Jones Energy (JONEQ) 10-Q 6 May 16 2016 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2016	Apr. 29, 2016
Entity Registrant Name	Jones Energy, Inc.
Entity Central Index Key	1,573,166
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Accelerated Filer
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1
Class A common stock
Entity Common Stock, Shares Outstanding		30,818,210
Class B common stock
Entity Common Stock, Shares Outstanding		31,230,213

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Current assets
Cash	$ 53,805	$ 21,893
Restricted cash	361	330
Accounts receivable, net
Oil and gas sales	16,093	19,292
Joint interest owners	7,399	11,314
Other	15,105	15,170
Commodity derivative assets	107,762	124,207
Other current assets	3,991	2,298
Total current assets	204,516	194,504
Oil and gas properties, net, at cost under the successful efforts method	1,600,290	1,635,766
Other property, plant and equipment, net	3,509	3,873
Commodity derivative assets	84,284	93,302
Other assets	7,309	7,709
Total assets	1,899,908	1,935,154
Current liabilities
Trade accounts payable	8,835	7,467
Oil and gas sales payable	28,548	32,408
Accrued liabilities	23,426	27,341
Commodity derivative liabilities		11
Asset retirement obligations	679	679
Total current liabilities	61,488	67,906
Long-term debt	749,312	837,654
Deferred revenue	10,772	11,417
Asset retirement obligations	20,629	20,301
Liability under tax receivable agreement	37,623	38,052
Deferred tax liabilities	33,533	22,972
Total liabilities	$ 913,357	$ 998,302
Commitments and contingencies (Note 12)
Stockholders' equity
Treasury stock, at cost; 22,602 shares at March 31, 2016 and December 31, 2015	$ (358)	$ (358)
Additional paid-in-capital	364,908	363,723
Retained earnings	55,480	36,569
Stockholders' equity	420,092	399,996
Non-controlling interest	566,459	536,856
Total stockholders' equity	986,551	936,852
Total liabilities and stockholders' equity	1,899,908	1,935,154
Class A common stock
Stockholders' equity
Common stock	31	31
Class B common stock
Stockholders' equity
Common stock	$ 31	$ 31

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Mar. 31, 2016	Dec. 31, 2015
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	30,573,509	30,573,509
Common stock, shares outstanding	30,550,907	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	31,273,130	31,273,130
Common stock, shares outstanding	31,273,130	31,273,130

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Operating revenues
Oil and gas sales	$ 25,080	$ 57,234
Other revenues	778	862
Total operating revenues	25,858	58,096
Operating costs and expenses
Lease operating	8,617	12,262
Production and ad valorem taxes	1,601	3,708
Exploration	162	164
Depletion, depreciation and amortization	41,762	52,083
Accretion of ARO liability	293	194
General and administrative	7,504	8,511
Other operating		3,012
Total operating expenses	59,939	79,934
Operating income (loss)	(34,081)	(21,838)
Other income (expense)
Interest expense	(14,798)	(14,129)
Gain on debt extinguishment	90,652
Net gain (loss) on commodity derivatives	17,219	46,306
Other income (expense)	225	(2,299)
Other income (expense), net	93,298	29,878
Income (loss) before income tax	59,217	8,040
Income tax provision (benefit)	10,703	2,344
Net income (loss)	48,514	5,696
Net income (loss) attributable to non-controlling interests	29,603	3,508
Net income (loss) attributable to controlling interests	$ 18,911	$ 2,188
Earnings per share:
Basic (in dollars per share)	$ 0.62	$ 0.12
Diluted (in dollars per share)	$ 0.62	$ 0.12
Weighted average shares outstanding:
Basic (in shares)	30,551	18,304
Diluted (in shares)	30,551	18,304

Statement of Changes in Stockho

Statement of Changes in Stockholders' Equity - 3 months ended Mar. 31, 2016 - 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, 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				1,185			1,185
Net income (loss)					18,911	29,603	48,514
Balance at Mar. 31, 2016	$ 31	$ 31	$ (358)	$ 364,908	$ 55,480	$ 566,459	$ 986,551
Balance (in shares) at Mar. 31, 2016	30,551	31,273	23

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities
Net income (loss)	$ 48,514	$ 5,696
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depletion, depreciation, and amortization	41,762	52,083
Exploration expense	27
Accretion of ARO liability	293	194
Amortization of debt issuance costs	1,129	937
Stock compensation expense	1,185	1,424
Other non-cash compensation expense	268	109
Amortization of deferred revenue	(645)	(525)
(Gain) loss on commodity derivatives	(17,219)	(46,306)
(Gain) loss on sales of assets	4	26
(Gain) on debt extinguishment	(90,652)
Deferred income tax provision	10,564	2,314
Other - net	(963)	407
Changes in operating assets and liabilities
Accounts receivable	10,655	36,268
Other assets	(1,700)	323
Accrued interest expense	(384)	10,904
Accounts payable and accrued liabilities	(7,634)	(18,340)
Net cash (used in) / provided by operations	(4,796)	45,514
Cash flows from investing activities
Additions to oil and gas properties	(7,176)	(151,104)
Proceeds from sales of assets	3	3
Acquisition of other property, plant and equipment	40	(62)
Current period settlements of matured derivative contracts	42,298	32,611
Change in restricted cash	(30)	(37)
Net cash (used in) / provided by investing	35,135	(118,589)
Cash flows from financing activities
Proceeds from issuance of long-term debt	75,000	65,000
Repayment under long-term debt		(335,000)
Proceeds from senior notes		236,475
Purchase of senior notes	(73,427)
Payment of debt issuance costs		(1,473)
Proceeds from sale of common stock		122,778
Net cash provided by financing	1,573	87,780
Net increase (decrease) in cash	31,912	14,705
Cash
Beginning of period	21,893	13,566
End of period	53,805	28,271
Supplemental disclosure of cash flow information
Cash paid for interest	14,053	1,939
Change in accrued additions to oil and gas properties	(686)	(68,521)
Current additions to ARO	$ 0	$ 736

Organization and Description of

Organization and Description of Business	3 Months Ended
	Mar. 31, 2016
Organization and Description of Business
Organization and Description of Business	1. Organization and Description of Business Organization Jones Energy, Inc. (the “Company”) was formed in March 2013 as a Delaware corporation to become a publicly-traded entity and the holding company of Jones Energy Holdings, LLC (“JEH”). As the sole managing member of JEH, the Company is responsible for all operational, management and administrative decisions relating to JEH’s business and consolidates the financial results of JEH and its subsidiaries. JEH was formed as a Delaware limited liability company on December 16, 2009 through investments made by the Jones family and through private equity funds managed by Metalmark Capital and Wells Fargo Energy Capital (collectively, the “Pre-IPO Owners”). JEH acts as a holding company of operating subsidiaries that own and operate assets that are used in the exploration, development, production and acquisition of oil and natural gas properties. The Company’s certificate of incorporation authorizes two classes of common stock, Class A common stock and Class B common stock. The Class B common stock is held by the owners of JEH prior to the Company’s initial public offering (“IPO”) and can be exchanged (together with a corresponding number of units representing membership interests in JEH (“JEH Units”)) for shares of Class A common stock on a one-for-one basis, subject to customary conversion rate adjustments for stock splits, stock dividends and reclassifications and other similar transactions. The Class B common stock has no economic rights but entitles its holders to one vote on all matters to be voted on by the Company’s stockholders generally. As a result of the IPO and as of March 31, 2016, the Pre-IPO Owners had 74.7% and 50.6%, respectively, of the total economic interest in JEH, but with no voting rights or management power over JEH, resulting in the Company reporting this ownership interest as a non-controlling interest. Description of Business The Company is engaged in the exploration, development, production and acquisition of oil and natural gas properties in the mid-continent United States. The Company’s assets are located within the Anadarko and Arkoma basins of Texas and Oklahoma, and are owned by JEH and its operating subsidiaries. The Company is headquartered in Austin, Texas.

Significant Accounting Policies

Significant Accounting Policies	3 Months Ended
	Mar. 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”). All significant intercompany transactions and balances have been eliminated in consolidation. The Company’s financial position as of December 31, 2015 and the financial statements reported for March 31, 2016 and 2015 and the three month period then ended include the Company and all of its subsidiaries. Certain prior period amounts have been reclassified to conform to the current presentation. These interim financial statements have not been audited. However, in the opinion of management, all adjustments necessary for a fair statement of the financial statements have been included, and all such adjustments are of a normal, reoccurring nature. As these are interim financial statements, they do not include all disclosures required for financial statements prepared in conformity with GAAP. Interim period results are not necessarily indicative of results of operations or cash flows for a full year. These consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Accordingly, they do not include all disclosures required by GAAP and should be read in conjunction with our most recent audited consolidated financial statements included in Jones Energy, Inc.’s Annual Report on Form 10-K for the year ended December 31, 2015. Use of Estimates There have been no significant changes in our use of estimates since those reported in Jones Energy, Inc.’s Annual Report on Form 10-K for the year ended December 31, 2015 Recent Accounting Pronouncements Adopted in the current period: In January 2015, the FASB issued ASU No. 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 has adopted ASU No. 2015-01 for the period ended March 31, 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 No. 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 No. 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 No. 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 has adopted ASU No. 2015-03 for the period ended March 31, 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 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. To be adopted in a future period: In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers,” which creates a new topic in the 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 currently evaluating the effect that the adoption of Update 2014-09 and Update 2015-14 will have on our financial statements. 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. 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. Early adoption is permitted. The Company is currently evaluating the effect that the adoption of ASU 2016-09 will have on our financial statements.

Properties, Plant and Equipment

Properties, Plant and Equipment	3 Months Ended
	Mar. 31, 2016
Properties, Plant and Equipment
Properties, Plant and Equipment	3. 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 March 31, 2016 and December 31, 2015: March 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 $ $ There were no exploratory wells during the three months ended March 31, 2016 and 2015, and as such, no associated costs were capitalized. The Company did not capitalize any interest during the three months ended March 31, 2016 as no projects lasted more than six months. Costs incurred to maintain wells and related equipment are charged to expense as incurred. Depletion of oil and gas properties amounted to $41.5 million and $51.8 million for the periods ended March 31, 2016 and March 31, 2015, respectively. The Company assessed its proved and unproved properties for impairment as of March 31, 2016 and no impairment charges were recorded. Other Property, Plant and Equipment Other property, plant and equipment consisted of the following at March 31, 2016 and December 31, 2015: March 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 $0.3 million and $0.3 million during the three months ended March 31, 2016 and 2015, respectively.

Long-Term Debt

Long-Term Debt	3 Months Ended
	Mar. 31, 2016
Long-Term Debt
Long-Term Debt	4. Long-Term Debt Long-term debt consisted of the following at March 31, 2016 and December 31, 2015: (in thousands of dollars) March 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 (together the “Issuers”), sold $500.0 million in aggregate principal amount of the Issuers’ 6.75% senior notes due 2022 (the “2022 Notes”). The Company used the net proceeds from the issuance of the 2022 Notes to repay all outstanding borrowings under the Term Loan ($160.0 million), a portion of the outstanding borrowings under the Revolver ($308.0 million) and for working capital and general corporate purposes. The Company subsequently terminated the Term Loan in accordance with its terms. The 2022 Notes bear interest at a rate of 6.75% per year, payable semi-annually on April 1 and October 1 of each year beginning October 1, 2014. On February 5, 2015, the Company filed a registration statement on Form S-4 to register exchange notes that are substantially similar to the 2022 Notes, except that the transfer restrictions, registration rights and additional interest provisions related to the outstanding 2022 Notes do not apply to the new 2022 Notes. On February 20, 2015, the registration statement was declared effective and the Company commenced an offer to exchange any and all of its $500 million outstanding principal amount of 2022 Notes for an equal amount of new 2022 Notes. The exchange offer expired on March 23, 2015. Tenders of $500 million aggregate principal amount, or 100%, of the 2022 Notes were received. 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. On November 18, 2015, the Company filed a registration statement on Form S-4 to register exchange notes that are substantially similar to the 9.25% senior notes due November 2023 (the “2023 Notes”), except that the transfer restrictions, registration rights and additional interest provisions related to the outstanding 2023 Notes do not apply to the new 2023 Notes. On January 12, 2016, the registration statement was declared effective and the Company commenced an offer to exchange any and all of its $250 million outstanding principal amount of 2023 Notes for an equal amount of new 2023 Notes. The exchange offer expired on February 11, 2016. Tenders of $250 million aggregate principal amount, or 100%, of the 2023 Notes were received. In January and February 2016, through several open market and privately negotiated purchases, the Company purchased an aggregate principal amount of $170.5 million of its senior unsecured notes. As of March 31, 2016, the Company had purchased $70.5 million principal amount of its 2022 Notes for $27.1 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 $90.7 million on a pre-tax basis. This income is recorded in Gain on debt extinguishment on the Company’s Consolidated Statement of Operations. Du ring the second quarter of 2016, the Company has repurchased additional 2022 Notes. See Note 13, “Subsequent Events,” for further discussion. The 2022 Notes and 2023 Notes are guaranteed on a senior unsecured basis by the Company and by all of its significant subsidiaries. The 2022 Notes and 2023 Notes will be senior in right of payment to any future subordinated indebtedness of the Issuers. The Company may redeem the 2022 Notes at any time on or after April 1, 2017 and the 2023 Notes at any time on or after March 15, 2018 at a declining redemption price set forth in the respective indentures, plus accrued and unpaid interest. The indentures governing the 2022 Notes and 2023 Notes are substantially identical and contain covenants that, among other things, limit the ability of the Company to incur additional indebtedness or issue certain preferred stock, pay dividends on capital stock, transfer or sell assets, make investments, create certain liens, enter into agreements that restrict dividends or other payments from the Company’s restricted subsidiaries to the Company, consolidate, merge or transfer all of the Company’s assets, engage in transactions with affiliates or create unrestricted subsidiaries. However, many of these covenants will be suspended if the Notes are rated investment grade. Other Long-Term Debt The Company entered into two credit agreements dated December 31, 2009, with Wells Fargo Bank N.A, the Senior Secured Revolving Credit Facility (the “Revolver”) and the Second Lien Term Loan (the “Term Loan”), each of which have been or were amended periodically. On April 1, 2014, the Term Loan was repaid in full and terminated in connection with the issuance of the 2022 Notes. On November 6, 2014, the Company amended the Revolver to, among other things, increase the borrowing base under the Revolver from $550.0 million to $625.0 million until the next re-determination thereof, and extend the maturity date of the Revolver to November 6, 2019. The Company’s oil and gas properties are pledged as collateral to secure its obligations under the Revolver. The borrowing base on the Revolver was subsequently adjusted to $562.5 million in accordance with its terms as a result of the issuance of the 2023 Notes in February 2015 and was reaffirmed at this level effective April 1, 2015. Effective October 8, 2015, the borrowing base was reduced to $510 million during the semi-annual borrowing base re-determination. 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. In light of current commodity prices, it is our expectation that the borrowing base will be reduced during the upcoming re-determination. 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 three months ended March 31, 2016, the average interest rate under the Revolver was 2.67% on an average outstanding balance of $143.1 million. For the three months ended March 31, 2015, the average interest rate under the Revolver was 2.46% on an average outstanding balance of $271.9 million. Total interest and commitment fees under the Revolver were $1.3 million and $2.0 million for the three months ended March 31, 2016 and 2015, respectively. Jones Energy, Inc. and its consolidated subsidiaries are subject to certain covenants under the Revolver, including the requirement to maintain the following financial ratios: · a total leverage ratio, consisting of consolidated debt to EBITDAX, of not greater than 4.00 to 1.00 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 1.0 to 1.0 as of the last day of any fiscal quarter. As of March 31, 2016, our total leverage ratio is approximately 3.0 and our current ratio is approximately 6.9, as calculated based on the requirements in our covenants. We are in compliance with all terms of our Revolver at March 31, 2016.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2016
Derivative Instruments and Hedging Activities
Derivative Instruments and Hedging Activities	5. Derivative Instruments and Hedging Activities The Company had various commodity derivatives in place that could affect its future operations as of March 31, 2016 and December 31, 2015, as follows: Hedging Positions March 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 — Basis swaps Contract differential $ ) $ ) $ ) December 2016 mmbtu per month Natural gas liquids swaps Exercise price $ $ $ December 2017 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 Basis swaps Contract differential $ ) $ ) $ ) December 2016 mmbtu per month Natural gas liquids swaps Exercise price $ $ $ December 2017 Barrels per month The Company recognized a net gain on derivative instruments of $17.2 million and $46.3 million for the three months ended March 31, 2016 and 2015, respectively. The Company routinely enters into oil and natural gas swap contracts as seller, thus resulting in a fixed rate. In the first quarter of 2016, the Company crystalized 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 crystalized 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. Since no contracts were canceled or liquidated, 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 March 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. We adopted the guidance requiring disclosure of both gross and net information about financial instruments eligible for netting in the balance sheet under our derivative agreements. The following table presents information about our commodity derivative contracts that are netted on our Consolidated Balance Sheet as of March 31, 2016 and December 31, 2015: (in thousands of dollars) Gross Amounts of Recognized Assets / Liabilities Gross Amounts Offset in the Balance Sheet Net Amounts of Assets / Liabilities Presented in the Balance Sheet Gross Amounts Not Offset in the Balance Sheet Net Amount March 31, 2016 Commodity derivative contracts Assets $ $ ) $ $ — $ Liabilities ) — — — December 31, 2015 Commodity derivative contracts Assets $ $ ) $ $ — $ Liabilities ) ) — )

Fair Value Measurement

Fair Value Measurement	3 Months Ended
	Mar. 31, 2016
Fair Value Measurement
Fair Value Measurement	6. 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 March 31, 2016 and December 31, 2015, by consolidated balance sheet caption and by valuation hierarchy, as described above are as follows: March 31, 2016 (in thousands of dollars) Fair Value Measurements Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ $ $ Long-term assets — — Current liabilities — — — — Long-term liabilities — — — — December 31, 2015 (in thousands of dollars) Fair Value Measurements Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ $ $ Long-term assets — — Current liabilities — — Long-term 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 March 31, 2016. Quantitative Information About Level 3 Fair Value Measurements Commodity Price Hedges Fair Value (000’s) Valuation Technique Unobservable Input Range Natural gas liquid swaps $ Use a discounted cash flow approach using inputs including forward price statements from counterparties Natural gas liquid futures prices $8.90 - $47.25 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 three months ended March 31, 2016. Changes in fair value of Level 3 instruments represent changes in gains and losses for the periods that are reported in other income (expense). New contracts entered into during the year are generally entered into at no cost with changes in fair value from the date of agreement representing the entire fair value of the instrument. Transfers between levels are evaluated at the end of the reporting period. (in thousands of dollars) Balance at December 31, 2015, net $ Purchases — Settlements ) Transfers to Level 2 — Transfers to Level 3 — Changes in fair value ) Balance at March 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: March 31, 2016 December 31, 2015 (in thousands of dollars) Principal Amount Fair Value Principal Amount Fair Value Debt: Revolver $ $ $ $ 2022 Notes 2023 Notes The Revolver (as defined in Note 4) 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 4) 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 4) 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. The Company reviews its proved oil and gas properties for impairment purposes by comparing the expected undiscounted future cash flows at a producing field level to the unamortized capitalized cost of the asset. Significant assumptions associated with the calculation of future cash flows used in the impairment analysis include the Company’s estimate of future commodity prices, production costs, development expenditures, production, risk-adjusted discount rates, and other relevant data. As such, the fair value of oil and gas properties used in estimating impairment represents a nonrecurring Level 3 measurement.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2016
Asset Retirement Obligations
Asset Retirement Obligations	7. Asset Retirement Obligations A summary of the Company’s ARO for three months ended March 31, 2016 is as follows: (in thousands of dollars) Balance at December 31, 2015 $ Liabilities incurred — Accretion of ARO liability Liabilities settled due to sale of related properties — Liabilities settled due to plugging and abandonment ) Change in estimate Balance at March 31, 2016 Less: Current portion of ARO ) Total long-term ARO at March 31, 2016 $

Stock-based Compensation

Stock-based Compensation	3 Months Ended
	Mar. 31, 2016
Stock-based Compensation
Stock-based Compensation	8. 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 March 31, 2016: JEH Units Weighted Average Grant Date Fair Value per Share Unvested at December 31, 2015 $ Granted Forfeited ) Vested ) Unvested at March 31, 2016 $ Stock compensation expense associated with the management units was $0.5 million and $0.3 million for the three months ended March 31, 2016 and 2015, respectively and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. 2013 Omnibus Incentive Plan Under the Jones Energy, Inc. 2013 Omnibus Incentive Plan (the “LTIP”), established in conjunction with the Company’s IPO, the Company reserved 3,850,000 shares of Class A common stock for non-employee director, consultant and employee stock-based compensation awards. On May 4, 2016, following approval by the Company’s stockholders, the Company adopted the Amended and Restated LTIP, pursuant to which, among other things, the Company reserved an additional 3,500,000 shares of Class A common stock for non-employee director, consultant and employee stock-based compensation awards. The Company granted (i) performance 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 and 2015. 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 was based on the value of the Company’s Class A common stock on the date of grant and is expensed on a straight-line basis over the applicable 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 March 31, 2016: Restricted Stock Unit Awards Weighted Average Grant Date Fair Value per Share Unvested at December 31, 2015 $ Granted Forfeited ) Vested — — Unvested at March 31, 2016 $ Stock compensation expense associated with the employee restricted stock unit awards for the three months ended March 31, 2016 and 2015 was $0.1 million and $0.5 million, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. Performance Unit Awards The Company has outstanding performance unit awards granted to certain members of the senior management team of the Company under the LTIP. Upon the completion of the applicable three-year performance period, each recipient may vest in a number of performance units. The percent of awarded performance 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 unit is exchangeable for one share of the Company’s Class A common stock. The grant date fair value of the performance units was determined using a Monte Carlo simulation model, which results in an estimated percentage of performance units earned. The fair value of the performance units is expensed on a straight-line basis over the applicable three-year performance period. The following table summarizes information related to the total number of units awarded to the officers as of March 31, 2016: Performance Unit Awards Weighted Average Grant Date Fair Value per Share Unvested at December 31, 2015 $ Granted Forfeited ) Vested — — Unvested at March 31, 2016 $ Stock compensation expense associated with the performance unit awards for the three months ended March 31, 2016 and 2015 was $0.4 million and $0.4 million, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations. Restricted Stock Awards The Company has outstanding restricted stock awards granted to the Company’s non-employee members of the Board of Directors 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 March 31, 2016: Restricted Stock Awards Weighted Average Grant Date Fair Value per Share Unvested at December 31, 2015 $ Granted — — Forfeited — — Vested — — Unvested at March 31, 2016 $ Stock compensation expense associated with the Board of Directors awards for the three months ended March 31, 2016 and 2015 was $0.2 million and $0.1 million, respectively, and is included in general and administrative expenses on the Company’s Consolidated Statement of Operations.

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2016
Income Taxes
Income Taxes	9. 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 Company’s effective tax rate for the three months ended March 31, 2016 and 2015 was 18.1% and 29.2%, respectively. The effective rate differs from the statutory rate of 35% due to net income allocated to the non-controlling interest, percentage depletion, state income taxes, and other permanent differences between book and tax accounting. The Company’s income tax provision was an expense of $10.7 million and $2.3 million for the three months ended March 31, 2016 and 2015, respectively. The following table summarizes information related to the allocation of the income tax provision between the controlling and non-controlling interests: Three Months Ended March 31, (in thousands of dollars) 2016 2015 Jones Energy, Inc. $ $ Non-controlling interest Income tax provision (benefit) $ $ The Company had deferred tax assets for its federal and state net operating loss carry forwards at March 31, 2016 recorded in its deferred taxes. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. As of March 31, 2016, we have a valuation allowance of $3.5 million as a result of management’s assessment of the realizability of deferred tax assets in Oklahoma. 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. Tax Receivable Agreement As of March 31, 2016 and December 31, 2015, respectively, the Company had recorded a TRA liability of $37.6 million and $38.1 million for the estimated payments that will be made to the pre-IPO members who have exchanged shares. Such exchanges generated tax basis increases leading to deferred tax assets as of March 31, 2016 and December 31, 2015, respectively, of $44.3 million and $44.8 million, net of valuation allowance. During the three months ended March 31, 2016, the amount of the TRA liability was reduced by $0.5 million as a result of the valuation allowance recorded against the Company’s deferred tax assets, which was recorded in other income (expense) on the Company’s Consolidated Statement of Operations. 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 March 31, 2016, the Company had not made any payments under the TRA to pre-IPO members who have exchanged JEH units and Class B common stock for Class A common stock. The Company does not anticipate making a material payment under the TRA in either 2016 or 2017.

Earnings per Share

Earnings per Share	3 Months Ended
	Mar. 31, 2016
Earnings per Share
Earnings per Share	10. Earnings per Share Basic earnings per share (“EPS”) is computed by dividing net income (loss) attributable to controlling interests by the weighted average number of shares of Class A common stock outstanding during the period. Shares of Class B common stock are not included in the calculation of earnings per share because they are not participating securities and have no economic interest in the Company. Diluted earnings per share takes into account the potential dilutive effect of shares that could be issued by the Company in conjunction with stock awards that have been granted to directors and employees. Awards of nonvested 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 three months ending March, 31, 2016, 606,272 restricted stock units, and 469,923 performance units were excluded from the calculation as they would have had an anti-dilutive effect. The following is a calculation of the basic and diluted weighted-average number of shares of Class A common stock outstanding and EPS for the three months ended March 31, 2016: (in thousands, except per share data) Three Months Ended March 31, 2016 Income (numerator): Net income attributable to controlling interests $ 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 per share: Basic $ Diluted $

Related Parties

Related Parties	3 Months Ended
	Mar. 31, 2016
Related Parties
Related Parties	11. 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. 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. Therefore, no related party revenue relating to natural gas and NGL production was recognized during 2016 associated with the aforementioned agreement. 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 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 three months ended March 31, 2016 and 2015, the Company amortized $0.6 million and $0.5 million, respectively, of the deferred revenue balance. This revenue is recorded in Other revenues on the Company’s Consolidated Statement of Operations. 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 of $0.7 million which were paid to Monarch Oil Pipeline LLC associated with the approximately 0.3 MMBoe of oil production transported under the agreement for the three months ended March 31, 2016. 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. Purchases of Senior Unsecured Notes On February 29, 2016, JEH and Jones Energy Finance Corp. purchased $50.0 million principal amount of their outstanding 2023 Notes from investment funds managed by Magnetar Capital and its affiliates, which investment funds collectively 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	3 Months Ended
	Mar. 31, 2016
Commitments and Contingencies
Commitments and Contingencies	12. Commitments and Contingencies The Company is subject to legal proceedings and claims that arise in the ordinary course of its business. The Company believes that the final disposition of such matters will not have a material adverse effect on its financial position, results of operations, or liquidity.

Subsequent Events

Subsequent Events	3 Months Ended
	Mar. 31, 2016
Subsequent Events
Subsequent Events	13. Subsequent Events During the second quarter of 2016 through April 29, 2016, the Company purchased, through several open market purchases, $20.3 million principal amount of its 2022 Notes for $11.2 million excluding accrued interest and including any associated fees. This debt was not cancelled and is available for future reissuance at the Company’s discretion. The Company used cash on hand to fund the note purchases. As a result of these purchases, the Company had aggregate principal amount of senior unsecured notes outstanding of $559.1 million, outstanding borrowings under its revolving credit facility of $185.0 million, $325.0 million undrawn on its revolving credit facility, and approximately $34.3 million in cash as of April 29, 2016. On April 12, 2016, JEH made an aggregate cash tax distribution of approximately $10.9 million to its members, including the Company, in accordance with the terms of its operating agreement. The distribution was made pro-rata to all members, and resulted in a $5.4 million payment to the Company, and a $5.5 million payment to Pre-IPO Owners. The distribution was based on projected taxable income of JEH for 2016 and represented the first quarterly payment required under the terms of its operating agreement. The determination regarding the payment of such amount was made by a Special Committee of the Board of Directors of the Company comprised solely of directors who do not have a direct or indirect financial interest in such distribution. On May 4, 2016, following approval by the Company’s stockholders, the Company adopted the Amended and Restated LTIP, pursuant to which, among other things, the Company reserved an additional 3,500,000 shares of Class A common stock for non-employee director, consultant and employee stock-based compensation awards.

Subsidiary Guarantors

Subsidiary Guarantors	3 Months Ended
	Mar. 31, 2016
Subsidiary Guarantors
Subsidiary Guarantors	14. 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. The 2022 Notes and the 2023 Notes are guaranteed on a senior unsecured basis by the Company and by all of JEH’s current subsidiaries (except Jones Energy Finance Corp. and two immaterial subsidiaries) and certain future subsidiaries, including any future subsidiaries that guarantee any indebtedness under the Revolver. Each subsidiary guarantor is 100% owned by JEH, and all guarantees are full and unconditional, subject to customary exceptions pursuant to the indentures governing our 2022 Notes and 2023 Notes, as discussed below, and joint and several with all other subsidiary guarantees and the parent guarantee. Any subsidiaries of JEH other than the subsidiary guarantors and Jones Energy Finance Corp. are immaterial. 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 March 31, 2016, the Company held approximately 49.4% of the economic interest in JEH, with the remaining 50.6% economic interest held by a group of investors that owned interests in JEH prior to the Company’s IPO (the “Pre-IPO Owners”). The Pre-IPO Owners have no voting rights with respect to their economic interest in JEH. The Company has two classes of common stock, Class A common stock, which was sold to investors in the IPO, and Class B common stock. Pursuant to the Company’s certificate of incorporation, each share of Class A common stock is entitled to one vote per share, and the shares of Class A common stock are entitled to 100% of the economic interests in the Company. Each share of Class B common stock has no economic rights in the Company, but entitles its holder to one vote on all matters to be voted on by the Company’s stockholders generally. In connection with a reorganization that occurred immediately prior to the IPO, each Existing Owner was issued a number of shares of Class B common stock that was equal to the number of JEH Units that such Existing Owner 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 Pre-IPO Owners collectively have a number of votes in the Company equal to the aggregate number of JEH Units that they hold. The Pre-IPO Owners have the right, pursuant to the terms of an Exchange Agreement by and among the Company, JEH and each of the Pre-IPO Owners, to exchange their JEH Units (together with a corresponding number of shares of Class B common stock) for shares of Class A common stock on a one-for-one basis, subject to customary conversion rate adjustments for stock splits, stock dividends and reclassifications and other similar transactions. As a result, the Company expects that over time the Company will have an increasing economic interest in JEH as Class B common stock and JEH Units are exchanged for Class A common stock. Moreover, any transfers of JEH Units outside of the Exchange Agreement (other than permitted transfers to affiliates) must be approved by the Company. The Company intends to retain full voting and management control over JEH. Jones Energy, Inc. Condensed Consolidating Balance Sheet March 31, 2016 (in thousands of dollars) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets Cash $ $ $ $ $ — $ Restricted 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 — — — — — — Asset retirement obligations — — — — Intercompany payable — — ) — Total current liabilities — ) Long-term debt — — — — Deferred revenue — — — — Asset retirement obligations — — — — Liability under tax receivable agreement — — — — 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 — — — — Class B common stock, $0.001 par value; 31,273,130 shares issued and outstanding — — — — Treasury stock, at cost; 22,602 shares ) — — — — ) Additional paid-in-capital — — — — Retained earnings — — — — Stockholders’ equity ) ) Non-controlling interest — — — — Total stockholders’ equity ) ) Total liabilities and stockholders’ equity $ $ $ $ $ ) $ Jones Energy, Inc. Condensed Consolidating Balance Sheet December 31, 2015 (in thousands of dollars) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets Cash $ $ $ $ $ — $ Restricted 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 — — — — Asset retirement obligations — — — — Intercompany payable — — ) — Total current liabilities — ) Long-term debt — — — — Deferred revenue — — — — Asset retirement obligations — — — — Liability under tax receivable agreement — — — — 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 — — — — Class B common stock, $0.001 par value; 31,273,130 shares issued and outstanding — — — — Treasury stock, at cost; 22,602 shares ) ) Additional paid-in-capital — — — — Retained earnings — — — — Stockholders’ equity ) ) Non-controlling interest — — — — Total stockholders’ equity ) ) Total liabilities and stockholders’ equity $ $ $ $ $ ) $ Jones Energy, Inc. Condensed Consolidating Statement of Operations and Comprehensive Income Three Months Ended March 31, 2016 (in thousands) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor 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 — ) ) ) — ) 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 — — — Net income (loss) $ $ $ ) $ ) $ ) $ Net income attributable to non-controlling interests — — — — Net income attributable to controlling interests $ $ — $ — $ — $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Operations and Comprehensive Income Three Months Ended March 31, 2015 (in thousands) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor 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 — ) ) ) — ) 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 — — — Net income (loss) $ $ $ ) $ ) $ ) $ Net income attributable to non-controlling interests — — — — Net income attributable to controlling interests $ $ — $ — $ — $ — $ Jones Energy, Inc. Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2016 (in thousands of dollars) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor 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 — — — — Change in restricted cash — — ) — — ) 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 — — — — — — Purchase of 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 Three Months Ended March 31, 2015 (in thousands of dollars) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor 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 — — — — Change in restricted cash — — ) — — ) 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 $ $ $ $ $ — $

Significant Accounting Polici21

Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 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”). All significant intercompany transactions and balances have been eliminated in consolidation. The Company’s financial position as of December 31, 2015 and the financial statements reported for March 31, 2016 and 2015 and the three month period then ended include the Company and all of its subsidiaries. Certain prior period amounts have been reclassified to conform to the current presentation. These interim financial statements have not been audited. However, in the opinion of management, all adjustments necessary for a fair statement of the financial statements have been included, and all such adjustments are of a normal, reoccurring nature. As these are interim financial statements, they do not include all disclosures required for financial statements prepared in conformity with GAAP. Interim period results are not necessarily indicative of results of operations or cash flows for a full year. These consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”) regarding interim financial reporting. Accordingly, they do not include all disclosures required by GAAP and should be read in conjunction with our most recent audited consolidated financial statements included in Jones Energy, Inc.’s Annual Report on Form 10-K for the year ended December 31, 2015.
Use of Estimates	Use of Estimates There have been no significant changes in our use of estimates since those reported in Jones Energy, Inc.’s Annual Report on Form 10-K for the year ended December 31, 2015
Recent Accounting Pronouncements	Recent Accounting Pronouncements Adopted in the current period: In January 2015, the FASB issued ASU No. 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 has adopted ASU No. 2015-01 for the period ended March 31, 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 No. 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 No. 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 No. 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 has adopted ASU No. 2015-03 for the period ended March 31, 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 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. To be adopted in a future period: In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2014-09, “Revenue from Contracts with Customers,” which creates a new topic in the 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 currently evaluating the effect that the adoption of Update 2014-09 and Update 2015-14 will have on our financial statements. 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. 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. Early adoption is permitted. The Company is currently evaluating the effect that the adoption of ASU 2016-09 will have on our financial statements.

Properties, Plant and Equipme22

Properties, Plant and Equipment (Tables)	3 Months Ended
	Mar. 31, 2016
Properties, Plant and Equipment
Schedule of oil and gas properties	March 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	March 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)	3 Months Ended
	Mar. 31, 2016
Long-Term Debt
Summary of long-term debt	(in thousands of dollars) March 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 He24

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 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	March 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 — Basis swaps Contract differential $ ) $ ) $ ) December 2016 mmbtu per month Natural gas liquids swaps Exercise price $ $ $ December 2017 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 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	(in thousands of dollars) Gross Amounts of Recognized Assets / Liabilities Gross Amounts Offset in the Balance Sheet Net Amounts of Assets / Liabilities Presented in the Balance Sheet Gross Amounts Not Offset in the Balance Sheet Net Amount March 31, 2016 Commodity derivative contracts Assets $ $ ) $ $ — $ Liabilities ) — — — December 31, 2015 Commodity derivative contracts Assets $ $ ) $ $ — $ Liabilities ) ) — )

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	3 Months Ended
	Mar. 31, 2016
Fair Value Measurement
Schedule of financial instruments carried at fair value	March 31, 2016 (in thousands of dollars) Fair Value Measurements Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ $ $ Long-term assets — — Current liabilities — — — — Long-term liabilities — — — — December 31, 2015 (in thousands of dollars) Fair Value Measurements Commodity Price Hedges (Level 1) (Level 2) (Level 3) Total Current assets $ — $ $ $ Long-term assets — — Current liabilities — — Long-term liabilities — — — —
Schedule of quantitative information about Level 3 inputs used in the fair value measurement, assets	The following table represents quantitative information about Level 3 inputs used in the fair value measurement of the Company’s commodity derivative contracts as of March 31, 2016. Quantitative Information About Level 3 Fair Value Measurements Commodity Price Hedges Fair Value (000’s) Valuation Technique Unobservable Input Range Natural gas liquid swaps $ Use a discounted cash flow approach using inputs including forward price statements from counterparties Natural gas liquid futures prices $8.90 - $47.25 per barrel
Schedule of changes in fair value of Level 3 financial instruments	(in thousands of dollars) Balance at December 31, 2015, net $ Purchases — Settlements ) Transfers to Level 2 — Transfers to Level 3 — Changes in fair value ) Balance at March 31, 2016, net $
Schedule of fair value of financial instruments that are not recorded at fair value in the consolidated financial statements	March 31, 2016 December 31, 2015 (in thousands of dollars) Principal Amount Fair Value Principal Amount Fair Value Debt: Revolver $ $ $ $ 2022 Notes 2023 Notes

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2016
Asset Retirement Obligations
Summary of the Company's ARO	(in thousands of dollars) Balance at December 31, 2015 $ Liabilities incurred — Accretion of ARO liability Liabilities settled due to sale of related properties — Liabilities settled due to plugging and abandonment ) Change in estimate Balance at March 31, 2016 Less: Current portion of ARO ) Total long-term ARO at March 31, 2016 $

Stock-based Compensation (Table

Stock-based Compensation (Tables)	3 Months Ended
	Mar. 31, 2016
Management Unit Awards
Stock-based Compensation
Summary of information related to the Units/shares or awards	JEH Units Weighted Average Grant Date Fair Value per Share Unvested at December 31, 2015 $ Granted Forfeited ) Vested ) Unvested at March 31, 2016 $
Restricted Stock Unit Awards
Stock-based Compensation
Summary of information related to the Units/shares or awards	Restricted Stock Unit Awards Weighted Average Grant Date Fair Value per Share Unvested at December 31, 2015 $ Granted Forfeited ) Vested — — Unvested at March 31, 2016 $
Performance Unit Awards
Stock-based Compensation
Summary of information related to the Units/shares or awards	Performance Unit Awards Weighted Average Grant Date Fair Value per Share Unvested at December 31, 2015 $ Granted Forfeited ) Vested — — Unvested at March 31, 2016 $
Restricted Stock Awards
Stock-based Compensation
Summary of information related to the Units/shares or awards	Restricted Stock Awards Weighted Average Grant Date Fair Value per Share Unvested at December 31, 2015 $ Granted — — Forfeited — — Vested — — Unvested at March 31, 2016 $

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2016
Income Taxes
Schedule of allocation of the income tax provision between the controlling and non-controlling interests	Three Months Ended March 31, (in thousands of dollars) 2016 2015 Jones Energy, Inc. $ $ Non-controlling interest Income tax provision (benefit) $ $

Earnings per Share (Tables)

Earnings per Share (Tables)	3 Months Ended
	Mar. 31, 2016
Earnings per Share
Schedule of calculation of the basic and diluted weighted-average shares and EPS	(in thousands, except per share data) Three Months Ended March 31, 2016 Income (numerator): Net income attributable to controlling interests $ 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 per share: Basic $ Diluted $

Subsidiary Guarantors (Tables)

Subsidiary Guarantors (Tables)	3 Months Ended
	Mar. 31, 2016
Subsidiary Guarantors
Condensed Consolidating Balance Sheet	Condensed Consolidating Balance Sheet March 31, 2016 (in thousands of dollars) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets Cash $ $ $ $ $ — $ Restricted 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 — — — — — — Asset retirement obligations — — — — Intercompany payable — — ) — Total current liabilities — ) Long-term debt — — — — Deferred revenue — — — — Asset retirement obligations — — — — Liability under tax receivable agreement — — — — 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 — — — — Class B common stock, $0.001 par value; 31,273,130 shares issued and outstanding — — — — Treasury stock, at cost; 22,602 shares ) — — — — ) Additional paid-in-capital — — — — Retained earnings — — — — Stockholders’ equity ) ) Non-controlling interest — — — — Total stockholders’ equity ) ) Total liabilities and stockholders’ equity $ $ $ $ $ ) $ Condensed Consolidating Balance Sheet December 31, 2015 (in thousands of dollars) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor Subsidiaries Eliminations Consolidated Assets Current assets Cash $ $ $ $ $ — $ Restricted 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 — — — — Asset retirement obligations — — — — Intercompany payable — — ) — Total current liabilities — ) Long-term debt — — — — Deferred revenue — — — — Asset retirement obligations — — — — Liability under tax receivable agreement — — — — 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 — — — — Class B common stock, $0.001 par value; 31,273,130 shares issued and outstanding — — — — Treasury stock, at cost; 22,602 shares ) ) Additional paid-in-capital — — — — Retained earnings — — — — Stockholders’ equity ) ) Non-controlling interest — — — — Total stockholders’ equity ) ) Total liabilities and stockholders’ equity $ $ $ $ $ ) $
Condensed Consolidating Statement of Operations and Comprehensive Income	Condensed Consolidating Statement of Operations and Comprehensive Income Three Months Ended March 31, 2016 (in thousands) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor 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 — ) ) ) — ) 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 — — — Net income (loss) $ $ $ ) $ ) $ ) $ Net income attributable to non-controlling interests — — — — Net income attributable to controlling interests $ $ — $ — $ — $ — $ Condensed Consolidating Statement of Operations and Comprehensive Income Three Months Ended March 31, 2015 (in thousands) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor 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 — ) ) ) — ) 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 — — — Net income (loss) $ $ $ ) $ ) $ ) $ Net income attributable to non-controlling interests — — — — Net income attributable to controlling interests $ $ — $ — $ — $ — $
Condensed Consolidating Statement of Cash Flows	Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2016 (in thousands of dollars) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor 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 — — — — Change in restricted cash — — ) — — ) 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 — — — — — — Purchase of 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 $ $ $ $ $ — $ Condensed Consolidating Statement of Cash Flows Three Months Ended March 31, 2015 (in thousands of dollars) JEI (Parent) Issuers Guarantor Subsidiaries Non- Guarantor 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 — — — — Change in restricted cash — — ) — — ) 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 $ $ $ $ $ — $

Organization and Description 31

Organization and Description of Business (Details)	3 Months Ended
	Mar. 31, 2016Voteclass	Jul. 29, 2013
Organization
Classes of stock, number | class	2
Number of votes for each holder of common stock | Vote	1
Pre-IPO Owners (Existing Owners)
Organization
Ratio in which JEH Units and Class B common stock are exchanged for Class A common stock	1
The Existing Owners' economic interest in JEH (as a percent)	50.60%	74.70%

Significant Accounting Polici32

Significant Accounting Policies - Recent Accounting Pronouncements (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Recent Accounting Pronouncements
Other assets	$ 7,309	$ 7,709
Long-term debt	$ 749,312	837,654
Scenario, Adjustment | Accounting Standards Update 2015-03
Recent Accounting Pronouncements
Other assets		(10,300)
Long-term debt		$ (10,300)

Properties, Plant and Equipme33

Properties, Plant and Equipment - Oil and Gas Properties - Tabular Information (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Mineral interests in properties
Unproved	$ 75,769	$ 75,308
Proved	1,034,029	1,031,669
Wells and equipment and related facilities	1,292,491	1,289,323
Gross oil and gas properties	2,402,289	2,396,300
Less: Accumulated depletion and impairment	(801,999)	(760,534)
Net oil and gas properties	$ 1,600,290	$ 1,635,766

Properties, Plant and Equipme34

Properties, Plant and Equipment - Oil and Gas Properties - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Oil and Gas Properties
Costs capitalized in connection with exploratory wells	$ 0	$ 0
Amount of capitalized interest on expenditures	0
Depletion of oil and gas properties	41,500	$ 51,800
Impairments of proved or unproved oil and gas properties	$ 0

Properties, Plant and Equipme35

Properties, Plant and Equipment - Other Property, Plant and Equipment - Tabular Information (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Other Property, Plant and Equipment
Gross other property, plant and equipment	$ 8,004	$ 8,044
Less: Accumulated depreciation and amortization	(4,495)	(4,171)
Net other property, plant and equipment	3,509	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	4,092	4,090
Vehicles
Other Property, Plant and Equipment
Gross other property, plant and equipment	1,537	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	$ 252	$ 247

Properties, Plant and Equipme36

Properties, Plant and Equipment - Other Property, Plant and Equipment - Depreciation and Amortization (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Properties, Plant and Equipment
Depreciation and amortization of other property, plant and equipment	$ 0.3	$ 0.3

Long-Term Debt - Tabular Disclo

Long-Term Debt - Tabular Disclosure (Details) - USD ($) $ in Thousands	Apr. 29, 2016	Mar. 31, 2016	Dec. 31, 2015
Long-Term Debt
Total principal amount		$ 764,485	$ 860,000
Less: unamortized discount		(7,000)	(12,088)
Less: debt issuance costs, net		(8,173)	(10,258)
Total carrying amount		749,312	837,654
Senior notes
Long-Term Debt
Total principal amount	$ 559,100
2022 Notes | Senior notes
Long-Term Debt
Total principal amount		429,485	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	$ 185,000	$ 185,000	$ 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	Feb. 29, 2016	Mar. 31, 2016	Mar. 31, 2015	Feb. 11, 2016	Jan. 12, 2016	Nov. 18, 2015	Mar. 23, 2015	Feb. 20, 2015
Senior Unsecured Notes
Notes proceeds from issuance						$ 236,475
Repayment under long-term debt						$ 335,000
Gain on debt extinguishment					$ 90,652
Senior notes
Senior Unsecured Notes
Aggregate principal amount repurchased	$ 170,500			$ 170,500
Gain on debt extinguishment				90,700
2022 Notes | Senior notes
Senior Unsecured Notes
Aggregate principal amount			$ 500,000							$ 500,000	$ 500,000
Stated interest rate (as a percent)			6.75%
Tenders received (as a percent)										100.00%
Aggregate principal amount repurchased	70,500			70,500
Purchased amount				27,100
2023 Notes | Senior notes
Senior Unsecured Notes
Aggregate principal amount		$ 250,000					$ 250,000	$ 250,000
Stated interest rate (as a percent)		9.25%							9.25%
Discount of principal amount (as a percent)		94.59%
Notes proceeds from issuance		$ 236,500
Tenders received (as a percent)							100.00%
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 repurchased	100,000			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	3 Months Ended
	Mar. 31, 2016USD ($)	Mar. 31, 2015USD ($)	Oct. 08, 2015USD ($)	Feb. 23, 2015USD ($)	Nov. 06, 2014USD ($)	Nov. 05, 2014USD ($)	Dec. 31, 2009agreement
Other Long-Term Debt
Number of credit agreements | agreement							2
Revolving credit facility | Revolver
Other Long-Term Debt
Borrowing base			$ 510	$ 562.5	$ 625	$ 550
Average interest rate (as a percent)	2.67%	2.46%
Average outstanding balance	$ 143.1	$ 271.9
Total interest and commitment fees	$ 1.3	$ 2
Covenant, total leverage ratio	4
Covenant, current ratio	1
Total leverage ratio	3
Current ratio	6.9
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%

Derivative Instruments and He40

Derivative Instruments and Hedging Activities - Hedging Positions (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2016$ / bblbbl / moMMBTU / mo$ / MMBTU	Dec. 31, 2015bbl / moMMBTU / mo$ / bbl$ / MMBTU
Basis swaps | Minimum
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU		(0.39)
Net mmbtu per month (in mmbtu per month) | MMBTU / mo		1,190,000
Basis swaps | Maximum
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU		(0.11)
Net mmbtu per month (in mmbtu per month) | MMBTU / mo		1,730,000
Basis swaps | Weighted Average
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU		(0.18)
Net mmbtu per month (in mmbtu per month) | MMBTU / mo		1,360,833
Oil | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl		54.53
Net barrels per month (in barrels per month) | bbl / mo		54,000
Oil | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl		100.87
Net barrels per month (in barrels per month) | bbl / mo		194,000
Oil | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl		79.16
Net barrels per month (in barrels per month) | bbl / mo		97,119
Natural gas | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU		3.22
Net mmbtu per month (in mmbtu per month) | MMBTU / mo		700,000
Natural gas | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU		6.45
Net mmbtu per month (in mmbtu per month) | MMBTU / mo		1,640,000
Natural gas | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU		4.25
Net mmbtu per month (in mmbtu per month) | MMBTU / mo		1,042,857
Natural gas liquids | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / bbl		8.90
Net mmbtu per month (in mmbtu per month) | bbl / mo		2,000
Natural gas liquids | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / bbl		95.24
Net mmbtu per month (in mmbtu per month) | bbl / mo		112,000
Natural gas liquids | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / bbl		32.62
Net mmbtu per month (in mmbtu per month) | bbl / mo		51,792
Commodity Derivative Instruments | Basis swaps | Minimum
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU	0.30
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	1,240,000
Commodity Derivative Instruments | Basis swaps | Maximum
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU	(0.15)
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	1,380,000
Commodity Derivative Instruments | Basis swaps | Weighted Average
Hedging Positions
Contract differential (in dollars per mmbtu) | $ / MMBTU	(0.18)
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	1,295,556
Commodity Derivative Instruments | Oil | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl	60
Offset exercise price (in dollars per barrel) | $ / bbl	34.70
Commodity Derivative Instruments | Oil | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl	92.60
Offset exercise price (in dollars per barrel) | $ / bbl	49
Net barrels per month (in barrels per month) | bbl / mo	133,000
Commodity Derivative Instruments | Oil | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl	79.97
Offset exercise price (in dollars per barrel) | $ / bbl	44.53
Net barrels per month (in barrels per month) | bbl / mo	51,436
Commodity Derivative Instruments | Natural gas | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU	2.84
Offset exercise price (in dollars per mmbtu) | $ / MMBTU	2.34
Commodity Derivative Instruments | Natural gas | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU	5.56
Offset exercise price (in dollars per mmbtu) | $ / MMBTU	3.02
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	1,500,000
Commodity Derivative Instruments | Natural gas | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per mmbtu) | $ / MMBTU	4.21
Offset exercise price (in dollars per mmbtu) | $ / MMBTU	2.83
Net mmbtu per month (in mmbtu per month) | MMBTU / mo	619,231
Commodity Derivative Instruments | Natural gas liquids | Swaps | Minimum
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl	8.90
Net barrels per month (in barrels per month) | bbl / mo	2,000
Commodity Derivative Instruments | Natural gas liquids | Swaps | Maximum
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl	84.11
Net barrels per month (in barrels per month) | bbl / mo	107,000
Commodity Derivative Instruments | Natural gas liquids | Swaps | Weighted Average
Hedging Positions
Exercise price (in dollars per barrel) | $ / bbl	32.94
Net barrels per month (in barrels per month) | bbl / mo	43,381

Derivative Instruments and He41

Derivative Instruments and Hedging Activities - Recognized Gain (Loss ) on Derivative Instruments (Details) - Commodity Derivative Instruments $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)contract	Mar. 31, 2015USD ($)
Recognized Net Gain (Loss) on Derivative Instruments
Net gains (losses) recognized on derivative instruments | $	$ 17.2	$ 46.3
Number of canceled or liquidated contracts | contract	0

Derivative Instruments and He42

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

Derivative Instruments and He43

Derivative Instruments and Hedging Activities - Offsetting Assets (Details) - Commodity Derivative Instruments - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Assets
Gross Amounts of Recognized Assets	$ 192,936	$ 218,036
Gross Amounts Offset in the Balance Sheet	(890)	(527)
Net Amounts of Assets Presented in the Balance Sheet	192,046	217,509
Net Amount	$ 192,046	$ 217,509

Derivative Instruments and He44

Derivative Instruments and Hedging Activities - Offsetting Liabilities (Details) - Commodity Derivative Instruments - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Liabilities
Gross Amounts of Recognized Liabilities	$ (890)	$ (538)
Gross Amounts Offset in the Balance Sheet	$ 890	527
Net Amounts of Liabilities Presented in the Balance Sheet		(11)
Net Amount		$ (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	Mar. 31, 2016	Dec. 31, 2015
Valuation Hierarchy
Current assets	$ 107,762	$ 124,207
Long-term assets	84,284	93,302
Current liabilities		11
Recurring | Commodity Derivative Instruments
Valuation Hierarchy
Current assets	107,762	124,207
Long-term assets	84,284	93,302
Current liabilities		11
Recurring | Level 2 | Commodity Derivative Instruments
Valuation Hierarchy
Current assets	106,795	122,779
Long-term assets	84,284	93,302
Current liabilities		11
Recurring | Level 3 | Commodity Derivative Instruments
Valuation Hierarchy
Current assets	$ 967	$ 1,428

Fair Value Measurement - Quanti

Fair Value Measurement - Quantitative Information about Level 3 Inputs - Assets (Details) - Commodity Derivative Instruments $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)$ / bbl	Dec. 31, 2015USD ($)
Commodity Derivative Instruments - Assets
Fair Value | $	$ 192,936	$ 218,036
Natural gas liquids | Swaps | Minimum
Commodity Derivative Instruments - Assets
Natural gas liquid futures prices (in dollars per barrel)	8.90
Natural gas liquids | Swaps | Maximum
Commodity Derivative Instruments - Assets
Natural gas liquid futures prices (in dollars per barrel)	84.11
Discounted cash flow approach | Level 3 | Natural gas liquids | Swaps
Commodity Derivative Instruments - Assets
Fair Value | $	$ 967
Discounted cash flow approach | Level 3 | Natural gas liquids | Swaps | Minimum
Commodity Derivative Instruments - Assets
Natural gas liquid futures prices (in dollars per barrel)	8.90
Discounted cash flow approach | Level 3 | Natural gas liquids | Swaps | Maximum
Commodity Derivative Instruments - Assets
Natural gas liquid futures prices (in dollars per barrel)	47.25

Fair Value Measurement - Change

Fair Value Measurement - Changes in Level 3 Financial Instruments (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)
Changes in fair value of Level 3 instruments
Balance at the beginning of the period	$ 1,428
Settlements	(431)
Changes in fair value	(30)
Balance at the end of the period	$ 967

Fair Value Measurement - Assets

Fair Value Measurement - Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis (Details) - Nonrecurring - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Carrying Amount | 2022 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	$ 429,485	$ 500,000
Carrying Amount | 2023 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	150,000	250,000
Carrying Amount | Revolving credit facility | Revolver | Line of credit
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	185,000	110,000
Fair Value | 2022 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	236,217	260,000
Fair Value | 2023 Notes | Senior notes
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	84,375	153,283
Fair Value | Revolving credit facility | Revolver | Line of credit
Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
Debt	$ 185,000	$ 110,000

Asset Retirement Obligations -

Asset Retirement Obligations - Roll Forward (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Asset Retirement Obligations
Balance at beginning of period	$ 20,980
Liabilities incurred	0	$ 736
Accretion of ARO liability	293	$ 194
Liabilities settled due to sale of related properties	0
Liabilities settled due to plugging and abandonment	(15)
Change in estimate	50
Balance at end of period	$ 21,308

Asset Retirement Obligations 50

Asset Retirement Obligations - Liability at Period End (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Asset Retirement Obligations
ARO liability at end of period	$ 21,308	$ 20,980
Less: Current portion of ARO	(679)	(679)
Total long-term ARO at end of period	$ 20,629	$ 20,301

Stock-based Compensation - Mana

Stock-based Compensation - Management Unit Awards - New Awards (Details)	32 Months Ended
	Mar. 31, 2016shares
Management Unit Awards
Additional disclosures
Awards (in shares)	0

Stock-based Compensation - Ma52

Stock-based Compensation - Management Unit Awards - Activity (Details) - Management Unit Awards	3 Months Ended
	Mar. 31, 2016$ / sharesshares
Units
Unvested at the beginning of the period (in shares) | shares	189,355
Granted (in shares) | shares	39,198
Forfeited (in shares) | shares	(39,198)
Vested (in shares) | shares	(39,198)
Unvested at the end of the period (in shares) | shares	150,157
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 - Ma53

Stock-based Compensation - Management Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
General and administrative expenses | Management Unit Awards
Stock compensation expense
Stock compensation expense	$ 0.5	$ 0.3

Stock-based Compensation - 2013

Stock-based Compensation - 2013 Omnibus Incentive Plan (Details) - 2013 Omnibus Incentive Plan - Class A common stock - shares	May. 04, 2016	Mar. 31, 2016
Stock-based Compensation
Shares reserved (in shares)		3,850,000
Subsequent event
Stock-based Compensation
Additional shares reserved (in shares)	3,500,000

Stock-based Compensation - Rest

Stock-based Compensation - Restricted Stock Unit Awards - Activity (Details) - Restricted Stock Unit Awards	3 Months Ended
	Mar. 31, 2016$ / sharesshares
Awards
Unvested at the beginning of the period (in shares) | shares	757,245
Granted (in shares) | shares	40,701
Forfeited (in shares) | shares	(191,674)
Unvested at the end of the period (in shares) | shares	606,272
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (in dollars per share) | $ / shares	$ 11.65
Granted (in dollars per share) | $ / shares	3.85
Forfeited (in dollars per share) | $ / shares	10.75
Unvested at the end of the period (in dollars per share) | $ / shares	$ 11.41

Stock-based Compensation - Re56

Stock-based Compensation - Restricted Stock Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
General and administrative expenses | Restricted Stock Unit Awards
Stock compensation expense
Stock compensation expense	$ 0.1	$ 0.5

Stock-based Compensation - Perf

Stock-based Compensation - Performance Unit Awards - General Information (Details) - Performance Unit Awards	3 Months Ended
	Mar. 31, 2016
Additional disclosures
Vesting term	3 years
Exchangeable ratio of vested performance unit (as a percent)	1
Class A common stock | Minimum
Additional disclosures
Number of shares of common stock issuable upon vesting of the performance unit awards (as a percent)	0.00%
Class A common stock | Maximum
Additional disclosures
Number of shares of common stock issuable upon vesting of the performance unit awards (as a percent)	200.00%

Stock-based Compensation - Pe58

Stock-based Compensation - Performance Unit Awards - Activity (Details) - Performance Unit Awards	3 Months Ended
	Mar. 31, 2016$ / sharesshares
Awards
Unvested at the beginning of the period (in shares) | shares	539,188
Granted (in shares) | shares	16,195
Forfeited (in shares) | shares	(85,460)
Unvested at the end of the period (in shares) | shares	469,923
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (in dollars per share) | $ / shares	$ 14.22
Granted (in dollars per share) | $ / shares	3.85
Forfeited (in dollars per share) | $ / shares	12.21
Unvested at the end of the period (in dollars per share) | $ / shares	$ 14.23

Stock-based Compensation - Pe59

Stock-based Compensation - Performance Unit Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
General and administrative expenses | Performance Unit Awards
Stock compensation expense
Stock compensation expense	$ 0.4	$ 0.4

Stock-based Compensation - Re60

Stock-based Compensation - Restricted Stock Awards - General Information (Details)	3 Months Ended
	Mar. 31, 2016
Restricted Stock Awards
Additional disclosures
Service period from date of grant	1 year

Stock-based Compensation - Re61

Stock-based Compensation - Restricted Stock Awards - Activity (Details) - Restricted Stock Awards	3 Months Ended
	Mar. 31, 2016$ / sharesshares
Awards
Unvested at the beginning of the period (in shares) | shares	67,380
Unvested at the end of the period (in shares) | shares	67,380
Weighted Average Grant Date Fair Value per Share
Unvested at the beginning of the period (in dollars per share) | $ / shares	$ 7.30
Unvested at the end of the period (in dollars per share) | $ / shares	$ 7.30

Stock-based Compensation - Re62

Stock-based Compensation - Restricted Stock Awards - Stock Compensation Expense (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
General and administrative expenses | Restricted Stock Awards
Stock compensation expense
Stock compensation expense	$ 0.2	$ 0.1

Income Taxes - Tax Rate (Detail

Income Taxes - Tax Rate (Details)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Income Taxes
Effective tax rate (as a percent)	18.10%	29.20%
Statutory rate (as a percent)	35.00%	35.00%

Income Taxes - Tax Provision -

Income Taxes - Tax Provision - Attributable to Controlling Interests and Non-controlling Interests (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Tax provision
Tax expense (benefit) attributable to controlling interests	$ 10,569	$ 441
Tax expense attributable to non-controlling interests	134	1,903
Total income tax provision (benefit)	$ 10,703	$ 2,344

Income Taxes - Net Operating Lo

Income Taxes - Net Operating Loss Carry-forward (Details) $ in Millions	Mar. 31, 2016USD ($)
Income Taxes
Valuation allowance	$ 3.5

Income Taxes - Tax Receivable A

Income Taxes - Tax Receivable Agreement (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Income Taxes
Liability under tax receivable agreement	$ 37,623	$ 38,052
Deferred tax assets associated with exchanges of shares, net of valuation allowance	44,300	$ 44,800
Reduction in the liability	$ 500

Earnings per Share - Anti-dilut

Earnings per Share - Anti-dilutive Securities (Details)	3 Months Ended
	Mar. 31, 2016shares
Restricted Stock Unit Awards
Earnings per Share
Antidilutive securities (in shares)	606,272
Performance Unit Awards
Earnings per Share
Antidilutive securities (in shares)	469,923
Class B common stock
Earnings per Share
Economic interest (as a percent)	0.00%

Earnings per Share - Basic Earn

Earnings per Share - Basic Earnings per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Income (numerator):
Net income (loss) attributable to controlling interests	$ 18,911	$ 2,188
Weighted-average shares (denominator):
Weighted-average number of shares of Class A common stock - basic	30,551	18,304
Weighted-average number of shares of Class A common stock - diluted	30,551	18,304
Earnings per share:
Basic (in dollars per share)	$ 0.62	$ 0.12
Diluted (in dollars per share)	$ 0.62	$ 0.12

Related Parties - Natural Gas S

Related Parties - Natural Gas Sale and Purchase Agreement with Monarch Natural Gas, LLC (Details) - USD ($) $ in Thousands	Sep. 01, 2013	Mar. 31, 2016
Enable Midstream Partners LP
Related Party Transactions
Initial term of the agreement (in years)	10 years
Investee | Monarch Natural Gas, LLC
Related Party Transactions
Related party revenue		$ 0

Related Parties - Metalmark Cap

Related Parties - Metalmark Capital and Monarch Natural Gas, LLC (Details) - director	May. 07, 2013	Mar. 31, 2016
Monarch Natural Gas, LLC | Investee | Metalmark
Related Party Transactions
Metalmark Capital's ownership percentage in Monarch (as a percent)	81.00%
Metalmark | Beneficial owner
Related Party Transactions
Number of directors who are managing directors of the related party		2
Minimum | Metalmark | Beneficial owner
Related Party Transactions
Beneficial ownership interest (as a percent)		5.00%

Related Parties - Monarch Natur

Related Parties - Monarch Natural Gas, LLC Equity Interests (Details) - Monarch Natural Gas, LLC - Investee - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	May. 07, 2013
Related Party Transactions
Estimated fair value of equity interests issued to the entity			$ 15
Amortization of deferred revenue	$ 0.6	$ 0.5

Related Parties - Transportatio

Related Parties - Transportation Agreement with Monarch Oil Pipeline LLC (Details) - Monarch Oil Pipeline LLC - Investee $ in Millions	1 Months Ended	3 Months Ended
	Sep. 30, 2014	Mar. 31, 2016USD ($)MMBoe
Related Party Transactions
Term of Oil Gathering and Transportation Agreement (in years)	10 years
Gathering fees | $		$ 0.7
Oil production transported (in MMBoe) | MMBoe		0.3

Related Parties - Purchases of

Related Parties - Purchases of Senior Notes (Details) - USD ($) $ in Thousands	Feb. 29, 2016	Feb. 29, 2016	Mar. 31, 2016
Senior Unsecured Notes
Gain on debt extinguishment			$ 90,652
Minimum | Magnetar Capital and Affiliates | Beneficial owner
Senior Unsecured Notes
Beneficial ownership interest (as a percent)	5.00%	5.00%
Minimum | Blackstone Group Management L.L.C. and Affiliates | Beneficial owner
Senior Unsecured Notes
Beneficial ownership interest (as a percent)	5.00%	5.00%
Senior notes
Senior Unsecured Notes
Aggregate principal amount repurchased	$ 170,500	$ 170,500
Gain on debt extinguishment		90,700
2023 Notes | Senior notes | Beneficial owner
Senior Unsecured Notes
Aggregate principal amount repurchased	100,000	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	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	$ 50,000
Purchased amount	$ 23,300

Subsequent Events - Long-Term D

Subsequent Events - Long-Term Debt (Details) - USD ($) $ in Thousands	Apr. 29, 2016	Feb. 29, 2016	Mar. 31, 2016	Dec. 31, 2015
Long-Term Debt
Aggregate principal carrying amount			$ 764,485	$ 860,000
Cash
Cash	$ 34,300		53,805	21,893
Senior notes
Long-Term Debt
Aggregate principal amount repurchased		$ 170,500
Aggregate principal carrying amount	559,100
2022 Notes | Senior notes
Long-Term Debt
Aggregate principal amount repurchased		70,500
Purchased amount		$ 27,100
Aggregate principal carrying amount			429,485	500,000
2022 Notes | Senior notes | Subsequent event
Long-Term Debt
Aggregate principal amount repurchased	20,300
Purchased amount	11,200
Wells Fargo Bank N.A. | Revolving credit facility | Revolver | Line of credit
Long-Term Debt
Aggregate principal carrying amount	185,000		$ 185,000	$ 110,000
Undrawn balance	$ 325,000

Subsequent Events - JEH Cash Ta

Subsequent Events - JEH Cash Tax Distribution (Details) - Subsequent event $ in Millions	Apr. 12, 2016USD ($)
JEH
Subsequent Events
Cash tax distribution	$ 10.9
JEH
Subsequent Events
Tax payment from JEH	5.4
Pre-IPO Owners (Existing Owners) | JEH
Subsequent Events
Cash tax distribution	$ 5.5

Subsequent Events - 2013 Omnibu

Subsequent Events - 2013 Omnibus Incentive Plan (Details)	May. 04, 2016shares
Class A common stock | 2013 Omnibus Incentive Plan | Subsequent event
Stock-based Compensation
Additional shares reserved (in shares)	3,500,000

Subsidiary Guarantors - Debt Is

Subsidiary Guarantors - Debt Issued (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Feb. 11, 2016	Jan. 12, 2016	Mar. 23, 2015	Feb. 23, 2015	Feb. 20, 2015	Apr. 01, 2014
Senior notes | 2022 Notes
Subsidiary Guarantors
Issuance of debt				$ 500		$ 500	$ 500
Senior notes | 2023 Notes
Subsidiary Guarantors
Issuance of debt		$ 250	$ 250		$ 250
Issuers | Guarantor Subsidiaries
Subsidiary Guarantors
Ownership percentage in subsidiary guarantors	100.00%

Subsidiary Guarantors - General

Subsidiary Guarantors - General Information (Details)	3 Months Ended
	Mar. 31, 2016class	Jul. 29, 2013
Subsidiary Guarantors
Classes of stock, number	2
Class A common stock
Subsidiary Guarantors
Economic interests/rights (as a percent)	100.00%
Votes per share entitled to stockholders	1
Class B common stock
Subsidiary Guarantors
Economic interest (as a percent)	0.00%
Economic interests/rights (as a percent)	0.00%
Votes per share entitled to stockholders	1
Pre-IPO Owners (Existing Owners)
Subsidiary Guarantors
The Existing Owners' economic interest in JEH (as a percent)	50.60%	74.70%
Ratio in which JEH Units and Class B common stock are exchanged for Class A common stock	1
Pre-IPO Owners (Existing Owners) | Class A common stock
Subsidiary Guarantors
Ratio in which JEH Units and Class B common stock are exchanged for Class A common stock	1
Issuers
Subsidiary Guarantors
The Company's economic interest in JEH (as a percent)	49.40%
Pre-IPO Owners (Existing Owners) | Issuers
Subsidiary Guarantors
Economic interest (as a percent)	50.60%

Subsidiary Guarantors - Condens

Subsidiary Guarantors - Condensed Consolidating Balance Sheet (Details) - USD ($) $ in Thousands	Apr. 29, 2016	Mar. 31, 2016	Dec. 31, 2015
Current assets
Cash	$ 34,300	$ 53,805	$ 21,893
Restricted cash		361	330
Accounts receivable, net
Oil and gas sales		16,093	19,292
Joint interest owners		7,399	11,314
Other		15,105	15,170
Commodity derivative assets		107,762	124,207
Other current assets		3,991	2,298
Total current assets		204,516	194,504
Oil and gas properties, net, at cost under the successful efforts method		1,600,290	1,635,766
Other property, plant and equipment, net		3,509	3,873
Commodity derivative assets		84,284	93,302
Other assets		7,309	7,709
Total assets		1,899,908	1,935,154
Current liabilities
Trade accounts payable		8,835	7,467
Oil and gas sales payable		28,548	32,408
Accrued liabilities		23,426	27,341
Commodity derivative liabilities			11
Asset retirement obligations		679	679
Total current liabilities		61,488	67,906
Long-term debt		749,312	837,654
Deferred revenue		10,772	11,417
Asset retirement obligations		20,629	20,301
Liability under tax receivable agreement		37,623	38,052
Deferred tax liabilities		33,533	22,972
Total liabilities		913,357	998,302
Stockholders' / members' equity
Treasury stock, at cost; 22,602 shares at March 31, 2016 and December 31, 2015		(358)	(358)
Additional paid-in-capital		364,908	363,723
Retained earnings		55,480	36,569
Stockholders' equity		420,092	399,996
Non-controlling interest		566,459	536,856
Total stockholders' equity		986,551	936,852
Total liabilities and stockholders' equity		1,899,908	1,935,154
Class A common stock
Stockholders' / members' equity
Common stock		31	31
Class B common stock
Stockholders' / members' equity
Common stock		31	31
Eliminations
Accounts receivable, net
Intercompany receivable		(1,203,044)	(1,174,863)
Total current assets		(1,203,044)	(1,174,863)
Investment in subsidiaries		(473,332)	(444,362)
Total assets		(1,676,376)	(1,619,225)
Current liabilities
Intercompany payable		(1,422,454)	(1,394,272)
Total current liabilities		(1,422,454)	(1,394,272)
Total liabilities		(1,422,454)	(1,394,272)
Stockholders' / members' equity
Members' equity		(820,381)	(761,809)
Non-controlling interest		566,459	536,856
Total stockholders' equity		(253,922)	(224,953)
Total liabilities and stockholders' equity		(1,676,376)	(1,619,225)
JEI (Parent)
Current assets
Cash		100	100
Accounts receivable, net
Intercompany receivable		13,954	12,866
Total current assets		14,054	12,966
Investment in subsidiaries		473,332	444,362
Total assets		487,386	457,328
Current liabilities
Liability under tax receivable agreement		37,623	38,052
Deferred tax liabilities		29,671	19,280
Total liabilities		67,294	57,332
Stockholders' / members' equity
Treasury stock, at cost; 22,602 shares at March 31, 2016 and December 31, 2015		(358)	(358)
Additional paid-in-capital		364,908	363,723
Retained earnings		55,480	36,569
Stockholders' equity		420,092	399,996
Total stockholders' equity		420,092	399,996
Total liabilities and stockholders' equity		487,386	457,328
JEI (Parent) | Class A common stock
Stockholders' / members' equity
Common stock		31	31
JEI (Parent) | Class B common stock
Stockholders' / members' equity
Common stock		31	31
Issuers
Current assets
Cash		12,380	12,448
Accounts receivable, net
Other		14,817	14,444
Commodity derivative assets		107,762	124,207
Other current assets		233	444
Intercompany receivable		1,189,090	1,161,997
Total current assets		1,324,282	1,313,540
Commodity derivative assets		84,284	93,302
Other assets		7,056	7,456
Total assets		1,415,622	1,414,298
Current liabilities
Trade accounts payable		204	388
Accrued liabilities		15,891	15,741
Commodity derivative liabilities			11
Total current liabilities		16,095	16,140
Long-term debt		749,312	837,654
Deferred revenue		10,772	11,417
Deferred tax liabilities		3,862	3,692
Total liabilities		780,041	868,903
Stockholders' / members' equity
Members' equity		635,581	545,395
Total stockholders' equity		635,581	545,395
Total liabilities and stockholders' equity		1,415,622	1,414,298
Guarantor Subsidiaries
Current assets
Cash		41,305	9,325
Restricted cash		361	330
Accounts receivable, net
Oil and gas sales		16,093	19,292
Joint interest owners		7,399	11,314
Other		288	726
Other current assets		3,758	1,854
Total current assets		69,204	42,841
Oil and gas properties, net, at cost under the successful efforts method		1,600,290	1,635,766
Other property, plant and equipment, net		2,826	3,168
Other assets		253	253
Total assets		1,672,573	1,682,028
Current liabilities
Trade accounts payable		8,631	7,079
Oil and gas sales payable		28,548	32,408
Accrued liabilities		7,535	11,600
Asset retirement obligations		679	679
Intercompany payable		1,419,994	1,391,838
Total current liabilities		1,465,387	1,443,604
Asset retirement obligations		20,629	20,301
Total liabilities		1,486,016	1,463,905
Stockholders' / members' equity
Members' equity		186,557	218,123
Total stockholders' equity		186,557	218,123
Total liabilities and stockholders' equity		1,672,573	1,682,028
Non-Guarantor Subsidiaries
Current assets
Cash		20	20
Accounts receivable, net
Total current assets		20	20
Other property, plant and equipment, net		683	705
Total assets		703	725
Current liabilities
Intercompany payable		2,460	2,434
Total current liabilities		2,460	2,434
Total liabilities		2,460	2,434
Stockholders' / members' equity
Members' equity		(1,757)	(1,709)
Total stockholders' equity		(1,757)	(1,709)
Total liabilities and stockholders' equity		$ 703	$ 725

Subsidiary Guarantors - Conde80

Subsidiary Guarantors - Condensed Consolidating Balance Sheet - Additional Information (Details) - $ / shares	Mar. 31, 2016	Dec. 31, 2015
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	30,573,509	30,573,509
Common stock, shares outstanding	30,550,907	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	31,273,130	31,273,130
Common stock, shares outstanding	31,273,130	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	30,573,509	30,573,509
Common stock, shares outstanding	30,550,907	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	31,273,130	31,273,130
Common stock, shares outstanding	31,273,130	31,273,130

Subsidiary Guarantors - Conde81

Subsidiary Guarantors - Condensed Consolidating Statement of Operations and Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Operating revenues
Oil and gas sales	$ 25,080	$ 57,234
Other revenues	778	862
Total operating revenues	25,858	58,096
Operating costs and expenses
Lease operating	8,617	12,262
Production and Ad Valorem Taxes	1,601	3,708
Exploration	162	164
Depletion, depreciation and amortization	41,762	52,083
Accretion of ARO liability	293	194
General and administrative	7,504	8,511
Other operating		3,012
Total operating expenses	59,939	79,934
Operating income (loss)	(34,081)	(21,838)
Other income (expense)
Interest expense	(14,798)	(14,129)
Gain on debt extinguishment	90,652
Net gain (loss) on commodity derivatives	17,219	46,306
Other income (expense)	225	(2,299)
Other income (expense), net	93,298	29,878
Income (loss) before income tax	59,217	8,040
Total income tax provision (benefit)	10,703	2,344
Net income (loss)	48,514	5,696
Net income (loss) attributable to non-controlling interests	29,603	3,508
Net income (loss) attributable to controlling interests	18,911	2,188
Eliminations
Other income (expense)
Equity interest in income	(28,968)	(2,629)
Net income (loss)	(28,968)	(2,629)
Net income (loss) attributable to non-controlling interests	29,603	3,508
JEI (Parent)
Other income (expense)
Other income (expense)	429
Other income (expense), net	429
Income (loss) before income tax	429
Equity interest in income	28,968	2,629
Total income tax provision (benefit)	10,486	441
Net income (loss)	18,911	2,188
Net income (loss) attributable to controlling interests	18,911	2,188
Issuers
Operating revenues
Other revenues	645	525
Total operating revenues	645	525
Operating costs and expenses
General and administrative	2,878	2,827
Total operating expenses	2,878	2,827
Operating income (loss)	(2,233)	(2,302)
Other income (expense)
Interest expense	(15,038)	(13,684)
Gain on debt extinguishment	90,652
Net gain (loss) on commodity derivatives	17,219	46,306
Other income (expense)	(200)	(2,273)
Other income (expense), net	92,633	30,349
Income (loss) before income tax	90,400	28,047
Total income tax provision (benefit)	217	1,903
Net income (loss)	90,183	26,144
Guarantor Subsidiaries
Operating revenues
Oil and gas sales	25,080	57,234
Other revenues	133	337
Total operating revenues	25,213	57,571
Operating costs and expenses
Lease operating	8,617	12,262
Production and Ad Valorem Taxes	1,601	3,708
Exploration	162	164
Depletion, depreciation and amortization	41,739	52,060
Accretion of ARO liability	293	194
General and administrative	4,601	5,661
Other operating		3,012
Total operating expenses	57,013	77,061
Operating income (loss)	(31,800)	(19,490)
Other income (expense)
Interest expense	240	(445)
Other income (expense)	(4)	(26)
Other income (expense), net	236	(471)
Income (loss) before income tax	(31,564)	(19,961)
Net income (loss)	(31,564)	(19,961)
Non-Guarantor Subsidiaries
Operating costs and expenses
Depletion, depreciation and amortization	23	23
General and administrative	25	23
Total operating expenses	48	46
Operating income (loss)	(48)	(46)
Other income (expense)
Income (loss) before income tax	(48)	(46)
Net income (loss)	$ (48)	$ (46)

Subsidiary Guarantors - Conde82

Subsidiary Guarantors - Condensed Consolidating Statement of Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities
Net income (loss)	$ 48,514	$ 5,696
Adjustments to reconcile net income (loss) to net cash provided by operating activities	(53,310)	39,818
Net cash (used in) / provided by operations	(4,796)	45,514
Cash flows from investing activities
Additions to oil and gas properties	(7,176)	(151,104)
Proceeds from sales of assets	3	3
Acquisition of other property, plant and equipment	40	(62)
Current period settlements of matured derivative contracts	42,298	32,611
Change in restricted cash	(30)	(37)
Net cash (used in) / provided by investing	35,135	(118,589)
Cash flows from financing activities
Proceeds from issuance of long-term debt	75,000	65,000
Repayment under long-term debt		(335,000)
Purchase of senior notes	(73,427)
Proceeds from senior notes		236,475
Payment of debt issuance costs		(1,473)
Proceeds from sale of common stock		122,778
Net cash provided by financing	1,573	87,780
Net increase (decrease) in cash	31,912	14,705
Cash
Beginning of period	21,893	13,566
End of period	53,805	28,271
Eliminations
Cash flows from operating activities
Net income (loss)	(28,968)	(2,629)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	28,968	2,629
JEI (Parent)
Cash flows from operating activities
Net income (loss)	18,911	2,188
Adjustments to reconcile net income (loss) to net cash provided by operating activities	(18,911)	(124,966)
Net cash (used in) / provided by operations		(122,778)
Cash flows from financing activities
Proceeds from sale of common stock		122,778
Net cash provided by financing		122,778
Cash
Beginning of period	100	100
End of period	100	100
Issuers
Cash flows from operating activities
Net income (loss)	90,183	26,144
Adjustments to reconcile net income (loss) to net cash provided by operating activities	(134,122)	(23,757)
Net cash (used in) / provided by operations	(43,939)	2,387
Cash flows from investing activities
Current period settlements of matured derivative contracts	42,298	32,611
Net cash (used in) / provided by investing	42,298	32,611
Cash flows from financing activities
Proceeds from issuance of long-term debt	75,000	65,000
Repayment under long-term debt		(335,000)
Purchase of senior notes	(73,427)
Proceeds from senior notes		236,475
Payment of debt issuance costs		(1,473)
Net cash provided by financing	1,573	(34,998)
Net increase (decrease) in cash	(68)
Cash
Beginning of period	12,448	1,000
End of period	12,380	1,000
Guarantor Subsidiaries
Cash flows from operating activities
Net income (loss)	(31,564)	(19,961)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	70,707	185,866
Net cash (used in) / provided by operations	39,143	165,905
Cash flows from investing activities
Additions to oil and gas properties	(7,176)	(151,104)
Proceeds from sales of assets	3	3
Acquisition of other property, plant and equipment	40	(62)
Change in restricted cash	(30)	(37)
Net cash (used in) / provided by investing	(7,163)	(151,200)
Cash flows from financing activities
Net increase (decrease) in cash	31,980	14,705
Cash
Beginning of period	9,325	12,436
End of period	41,305	27,141
Non-Guarantor Subsidiaries
Cash flows from operating activities
Net income (loss)	(48)	(46)
Adjustments to reconcile net income (loss) to net cash provided by operating activities	48	46
Cash
Beginning of period	20	30
End of period	$ 20	$ 30