Performance Unit Awards Forecast period (years) Risk-free interest rate % Jones stock price volatility % For the performance units granted during the year ended December 31, 2016, the Monte Carlo simulation model resulted in an expected payout of $67.38 per performance unit as of the grant date. Stock compensation expense associated with the performance unit awards was $0.3 million for the year ended December 31, 2016, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. As of December 31, 2016, $0.9 million of unrecognized compensation expense related to 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 2.0 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, 2016: Weighted Average Restricted Grant Date Fair Value Stock Awards per Share Unvested at December 31, 2015 $ Granted Forfeited — Vested Unvested at December 31, 2016 $ Stock compensation expense associated with awards to the members of the Board of Directors for the years ended December 31, 2016, 2015 and 2014 was $0.6 million, $0.6 million, and $0.4 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 $4.00 per share, $7.30 per share, and $18.77 per share for the years ended December 31, 2016, 2015, and 2014. Unrecognized expense as of December 31, 2016 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, 2016, 2015, and 2014, the Company had an associated tax benefit of $1.4 million, $1.1 million, and $0.4 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, 2016
Benefit Plans
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, 2016, 2015, and 2014, our total expense relating to these plans was $0.4 million, $0.5 million, and $0.3 million, respectively.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Taxes
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. The following table summarizes the tax provision for the years ended December 31, 2016, 2015, and 2014: Year Ended December 31, (in thousands of dollars) 2016 2015 2014 Current tax expense: Federal $ $ — $ State — Total current expense Deferred tax expense (benefit): Federal State Total deferred expense (benefit) Total tax expense (benefit) $ $ $ Tax expense (benefit) attributable to controlling interests Tax expense attributable to non-controlling interests Total income tax expense (benefit) $ $ $ 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) 2016 2015 2014 Provision calculated at federal statutory income tax rate: Net income before taxes $ $ $ Statutory rate % % % Income tax expense (benefit) computed at statutory rate $ $ $ Less: Non-controlling interests Income tax expense (benefit) attributable to controlling interests State and local income taxes, net of federal benefit Reduction of TRA liability — Equity compensation, shortfall — — Change in enacted rate — — Change in valuation allowance — Other Tax expense (benefit) attributable to controlling interests Tax expense attributable to non-controlling interests Total income tax expense (benefit) $ $ $ 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 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) 2016 2015 Deferred tax assets Net operating loss $ $ Section 754 election tax basis adjustment Other deferred tax asset — Total deferred tax assets Deferred tax liabilities Investment in consolidated subsidiary JEH Noncurrent state deferred tax liability Total deferred tax liabilities Net deferred tax assets (liabilities) Valuation allowance Net deferred tax assets (liabilities) $ $ The Company has a federal net operating loss carry-forward totaling $19.5 million and state net operating loss carry-forward of $48.2 million, of which the federal net operating loss carry-forward expires between 2033 and 2035 and with state net operating loss carryforwards expiring between 2033 and 2036. 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, 2016, we had a valuation allowance of $3.2 million 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. Internal Revenue Code ("IRC") Section 382 addresses company ownership changes and specifically limits the utilization of certain deductions and other tax attributes on an annual basis following an ownership change. The Company experienced an ownership change within the meaning of IRC Section 382 during 2015 that subjects a portion of the federal net operating loss carryforwards to an IRC Section 382 limitation. Although such limitation is not expected to limit the Company’s ability to utilize its net operating loss carryforwards before expiration, the limitation contributes to a current federal tax liability for the year ended December 31, 2016. 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 2012 through 2016. The tax years 2013 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, 2016, 2015, and 2014 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 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. In the event that the Company records a valuation allowance against its deferred tax assets associated with an exchange, the TRA liability will also be reduced as the payment of the TRA liability is dependent on the realizability of the deferred tax assets. As of December 31, 2016 and 2015, the amount of the TRA liability was reduced by $2.7 million, and $2.0 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, 2016, and 2015 the Company had recorded a TRA liability of $43.0 million, and $38.1 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, along with corresponding deferred tax assets, net of valuation allowance, of $50.6 million, and $44.8 million, respectively, as a result of the increase in tax basis generated arising from such exchanges. As of December 31, 2016, 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 anticipates making a payment of approximately $0.6 million under the TRA with respect to cash savings that the Company will realize on its 2016 tax returns as a result of tax attributes arising from prior exchanges, to be paid in the first quarter of 2018. 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 2016 of $41.0 million (including distributions to us) to its unitholders towards its total 2016 projected tax distribution obligation. The distributions 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.

Stockholders_ and Mezzanine equ

Stockholders’ and Mezzanine equity	12 Months Ended
	Dec. 31, 2016
Stockholders’ and Mezzanine equity
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, 2016, the Company sold approximately 0.5 million Class A Shares under the Equity Distribution Agreement for net proceeds of approximately $1.8 million ($2.1 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. At December 31, 2016, approximately $70.9 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 19, 2016, the Company and JEH entered into an underwriting agreement (the “Common Stock Underwriting Agreement”) with Credit Suisse Securities (USA) LLC and J.P. Morgan Securities LLC, as representatives of the underwriters named therein (the “Common Stock Underwriters”), with respect to the offer and sale of 21,000,000 shares of the Company’s Class A common stock, par value $0.001 per share (the “Class A Common Stock”). The Common Stock Underwriting Agreement also provided the Common Stock Underwriters an option (the “Common Stock Option”) to purchase up to an additional 3,150,000 shares of Class A Common Stock (the “Additional Offering”) within 30 days of the date of the Common Stock Underwriting Agreement. On September 7, 2016, the Underwriters exercised the Common Stock Option in full. The total net proceeds from the offering of Class A Common Stock (after underwriters’ compensation, but before estimated expenses) pursuant to the Common Stock Underwriting Agreement, including the exercise of the Common Stock Option, was $64.0 million. The Class A Common Stock was issued pursuant to the Company’s shelf registration statement on Form S-3 (Registration No. 333-211568), which became effective July 26, 2016, and a prospectus, which consists of a base prospectus, dated as of July 26, 2016, and a prospectus supplement, dated August 19, 2016. The closing of the sale of Class A Common Stock occurred on August 26, 2016 and the Additional Offering closed on September 12, 2016. Offering of 8.0% Series A Perpetual Convertible Preferred Stock On August 19, 2016, the Company and JEH entered into an underwriting agreement (the “Preferred Stock Underwriting Agreement”) with Credit Suisse Securities (USA) LLC and J.P. Morgan Securities LLC (the “Preferred Stock Underwriters”) with respect to the offer and sale of 1,600,000 shares of the Series A preferred stock. The Preferred Stock Underwriting Agreement also provided the Preferred Stock Underwriters an option (the “Preferred Stock Option”) to purchase an additional 240,000 shares of Series A preferred stock, which was exercised in full. The total net proceeds from the offering of Series A preferred stock (after underwriters’ compensation, but before estimated expenses) pursuant to the Preferred Stock Underwriting Agreement, including the exercise of the Preferred Stock Option, was $88.3 million. The Series A preferred stock was issued pursuant to the Company’s shelf registration statement on Form S-3 (Registration No. 333-211568), which became effective July 26, 2016, and an additional registration statement with respect thereto on Form S-3 (Registration No. 333-213201) filed under Rule 462(b) of the Act, which became effective upon filing on August 19, 2016. The closing of the sale of Series A preferred stock occurred on August 26, 2016. 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 conditions, 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, initially into approximately 15.6961 shares of Class A common stock (which is equivalent to an initial conversion price of approximately $3.19 per share), subject to specified adjustments and limitations as set forth in the certificate of designations for the Series A preferred stock. Based on the initial conversion rate and the full exercise of the Preferred Stock Underwriters’ over-allotment option, approximately 28.9 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. Mezzanine equity consisted of the following at December 31, 2016: (in thousands of dollars) December 31, 2016 Series A preferred stock, at issuance (net) $ Dividends on preferred stock Accretion on preferred stock Mezzanine equity at December 31, 2016 $

Earnings per Share

Earnings per Share	12 Months Ended
	Dec. 31, 2016
Earnings per Share
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, 2016, 1,249,825 restricted stock units, and 1,035,205 performance share units, and 28,880,824 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, 757,245 restricted stock units, and 539,188 performance share units were excluded from the calculation as they would have had an anti-dilutive effect. For the year ended December 31, 2014, 27,430 restricted stock shares, 54,656 restricted stock units and 192,998 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) 2016 2015 2014 Income (numerator): Net income (loss) attributable to controlling interests $ $ $ Less: Dividends and accretion on preferred stock — — Net income (loss) attributable to common shareholder $ $ $ Weighted-average shares (denominator): Weighted-average number of shares of Class A common stock - basic Weighted-average number of shares of Class A common stock - diluted Earnings (loss) per share: Basic - Net income (loss) attributable to common shareholders $ $ $ Diluted - Net income (loss) attributable to common shareholders $ $ $

Related Parties

Related Parties	12 Months Ended
	Dec. 31, 2016
Related Parties
Related Parties	14. Related Parties Related Party Transactions Transactions with Our Executive Officers, Directors and 5% Stockholders 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 directors, Howard I. Hoffen and Gregory D. Myers, are managing directors of Metalmark Capital. 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, 2016, 2015, and 2014, the Company amortized $2.4 million, $2.0 million, and $1.2 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 the $15.0 million Monarch equity interests, JEH assigned $2.4 million of the equity interests to Jonny Jones, the Company’s chief executive officer and chairman of the board, 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, Robert Brooks and Eric Niccum. The remaining $10.0 million of Monarch equity interests was distributed to certain of the Class B shareholders, which included Metalmark Capital, Wells Fargo, the Jones family entities, and certain of the Company’s officers and directors, including Jonny Jones, Mike McConnell and Eric Niccum. As of December 31, 2016, equity interests in Monarch of $0.7 million are included in Other assets on the Company’s Consolidated Balance Sheet. During the years ended December 31, 2016, 2015, and 2014, equity interests of $0.6 million, $0.8 million, and $0.5 million, respectively, were distributed to management under the incentive plan. The Company recognized expense of $0.5 million, $0.5 million, and $0.8 million during the years ended December 31, 2016, 2015, and 2014, 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 $2.7 million and $0.4 million associated with the approximately 1.3 MMBoe and 0.2 MMBoe of oil production transported under the agreement for the years ended December 31, 2016 and 2015. 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 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). Purchase 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 own 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 own 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.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies
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 5,500 square feet of office space in Oklahoma City, Oklahoma. Future minimum payments for all noncancellable operating leases extending beyond one year at December 31, 2016 are as follows: (in thousands of dollars) Years Ending December 31, 2017 $ 2018 2019 2020 2021 — Thereafter — $ Rent expense under operating leases was $1.6 million, $1.6 million, and $0.9 million for the years ended December 31, 2016, 2015, and 2014, 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 fracking 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 has 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 for the year ended December 31, 2016. However, no certainty exists that a settlement will be reached or if so, the amount of any such settlement. Therefore, the ultimate loss could be greater or less than the amount accrued. In the event the plaintiffs and the Company are not able to reach a settlement, a court date is anticipated to occur during the third quarter of 2017.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2016
Subsequent Events
Subsequent Events	16. Subsequent Events Preferred Stock Dividend Declared 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 Company’s 8.0% Series A Perpetual Convertible 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. Special Stock Dividend Declared On March 3, 2017, the Company’s Board of Directors declared a special stock dividend of 0.087423 shares of the Company’s Class A common stock, $0.001 par value (“Class A Common Stock”), for each outstanding share of Class A Common Stock (based on the number of shares outstanding on the date hereof). The special stock dividend is payable on March 31, 2017 to stockholders of record as of the close of business on March 15, 2017. In lieu of issuing fractional shares of Class A Common Stock, cash will be distributed. From time-to-time, the Company’s subsidiary Jones Energy Holdings, LLC (“JEH”) makes cash distributions to the holders of common units representing membership interests in JEH (“JEH Common Units”) to cover tax obligations that may occur as a result of any net taxable income of JEH allocable to holders of JEH Common Units. As a JEH Common Unit holder, 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 is using the excess cash of approximately $17.5 million in the aggregate to acquire newly-issued JEH Common Units from JEH, who will use the $17.5 million in proceeds to pay down debt outstanding under its credit facility. The stock dividend has been declared in order to equalize the number of shares of Class A Common Stock outstanding to the number of JEH Common Units held by the Company, and the aggregate number of Class A Common Stock issued in the stock dividend will equal the number of additional JEH Common Units the Company is purchasing from JEH. The JEH Common Units will be purchased 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. Cash payments in lieu of fractional shares will also be made on the basis of a value per share of Class A Common Stock of $3.50 per share. The declaration, amount and payment of any future dividends on shares of Class A Common Stock will be at the sole discretion of Jones Energy’s board of directors and the amount and timing of any future dividends cannot be predicted at this time.

Subsidiary Guarantors

Subsidiary Guarantors	12 Months Ended
	Dec. 31, 2016
Subsidiary Guarantors
Subsidiary Guarantors	17. Subsidiary Guarantors On April 1, 2014, the Issuers sold $500.0 million in aggregate principal amount of the 2022 Notes. On February 23, 2015, the Issuers sold $250.0 million in aggregate principal amount of the 2023 Notes. As of December 31, 2016, the 2022 Notes and the 2023 Notes are 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. Therefore, these two subsidiaries are not displayed as subsidiary guarantors in our financial statements for the year ending December 31, 2016. Nosley SCOOP, LLC and Nosley Acquisition, LLC have since become guarantors during the first quarter of 2017 and will be presented as such going forward. 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. 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. As of December 31, 2016, the Company held 57,025,474 JEH Units and all of the preferred units representing membership interests in JEH, and the remaining 29,832,098 JEH Units are held by a group of investors that owned interests in JEH prior to the Company’s IPO (the “Class B shareholders”). The Class B shareholders have no voting rights with respect to their economic interest in JEH. The Company has two classes of common stock, Class A common stock, which was sold to investors in the IPO, and Class B common stock, and one series of preferred stock, Series A preferred stock. Pursuant to the Company’s certificate of incorporation, each share of Class A common stock is entitled to one vote per share, and the shares of Class A common stock are entitled to 100% of the economic interests in the Company. Each share of Class B common stock has no economic rights in the Company, but entitles its holder to one vote on all matters to be voted on by the Company’s stockholders generally. 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). In connection with a reorganization that occurred immediately prior to the IPO, each Existing Owner was issued a number of shares of Class B common stock that was equal to the number of JEH Units that such Class B shareholder held. Holders of the Company’s Class A common stock and Class B common stock generally vote together as a single class on all matters presented to the Company’s stockholders for their vote or approval. Accordingly, the Existing Owners collectively have a number of votes in the Company equal to the aggregate number of JEH Units that they hold. The Class B shareholders have the right, pursuant to the terms of an exchange agreement by and among the Company, JEH and each of the Class B shareholders (the “Exchange Agreement”), to exchange their JEH Units (together with a corresponding number of shares of Class B common stock) for shares of Class A common stock on a one-for-one basis, subject to customary conversion rate adjustments for stock splits, stock dividends and reclassifications and other similar transactions. As a result, the Company expects that over time the Company will have an increasing economic interest in JEH as Class B common stock and JEH Units are exchanged for Class A common stock. Moreover, any transfers of JEH Units outside of the Exchange Agreement (other than permitted transfers to affiliates) must be approved by the Company. The Company intends to retain full voting and management control over JEH. Jones Energy, Inc. Condensed Consolidating Balance Sheet December 31, 2016 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Assets Current assets Cash $ $ $ $ $ — $ Accounts receivable, net Oil and gas sales — — — — Joint interest owners — — — — Other — — — Commodity derivative assets — — — — Other current assets — — — Intercompany receivable — — — Total current assets Oil and gas properties, net, at cost under the successful efforts method — — — Other property, plant and equipment, net — — — Commodity derivative assets — — — — Other assets — — — Investment in subsidiaries — — — — Total assets $ $ $ $ $ $ Liabilities and Stockholders’ Equity Current liabilities Trade accounts payable $ — $ $ $ — $ — $ Oil and gas sales payable — — — — Accrued liabilities — Commodity derivative liabilities — — — — Other current liabilities — — — Intercompany payable — — — Total current liabilities Long-term debt — — — — Deferred revenue — — — — Commodity derivative liabilities — — — — Asset retirement obligations — — — Liability under tax receivable agreement — — — — Other liabilities — — — Deferred tax liabilities — — — Total liabilities Mezzanine equity Series A preferred stock, $0.001 par value; 1,840,000 shares issued and outstanding at December 31, 2016 — — — — Stockholders’/ members' equity Members' equity — — Class A common stock, $0.001 par value; 57,048,076 shares issued and 57,025,474 shares outstanding at December 31, 2016 — — — — Class B common stock, $0.001 par value; 29,832,098 shares issued and outstanding at December 31, 2016 — — — — Treasury stock, at cost: 22,602 shares at December 31, 2016 — — — — Additional paid-in-capital — — — — Retained earnings (deficit) — — — — Stockholders' equity Non-controlling interest — — — — Total stockholders’ equity Total liabilities and stockholders’ equity $ $ $ $ $ $ Jones Energy, Inc. Condensed Consolidating Balance Sheet December 31, 2015 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Assets Current assets Cash $ $ $ $ $ — $ Accounts receivable, net Oil and gas sales — — — — Joint interest owners — — — — Other — — — Commodity derivative assets — — — — Other current assets — — — Intercompany receivable — — — Total current assets Oil and gas properties, net, at cost under the successful efforts method — — — — Other property, plant and equipment, net — — — Commodity derivative assets — — — — Other assets — — — Investment in subsidiaries — — — — Total assets $ $ $ $ $ $ Liabilities and Stockholders’ Equity Current liabilities Trade accounts payable $ — $ $ $ — $ — $ Oil and gas sales payable — — — — Accrued liabilities — — — Commodity derivative liabilities — — — — Other current liabilities — — — — Intercompany payable — — — Total current liabilities — Long-term debt — — — — Deferred revenue — — — — Asset retirement obligations — — — — Liability under tax receivable agreement — — — — Other liabilities — — — — Deferred tax liabilities — — — Total liabilities Stockholders’/ members' equity Members' equity — — Class A common stock, $0.001 par value; 30,573,509 shares issued and 30,550,907 shares outstanding at December 31, 2015 — — — — Class B common stock, $0.001 par value; 31,273,130 shares issued and outstanding at December 31, 2015 — — — — Treasury stock, at cost: 22,602 shares at December 31, 2015 — — — — Additional paid-in-capital — — — — Retained earnings (deficit) — — — — Stockholders' equity Non-controlling interest — — — — Total stockholders’ equity Total liabilities and stockholders’ equity $ $ $ $ $ $ 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 $ — $ — $ $ $ — $ Other revenues — — — Total operating revenues — — Operating costs and expenses Lease operating — — — Production and ad valorem taxes — — — — Exploration — — — — Depletion, depreciation and amortization — — — Accretion of ARO liability — — — — General and administrative — — Other operating — — — — Total operating expenses — — Operating income (loss) — — Other income (expense) Interest expense — — — Gain on debt extinguishment — — — — Net gain (loss) on commodity derivatives — — — — Other income (expense) — — Other income (expense), net — — Income (loss) before income tax — Equity interest in income — — — — Income tax provision (benefit) — — — Net income (loss) Net income (loss) attributable to non-controlling interests — — — — Net income (loss) attributable to controlling interests $ $ — $ — $ — $ — $ Dividends and accretion on preferred stock — — — — Net income (loss) attributable to common shareholders $ $ — $ — $ — $ — $ 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 $ — $ — $ $ — $ — $ Other revenues — — — Total operating revenues — — — Operating costs and expenses Lease operating — — — — Production and ad valorem taxes — — — — Exploration — — — — Depletion, depreciation and amortization — — — Accretion of ARO liability — — — — General and administrative — — Other operating — — Total operating expenses — — Operating income (loss) — — Other income (expense) Interest expense — — — Net gain (loss) on commodity derivatives — — — — Other income (expense) — — Other income (expense), net — — Income (loss) before income tax — Equity interest in income — — — — Income tax provision (benefit) — — — Net income (loss) Net income (loss) attributable to non-controlling interests — — — — Net income (loss) attributable to controlling interests $ $ — $ — $ — $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Operations Year Ended December 31, 2014 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Operating revenues Oil and gas sales $ — $ — $ $ — $ — $ Other revenues — — — Total operating revenues — — — Operating costs and expenses Lease operating — — — — Production and ad valorem taxes — — — — Exploration — — — — Depletion, depreciation and amortization — — — Accretion of ARO liability — — — — General and administrative — — Total operating expenses — — Operating income (loss) — — Other income (expense) Interest expense — — — Net gain (loss) on commodity derivatives — — — — Other income (expense) — — — Other income (expense), net — — — Income (loss) before income tax — — Equity interest in income — — — — Income tax provision (benefit) — — — Net income (loss) Net income (loss) attributable to non-controlling interests — — — — Net income (loss) attributable to controlling interests $ $ — $ — $ — $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2016 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ $ $ $ $ $ Adjustments to reconcile net income (loss) to net cash provided by operating activities Net cash (used in) / provided by operations — Cash flows from investing activities Additions to oil and gas properties — — — Proceeds from sales of assets — — — — Acquisition of other property, plant and equipment — — — — Current period settlements of matured derivative contracts — — — — Net cash (used in) / provided by investing — — Cash flows from financing activities Proceeds from issuance of long-term debt — — — — Repayment under long-term debt — — — — Purchase of senior notes — — — — Payment of dividends on preferred stock — — — — Net distributions paid to JEH unitholders — — — Proceeds from sale of common stock — — — — Proceeds from sale of preferred stock — — — — Net cash (used in) / provided by financing — — — Net increase (decrease) in cash — — Cash Beginning of period — End of period $ $ $ $ $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2015 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ $ $ $ $ $ Adjustments to reconcile net income (loss) to net cash provided by operating activities Net cash (used in) / provided by operations — Cash flows from investing activities Additions to oil and gas properties — — — — Proceeds from sales of assets — — — — Acquisition of other property, plant and equipment — — — — Current period settlements of matured derivative contracts — — — Net cash (used in) / provided by investing — — — Cash flows from financing activities Proceeds from issuance of long-term debt — — — — Repayment under long-term debt — — — — Proceeds from senior notes — — — — Payment of debt issuance costs — — — — Proceeds from sale of common stock, net of expense — — — — Net cash (used in) / provided by financing — — — Net increase (decrease) in cash — — Cash — Beginning of period — End of period $ $ $ $ $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2014 Non- Guarantor Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ $ $ $ $ $ Adjustments to reconcile net income (loss) to net cash provided by operating activities Net cash (used in) / provided by operations — Cash flows from investing activities Additions to oil and gas properties — — — — Net adjustments to purchase price of properties acquired — — — — Proceeds from sales of assets — — — — Acquisition of other property, plant and equipment — — — — Current period settlements of matured derivative contracts — — — — Net cash (used in) / provided by investing — — — Cash flows from financing activities Proceeds from issuance of long-term debt — — — — Repayment under long-term debt — — — — Proceeds from senior notes — — — — Payment of debt issuance costs — — — — Purchases of treasury stock — — — — Net cash (used in) / provided by financing — — — Net increase (decrease) in cash — — Cash Beginning of period — End of period $ $ $ $ $ — $

Significant Accounting Polici24

Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Significant Accounting Policies
Basis of Presentation	Basis of Presentation The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) 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, 2016 and 2015 and the financial statements reported for each of the three years in the period ended December 31, 2016 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, 2016 and at December 31, 2015 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, 2016 and 2015, 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, 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. As of December 31, 2014, 70% of Accounts receivable—Oil and gas sales were due from five purchasers and 67% of Accounts receivable—Joint interest owners were 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, 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. During the year ended December 31, 2014, the largest purchasers of our production were Valero Energy Corp. (“Valero”), NGL Energy Partners LP, PVR Midstream LLC (“PVR Midstream”), Plains Marketing LP (“Plains Marketing”), and Monarch Natural Gas LLC which accounted for approximately 22%, 12%, 12%, 10% and 10% of consolidated oil and gas sales, respectively. 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 results of any drilling and seismic 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.
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, 2016, 2015 and 2014, 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. Any such imbalances were not significant as of December 31, 2016, 2015, and 2014.
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. 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 August 2014, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) 2014-15, “Presentation of Financial Statements—Going Concern (Subtopic 205-40): Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern.” This ASU requires management to evaluate whether there are conditions or events that raise substantial doubt about an entity’s ability to continue as a “going concern” and to provide disclosures when certain criteria are met. Substantial doubt exists when relevant conditions and events, considered in the aggregate, indicate that it is probable that the entity will be unable to meet its obligations as they become due within one year after the date that the financial statements are issued (or available to be issued). The amendments are effective for interim and annual reporting periods beginning after December 15, 2016. Early adoption is permitted and the Company chose to early adopt ASU 2014-15 beginning October 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In January 2015, the FASB issued ASU 2015-01, “Income Statement—Extraordinary and Unusual Items.” This ASU removes the concept of extraordinary items from GAAP. Under existing guidance, an entity is required to separately disclose extraordinary items, net of tax, in the income statement after income from continuing operations if an event or transaction is of an unusual nature and occurs infrequently. This separate, net of tax presentation will no longer be allowed. The amendments are effective for interim and annual reporting periods beginning after December 15, 2015. Therefore, the Company adopted ASU 2015-01 beginning January 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In April 2015, the FASB issued ASU 2015-03, “Interest—Imputation of Interest” (Subtopic 835-30): “Simplifying the Presentation of Debt Issuance Costs.” Entities that have historically presented debt issuance costs as an asset, related to a recognized debt liability, will be required to present those costs as a direct deduction from the carrying amount of that debt liability. The ASU does not change the recognition, measurement, or subsequent measurement guidance for debt issuance costs. Adoption of this ASU will be applied retrospectively. In August 2015, the FASB issued ASU 2015-15, “Interest—Imputation of Interest” (Subtopic 835-30), which addresses the presentation or subsequent measurement of debt issuance costs related to line-of-credit arrangements, given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements. The amendments are effective for interim and annual reporting periods beginning after December 15, 2015. Therefore, the Company adopted ASU 2015-03 beginning January 1, 2016. Changes to the balance sheet have been applied on a retrospective basis. This resulted in the reclassification of debt issuance costs of $10.3 million associated with our Senior Unsecured Notes from Other assets to Long-term debt in the Consolidated Balance Sheet for the period ended December 31, 2015. Adoption did not have a material impact on the financial position, cash flows or results of operations. In September 2015, the FASB issued ASU 2015-16, “Business Combinations” (Topic 805): “Simplifying the Measurement-Period Adjustments.” The new standard eliminates the requirement that an acquirer in a business combination account for measurement-period adjustments retrospectively. Instead, an acquirer will recognize a measurement-period adjustment during the period in which it determines the amount of the adjustment. The standard is effective for interim and annual reporting periods beginning after December 15, 2015. Therefore, the Company adopted ASU 2015-16 beginning January 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In August 2016, the FASB issued ASU 2016‑15, “Statement of Cash Flows” (Topic 230). This amendment is intended to reduce diversity in practice in how certain transactions are classified in the statement of cash flows, specifically in regard to (1) debt prepayment or debt extinguishment costs, (2) settlement of zero­coupon debt instruments, (3) contingent consideration payments made after a business combination, (4) proceeds from the settlement of insurance claims, (5) proceeds from the settlement of corporate­owned life insurance policies, including bank­owned life insurance policies, (6) distributions received from equity method investments, (7) beneficial interests in securitization transactions, and (8) separately identifiable cash flows and application of the predominance principle. 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 2016-15 beginning October 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In November 2016, the FASB issued ASU 2016‑18, “Statement of Cash Flows: Restricted Cash” (Topic 230). The new standard requires that the statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. This standard also requires entities to reconcile such total to amounts on the balance sheet and disclose the nature of the restrictions. The standard is effective for interim and annual reporting periods beginning after December 15, 2017. Early adoption is permitted and the Company chose to early adopt ASU 2016-18 beginning October 1, 2016. Adoption did not have a material impact on the financial position, cash flows or results of operations. In January 2017, the FASB issued ASU 2017‑01, “Business Combinations” (Topic 805). This amendment is intended to clarify the definition of a business. The standard is effective for interim and annual reporting periods beginning after December 15, 2017. Early adoption is permitted and the Company chose to early adopt ASU 2017-01 beginning October 1, 2016. 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 ASU sets forth a five‑step model for determining when and how revenue is recognized. Under the model, an entity will be required to recognize revenue to depict the transfer of goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods or services. Additional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. 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. The Company is in the early stages of evaluating the effect that the adoption of Update 2014‑09 and Update 2015‑14 will have on our financial statements. At this time, we are performing a review on a sample of revenue contracts to determine the impact of adoption. The Company will continue to further evaluate the effect that the adoption of Update 2014-09 and Update 2015-14 will have on our financial statements. We anticipate adoption of Update 2014‑09 and Update 2015‑14 effective as of January 1, 2018. 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. 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, 2018. In March 2016, the FASB issued ASU 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. Adoption did not have a material impact on the financial position, cash flows or results of operations.

Properties, Plant and Equipme25

Properties, Plant and Equipment (Tables)	12 Months Ended
	Dec. 31, 2016
Properties, Plant and Equipment
Schedule of oil and gas properties	December 31, December 31, (in thousands of dollars) 2016 2015 Mineral interests in properties Unproved $ $ Proved Wells and equipment and related facilities Less: Accumulated depletion and impairment Net oil and gas properties $ $
Schedule of other property, plant and equipment	December 31, December 31, (in thousands of dollars) 2016 2015 Leasehold improvements $ $ Furniture, fixtures, computers and software Vehicles Aircraft Other Less: Accumulated depreciation and amortization Net other property, plant and equipment $ $

Long-Term Debt (Tables)

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Long-Term Debt
Summary of long-term debt	(in thousands of dollars) December 31, 2016 December 31, 2015 Revolver $ $ 2022 Notes 2023 Notes Total principal amount Less: unamortized discount Less: debt issuance costs, net Total carrying amount $ $

Derivative Instruments and He27

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative Instruments and Hedging Activities
Schedule of various commodity derivatives in place to offset uncertain price fluctuations that could affect the entity's future operations	December 31, 2016 Weighted Final Low High Average Expiration Oil swaps Exercise price $ $ $ June 2019 Offset exercise price $ $ $ Net barrels per month — Natural gas swaps Exercise price $ $ $ June 2019 Offset exercise price $ $ $ Net mmbtu per month — Natural gas liquids swaps Exercise price $ $ $ December 2017 Barrels per month Oil collars Puts (floors) $ $ $ December 2019 Calls (ceilings) $ $ $ Net barrels per month Natural gas collars Puts (floors) $ $ $ December 2019 Calls (ceilings) $ $ $ Net barrels per month December 31, 2015 Weighted Final Low High Average Expiration Oil swaps Exercise price $ $ $ June 2019 Barrels per month Natural gas swaps Exercise price $ $ $ June 2019 mmbtu per month Natural gas basis swaps Contract differential $ $ $ December 2016 mmbtu per month Natural gas liquids swaps Exercise price $ $ $ December 2017 Barrels per month
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, 2016 Commodity derivative contracts Assets $ $ $ $ — $ Liabilities — December 31, 2015 Commodity derivative contracts Assets $ $ $ $ — $ Liabilities —

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Measurement
Schedule of financial instruments carried at fair value	(in thousands of dollars) December 31, 2016 Fair Value Measurements Using Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ $ — $ Long-term assets (1) — Current liabilities — Long-term liabilities — (in thousands of dollars) December 31, 2015 Fair Value Measurements Using Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ $ $ Long-term assets — — Current liabilities — — Long-term liabilities — — — — (1) Level 3 long-term assets are negative as a result of the netting of our commodity derivative 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 $ Use a discounted cash flow approach using inputs including forward price statements from counterparties Natural gas liquid futures $23.94 per barrel Crude oil collars $ 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 $ 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, 2014, net $ Purchases Settlements Transfers into Level 3 — Transfers to Level 2 Changes in fair value Balance at December 31, 2015, net $ Purchases Settlements Transfers to Level 2 Transfers to Level 3 — Changes in fair value Balance at December 31, 2016, net $
Schedule of fair value of financial instruments that are not recorded at fair value in the consolidated financial statements	December 31, 2016 December 31, 2015 Principal Principal (in thousands of dollars) Amount Fair Value Amount Fair Value Debt: Revolver $ $ $ $ 2022 Notes 2023 Notes

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligations
Summary of the Company's ARO	(in thousands of dollars) 2016 2015 ARO liability at beginning of year $ $ Liabilities incurred (1) Accretion of ARO liability Liabilities settled due to sale of related properties Liabilities settled due to plugging and abandonment Change in estimate (2) ARO liability at end of year Less: Current portion of ARO at end of year Total long-term ARO at end of year $ $ (1) 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, 2016
Management Unit Awards
Stock-based Compensation
Summary of information related to the units/shares or awards	Weighted Average Grant Date Fair Value JEH Units per Share Unvested at December 31, 2015 $ Granted Forfeited Vested Unvested at December 31, 2016 $
Restricted Stock Unit Awards
Stock-based Compensation
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, 2015 $ Granted Forfeited Vested Unvested at December 31, 2016 $
Performance Share Unit Awards
Stock-based Compensation
Schedule of assumptions used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense	Performance Share Unit Awards 2016 2015 2014 Forecast period (years) Risk-free interest rate % % % Jones stock price volatility % % %
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, 2015 $ Granted Forfeited Vested Unvested at December 31, 2016 $
Performance Unit Awards
Stock-based Compensation
Schedule of assumptions used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense	2016 Performance Unit Awards Forecast period (years) Risk-free interest rate % Jones stock price volatility %
Restricted Stock Awards
Stock-based Compensation
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, 2015 $ Granted Forfeited — Vested Unvested at December 31, 2016 $

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Taxes
Schedule of income tax provision	Year Ended December 31, (in thousands of dollars) 2016 2015 2014 Current tax expense: Federal $ $ — $ State — Total current expense Deferred tax expense (benefit): Federal State Total deferred expense (benefit) Total tax expense (benefit) $ $ $ Tax expense (benefit) attributable to controlling interests Tax expense attributable to non-controlling interests Total income tax expense (benefit) $ $ $
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) 2016 2015 2014 Provision calculated at federal statutory income tax rate: Net income before taxes $ $ $ Statutory rate % % % Income tax expense (benefit) computed at statutory rate $ $ $ Less: Non-controlling interests Income tax expense (benefit) attributable to controlling interests State and local income taxes, net of federal benefit Reduction of TRA liability — Equity compensation, shortfall — — Change in enacted rate — — Change in valuation allowance — Other Tax expense (benefit) attributable to controlling interests Tax expense attributable to non-controlling interests Total income tax expense (benefit) $ $ $
Schedule of significant components of the Company's deferred tax assets and deferred tax liability	As of December 31, (in thousands of dollars) 2016 2015 Deferred tax assets Net operating loss $ $ Section 754 election tax basis adjustment Other deferred tax asset — Total deferred tax assets Deferred tax liabilities Investment in consolidated subsidiary JEH Noncurrent state deferred tax liability Total deferred tax liabilities Net deferred tax assets (liabilities) Valuation allowance Net deferred tax assets (liabilities) $ $

Stockholder's and Mezzanine equ

Stockholder's and Mezzanine equity (Tables)	12 Months Ended
	Dec. 31, 2016
Stockholders’ and Mezzanine equity
Schedule of mezzanine equity	(in thousands of dollars) December 31, 2016 Series A preferred stock, at issuance (net) $ Dividends on preferred stock Accretion on preferred stock Mezzanine equity at December 31, 2016 $

Earnings per Share (Tables)

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2016
Earnings per Share
Schedule of calculation of the basic and diluted weighted-average shares and EPS	Year Ended December 31, (in thousands, except per share data) 2016 2015 2014 Income (numerator): Net income (loss) attributable to controlling interests $ $ $ Less: Dividends and accretion on preferred stock — — Net income (loss) attributable to common shareholder $ $ $ Weighted-average shares (denominator): Weighted-average number of shares of Class A common stock - basic Weighted-average number of shares of Class A common stock - diluted Earnings (loss) per share: Basic - Net income (loss) attributable to common shareholders $ $ $ Diluted - Net income (loss) attributable to common shareholders $ $ $

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments and Contingencies
Schedule of future minimum payments for noncancellable operating leases extending beyond one year	(in thousands of dollars) Years Ending December 31, 2017 $ 2018 2019 2020 2021 — Thereafter — $

Subsidiary Guarantors (Tables)

Subsidiary Guarantors (Tables)	12 Months Ended
	Dec. 31, 2016
Subsidiary Guarantors
Condensed Consolidating Balance Sheet	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 $ $ $ $ $ — $ Accounts receivable, net Oil and gas sales — — — — Joint interest owners — — — — Other — — — Commodity derivative assets — — — — Other current assets — — — Intercompany receivable — — — Total current assets Oil and gas properties, net, at cost under the successful efforts method — — — Other property, plant and equipment, net — — — Commodity derivative assets — — — — Other assets — — — Investment in subsidiaries — — — — Total assets $ $ $ $ $ $ Liabilities and Stockholders’ Equity Current liabilities Trade accounts payable $ — $ $ $ — $ — $ Oil and gas sales payable — — — — Accrued liabilities — Commodity derivative liabilities — — — — Other current liabilities — — — Intercompany payable — — — Total current liabilities Long-term debt — — — — Deferred revenue — — — — Commodity derivative liabilities — — — — Asset retirement obligations — — — Liability under tax receivable agreement — — — — Other liabilities — — — Deferred tax liabilities — — — Total liabilities Mezzanine equity Series A preferred stock, $0.001 par value; 1,840,000 shares issued and outstanding at December 31, 2016 — — — — Stockholders’/ members' equity Members' equity — — Class A common stock, $0.001 par value; 57,048,076 shares issued and 57,025,474 shares outstanding at December 31, 2016 — — — — Class B common stock, $0.001 par value; 29,832,098 shares issued and outstanding at December 31, 2016 — — — — Treasury stock, at cost: 22,602 shares at December 31, 2016 — — — — Additional paid-in-capital — — — — Retained earnings (deficit) — — — — Stockholders' equity Non-controlling interest — — — — Total stockholders’ equity Total liabilities and stockholders’ equity $ $ $ $ $ $ Jones Energy, Inc. Condensed Consolidating Balance Sheet December 31, 2015 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Assets Current assets Cash $ $ $ $ $ — $ Accounts receivable, net Oil and gas sales — — — — Joint interest owners — — — — Other — — — Commodity derivative assets — — — — Other current assets — — — Intercompany receivable — — — Total current assets Oil and gas properties, net, at cost under the successful efforts method — — — — Other property, plant and equipment, net — — — Commodity derivative assets — — — — Other assets — — — Investment in subsidiaries — — — — Total assets $ $ $ $ $ $ Liabilities and Stockholders’ Equity Current liabilities Trade accounts payable $ — $ $ $ — $ — $ Oil and gas sales payable — — — — Accrued liabilities — — — Commodity derivative liabilities — — — — Other current liabilities — — — — Intercompany payable — — — Total current liabilities — Long-term debt — — — — Deferred revenue — — — — Asset retirement obligations — — — — Liability under tax receivable agreement — — — — Other liabilities — — — — Deferred tax liabilities — — — Total liabilities Stockholders’/ members' equity Members' equity — — Class A common stock, $0.001 par value; 30,573,509 shares issued and 30,550,907 shares outstanding at December 31, 2015 — — — — Class B common stock, $0.001 par value; 31,273,130 shares issued and outstanding at December 31, 2015 — — — — Treasury stock, at cost: 22,602 shares at December 31, 2015 — — — — Additional paid-in-capital — — — — Retained earnings (deficit) — — — — Stockholders' equity Non-controlling interest — — — — Total stockholders’ equity Total liabilities and stockholders’ equity $ $ $ $ $ $
Condensed Consolidating Statement of Operations	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 $ — $ — $ $ $ — $ Other revenues — — — Total operating revenues — — Operating costs and expenses Lease operating — — — Production and ad valorem taxes — — — — Exploration — — — — Depletion, depreciation and amortization — — — Accretion of ARO liability — — — — General and administrative — — Other operating — — — — Total operating expenses — — Operating income (loss) — — Other income (expense) Interest expense — — — Gain on debt extinguishment — — — — Net gain (loss) on commodity derivatives — — — — Other income (expense) — — Other income (expense), net — — Income (loss) before income tax — Equity interest in income — — — — Income tax provision (benefit) — — — Net income (loss) Net income (loss) attributable to non-controlling interests — — — — Net income (loss) attributable to controlling interests $ $ — $ — $ — $ — $ Dividends and accretion on preferred stock — — — — Net income (loss) attributable to common shareholders $ $ — $ — $ — $ — $ 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 $ — $ — $ $ — $ — $ Other revenues — — — Total operating revenues — — — Operating costs and expenses Lease operating — — — — Production and ad valorem taxes — — — — Exploration — — — — Depletion, depreciation and amortization — — — Accretion of ARO liability — — — — General and administrative — — Other operating — — Total operating expenses — — Operating income (loss) — — Other income (expense) Interest expense — — — Net gain (loss) on commodity derivatives — — — — Other income (expense) — — Other income (expense), net — — Income (loss) before income tax — Equity interest in income — — — — Income tax provision (benefit) — — — Net income (loss) Net income (loss) attributable to non-controlling interests — — — — Net income (loss) attributable to controlling interests $ $ — $ — $ — $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Operations Year Ended December 31, 2014 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Operating revenues Oil and gas sales $ — $ — $ $ — $ — $ Other revenues — — — Total operating revenues — — — Operating costs and expenses Lease operating — — — — Production and ad valorem taxes — — — — Exploration — — — — Depletion, depreciation and amortization — — — Accretion of ARO liability — — — — General and administrative — — Total operating expenses — — Operating income (loss) — — Other income (expense) Interest expense — — — Net gain (loss) on commodity derivatives — — — — Other income (expense) — — — Other income (expense), net — — — Income (loss) before income tax — — Equity interest in income — — — — Income tax provision (benefit) — — — Net income (loss) Net income (loss) attributable to non-controlling interests — — — — Net income (loss) attributable to controlling interests $ $ — $ — $ — $ — $
Condensed Consolidating Statement of Cash Flows	Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2016 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ $ $ $ $ $ Adjustments to reconcile net income (loss) to net cash provided by operating activities Net cash (used in) / provided by operations — Cash flows from investing activities Additions to oil and gas properties — — — Proceeds from sales of assets — — — — Acquisition of other property, plant and equipment — — — — Current period settlements of matured derivative contracts — — — — Net cash (used in) / provided by investing — — Cash flows from financing activities Proceeds from issuance of long-term debt — — — — Repayment under long-term debt — — — — Purchase of senior notes — — — — Payment of dividends on preferred stock — — — — Net distributions paid to JEH unitholders — — — Proceeds from sale of common stock — — — — Proceeds from sale of preferred stock — — — — Net cash (used in) / provided by financing — — — Net increase (decrease) in cash — — Cash Beginning of period — End of period $ $ $ $ $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2015 Guarantor Non-Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ $ $ $ $ $ Adjustments to reconcile net income (loss) to net cash provided by operating activities Net cash (used in) / provided by operations — Cash flows from investing activities Additions to oil and gas properties — — — — Proceeds from sales of assets — — — — Acquisition of other property, plant and equipment — — — — Current period settlements of matured derivative contracts — — — Net cash (used in) / provided by investing — — — Cash flows from financing activities Proceeds from issuance of long-term debt — — — — Repayment under long-term debt — — — — Proceeds from senior notes — — — — Payment of debt issuance costs — — — — Proceeds from sale of common stock, net of expense — — — — Net cash (used in) / provided by financing — — — Net increase (decrease) in cash — — Cash — Beginning of period — End of period $ $ $ $ $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Year Ended December 31, 2014 Non- Guarantor Guarantor (in thousands of dollars) JEI (Parent) Issuers Subsidiaries Subsidiaries Eliminations Consolidated Cash flows from operating activities Net income (loss) $ $ $ $ $ $ Adjustments to reconcile net income (loss) to net cash provided by operating activities Net cash (used in) / provided by operations — Cash flows from investing activities Additions to oil and gas properties — — — — Net adjustments to purchase price of properties acquired — — — — Proceeds from sales of assets — — — — Acquisition of other property, plant and equipment — — — — Current period settlements of matured derivative contracts — — — — Net cash (used in) / provided by investing — — — Cash flows from financing activities Proceeds from issuance of long-term debt — — — — Repayment under long-term debt — — — — Proceeds from senior notes — — — — Payment of debt issuance costs — — — — Purchases of treasury stock — — — — Net cash (used in) / provided by financing — — — Net increase (decrease) in cash — — Cash Beginning of period — End of period $ $ $ $ $ — $

Organization and Description 36

Organization and Description of Business - Common Stock (Details)	12 Months Ended
	Dec. 31, 2016classshares
Common Stock
Number of classes of common stock | class	2
Class A common stock
Common Stock
Ratio in which JEH Units and Class B common stock are exchanged for Class A common stock	1
Economic interests/rights (as a percent)	100.00%
Votes per share entitled to holders	1
Class B common stock
Common Stock
Economic interests/rights (as a percent)	0.00%
Votes per share entitled to holders	1
JEH | Class B common stock
Common Stock
Number of units held (in shares)	29,832,098
JEH | Jones Energy, Inc.
Common Stock
Number of units held (in shares)	57,025,474

Organization and Description 37

Organization and Description of Business - Series A Perpetual Convertible Preferred Stock (Details) - USD ($) $ / shares in Units, $ in Thousands	Oct. 18, 2016	Aug. 25, 2016	Dec. 31, 2016	Dec. 31, 2015
Series A Perpetual Conertible Preferred Stock
Series A preferred stock, par value (in dollars per share)			$ 0.001	$ 0.001
Series A preferred stock
Series A Perpetual Conertible Preferred Stock
Shares issued (in shares)		1.84
Dividend rate (as a percent)	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
Gross proceeds form sale of preferred stock		$ 92,000
Underwriting discounts and commissions		$ 3,680

Significant Accounting Polici38

Significant Accounting Policies - Segment Information (Details)	12 Months Ended
	Dec. 31, 2016segmentarea
Segment Information
Number of industry segments | segment	1
Number of Geographic Areas in which Entity Operates | area	1

Significant Accounting Polici39

Significant Accounting Policies - Accounts Receivable (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
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 Polici40

Significant Accounting Policies - Concentration of Risk (Details) - Credit risk	12 Months Ended
	Dec. 31, 2016customerOwner	Dec. 31, 2015customerOwner	Dec. 31, 2014customerOwner
Accounts receivable - Oil and gas sales
Concentration of Risk
Concentration risk (as a percent)	77.00%	68.00%	70.00%
Number of customers | customer	4	4	5
Accounts receivable - Joint interest owners
Concentration of Risk
Concentration risk (as a percent)	48.00%	80.00%	67.00%
Number of customers | Owner	5	5	5

Significant Accounting Polici41

Significant Accounting Policies - Dependence on Major Customers (Details) - Oil and gas sales - Customer concentration	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Valero Energy Corp.
Dependence on Major Customers
Concentration risk (as a percent)		18.00%	22.00%
ETC Field Services LLC
Dependence on Major Customers
Concentration risk (as a percent)	24.00%	17.00%
NGL Energy Partners LP
Dependence on Major Customers
Concentration risk (as a percent)		15.00%	12.00%
PVR Midstream
Dependence on Major Customers
Concentration risk (as a percent)			12.00%
Plains Marketing
Dependence on Major Customers
Concentration risk (as a percent)	37.00%	16.00%	10.00%
Monarch Natural Gas, LLC
Dependence on Major Customers
Concentration risk (as a percent)			10.00%

Significant Accounting Polici42

Significant Accounting Policies - Oil and Gas Properties (Details)	12 Months Ended
	Dec. 31, 2016ft³ / Boe
Oil and Gas Properties
Minimum project period for capitalization of interest on expenditures	6 months
Unit conversion ratio	6,000

Significant Accounting Polici43

Significant Accounting Policies - Other Property, Plant and Equipment (Details)	12 Months Ended
	Dec. 31, 2016
Minimum
Other Property, Plant and Equipment
Estimated useful lives	3 years
Maximum
Other Property, Plant and Equipment
Estimated useful lives	10 years

Significant Accounting Polici44

Significant Accounting Policies - Oil and Gas Sales Payable (Details)	12 Months Ended
	Dec. 31, 2016
Significant Accounting Policies
Period of remittance for oil and gas sales payable	60 days

Significant Accounting Polici45

Significant Accounting Policies - Recent Accounting Pronouncements (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Recent Accounting Pronouncements
Other assets	$ 6,050	$ 8,039
Long-term debt	$ 724,009	837,654
Accounting Standards Update 2015-03
Recent Accounting Pronouncements
Other assets		10,300
Long-term debt		$ 10,300

Acquisitions - Merge Acquisitio

Acquisitions - Merge Acquisition (Details) - Merge Acquisition $ in Millions	Sep. 22, 2016USD ($)a
Acquisitions
Number of net acres | a	18,000
Purchase consideration | $	$ 136.8

Acquisitions - Andarko Acquisit

Acquisitions - Andarko Acquisition - General Information (Details) - Anadarko Acquisition $ in Millions	Oct. 24, 2016USD ($)	Aug. 25, 2016abbl / ditem
Acquisitions
Closing adjustments	$ 27.1
Purchase consideration	$ 25.9
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 - Andarko Acquis48

Acquisitions - Andarko Acquisition - Purchase Price Allocation (Details) - Anadarko Acquisition $ in Millions	Oct. 24, 2016USD ($)
Oil and gas properties
Oil and gas properties	$ 32.3
Unproved	3
Proved	17
Wells and equipment and related facilities	12.3
Asset retirement obligations	$ 6.4

Properties, Plant and Equipme49

Properties, Plant and Equipment - Oil and Gas Properties - Tabular Information (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Mineral interests in properties
Unproved	$ 213,153	$ 75,308
Proved	1,054,683	1,031,669
Wells and equipment and related facilities	1,395,291	1,289,323
Gross oil and gas properties	2,663,127	2,396,300
Less: Accumulated depletion and impairment	(919,539)	(760,534)
Net oil and gas properties	$ 1,743,588	$ 1,635,766

Properties, Plant and Equipme50

Properties, Plant and Equipment - Oil and Gas Properties - Additional Information (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)project	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Oil and Gas Properties
Number of exploratory wells for which costs were capitalized | project	1
Costs capitalized in connection with exploratory wells	$ 1,300
Exploration expense on exploratory wells	0
Amount of capitalized interest on expenditures	0	$ 0
Depletion of oil and gas properties	152,700	204,200	$ 180,600
Impairments of proved or unproved oil and gas properties	$ 0	$ 0	$ 0

Properties, Plant and Equipme51

Properties, Plant and Equipment - Other Property, Plant and Equipment - Tabular Information (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Other Property, Plant and Equipment
Gross other property, plant and equipment	$ 8,254	$ 8,044
Less: Accumulated depreciation and amortization	(5,258)	(4,171)
Net other property, plant and equipment	2,996	3,873
Leasehold improvements
Other Property, Plant and Equipment
Gross other property, plant and equipment	1,213	1,260
Furniture, fixtures, computers and software
Other Property, Plant and Equipment
Gross other property, plant and equipment	4,170	4,090
Vehicles
Other Property, Plant and Equipment
Gross other property, plant and equipment	1,677	1,537
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	$ 284	$ 247

Properties, Plant and Equipme52

Properties, Plant and Equipment - Other Property, Plant and Equipment - Depreciation and Amortization (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Properties, Plant and Equipment
Depreciation and amortization of other property, plant and equipment	$ 1.2	$ 1.3	$ 1.1

Long-Term Debt - Tabular Disclo

Long-Term Debt - Tabular Disclosure (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Long-Term Debt
Total principal amount	$ 737,148	$ 860,000
Less: unamortized discount	(6,240)	(12,088)
Less: debt issuance costs, net	(6,899)	(10,258)
Total carrying amount	724,009	837,654
2022 Notes | Senior notes
Long-Term Debt
Total principal amount	409,148	500,000
2023 Notes | Senior notes
Long-Term Debt
Total principal amount	150,000	250,000
Revolving credit facility | Wells Fargo Bank N.A. | Revolver | Line of credit
Long-Term Debt
Total principal amount	$ 178,000	$ 110,000

Long-Term Debt - Senior Unsecur

Long-Term Debt - Senior Unsecured Notes (Details) - USD ($) $ in Thousands	Feb. 29, 2016	Feb. 23, 2015	Apr. 01, 2014	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Senior Unsecured Notes
Notes proceeds from issuance					$ 236,475	$ 500,000
Repayment under long-term debt				$ 62,000	$ 335,000	$ 468,000
Gain on debt extinguishment				99,530
Senior notes
Senior Unsecured Notes
Aggregate principal amount				190,900
Gain on debt extinguishment				99,500
2022 Notes | Senior notes
Senior Unsecured Notes
Aggregate principal amount			$ 500,000	90,900
Stated interest rate (as a percent)			6.75%
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
Wells Fargo Bank N.A. | Revolving credit facility | Revolver | Line of credit
Senior Unsecured Notes
Repayment under long-term debt			$ 308,000
Wells Fargo Bank N.A. | Term loan | Term Loan | Line of credit
Senior Unsecured Notes
Repayment under long-term debt			$ 160,000
Beneficial owner | 2023 Notes | Senior notes
Senior Unsecured Notes
Aggregate principal amount				100,000
Aggregate principal amount repurchased	$ 100,000
Purchased amount				$ 46,500
Gain on debt extinguishment	$ 48,300

Long-Term Debt - Other Long-Ter

Long-Term Debt - Other Long-Term Debt (Details) - Wells Fargo Bank N.A. - Line of credit $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Aug. 01, 2016USD ($)	Oct. 08, 2015USD ($)	Feb. 23, 2015USD ($)
Revolving credit facility | Revolver
Other Long-Term Debt
Borrowing base				$ 425	$ 510	$ 562.5
Cash balance threshold				$ 30
Average interest rate (as a percent)	2.40%	2.39%
Average outstanding balance	$ 172.3	$ 144.9
Total interest and commitment fees	$ 5.3	$ 5.1	$ 9.5
Covenant, total leverage ratio	4
Covenant, current ratio	1
Total leverage ratio	3.9
Current ratio	3.5
Revolving credit facility | London Interbank Offered Rate (LIBOR) | Minimum | Revolver
Other Long-Term Debt
Margin interest rate (as a percent)	1.50%
Revolving credit facility | London Interbank Offered Rate (LIBOR) | Maximum | Revolver
Other Long-Term Debt
Margin interest rate (as a percent)	2.50%
Revolving credit facility | Federal Funds Effective Swap Rate | Revolver
Other Long-Term Debt
Margin interest rate (as a percent)	0.50%
Revolving credit facility | One Month Adjust LIBO Rate | Revolver
Other Long-Term Debt
Margin interest rate (as a percent)	1.00%
Revolving credit facility | Base rate | Minimum | Revolver
Other Long-Term Debt
Margin interest rate (as a percent)	0.50%
Revolving credit facility | Base rate | Maximum | Revolver
Other Long-Term Debt
Margin interest rate (as a percent)	1.50%
Term loan | Term Loan
Other Long-Term Debt
Total interest and commitment fees			$ 3.6

Derivative Instruments and He56

Derivative Instruments and Hedging Activities - Hedging Positions (Details)	12 Months Ended
	Dec. 31, 2016$ / bblbbl / moMMBTU / mo$ / MMBTU	Dec. 31, 2015bbl / moMMBoe / mo$ / bbl$ / MMBTU
Oil | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per barrel)	43.65	54.53
Offset exercise price (in dollars per barrel)	42
Net barrels per month (in barrels per month) | bbl / mo		54,000
Oil | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per barrel)	86.85	100.87
Offset exercise price (in dollars per barrel)	49
Net barrels per month (in barrels per month) | bbl / mo	148,000	194,000
Oil | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel)	64.49	79.16
Offset exercise price (in dollars per barrel)	47.14
Net barrels per month (in barrels per month) | bbl / mo	87,233	97,119
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	2.78	3.22
Offset exercise price (in dollars per mmbtu)	2.75
Net mmbtu per month (in mmbtu per month) | MMBoe / mo		700,000
Natural gas | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU	4.67	6.45
Offset exercise price (in dollars per mmbtu)	3.02
Net mmbtu per month (in mmbtu per month)	1,470,000	1,640,000
Natural gas | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU	3.65	4.25
Offset exercise price (in dollars per mmbtu)	2.83
Net mmbtu per month (in mmbtu per month)	1,024,000	1,042,857
Natural gas | Basis swaps | Minimum
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU		(0.39)
Net mmbtu per month (in mmbtu per month) | MMBoe / mo		1,190,000
Natural gas | Basis swaps | Maximum
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU		(0.11)
Net mmbtu per month (in mmbtu per month) | MMBoe / mo		1,730,000
Natural gas | Basis swaps | Weighted Average
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU		(0.18)
Net mmbtu per month (in mmbtu per month) | MMBoe / mo		1,360,833
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 liquids | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per barrel)	18.06	8.90
Net barrels per month (in barrels per month) | bbl / mo	110,000	2,000
Natural gas liquids | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per barrel)	72.52	95.24
Net barrels per month (in barrels per month) | bbl / mo	121,000	112,000
Natural gas liquids | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel)	24.60	32.62
Net barrels per month (in barrels per month) | bbl / mo	114,833	51,792
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 He57

Derivative Instruments and Hedging Activities - Recognized Gain (Loss ) on Derivative Instruments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Commodity Derivative Instruments
Recognized Net Gain (Loss) on Derivative Instruments
Net (losses) gains recognized on derivative instruments	$ 51.3	$ 158.8	$ 189.6

Derivative Instruments and He58

Derivative Instruments and Hedging Activities - Offsetting Assets and Liabilities - Counterparties (Details)	Dec. 31, 2016Counterparty
Derivative Instruments and Hedging Activities
Number of counterparties to commodity derivative contracts	6

Derivative Instruments and He59

Derivative Instruments and Hedging Activities - Offsetting Assets (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Assets
Gross Amounts of Recognized Assets	$ 79,649	$ 218,036
Gross Amounts Offset in the Balance Sheet	(20,805)	(527)
Net Amounts of Assets Presented in the Balance Sheet	58,844	217,509
Net Amount	$ 58,844	$ 217,509

Derivative Instruments and He60

Derivative Instruments and Hedging Activities - Offsetting Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Liabilities
Gross Amounts of Recognized Liabilities	$ (36,664)	$ (538)
Gross Amounts Offset in the Balance Sheet	20,805	527
Net Amounts of Liabilities Presented in the Balance Sheet	(15,859)	(11)
Net Amount	$ (15,859)	$ (11)

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, 2016	Dec. 31, 2015
Valuation Hierarchy
Current assets	$ 24,100	$ 124,207
Long-term assets	34,744	93,302
Current liabilities	14,650	11
Long-term liabilities	1,209
Recurring | Commodity Derivative Instruments
Valuation Hierarchy
Current assets	24,100	124,207
Long-term assets	34,744	93,302
Current liabilities	14,650	11
Long-term liabilities	1,209
Recurring | Level 2 | Commodity Derivative Instruments
Valuation Hierarchy
Current assets	24,100	122,779
Long-term assets	36,384	93,302
Current liabilities	13,636	11
Long-term liabilities	892
Recurring | Level 3 | Commodity Derivative Instruments
Valuation Hierarchy
Current assets		$ 1,428
Long-term assets	(1,640)
Current liabilities	1,014
Long-term liabilities	$ 317

Fair Value Measurement - Quanti

Fair Value Measurement - Quantitative Information about Level 3 Inputs (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)$ / bbl	Dec. 31, 2015$ / bbl
Natural gas liquids | Swaps | Minimum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	18.06	8.90
Natural gas liquids | Swaps | Maximum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	72.52	95.24
Oil | Swaps | Minimum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	43.65	54.53
Oil | Swaps | Maximum
Commodity Derivative Instruments - Assets
Price (in dollars per barrel)	86.85	100.87
Discounted cash flow approach | Level 3 | Natural gas liquids | Swaps
Commodity Derivative Instruments - Assets
Fair Value | $	$ (1,014)
Price (in dollars per barrel)	23.94
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 | Natural gas | Collars
Commodity Derivative Instruments - Assets
Fair Value | $	$ (791)
Discounted option model approach | Level 3 | Oil | Collars
Commodity Derivative Instruments - Assets
Fair Value | $	$ (1,166)
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

Fair Value Measurement - Change

Fair Value Measurement - Changes in Level 3 Financial Instruments (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Changes in fair value of Level 3 instruments
Balance at the beginning of the period	$ 1,428	$ 2,780
Purchases	(5,208)	648
Settlements	(171)	(960)
Transfers to Level 2	2,363	(1,367)
Changes in fair value	(1,383)	327
Balance at the end of the period	$ (2,971)	$ 1,428

Fair Value Measurement - Assets

Fair Value Measurement - Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Principal Amount | 2022 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	$ 409,148	$ 500,000
Principal Amount | 2023 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	150,000	250,000
Principal Amount | Revolving credit facility | Revolver | Line of credit
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	178,000	110,000
Level 3 | Nonrecurring | Fair Value | Revolving credit facility | Revolver | Line of credit
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	178,000	110,000
Level 1 | Nonrecurring | Fair Value | 2022 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	393,150	260,000
Level 2 | Nonrecurring | Fair Value | 2023 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	$ 153,375	$ 153,283

Asset Retirement Obligations -

Asset Retirement Obligations - Roll Forward (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations
Balance at beginning of period	$ 20,980	$ 13,610
Liabilities incurred	6,947	6,349
Accretion of ARO liability	1,263	1,087	$ 770
Liabilities settled due to sale of related properties	(446)	(19)
Liabilities settled due to plugging and abandonment	(463)	(69)
Change in estimate	(8,223)	22
Balance at end of period	$ 20,058	$ 20,980	$ 13,610

Asset Retirement Obligations 66

Asset Retirement Obligations - Liability at Period End (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations
ARO liability at end of period	$ 20,058	$ 20,980	$ 13,610
Less: Current portion of ARO	(600)	(679)
Total long-term ARO at end of period	$ 19,458	$ 20,301

Asset Retirement Obligations 67

Asset Retirement Obligations - Related to Acquisition (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Asset Retirement Obligations
Liabilities incurred	$ 6,947	$ 6,349
Anadarko Acquisition
Asset Retirement Obligations
Liabilities incurred	$ 6,400

Stock-based Compensation - Mana

Stock-based Compensation - Management Unit Awards - New Awards (Details)	41 Months Ended
	Dec. 31, 2016shares
Management Unit Awards
Stock-based Compensation
Awards (in shares)	0

Stock-based Compensation - Ma69

Stock-based Compensation - Management Unit Awards - Activity (Details) - Management Unit Awards	12 Months Ended
	Dec. 31, 2016$ / sharesshares
Units
Unvested at the beginning of the period (in shares) | shares	189,355
Granted (in shares) | shares	40,630
Forfeited (in shares) | shares	(40,630)
Vested (in shares) | shares	(98,593)
Unvested at the end of the period (in shares) | shares	90,762
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (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 of the period (in dollars per share) | $ / shares	$ 15

Stock-based Compensation - Ma70

Stock-based Compensation - Management Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
General and administrative expenses | Management Unit Awards
Stock compensation expense
Stock compensation expense	$ 1.2	$ 1.3	$ 1.6

Stock-based Compensation - Ma71

Stock-based Compensation - Management Unit Awards - Additional Disclosures (Details) - Management Unit Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Stock-based Compensation
Weighted average grant date fair value (in dollars per share)	$ 15	$ 15
Unrecognized expenses	$ 0.9
Weighted-average remaining recognition period (in years)	1 year 3 months 18 days

Stock-based Compensation - 2013

Stock-based Compensation - 2013 Omnibus Incentive Plan (Details)	Dec. 31, 2016shares
2013 Omnibus Incentive Plan | Class A common stock
Stock-based Compensation
Shares reserved (in shares)	7,350,000

Stock-based Compensation - Rest

Stock-based Compensation - Restricted Stock Unit Awards - General Information (Details)	12 Months Ended
	Dec. 31, 2016
Restricted Stock Unit Awards
Stock-based Compensation
Vesting term	3 years

Stock-based Compensation - Re74

Stock-based Compensation - Restricted Stock Unit Awards - Activity (Details) - Restricted Stock Unit Awards - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Awards
Unvested at the beginning of the period (in shares)	757,245
Granted (in shares)	942,377
Forfeited (in shares)	(204,487)
Vested (in shares)	(245,312)
Unvested at the end of the period (in shares)	1,249,823	757,245
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (in dollars per share)	$ 11.65
Granted (in dollars per share)	3.99	$ 9.58	$ 17.31
Forfeited (in dollars per share)	9.69
Vested (in dollars per share)	12.18
Unvested at the end of the period (in dollars per share)	$ 6.09	$ 11.65

Stock-based Compensation - Re75

Stock-based Compensation - Restricted Stock Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
General and administrative expenses | Restricted Stock Unit Awards
Stock compensation expense
Stock compensation expense	$ 3	$ 3.1	$ 1.1

Stock-based Compensation - Re76

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, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock-based Compensation
Weighted average grant date fair value (in dollars per share)	$ 3.99	$ 9.58	$ 17.31
Awards (in shares)	942,377
Unrecognized expenses	$ 4.4
Weighted-average remaining recognition period (in years)	1 year 9 months 18 days

Stock-based Compensation - Perf

Stock-based Compensation - Performance Share Unit Awards - General Information (Details) - Performance Share Unit Awards	12 Months Ended
	Dec. 31, 2016
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 - Pe78

Stock-based Compensation - Performance Share Unit Awards - Activity (Details) - Performance Share Unit Awards - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Awards
Unvested at the beginning of the period (in shares)	539,188
Granted (in shares)	551,252
Forfeited (in shares)	(55,235)
Vested (in shares)	(168,877)
Unvested at the end of the period (in shares)	866,328	539,188
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (in dollars per share)	$ 14.22
Granted (in dollars per share)	4.75	$ 10.27	$ 21.65
Forfeited (in dollars per share)	13.27
Vested (in dollars per share)	21.65
Unvested at the end of the period (in dollars per share)	$ 6.81	$ 14.22

Stock-based Compensation - Pe79

Stock-based Compensation - Performance Share Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
General and administrative expenses | Performance Share Unit Awards
Stock compensation expense
Stock compensation expense	$ 2.7	$ 2.6	$ 0.9

Stock-based Compensation - Pe80

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, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock-based Compensation
Weighted average grant date fair value (in dollars per share)	$ 4.75	$ 10.27	$ 21.65
Unrecognized expenses	$ 2.7
Weighted-average remaining recognition period (in years)	1 year 7 months 6 days

Stock-based Compensation - Pe81

Stock-based Compensation - Performance Share Unit Awards - Assumptions (Details) - Performance Share Unit Awards	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock-based Compensation
Forecast period (years)	2 years 7 months 6 days	2 years 8 months 1 day	2 years 7 months 13 days
Risk-free interest rate (as a percent)	1.00%	0.79%	0.61%
Jones stock price volatility (as a percent)	71.47%	52.87%	40.40%
Average historical combined volatilities for the Company and each peer company (as a percent)	70.45%	55.13%	46.95%
Expected percentage of performance share units earned (as a percent)	123.84%	101.61%	126.80%

Stock-based Compensation - Pe82

Stock-based Compensation - Performance Unit Awards - General Information (Details) - Performance Unit Awards $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)$ / shares
Stock-based Compensation
Performance period (in years)	3 years
Estimated final value upon vesting | $	$ 1.3
Fair value | $	$ 1.2
Minimum
Stock-based Compensation
Vested (in dollars per share) | $ / shares	$ 0
Maximum
Stock-based Compensation
Vested (in dollars per share) | $ / shares	$ 200

Stock-based Compensation - Pe83

Stock-based Compensation - Performance Unit Awards - Assumptions (Details) - Performance Unit Awards	12 Months Ended
	Dec. 31, 2016$ / shares
Stock-based Compensation
Forecast period (years)	2 years 7 months 6 days
Risk-free interest rate (as a percent)	1.00%
Jones stock price volatility (as a percent)	71.47%
Expected payout per unit as of the grant date (in dollars per share)	$ 67.38

Stock-based Compensation - Pe84

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

Stock-based Compensation - Pe85

Stock-based Compensation - Performance Unit Awards - Additional Disclosures (Details) - Performance Unit Awards $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Stock-based Compensation
Unrecognized expenses	$ 0.9
Weighted-average remaining recognition period (in years)	2 years

Stock-based Compensation - Re86

Stock-based Compensation - Restricted Stock Awards - General Information (Details)	12 Months Ended
	Dec. 31, 2016
Restricted Stock Awards
Stock-based Compensation
Service period from date of grant	1 year

Stock-based Compensation - Re87

Stock-based Compensation - Restricted Stock Awards - Activity (Details) - Restricted Stock Awards - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Awards
Unvested at the beginning of the period (in shares)	67,380
Granted (in shares)	139,825
Vested (in shares)	(67,380)
Unvested at the end of the period (in shares)	139,825	67,380
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (in dollars per share)	$ 7.30
Granted (in dollars per share)	4	$ 7.30	$ 18.77
Vested (in dollars per share)	7.30
Unvested at the end of the period (in dollars per share)	$ 4	$ 7.30

Stock-based Compensation - Re88

Stock-based Compensation - Restricted Stock Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
General and administrative expenses | Restricted Stock Awards
Stock compensation expense
Stock compensation expense	$ 0.6	$ 0.6	$ 0.4

Stock-based Compensation - Re89

Stock-based Compensation - Restricted Stock Awards - Additional Disclosures (Details) - Restricted Stock Awards - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock-based Compensation
Weighted average grant date fair value (in dollars per share)	$ 4	$ 7.30	$ 18.77
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, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock-based Compensation
Associated tax benefit	$ 1.4	$ 1.1	$ 0.4

Benefit Plans (Details)

Benefit Plans (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Benefit Plans
Expenses	$ 0.4	$ 0.5	$ 0.3

Income Taxes - Tax Provision -

Income Taxes - Tax Provision - Current and Deferred (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Current tax expense:
Federal	$ 3,758		$ 53
State	223	$ 113
Total current expense	3,981	113	53
Deferred tax expense (benefit):
Federal	(27,245)	(1,137)	22,140
State	(522)	(1,757)	4,025
Total deferred expense (benefit)	(27,767)	(2,894)	26,165
Total income tax provision (benefit)	$ (23,786)	$ (2,781)	$ 26,218

Income Taxes - Tax Provision 93

Income Taxes - Tax Provision - Attributable to Controlling Interests and Non-controlling Interests (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Tax provision
Jones Energy, Inc.	$ (23,263)	$ (1,160)	$ 22,819
Non-controlling interest	(523)	(1,621)	3,399
Total income tax provision (benefit)	$ (23,786)	$ (2,781)	$ 26,218

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of the Provision for Income Taxes - Tabular Disclosure (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Provision calculated at federal statutory income tax rate:
Net income before taxes	$ (108,591)	$ (11,858)	$ 251,838
Statutory rate (as a percent)	35.00%	35.00%	35.00%
Income tax expense computed at statutory rate	$ (38,007)	$ (4,150)	$ 88,144
Less: Noncontrolling interests	14,972	2,911	(65,759)
Income tax expense (benefit) attributable to controlling interests	(23,035)	(1,239)	22,385
State and local income taxes, net of federal benefit	(622)	(1,011)	626
Reduction of TRA liability	(282)	(694)
Equity compensation, shortfall		338
Change in enacted rate		(650)
Change in valuation allowance	950	2,333
Other	(274)	(237)	(192)
Tax expense (benefit) attributable to controlling interests	(23,263)	(1,160)	22,819
Tax expense attributable to non-controlling interests	(523)	(1,621)	3,399
Total income tax provision (benefit)	$ (23,786)	$ (2,781)	$ 26,218

Income Taxes - Reconciliation95

Income Taxes - Reconciliation of the Provision for Income Taxes - Immaterial Error (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Provision calculated at federal statutory income tax rate:
Deferred income tax provision	$ (27,767)	$ (2,894)	$ 26,165

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 state 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, 2016	Dec. 31, 2015
Deferred tax assets
Net operating loss	$ 8,687	$ 9,414
Section 754 election tax basis adjustment	51,154	47,100
State deferred tax asset		505
Total deferred tax assets	59,841	57,019
Deferred tax liabilities
Investment in consolidated subsidiary JEH	56,888	73,559
Noncurrent state deferred tax liability	2,703	4,099
Total deferred tax liabilities	59,591	77,658
Net deferred tax assets (liabilities)	250	(20,639)
Valuation allowance	(3,155)	(2,333)
Net deferred tax assets (liabilities)	$ (2,905)	$ (22,972)

Income Taxes - Net Operating Lo

Income Taxes - Net Operating Loss Carry-forward (Details) $ in Millions	Dec. 31, 2016USD ($)
Operating loss carry-forward
Valuation allowance	$ 3.2
Federal
Operating loss carry-forward
Net operating loss carry-forward	19.5
State
Operating loss carry-forward
Net operating loss carry-forward	$ 48.2

Income Taxes - Tax Receivable A

Income Taxes - Tax Receivable Agreement (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Income Taxes
Cash seavings percentage (as a percent)	85.00%
Benefits of cash savings retained under tax receivable agreement (as a percent)	15.00%
Increase (decrease) in TRA liability due to valuation allowance recorded	$ (2,700)	$ (2,000)
Liability under tax receivable agreement	43,045	38,052
Valuation allowance	50,600	$ 44,800
Anticipated payment	$ 600

Income Taxes - Cash Tax Distrib

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

Stockholders_ and Mezzanine 101

Stockholders’ and Mezzanine equity - Common Stock (Details)	12 Months Ended
	Dec. 31, 2016class
Common Stock
Number of classes of common stock	2
Class A common stock
Common Stock
Ratio in which JEH Units and Class B common stock are exchanged for Class A common stock	1
Economic interests/rights (as a percent)	100.00%
Votes per share entitled to holders	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 102

Stockholders’ and Mezzanine equity - Series A Perpetual Convertible Preferred Stock (Details)	Oct. 18, 2016	Aug. 25, 2016
Series A preferred stock
Series A Perpetual Conertible Preferred Stock
Dividend rate (as a percent)	8.00%	8.00%

Stockholders_ and Mezzanine 103

Stockholders’ and Mezzanine equity - Equity Distribution Agreement (Details) - USD ($) $ in Thousands, shares in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	May 24, 2016
Common Stock
Proceeds from sale of common stock	$ 65,446	$ 122,779
Class A common stock
Common Stock
Offering value to sell common stock shares under equity distribution agreement			$ 73,000
Proceeds from sale of common stock	1,800
Gross proceeds from sale of common stock	2,100
Professional services expenses	300
Aggregate offering price	$ 70,900
Common Stock | Class A common stock
Common Stock
Sale of stock (in shares)	0.5

Stockholders' and Mezzanine equ

Stockholders' and Mezzanine equity - Offering of Class A Common Stock (Details) - USD ($) $ / shares in Units, $ in Thousands	Sep. 07, 2016	Aug. 19, 2016	Dec. 31, 2016	Dec. 31, 2015
Common Stock
Proceeds from sale of common stock			$ 65,446	$ 122,779
Class A common stock
Common Stock
Common stock, par value (in dollars per share)			$ 0.001	$ 0.001
Proceeds from sale of common stock			$ 1,800
Class A common stock | Common Stock Underwriting Agreement
Common Stock
Shares issued		21,000,000
Common stock, par value (in dollars per share)		$ 0.001
Period for purchase of additional shares by underwriters		30 days
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 105

Stockholders’ and Mezzanine equity - Mezzanine Equity - General Information (Details) $ / shares in Units, $ in Thousands	Oct. 18, 2016	Aug. 25, 2016$ / sharesshares	Aug. 19, 2016USD ($)item$ / sharesshares	Dec. 31, 2016USD ($)$ / shares	Dec. 31, 2015$ / shares
Series A Perpetual Conertible Preferred Stock
Net proceeds from offering | $				$ 87,988
Series A preferred stock, par value (in dollars per share) | $ / shares				$ 0.001	$ 0.001
Conversion threshold (as a percent)				175.00%
Series A preferred stock
Series A Perpetual Conertible Preferred Stock
Dividend rate (as a percent)	8.00%	8.00%
Shares issued (in shares) | shares		1.84
Liquidation preference (in dollars per share) | $ / shares			$ 50
Series A preferred stock, par value (in dollars per share) | $ / shares		$ 0.001
Conversion ratio			15.6961
Equivalent conversion price (in dollars per share) | $ / shares			$ 3.19
Shares issuable upon conversion | shares			28,900,000
Minimum number of trading days | item			20
Consecutive trading days			30 days
Series A preferred stock | Preferred Stock Underwriting Agreement
Series A Perpetual Conertible Preferred Stock
Shares issued (in shares) | shares			1,600,000
Net proceeds from offering | $			$ 88,300
Series A preferred stock | Over-Allotment Option
Series A Perpetual Conertible Preferred Stock
Shares issued (in shares) | shares			240,000

Stockholders_ and Mezzanine 106

Stockholders’ and Mezzanine equity - Mezzanine Equity - Tabular Disclosure (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)
Stockholders’ and Mezzanine equity
Series A preferred stock, at issuance (net)	$ 87,922
Dividends on preferred stock	940
Accretion on preferred stock	113
Mezzanine equity at end of period	$ 88,975

Earnings per Share - Anti-dilut

Earnings per Share - Anti-dilutive Securities (Details) - shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Restricted Stock Awards
Earnings per Share
Antidilutive securities (in shares)			27,430
Restricted Stock Unit Awards
Earnings per Share
Antidilutive securities (in shares)	1,249,825	757,245	54,656
Performance Share Unit Awards
Earnings per Share
Antidilutive securities (in shares)	1,035,205	539,188	192,998
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)	28,880,824

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, 2016	Dec. 31, 2015	Dec. 31, 2014
Income (numerator):
Net income (loss) attributable to controlling interests	$ (42,552)	$ (2,381)	$ 41,136
Less: Dividends and accretion on preferred stock	(2,669)
Net income (loss) attributable to common shareholders	$ (45,221)	$ (2,381)	$ 41,136
Weighted-average shares (denominator):
Weighted-average number of shares of Class A common stock - basic	40,009	26,816	12,526
Weighted-average number of shares of Class A common stock - diluted	40,009	26,816	12,535
Earnings (loss) per share:
Basic - Net income (loss) attributable to common shareholders	$ (1.13)	$ (0.09)	$ 3.28
Diluted - Net income (loss) attributable to common shareholders	$ (1.13)	$ (0.09)	$ 3.28

Related Parties - Transportatio

Related Parties - Transportation Agreement with Monarch Oil Pipeline LLC (Details) $ in Thousands	Sep. 01, 2013	May 07, 2013	May 31, 2015USD ($)	Sep. 30, 2014	Dec. 31, 2016USD ($)MMBoedirector	Dec. 31, 2015USD ($)MMBoe	Dec. 31, 2014USD ($)MMBoe
Related Party Transactions
Oil and gas sales					$ 124,877	$ 194,555	$ 378,401
Monarch Oil Pipeline LLC | Investee
Related Party Transactions
Term of Oil Gathering and Transportation Agreement (in years)				10 years
Gathering fees					$ 2,700	$ 400
Oil production transported (in MMBoe) | MMBoe					1.3	0.2
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 - Monarch Natur

Related Parties - Monarch Natural Gas, LLC Equity Interests (Details) - Monarch Natural Gas, LLC - Investee - USD ($) $ in Millions	May 07, 2013	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Related Party Transactions
Estimated fair value of equity interests issued to the entity	$ 15
Amortization of deferred revenue		$ 2.4	$ 2	$ 1.2
Value of equity interests from related party	15
Value of equity interests assigned to Jonny Jones	2.4
Value of equity interests reserved for 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		0.6	0.8	0.5
Allocated Share-based Compensation Expense		0.5	$ 0.5	$ 0.8
Other assets
Related Party Transactions
Estimated fair value of equity interests issued to the entity		$ 0.7

Related Parties - Purchase of S

Related Parties - Purchase of Senior Notes (Details) - USD ($) $ in Thousands	Feb. 29, 2016	Dec. 31, 2016
Senior Unsecured Notes
Gain on debt extinguishment		$ 99,530
Blackstone Group Management L.L.C. and Affiliates | Beneficial owner
Senior Unsecured Notes
Beneficial ownership interest (as a percent)	5.00%
Minimum | Blackstone Group Management L.L.C. and Affiliates | Beneficial owner
Senior Unsecured Notes
Beneficial ownership interest (as a percent)	5.00%
Senior notes
Senior Unsecured Notes
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

Commitments and Contingencies -

Commitments and Contingencies - Leased Space (Details)	Dec. 31, 2016ft²
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)	5,500

Commitments and Contingencie113

Commitments and Contingencies - Future Minimum Payments (Details) $ in Thousands	Dec. 31, 2016USD ($)
Future minimum payments for noncancellable operating leases
2,017	$ 1,054
2,018	1,118
2,019	1,125
2,020	375
Total	$ 3,672

Commitments and Contingencie114

Commitments and Contingencies - Rent Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Commitments and Contingencies
Rent expense under operating leases	$ 1.6	$ 1.6	$ 0.9

Commitments and Contingencie115

Commitments and Contingencies - Litigation (Details) $ in Millions	Dec. 31, 2016USD ($)
Surface Rights Use Violation Case
Litigation
Accrued liability on settlement offer	$ 1.5

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ / shares in Units, $ in Millions	Mar. 03, 2017	Jan. 19, 2017	Oct. 18, 2016	Aug. 25, 2016	Mar. 10, 2017	Dec. 31, 2016	Aug. 19, 2016	Dec. 31, 2015
Subsequent Event
Special Stock Dividend Declared
Distributions from JEH					$ 17.5
Volume weighted average price per share, period	5 days
Series A preferred stock
Preferred Stock Dividend Declared
Dividend rate (as a percent)			8.00%	8.00%
Liquidation preference (in dollars per share)							$ 50
Series A preferred stock | 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
Class A common stock
Special Stock Dividend Declared
Common stock, par value (in dollars per share)						$ 0.001		$ 0.001
Class A common stock | Subsequent Event
Special Stock Dividend Declared
Special stock dividend declared per share (in shares)	0.087423
Common stock, par value (in dollars per share)	$ 0.001
Share price (in dollars per share)	3.50
JEH | Subsequent Event
Special Stock Dividend Declared
Share price (in dollars per share)	$ 3.50

Subsidiary Guarantors - Debt an

Subsidiary Guarantors - Debt and Equity (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Feb. 23, 2015	Apr. 01, 2014
Senior notes
Subsidiary Guarantors
Issuance of debt	$ 190.9
Senior notes | 2022 Notes
Subsidiary Guarantors
Issuance of debt	$ 90.9		$ 500
Senior notes | 2023 Notes
Subsidiary Guarantors
Issuance of debt		$ 250
Issuers | Senior notes | 2022 Notes
Subsidiary Guarantors
Issuance of debt			$ 500
Issuers | Senior notes | 2023 Notes
Subsidiary Guarantors
Issuance of debt		$ 250
JEH | Guarantor Subsidiaries
Subsidiary Guarantors
Ownership percentage in subsidiary guarantors	100.00%

Subsidiary Guarantors - General

Subsidiary Guarantors - General Information (Details)	12 Months Ended
	Dec. 31, 2016classshares
Subsidiary Guarantors
Number of classes of common stock | class	2
Class A common stock
Subsidiary Guarantors
Votes per share entitled to holders	1
Economic interests/rights (as a percent)	100.00%
Ratio in which JEH Units and Class B common stock are exchanged for Class A common stock	1
Class B common stock
Subsidiary Guarantors
Votes per share entitled to holders	1
Economic interests/rights (as a percent)	0.00%
JEH | Class B common stock
Subsidiary Guarantors
Number of units held (in shares)	29,832,098
JEH | Jones Energy, Inc.
Subsidiary Guarantors
Number of units held (in shares)	57,025,474

Subsidiary Guarantors - Condens

Subsidiary Guarantors - Condensed Consolidating Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Current assets
Cash	$ 34,642	$ 21,893
Accounts receivable, net
Oil and gas sales	26,568	19,292
Joint interest owners	5,267	11,314
Other	6,061	15,170
Commodity derivative assets	24,100	124,207
Other current assets	2,684	2,298
Total current assets	99,322	194,174
Oil and gas properties, net, at cost under the successful efforts method	1,743,588	1,635,766
Other property, plant and equipment, net	2,996	3,873
Commodity derivative assets	34,744	93,302
Other assets	6,050	8,039
Total assets	1,886,700	1,935,154
Current liabilities
Trade accounts payable	36,527	7,467
Oil and gas sales payable	28,339	32,408
Accrued liabilities	25,707	27,011
Commodity derivative liabilities	14,650	11
Other current liabilities	2,584	679
Total current liabilities	107,807	67,576
Long-term debt	724,009	837,654
Deferred revenue	7,049	11,417
Commodity derivative liabilities	1,209
Asset retirement obligations	19,458	20,301
Liability under tax receivable agreement	43,045	38,052
Other liabilities	792	330
Deferred tax liabilities	2,905	22,972
Total liabilities	906,274	998,302
Mezzanine equity
Series A preferred stock, $0.001 par value; 1,840,000 shares issued and outstanding at December 31, 2016 and no shares issued and outstanding at December 31, 2015	88,975
Stockholders' / members' equity
Treasury stock, at cost: 22,602 shares at December 31, 2016 and December 31, 2015	(358)	(358)
Additional paid-in-capital	447,137	363,723
Retained earnings (deficit)	(8,652)	36,569
Stockholders' equity	438,214	399,996
Non-controlling interest	453,237	536,856
Total stockholders' equity	891,451	936,852	$ 853,350	$ 624,124
Total liabilities and stockholders' equity	1,886,700	1,935,154
Class A common stock
Current liabilities
Total liabilities		998,302
Stockholders' / members' equity
Common stock	57	31
Class B common stock
Stockholders' / members' equity
Common stock	30	31
Eliminations
Accounts receivable, net
Intercompany receivable	(1,196,525)	(1,174,863)
Total current assets	(1,196,525)	(1,174,863)
Investment in subsidiaries	(531,363)	(444,362)
Total assets	(1,727,888)	(1,619,225)
Current liabilities
Intercompany payable	(1,569,737)	(1,394,272)
Total current liabilities	(1,569,737)	(1,394,272)
Total liabilities	(1,569,737)
Stockholders' / members' equity
Members' equity	(611,388)
Treasury stock, at cost: 22,602 shares at December 31, 2016 and December 31, 2015		(761,809)
Stockholders' equity		(761,809)
Non-controlling interest	453,237	536,856
Total stockholders' equity	(158,151)	(224,953)
Total liabilities and stockholders' equity	(1,727,888)	(1,619,225)
Eliminations | Class A common stock
Current liabilities
Total liabilities		(1,394,272)
JEI (Parent)
Current assets
Cash	27,164	100
Accounts receivable, net
Intercompany receivable	15,666	12,866
Total current assets	42,830	12,966
Investment in subsidiaries	531,363	444,362
Total assets	574,193	457,328
Current liabilities
Accrued liabilities	3,874
Total current liabilities	3,874
Liability under tax receivable agreement	43,045	38,052
Deferred tax liabilities	85	19,280
Total liabilities	47,004
Mezzanine equity
Series A preferred stock, $0.001 par value; 1,840,000 shares issued and outstanding at December 31, 2016 and no shares issued and outstanding at December 31, 2015	88,975
Stockholders' / members' equity
Treasury stock, at cost: 22,602 shares at December 31, 2016 and December 31, 2015	(358)	(358)
Additional paid-in-capital	447,137	363,723
Retained earnings (deficit)	(8,652)	36,569
Stockholders' equity	438,214	399,996
Total stockholders' equity	438,214	399,996
Total liabilities and stockholders' equity	574,193	457,328
JEI (Parent) | Class A common stock
Current liabilities
Total liabilities		57,332
Stockholders' / members' equity
Common stock	57	31
JEI (Parent) | Class B common stock
Stockholders' / members' equity
Common stock	30	31
Issuers
Current assets
Cash	1,975	12,448
Accounts receivable, net
Other	5,434	14,444
Commodity derivative assets	24,100	124,207
Other current assets	422	444
Intercompany receivable	1,180,859	1,161,997
Total current assets	1,212,790	1,313,540
Commodity derivative assets	34,744	93,302
Other assets	5,265	7,456
Total assets	1,252,799	1,414,298
Current liabilities
Trade accounts payable	13	388
Accrued liabilities	11,227	15,741
Commodity derivative liabilities	14,650	11
Other current liabilities	1,984
Total current liabilities	27,874	16,140
Long-term debt	724,009	837,654
Deferred revenue	7,049	11,417
Commodity derivative liabilities	1,209
Other liabilities	269
Deferred tax liabilities	2,820	3,692
Total liabilities	763,230
Stockholders' / members' equity
Members' equity	489,569
Treasury stock, at cost: 22,602 shares at December 31, 2016 and December 31, 2015		545,395
Stockholders' equity		545,395
Total stockholders' equity	489,569	545,395
Total liabilities and stockholders' equity	1,252,799	1,414,298
Issuers | Class A common stock
Current liabilities
Total liabilities		868,903
Guarantor Subsidiaries
Current assets
Cash	5,483	9,325
Accounts receivable, net
Oil and gas sales	26,568	19,292
Joint interest owners	5,267	11,314
Other	627	726
Other current assets	2,262	1,854
Total current assets	40,207	42,511
Oil and gas properties, net, at cost under the successful efforts method	1,586,707	1,635,766
Other property, plant and equipment, net	2,378	3,168
Other assets	785	583
Total assets	1,630,077	1,682,028
Current liabilities
Trade accounts payable	36,514	7,079
Oil and gas sales payable	28,339	32,408
Accrued liabilities	10,597	11,270
Other current liabilities	600	679
Intercompany payable	1,410,077	1,391,838
Total current liabilities	1,486,127	1,443,274
Asset retirement obligations	19,441	20,301
Other liabilities	523	330
Total liabilities	1,506,091
Stockholders' / members' equity
Members' equity	123,986
Treasury stock, at cost: 22,602 shares at December 31, 2016 and December 31, 2015		218,123
Stockholders' equity		218,123
Total stockholders' equity	123,986	218,123
Total liabilities and stockholders' equity	1,630,077	1,682,028
Guarantor Subsidiaries | Class A common stock
Current liabilities
Total liabilities		1,463,905
Non-Guarantor Subsidiaries
Current assets
Cash	20	20
Accounts receivable, net
Total current assets	20	20
Oil and gas properties, net, at cost under the successful efforts method	156,881
Other property, plant and equipment, net	618	705
Total assets	157,519	725
Current liabilities
Accrued liabilities	9
Intercompany payable	159,660	2,434
Total current liabilities	159,669	2,434
Asset retirement obligations	17
Total liabilities	159,686
Stockholders' / members' equity
Members' equity	(2,167)
Treasury stock, at cost: 22,602 shares at December 31, 2016 and December 31, 2015		(1,709)
Stockholders' equity		(1,709)
Total stockholders' equity	(2,167)	(1,709)
Total liabilities and stockholders' equity	$ 157,519	725
Non-Guarantor Subsidiaries | Class A common stock
Current liabilities
Total liabilities		$ 2,434

Subsidiary Guarantors - Cond120

Subsidiary Guarantors - Condensed Consolidating Balance Sheet - Additional Information (Details) - $ / shares	Dec. 31, 2016	Dec. 31, 2015
Mezzanine equity
Series A preferred stock, par value (in dollars per share)	$ 0.001	$ 0.001
Series A preferred stock, shares issued	1,840,000	0
Series A preferred stock, shares outstanding	1,840,000	0
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	57,048,076	30,573,509
Common stock, shares outstanding	57,025,474	30,550,907
Class B common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	29,832,098	31,273,130
Common stock, shares outstanding	29,832,098	31,273,130
JEI (Parent)
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	57,048,076	30,573,509
Common stock, shares outstanding	57,025,474	30,550,907
JEI (Parent) | Class B common stock
Common stock
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares issued	29,832,098	31,273,130
Common stock, shares outstanding	29,832,098	31,273,130

Subsidiary Guarantors - Cond121

Subsidiary Guarantors - Condensed Consolidating Statement of Operations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating revenues
Oil and gas sales	$ 124,877	$ 194,555	$ 378,401
Other revenues	2,970	2,844	2,196
Total operating revenues	127,847	197,399	380,597
Operating costs and expenses
Lease operating	32,640	41,027	37,760
Production and ad valorem taxes	7,768	12,130	22,556
Exploration	6,673	6,551	3,453
Depletion, depreciation and amortization	153,930	205,498	181,669
Accretion of ARO liability	1,263	1,087	770
General and administrative	29,640	33,388	25,763
Other operating	199	4,188
Total operating expenses	232,113	303,869	271,971
Operating income (loss)	(104,266)	(106,470)	108,626
Other income (expense)
Interest expense	(53,127)	(64,458)	(41,875)
Gain on debt extinguishment	99,530
Net gain (loss) on commodity derivatives	(51,264)	158,753	189,641
Other income (expense)	536	317	(4,554)
Other income (expense), net	(4,325)	94,612	143,212
Income (loss) before income tax	(108,591)	(11,858)	251,838
Income tax provision (benefit)	(23,786)	(2,781)	26,218
Net income (loss)	(84,805)	(9,077)	225,620
Net income (loss) attributable to non-controlling interests	(42,253)	(6,696)	184,484
Net income (loss) attributable to controlling interests	(42,552)	(2,381)	41,136
Dividends and accretion on preferred stock	(2,669)
Net income (loss) attributable to common shareholders	(45,221)	(2,381)	41,136
Eliminations
Other income (expense)
Equity interest in income	66,804	4,728	(63,197)
Net income (loss)	66,804	4,728	(63,197)
Net income (loss) attributable to non-controlling interests	(42,253)	(6,696)	184,484
JEI (Parent)
Other income (expense)
Other income (expense)	784	1,984
Other income (expense), net	784	1,984
Income (loss) before income tax	784	1,984
Equity interest in income	(66,804)	(4,728)	63,197
Income tax provision (benefit)	(23,468)	(363)	22,061
Net income (loss)	(42,552)	(2,381)	41,136
Net income (loss) attributable to controlling interests	(42,552)	(2,381)	41,136
Dividends and accretion on preferred stock	(2,669)
Net income (loss) attributable to common shareholders	(45,221)
Issuers
Operating revenues
Other revenues	2,384	1,960	1,154
Total operating revenues	2,384	1,960	1,154
Operating costs and expenses
General and administrative	12,028	13,565	4,493
Total operating expenses	12,028	13,565	4,493
Operating income (loss)	(9,644)	(11,605)	(3,339)
Other income (expense)
Interest expense	(53,080)	(63,160)	(40,365)
Gain on debt extinguishment	99,530
Net gain (loss) on commodity derivatives	(51,264)	158,753	189,641
Other income (expense)	(321)	(1,663)	(4,851)
Other income (expense), net	(5,135)	93,930	144,425
Income (loss) before income tax	(14,779)	82,325	141,086
Income tax provision (benefit)	(318)	(2,418)	4,157
Net income (loss)	(14,461)	84,743	136,929
Guarantor Subsidiaries
Operating revenues
Oil and gas sales	124,861	194,555	378,401
Other revenues	586	884	1,042
Total operating revenues	125,447	195,439	379,443
Operating costs and expenses
Lease operating	32,633	41,027	37,760
Production and ad valorem taxes	7,768	12,130	22,556
Exploration	6,673	6,551	3,453
Depletion, depreciation and amortization	153,831	205,407	181,578
Accretion of ARO liability	1,263	1,087	770
General and administrative	17,244	19,707	21,181
Other operating	199	4,188
Total operating expenses	219,611	290,097	267,298
Operating income (loss)	(94,164)	(94,658)	112,145
Other income (expense)
Interest expense	(47)	(1,298)	(1,510)
Other income (expense)	73	(4)	297
Other income (expense), net	26	(1,302)	(1,213)
Income (loss) before income tax	(94,138)	(95,960)	110,932
Net income (loss)	(94,138)	(95,960)	110,932
Non-Guarantor Subsidiaries
Operating revenues
Oil and gas sales	16
Total operating revenues	16
Operating costs and expenses
Lease operating	7
Depletion, depreciation and amortization	99	91	91
General and administrative	368	116	89
Total operating expenses	474	207	180
Operating income (loss)	(458)	(207)	(180)
Other income (expense)
Income (loss) before income tax	(458)	(207)	(180)
Net income (loss)	$ (458)	$ (207)	$ (180)

Subsidiary Guarantors - Cond122

Subsidiary Guarantors - Condensed Consolidating Statement of Cash Flows (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash flows from operating activities
Net income (loss)	$ (84,805)	$ (9,077)	$ 225,620
Adjustments to reconcile net income (loss) to net cash provided by operating activities	110,505	77,926	39,699
Net cash provided by operations	25,700	68,849	265,319
Cash flows from investing activities
Additions to oil and gas properties	(264,462)	(311,305)	(474,619)
Net adjustments to purchase price of properties acquired			15,709
Proceeds from sales of assets	1,645	41	448
Acquisition of other property, plant and equipment	(310)	(1,101)	(1,683)
Current period settlements of matured derivative contracts	132,265	144,145	(3,654)
Net cash (used in) investing	(130,862)	(168,220)	(463,799)
Cash flows from financing activities
Proceeds from issuance of long-term debt	130,000	85,000	170,000
Repayment under long-term debt	(62,000)	(335,000)	(468,000)
Proceeds from senior notes		236,475	500,000
Purchase of senior notes	(84,589)
Purchase of treasury stock			(358)
Payment of debt issuance costs		(1,556)	(13,416)
Payment of dividends on preferred stock	(1,615)
Net distributions paid to JEH unitholders	(17,319)
Proceeds from sale of common stock, net of expense	65,446	122,779
Proceeds from sale of preferred stock	87,988
Net cash provided by financing	117,911	107,698	188,226
Net increase (decrease) in cash	12,749	8,327	(10,254)
Cash
Beginning of period	21,893	13,566	23,820
End of period	34,642	21,893	13,566
Eliminations
Cash flows from operating activities
Net income (loss)	66,804	4,728	(63,197)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	(66,804)	(4,728)	63,197
JEI (Parent)
Cash flows from operating activities
Net income (loss)	(42,552)	(2,381)	41,136
Adjustments to reconcile net income (loss) to net cash provided by operating activities	(105,877)	(120,398)	(40,778)
Net cash provided by operations	(148,429)	(122,779)	358
Cash flows from financing activities
Purchase of treasury stock			(358)
Payment of dividends on preferred stock	(1,615)
Net distributions paid to JEH unitholders	23,674
Proceeds from sale of common stock, net of expense	65,446	122,779
Proceeds from sale of preferred stock	87,988
Net cash provided by financing	175,493	122,779	(358)
Net increase (decrease) in cash	27,064
Cash
Beginning of period	100	100	100
End of period	27,164	100	100
Issuers
Cash flows from operating activities
Net income (loss)	(14,461)	84,743	136,929
Adjustments to reconcile net income (loss) to net cash provided by operating activities	(70,695)	(202,359)	(326,859)
Net cash provided by operations	(85,156)	(117,616)	(189,930)
Cash flows from investing activities
Current period settlements of matured derivative contracts	132,265	144,145	(3,654)
Net cash (used in) investing	132,265	144,145	(3,654)
Cash flows from financing activities
Proceeds from issuance of long-term debt	130,000	85,000	170,000
Repayment under long-term debt	(62,000)	(335,000)	(468,000)
Proceeds from senior notes		236,475	500,000
Purchase of senior notes	(84,589)
Payment of debt issuance costs		(1,556)	(13,416)
Net distributions paid to JEH unitholders	(40,993)
Net cash provided by financing	(57,582)	(15,081)	188,584
Net increase (decrease) in cash	(10,473)	11,448	(5,000)
Cash
Beginning of period	12,448	1,000	6,000
End of period	1,975	12,448	1,000
Guarantor Subsidiaries
Cash flows from operating activities
Net income (loss)	(94,138)	(95,960)	110,932
Adjustments to reconcile net income (loss) to net cash provided by operating activities	196,547	405,214	343,999
Net cash provided by operations	102,409	309,254	454,931
Cash flows from investing activities
Additions to oil and gas properties	(107,586)	(311,305)	(474,619)
Net adjustments to purchase price of properties acquired			15,709
Proceeds from sales of assets	1,645	41	448
Acquisition of other property, plant and equipment	(310)	(1,101)	(1,683)
Net cash (used in) investing	(106,251)	(312,365)	(460,145)
Cash flows from financing activities
Net increase (decrease) in cash	(3,842)	(3,111)	(5,214)
Cash
Beginning of period	9,325	12,436	17,650
End of period	5,483	9,325	12,436
Non-Guarantor Subsidiaries
Cash flows from operating activities
Net income (loss)	(458)	(207)	(180)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	157,334	197	140
Net cash provided by operations	156,876	(10)	(40)
Cash flows from investing activities
Additions to oil and gas properties	(156,876)
Net cash (used in) investing	(156,876)
Cash flows from financing activities
Net increase (decrease) in cash		(10)	(40)
Cash
Beginning of period	20	30	70
End of period	$ 20	$ 20	$ 30