Foresight Energy (FELPQ) 10-Q 10 May 16 2016 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2016	May. 06, 2016
Document And Entity Information [Line Items]
Entity Registrant Name	Foresight Energy LP
Entity Central Index Key	1,540,729
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Document Fiscal Year Focus	2,016
Trading Symbol	FELP
Document Fiscal Period Focus	Q1
Common Units
Document And Entity Information [Line Items]
Entity Units Outstanding		66,096,093
Subordinated Units
Document And Entity Information [Line Items]
Entity Units Outstanding		64,954,691

Unaudited Condensed Consolidate

Unaudited Condensed Consolidated Balance Sheets - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 16,220	$ 17,538
Accounts receivable	44,423	61,325
Due from affiliates	4,130	16,615
Financing receivables - affiliate	2,741	2,689
Inventories, net	65,197	50,652
Prepaid expenses	6,468	5,498
Prepaid royalties	4,068	5,386
Deferred longwall costs	17,628	18,476
Coal derivative assets	24,195	26,596
Other current assets	7,981	5,565
Total current assets	193,051	210,340
Property, plant, equipment and development, net	1,397,215	1,433,193
Due from affiliates	1,843	2,691
Financing receivables - affiliate	69,434	70,139
Prepaid royalties	70,727	70,300
Coal derivative assets	16,645	22,027
Other assets	14,091	12,493
Total assets	1,763,006	1,821,183
Current liabilities:
Current portion of long-term debt and capital lease obligations	1,404,874	1,434,566
Accrued interest	37,343	24,574
Accounts payable	51,953	55,192
Accrued expenses and other current liabilities	34,433	35,825
Due to affiliates	8,267	8,536
Total current liabilities	1,536,870	1,558,693
Sale-leaseback financing arrangements	193,434	193,434
Asset retirement obligations	44,041	43,277
Other long-term liabilities	6,656	6,896
Total liabilities	1,781,001	1,802,300
Limited partners' capital (deficit):
Total limited partners' (deficit) capital	(16,300)	20,599
Noncontrolling interests	(1,695)	(1,716)
Total partners' (deficit) capital	(17,995)	18,883
Total liabilities and partners' (deficit) capital	1,763,006	1,821,183
Common Units
Limited partners' capital (deficit):
Total limited partners' (deficit) capital	170,169	186,660
Subordinated Units
Limited partners' capital (deficit):
Total limited partners' (deficit) capital	$ (186,469)	$ (166,061)

Unaudited Condensed Consolidat3

Unaudited Condensed Consolidated Balance Sheets (Parenthetical) - shares shares in Thousands	Mar. 31, 2016	Dec. 31, 2015
Common Units
Capital units, Outstanding	65,193	65,192
Subordinated Units
Capital units, Outstanding	64,955	64,955

Unaudited Condensed Consolidat4

Unaudited Condensed Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Revenues
Coal sales	$ 163,097	$ 238,915
Other revenues	2,988
Total revenues	166,085	238,915
Costs and expenses:
Cost of coal produced (excluding depreciation, depletion and amortization)	89,177	110,588
Cost of coal purchased	550	106
Transportation	25,798	47,359
Depreciation, depletion and amortization	36,417	38,818
Accretion on asset retirement obligations	844	567
Selling, general and administrative	5,719	14,466
Transition and reorganization costs	5,940
Loss (gain) on commodity derivative contracts	523	(29,067)
Other operating income, net	(88)	(13,979)
Operating income	1,205	70,057
Other expenses:
Interest expense, net	32,995	27,341
Debt restructuring costs	9,710
Loss on extinguishment of debt	107
Net (loss) income	(41,607)	42,716
Less: net income attributable to noncontrolling interests	97	410
Net (loss) income attributable to controlling interests	(41,704)	42,306
Less: net income attributable to predecessor equity		23
Net income subsequent to initial public offering available to limited partner units - basic and diluted:
Net (loss) income attributable to limited partner units	(41,704)	$ 42,283
Weighted average limited partner units outstanding - basic and diluted:
Distributions declared per limited partner unit		$ 0.36
Common Units
Net income subsequent to initial public offering available to limited partner units - basic and diluted:
Net (loss) income attributable to limited partner units	$ (20,890)	$ 21,158
Net (loss) income per limited partner unit - basic and diluted	$ (0.32)	$ 0.33
Weighted average limited partner units outstanding - basic and diluted:
Weighted average limited partner units outstanding - basic and diluted	65,193	64,971
Subordinated Units
Net income subsequent to initial public offering available to limited partner units - basic and diluted:
Net (loss) income attributable to limited partner units	$ (20,814)	$ 21,125
Net (loss) income per limited partner unit - basic and diluted	$ (0.32)	$ 0.33
Weighted average limited partner units outstanding - basic and diluted:
Weighted average limited partner units outstanding - basic and diluted	64,955	64,871

Unaudited Condensed Consolidat5

Unaudited Condensed Consolidated Statement of Partners' Capital (Deficit) - 3 months ended Mar. 31, 2016 - USD ($) $ in Thousands	Total	Noncontrolling Interest	Limited PartnersCommon Units	Limited PartnersSubordinated Units
Beginning Balance at Dec. 31, 2015	$ 18,883	$ (1,716)	$ 186,660	$ (166,061)
Beginning Balance (in units) at Dec. 31, 2015			65,193,389	64,954,691
Net (loss) income	(41,607)	97	$ (20,890)	$ (20,814)
Cash distributions	(76)	(76)
Capital contributions from Foresight Reserves LP	813		407	406
Equity-based compensation	3,992		$ 3,992
Issuance of equity-based awards			257
Ending Balance at Mar. 31, 2016	$ (17,995)	$ (1,695)	$ 170,169	$ (186,469)
Ending Balance (in units) at Mar. 31, 2016			65,193,646	64,954,691

Unaudited Condensed Consolidat6

Unaudited Condensed Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Cash flows from operating activities
Net (loss) income	$ (41,607)	$ 42,716
Adjustments to reconcile net (loss) income to net cash provided by operating activities:
Depreciation, depletion and amortization	36,417	38,818
Equity-based compensation	3,992	8,231
Unrealized losses (gains) on commodity derivative contracts	389	(22,476)
Transition and reorganization expenses paid by Foresight Reserves (affiliate)	2,000
Other	3,299	(1,114)
Changes in operating assets and liabilities:
Accounts receivable	16,902	447
Due from/to affiliates, net	13,064	(3,908)
Inventories	(10,237)	(30,078)
Prepaid expenses and other current assets	(4,247)	(208)
Prepaid royalties	891	(769)
Coal derivative assets and liabilities	6,960	4,714
Accounts payable	(3,239)	(3,501)
Accrued interest	12,769	(10,907)
Accrued expenses and other current liabilities	(695)	(5,056)
Other	(2,436)	(1,790)
Net cash provided by operating activities	34,222	15,119
Cash flows from investing activities
Investment in property, plant, equipment and development	(5,040)	(33,277)
Return of investment on financing arrangements with Murray Energy (affiliate)	653
Settlement of certain coal derivatives		3,319
Proceeds from sale of equipment	83
Net cash used in investing activities	(4,304)	(29,958)
Cash flows from financing activities
Net change in borrowings under revolving credit facility		30,000
Net change in borrowings under A/R securitization program	(19,800)	47,500
Payments on other long-term debt and capital lease obligations	(11,097)	(10,860)
Payments on short-term debt	(167)
Distributions paid	(76)	(46,970)
Debt issuance costs paid		(439)
Other	(96)	(111)
Net cash (used in) provided by financing activities	(31,236)	19,120
Net (decrease) increase in cash and cash equivalents	(1,318)	4,281
Cash and cash equivalents, beginning of period	17,538	26,509
Cash and cash equivalents, end of period	16,220	30,790
Supplemental information:
Interest paid, net of amounts capitalized	18,551	$ 36,620
Supplemental disclosures of non-cash financing activities:
Non-cash capital contribution from Foresight Reserves LP (affiliate)	$ 813

Organization, Nature of Busines

Organization, Nature of Business and Basis of Presentation	3 Months Ended
	Mar. 31, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Organization, Nature of Business and Basis of Presentation	1. Organization, Nature of Business and Basis of Presentation Foresight Energy LLC (“FELLC”), a perpetual-term Delaware limited liability company, was formed in September 2006 for the development, mining, transportation and sale of coal. Prior to June 23, 2014, Foresight Reserves, LP (“Foresight Reserves”) owned 99.333% of FELLC and a member of FELLC’s management owned 0.667%. On June 23, 2014, in connection with the initial public offering (“IPO”) of Foresight Energy LP (“FELP”), Foresight Reserves and a member of management contributed their ownership interests in FELLC to FELP for which they were issued common and subordinated units in FELP. Because this transaction was between entities under common control, the contributed assets and liabilities of FELLC were recorded in the combined consolidated financial statements of FELP at FELLC’s historical cost. FELP has been managed by Foresight Energy GP LLC (“FEGP”) subsequent to the IPO. During the first quarter of 2015 (the “Contribution Date”), Foresight Reserves and a member of management contributed (through their incentive distribution rights) their 100% equity interest in Sitran LLC (“Sitran”), Adena Resources LLC (“Adena”), Hillsboro Transport LLC (“Hillsboro Transport”) and Akin Energy LLC (“Akin Energy”) to FELP for no consideration (collectively, the “Contributed Companies”). The aggregate net book value of the Contributed Companies on the Contribution Date was $60.6 million. Because Sitran, Akin Energy and FELP were under common control, FELP’s historical results prior to the Contribution Date have been recast to combine the financial position and results of operations of Sitran and Akin Energy. Hillsboro Transport and Adena were consolidated as variable interest entities (“VIEs”) prior to the Contribution Date (see Note 14); therefore, the contribution did not result in a change in reporting entity. The equity values of Sitran and Akin Energy prior to the Contribution Date are included in predecessor equity in the statement of partners’ capital (deficit), and on the Contribution Date, the net book values of these entities were reclassified from predecessor equity to limited partners’ capital. Similarly, the equity values of Hillsboro Transport and Adena were reclassified from noncontrolling interests to limited partners’ capital on the Contribution Date. The controlling interest net income of the Contributed Companies prior to the Contribution Date and the controlling interest net income of FELLC prior to the IPO are included in net income attributable to predecessor equity in the consolidated statements of operations. On April 16, 2015, Murray Energy Corporation (“Murray Energy”) and Foresight Reserves completed a transaction whereby Murray Energy acquired a 34% noncontrolling economic interest in FEGP and all of the outstanding subordinated units of FELP, representing a 50% ownership percentage of the Partnership’s limited partner units (see Note 13). As used hereafter in this report, the terms “Foresight Energy LP,” “FELP,” the “Partnership,” “we,” “us” or like terms, refer to the combined consolidated results of Foresight Energy LP, the Contributed Companies, and FELLC and its consolidated subsidiaries and affiliates, unless the context otherwise requires or where otherwise indicated. The information presented in this Quarterly Report on Form 10-Q contains, for all periods presented, the combined consolidated financial results of Foresight Energy LP, the Contributed Companies, FELLC, and VIEs for which FELLC or its subsidiaries are the primary beneficiary. The Partnership operates in a single reportable segment and currently has four underground mining complexes in the Illinois Basin: Williamson Energy, LLC (“Williamson”); Sugar Camp Energy, LLC (“Sugar Camp”); Hillsboro Energy, LLC (“Hillsboro”); and Macoupin Energy, LLC (“Macoupin”). Mining operations at our Hillsboro complex have been idled since March 2015 due to a combustion event. In April 2016, we temporarily sealed the entire mine to reduce the oxygen flow paths into the mine. We are uncertain as to when production will resume at this operation. Our mined coal is sold to a diverse customer base, including electric utility and industrial companies primarily in the eastern United States, as well as overseas markets. Intercompany transactions, including those between consolidated VIEs, the Contributed Companies, and FELP and its consolidated subsidiaries, are eliminated in consolidation. The accompanying condensed consolidated financial statements contain all significant adjustments (consisting of normal recurring accruals) that, in the opinion of management, are necessary to present fairly, the Partnership’s condensed consolidated financial position, results of operations and cash flows for all periods presented. In preparing the condensed consolidated financial statements, management used estimates and assumptions that may affect reported amounts and disclosures. To the extent there are material differences between the estimates and actual results, the impact to the Partnership’s financial condition or results of operations could be material. The unaudited condensed consolidated financial statements do not include footnotes and certain financial information as required annually under U.S. generally accepted accounting principles (“U.S. GAAP”) and, therefore, should be read in conjunction with the annual audited consolidated financial statements for the year ended December 31, 2015 included in our Annual Report on Form 10-K filed with the SEC on March 15, 2016. The results of operations for the three months ended March 31, 2016 are not necessarily indicative of results that can be expected for any future period, including the year ending December 31, 2016.

New Accounting Standards

New Accounting Standards	3 Months Ended
	Mar. 31, 2016
Accounting Policies [Abstract]
New Accounting Standards	2. New Accounting Standards I n February 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2015-02, Amendments to the Consolidation Analysis . ASU 2015-02 changes the requirements and analysis required when determining the reporting entity’s need to consolidate an entity, including modifying the evaluation of limited partnership variable interest status, the presumption that a general partner should consolidate a limited partnership and the consolidation criterion applied by a reporting entity involved with variable interest entities. We adopted ASU 2015-02 during the first quarter of 2016 and it did not have an impact on our historical consolidation conclusions. In April 2015, the FASB issued ASU 2015-06, Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs In February 2016, the FASB issued ASU 2016-02, Leases, In March 2016, the FASB issued ASU No. 2016-09, Compensation – Stock Compensation (Topic 718) No other new accounting pronouncement issued or effective during the fiscal year which was not previously disclosed in our Annual Report on Form 10-K had, or is expected to have, a material impact on our consolidated financial statements or related disclosures.

Debt Defaults and Liquidity

Debt Defaults and Liquidity	3 Months Ended
	Mar. 31, 2016
Debt Disclosure [Abstract]
Debt Defaults and Liquidity	3. Debt Defaults and Liquidity On December 4, 2015, the Delaware Court of Chancery issued a memorandum opinion concluding, among other things, that the purchase and sale agreement between Foresight Reserves and Murray Energy (see Note 13) constituted a “change of control” under the indenture (the “Indenture”) governing our 7.875% Senior Notes due 2021 (the “2021 Senior Notes”) and that an event of default occurred under the Indenture when we failed to offer to purchase the 2021 Senior Notes on or about May 18, 2015. Because of the existence of “change of control” provisions and cross-default or cross-event of default provisions in our other debt agreements, the purchase and sale agreement between Foresight Reserves and Murray Energy also resulted, directly or indirectly, in events of default under FELLC’s credit agreement governing its senior secured credit facilities (the “Credit Agreement”), Foresight Receivables LLC’s receivables securitization program and certain other financing arrangements, including our longwall financing arrangements. The existence of an event of default has prohibited us access to borrowings or other extensions of credit under our revolving credit facility (“Revolving Credit Facility”). On December 18, 2015, we entered into a forbearance agreement (as amended, the “Notes Forbearance Agreement”) with Wilmington Savings Fund Society, FSB, as successor indenture trustee (the “Trustee”), and certain holders of the 2021 Senior Notes, who collectively beneficially own or manage in excess of 75% of the aggregate principal amount of the 2021 Senior Notes. Under the Notes Forbearance Agreement, the noteholders and the Trustee agreed to forbear from exercising certain rights and remedies to which they may be entitled in respect of the 2021 Senior Notes or under the Indenture. The Notes Forbearance Agreement has been extended through May 17, 2016, unless extended by the noteholders in their sole discretion. There can be no assurances that the noteholders party thereto will agree to any extension of the Notes Forbearance Agreement or that if such forbearance agreement is terminated early or otherwise expires or terminates pursuant to its terms, that the requisite noteholders under the Indenture will not pursue any and all remedies available to them under the Indenture or otherwise. On January 27, 2016, we entered into a forbearance agreement in respect of our securitization program (as amended, the “Securitization Forbearance Agreement”), pursuant to which the agent under that facility and the lenders under the securitization program agreed to forbear from exercising certain rights and remedies to which they may be entitled. The Securitization Forbearance Agreement currently remains in effect through July 15, 2016, unless extended by the securitization lenders in their sole discretion. There can be no assurances that the securitization lenders will agree to any extension of the Securitization Forbearance Agreement or that if such forbearance agreement is terminated early or expires, that the securitization lenders will not pursue any and all remedies available to them. Also under the Securitization Forbearance Agreement, the receivables facility was amended to permanently reduce commitments to $50.0 million in total, and we may borrow up to an amount such that the aggregate amount outstanding plus any adjusted LC participation amount at such time does not exceed the least of: (i) $41.0 million, (ii) the borrowing base at such time and (iii) an amount equal to 70% of the outstanding balance of the eligible receivables. We have not entered into forbearance agreements with the lenders under our equipment financing arrangements. Therefore, the lenders under the equipment financing arrangements may exercise any remedies available to them at any time. The remedies available to these lenders include acceleration of the indebtedness owed thereunder and exercising remedies with respect to our collateral securing such indebtedness. There can be no assurances that our creditors will not accelerate the indebtedness under their respective facilities or exercise any rights or remedies to which they are entitled. We have not paid the $23.6 million of accrued interest owed to holders of the 2021 Senior Notes on February 16, 2016, resulting in an additional event of default. We are actively negotiating an out-of-court restructuring with certain holders of the 2021 Senior Notes, who collectively beneficially own or manage in excess of 75% of the aggregate principal amount of the 2021 Senior Notes, and our other creditors. There can be no assurance that these efforts will result in the successful consummation of such restructuring. We have engaged financial and legal advisors to advise us regarding potential alternatives to address the issues described above. We cannot provide any assurance that a restructuring will be possible on acceptable terms, if at all. It may be difficult to come to an agreement that is acceptable to all of our creditors. Our failure to reach an agreement on the terms of a restructuring with our creditors or the failure to extend any forbearance agreement in connection with the related negotiations would have a material adverse effect on our liquidity, financial condition and results of operations. During the three months ended March 31, 2016, we incurred legal and financial advisors fees of $9.7 million related to the above issues, which have been recorded as debt restructuring fees in the condensed consolidated statement of operations. We expect financial and legal advisor fees to continue to be substantial until such time as the above issues are remedied, if at all. If an agreement on the terms of an out-of-court restructuring is not reached, it may be necessary for us to file a voluntary petition for relief under Chapter 11 of the United States Bankruptcy Code in order to implement a restructuring, or our creditors could force us into an involuntary bankruptcy or liquidation. If a plan of reorganization is implemented in a bankruptcy proceeding, it is likely that holders of claims and interests with respect to, or rights to acquire our equity securities, would likely be entitled to little or no recovery, and those claims and interests would likely be canceled for little or no consideration. If that were to occur, we anticipate that all, or substantially all, of the value of all investments in our partnership units would be lost and that our unitholders would lose all or substantially all of their investment. It is also likely that our other stakeholders, including our secured and unsecured creditors, would receive substantially less than the amount of their claims. On April 18, 2016, we entered into a Transaction Support Agreement (as amended, the “Lender TSA”), with certain of the lenders The negotiations between the Partnership and its affiliates and the creditors, equityholders and other stakeholders of the Partnership concerning the terms of the proposed Restructuring transactions are ongoing and are not finalized. The Partnership is in active negotiations with the holders of the 2021 Senior Notes but has not reached an agreement with them on the terms of the restructuring, including the terms of the Lender TSA. There can be no assurance that the Partnership will reach an agreement with the noteholders by May 17, 2016 nor can there be any assurance that any of the foregoing parties to whom such Restructuring transactions have been proposed will agree to the terms of any such transactions in accordance with the terms described herein, or if at all. The other creditors and stakeholders of the Partnership and its affiliates who are not party to the Lender TSA have not approved nor agreed (either implicitly or explicitly) to the terms of the Restructuring and are not bound to take (or refrain from taking) any actions as a result of the execution of the Lender TSA. See Note 19 for additional discussion. Our primary cash requirements include, but are not limited to, working capital needs, capital expenditures, and debt service costs (interest and principal). Historically, our cash flows from operations and available capacity under our Revolving Credit Facility supported our cash requirements. However, our not having access to borrowings or other extensions of credit under our Revolving Credit Facility is having an adverse effect on our liquidity. Also, the recent losses incurred by the Partnership have had a significant negative impact on our compliance with the financial debt covenants under our Credit Agreement, which are calculated based on the rolling prior four quarters’ financial results. Our Credit Agreement requires that we maintain a consolidated interest coverage ratio of at least 2.00x and a consolidated net senior secured leverage ratio of no greater than 2.75x. As of March 31, 2016, our consolidated interest coverage ratio and consolidated net senior secured leverage ratio were 2.44x and 2.83x, respectively. As such, we are not in compliance with our consolidated net senior secured leverage ratio as of March 31, 2016, which constituted an additional event of default. Based has resulted or and/or event of default (and may in the future result in additional defaults and/or events of default) , Indenture governing the of

Transition and Reorganization C

Transition and Reorganization Costs	3 Months Ended
	Mar. 31, 2016
Restructuring Charges [Abstract]
Transition and Reorganization Costs	4. Transition and Reorganization Costs In connection with Murray Energy acquiring an ownership interest in the Partnership and its general partner, we entered into a management services agreement (“MSA”) with Murray American Coal Inc., an affiliate of Murray Energy, with the intent of optimizing and reorganizing certain corporate administrative functions and generating synergies between the two companies through the elimination of headcount and duplicate selling, general and administrative expenses (see Note 13). The costs are comprised of retention compensation to certain employees during the transition period and termination benefits to employees whose positions were replaced by Murray Energy employees under the MSA. Transition and reorganization costs were $5.9 million for the three months ended March 31, 2016. Included in transition and reorganization costs for the three months ended March 31, 2016 was $2.0 million of retention compensation expense (which was paid by Foresight Reserves during the current and prior periods and therefore was recorded as a capital contribution during the period of Foresight Reserves payment), $3.7 million of equity-based compensation for the accelerated vesting of certain equity awards, and $0.2 million of other one-time charges related to the Murray Energy transaction.

Commodity Derivative Contracts

Commodity Derivative Contracts	3 Months Ended
	Mar. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Commodity Derivative Contracts	5. Commodity Derivative Contracts The Partnership has commodity price risk for its coal sales as a result of changes in the market value of its coal. To minimize this risk, we enter into long-term, fixed price coal supply sales agreements and coal derivative swap contracts. As of March 31, 2016 and December 31, 2015, we had outstanding coal derivative swap contracts to fix the selling price on 1.0 million tons and 1.1 million tons, respectively. Swaps are designed so that the Partnership receives or makes payments based on a differential between fixed and variable prices for coal. The coal derivative contracts are economic hedges to certain future unpriced (indexed) sales commitments and expected sales through 2017. The coal derivative contracts are indexed to the Argus API 2 price index, the benchmark price for coal imported into northwest Europe. The coal derivative contracts are accounted for as freestanding derivatives and any gains or losses resulting from adjusting these contracts to fair value are recorded into earnings. We record the fair value of all positions with a given counterparty on a gross basis in the condensed consolidated balance sheets (see Note 17). We have diesel fuel price exposure in our transportation and production processes and therefore are subject to commodity price risk as a result of changes in the market value of diesel fuel. Beginning in 2015, to limit our exposure to diesel fuel price volatility, we entered into swap agreements with financial institutions which provide a fixed price per unit for the volume of purchases being hedged. As of March 31, 2016 and December 31, 2015, we had swap agreements outstanding for 2016 to hedge the variable cash flows related to 0.8 million and 1.0 million gallons, respectively, of diesel fuel. The diesel fuel derivative contracts are accounted for as freestanding derivatives, and any gains or losses resulting from adjusting these contracts to fair value are recorded into earnings. We have master netting agreements with all of our counterparties that allow for the settlement of contracts in an asset position with contracts in a liability position in the event of default. We manage counterparty risk through the utilization of investment grade commercial banks, diversification of counterparties and our counterparty netting arrangements. A summary of the unrealized and realized (losses) gains recorded on commodity derivative contracts for the three months ended March 31, 2016 and 2015 is as follows: Three Months Ended March 31, 2016 March 31, 2015 (In Thousands) Unrealized (loss) gain on commodity derivative contracts and prior cumulative unrealized gains realized during the period $ (5,642 ) $ 15,782 Realized gain on commodity derivative contracts 5,119 13,285 (Loss) gain on commodity derivative contracts $ (523 ) $ 29,067 We received $3.3 million in proceeds during the three months ended March 31, 2015 from the settlement of derivatives that were reclassified from an operating cash flow activity to an investing activity in the consolidated statement of cash flows because the derivative contracts were settled prior to the expiration of their contractual maturities and prior to the delivery date of the underlying sales contracts.

Accounts Receivable

Accounts Receivable	3 Months Ended
	Mar. 31, 2016
Receivables [Abstract]
Accounts Receivable	6. Accounts Receivable Accounts receivable consist of the following: March 31, 2016 December 31, 2015 (In Thousands) Trade accounts receivable $ 38,620 $ 56,013 Other receivables 5,803 5,312 Total accounts receivable $ 44,423 $ 61,325

Inventories

Inventories	3 Months Ended
	Mar. 31, 2016
Inventory Disclosure [Abstract]
Inventories	7. Inventories Inventories consist of the following: March 31, 2016 December 31, 2015 (In Thousands) Parts and supplies $ 22,555 $ 24,276 Raw coal 4,997 1,906 Clean coal 37,645 24,470 Total inventories $ 65,197 $ 50,652

Property, Plant, Equipment and

Property, Plant, Equipment and Development, Net	3 Months Ended
	Mar. 31, 2016
Property Plant And Equipment [Abstract]
Property, Plant, Equipment and Development, Net	8. Property, Plant, Equipment and Development, Net Property, plant, equipment and development, net consist of the following: March 31, 2016 December 31, 2015 (In Thousands) Land, land rights and mineral rights $ 99,626 $ 99,676 Machinery and equipment 1,142,504 1,140,256 Machinery and equipment under capital leases 126,401 126,401 Buildings and structures 248,587 248,946 Development costs 752,641 750,177 Other 9,370 9,369 Property, plant, equipment and development 2,379,129 2,374,825 Less: accumulated depreciation, depletion and amortization (981,914 ) (941,632 ) Property, plant, equipment and development, net $ 1,397,215 $ 1,433,193

Accrued Expenses and Other Curr

Accrued Expenses and Other Current Liabilities	3 Months Ended
	Mar. 31, 2016
Payables And Accruals [Abstract]
Accrued Expenses and Other Current Liabilities	9. Accrued Expenses and Other Current Liabilities Accrued expenses and other current liabilities consist of the following: March 31, 2016 December 31, 2015 (In Thousands) Employee compensation, benefits and payroll taxes $ 11,194 $ 12,393 Taxes other than income 7,284 6,560 Liquidated damages (non-affiliate) 6,745 6,404 Royalties (non-affiliate) 2,889 3,707 Other 6,321 6,761 Total accrued expenses and other current liabilities $ 34,433 $ 35,825

Long-Term Debt and Capital Leas

Long-Term Debt and Capital Lease Obligations	3 Months Ended
	Mar. 31, 2016
Debt Disclosure [Abstract]
Long-Term Debt and Capital Lease Obligations	10. Long-Term Debt and Capital Lease Obligations Long-term debt and capital lease obligations consist of the following: March 31, 2016 December 31, 2015 (In Thousands) 2021 Senior Notes $ 600,000 $ 600,000 Revolving Credit Facility 352,500 352,500 Term Loan 297,750 297,750 Trade A/R Securitization 21,200 41,000 5.78% longwall financing arrangement 50,423 50,423 5.555% longwall financing arrangement 46,406 51,563 Capital lease obligations 56,770 62,710 Subtotal - Total long-term debt and capital lease obligations principal outstanding 1,425,049 1,455,946 Unamortized deferred financing costs and debt discounts (20,175 ) (21,380 ) Total long-term debt and capital lease obligations 1,404,874 1,434,566 Less: current portion (1,404,874 ) (1,434,566 ) Non-current portion of long-term debt and capital lease obligations $ — $ — As discussed in Note 3 and further below, we were, and continue to be as of the filing date of these statements, in default under all of our long-term debt and capital lease obligations as of March 31, 2016 and December 31, 2015, and therefore, all outstanding long-term debt and capital lease obligations are reflected as a current liability in the condensed consolidated balance sheets. On December 4, 2015, the Delaware Court of Chancery issued a memorandum opinion concluding, among other things, that the purchase and sale agreement between Foresight Reserves and Murray Energy constituted a “change of control” under the Indenture governing the 2021 Senior Notes and that an event of default occurred under the Indenture when we failed to offer to purchase the 2021 Senior Notes on or about May 18, 2015 (see Note 3). On February 16, 2016, we did not pay the $23.6 million accrued interest owed to the holders of the 2021 Senior Notes on such day (or within the 30-day grace period); therefore an additional event of default exists under the Indenture. We are actively negotiating an out-of-court restructuring with certain holders of the 2021 Senior Notes and our other creditors. Because of the existence of change of control provisions and cross-default provisions in the Credit Agreement, the unfavorable Delaware Court of Chancery opinion and, consequently, the default under the Indenture discussed above also resulted in events of default under the Credit Agreement. As a result, we have not had access to borrowings or other extensions of credit under our Revolving Credit Facility, which is having an adverse effect on our liquidity. The Revolving Credit Facility is subject to customary debt covenants, including a consolidated interest coverage ratio and a consolidated net senior secured leverage ratio. As of March 31, 2016, our consolidated interest coverage ratio and consolidated net senior secured leverage ratio were 2.44x and 2.83x, respectively. Our covenants required a consolidated interest coverage ratio of at least 2.00x and a consolidated net senior secured leverage ratio of no greater than 2.75x as of March 31, 2016. As such, we were not in compliance with our consolidated net senior secured leverage ratio as of March 31, 2016, resulting in an additional event of default. On April 18, 2016, we entered into the Lender TSA with the Consenting Lenders under the Credit Agreement, pursuant to which the Consenting Lenders have agreed, subject to the terms and conditions within the Lender TSA, to support a proposed global restructuring of the Partnership’s indebtedness, including the proposed Amendment of the The negotiations between the Partnership and its affiliates and the creditors, equityholders and other stakeholders of the Partnership concerning the terms of the proposed Restructuring transactions are ongoing and are not finalized. The Partnership is in active negotiations with the holders of the 2021 Senior Notes but has not reached an agreement with them on the terms of the restructuring, including the terms of the Lender TSA. There can be no assurance that the Partnership will reach an agreement with the noteholders by May 17, 2016 nor can there be any assurance that any of the foregoing parties to whom such Restructuring transactions have been proposed will agree to the terms of any such transactions in accordance with the terms described herein, or if at all. The other creditors and stakeholders of the Partnership and its affiliates who are not party to the Lender TSA have not approved nor agreed (either implicitly or explicitly) to the terms of the Restructuring and are not bound to take (or refrain from taking) any actions as a result of the execution of the Lender TSA. See Notes 3 and 19 for additional discussion. In January 2016, we received notice from the administrative agent to the Credit Agreement that borrowings under our Credit Agreement would be subject to the default interest rate, as defined in the Credit Agreement, which has resulted in a 2% increase to our borrowing rates. As of March 31, 2016, the weighted-average interest rate on borrowings under the Revolving Credit Facility was 5.6% and the interest rate on borrowings under the Term Loan was 7.5%. At March 31, 2016, we had $6.5 million outstanding in letters of credit. In January 2016, we entered into a Securitization Forbearance Agreement pursuant to which the agent and the lenders under the Trade A/R Securitization program agreed to forbear from exercising certain rights and remedies to which they may be entitled. The Securitization Forbearance Agreement has been extended through July 15, 2016. There can be no assurances that the securitization lenders will agree to any extension of the Securitization Forbearance Agreement or that if such forbearance agreement is terminated early or expires, that the securitization lenders will not pursue any and all remedies available to them. Also under the Securitization Forbearance Agreement, the Trade A/R Securitization facility was amended to permanently reduce commitments to $50.0 million in total, and we may borrow up to an amount such that the aggregate amount outstanding plus any adjusted LC participation amount at such time does not exceed the least of (i) $41.0 million, (ii) the borrowing base at such time and (iii) an amount equal to 70% of the outstanding balance of the eligible receivables. Any extensions of credit by the lenders during the forbearance period are at the sole and absolute discretion of the lenders. As a result of the permanent reduction in capacity under this facility, we recorded a loss on extinguishment of debt charge of $0.1 million to write-off a portion of the deferred debt issue costs incurred to obtain this facility. As of March 31, 2016, we are paying the default interest rate of 5.5% on outstanding borrowings under this facility.

Sale-Leaseback Financing Arrang

Sale-Leaseback Financing Arrangements - Affiliates	3 Months Ended
	Mar. 31, 2016
Leases Capital [Abstract]
Sale-Leaseback Financing Arrangements – Affiliate	11. Sale-Leaseback Financing Arrangements – Affiliate In 2009, Macoupin sold certain of its coal reserves and rail facilities to WPP, LLC (“WPP”), a subsidiary of Natural Resource Partners, LP (“NRP”), and leased them back. The gross proceeds from this transaction were $143.5 million. As of March 31, 2016, the outstanding principal balance on the Macoupin and Sugar Camp sale-leaseback financing arrangements were $143.5 million and $50.0 million, respectively. The implied effective interest rate as of March 31, 2016 on the Macoupin sale-leaseback financing arrangement and the Sugar Camp sale-leaseback financing arrangement was 13.9% and 13.2%, respectively. If there is a material change to the mine plans, the impact of a change in the effective interest rate to the condensed consolidated statement of operations could be significant. Interest expense recorded on the Macoupin sale-leaseback was $4.4 million and $5.1 million for the three months ended March 31, 2016 and 2015, respectively. Interest expense recorded on the Sugar Camp sale-leaseback was $1.4 million and $1.5 million for the three months ended March 31, 2016 and 2015, respectively. As of March 31, 2016 and December 31, 2015, interest totaling $4.6 million and $2.1 million, respectively, was accrued in the condensed consolidated balance sheets for the Macoupin and Sugar Camp sale-leaseback financing arrangements.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	12. Asset Retirement Obligations The change in the carrying amount of our asset retirement obligations was as follows for the three months ended March 31, 2016: March 31, 2016 (In Thousands) Balance at January 1, 2016 (including current portion) $ 43,295 Accretion expense 844 Expenditures for reclamation activities (80 ) Balance at March 31, 2016 (including current portion) 44,059 Less: current portion of asset retirement obligations (18 ) Noncurrent portion of asset retirement obligations $ 44,041

Related-Party Transactions

Related-Party Transactions	3 Months Ended
	Mar. 31, 2016
Related Party Transactions [Abstract]
Related-Party Transactions	13. Related-Party Transactions The chairman of our general partner’s board of directors and the controlling member of Foresight Reserves, Chris Cline, directly and indirectly beneficially owns a 31% and 4% interest in the general and limited partner interests of NRP, respectively. Additionally, Donald R. Holcomb, who served as a director on NRP’s board through April 2016, is the member for the Cline Trust Company LLC, which owns 20.3 million of the Partnership’s common units. We routinely engage in transactions in the normal course of business with NRP and its subsidiaries and Foresight Reserves and its affiliates. These transactions include production royalties, transportation services, administrative arrangements, coal handling and storage services, supply agreements, service agreements, land leases and sale-leaseback financing arrangements (see Note 11, sale-leaseback financing arrangements are excluded from the discussion and tables below). We also acquire, from time to time, mining equipment from Foresight Reserves and affiliated entities. Also, in connection with the reorganization of the Partnership pursuant to the execution of the MSA, Foresight Reserves paid retention bonuses to certain Partnership employees which were recorded as capital contributions during the period of payment (see Note 4). On April 16, 2015, Foresight Reserves and Murray Energy executed a purchase and sale agreement whereby Murray Energy paid Foresight Reserves $1.37 billion to acquire a 34% voting interest in FEGP, 77.5% of FELP’s incentive distribution rights (“IDR”) and nearly 50% of the outstanding limited partner units in FELP, including all of the outstanding subordinated units. FEGP will continue to govern the Partnership subsequent to this transaction. As part of the transaction, Murray Energy obtained an option, subject to certain conditions described below, to purchase an additional 46% of the voting interests in FEGP for $25 million during a five-year period. Murray Energy’s ability to exercise the option is conditioned upon (i) the exercise of the call option with respect to Colt LLC, a wholly-owned subsidiary of Foresight Reserves and (ii) the refinancing of the FELP notes and FELP’s existing credit facilities on terms reasonably acceptable to Foresight Reserves, or any other transaction (whether by amendment, waiver or a consent solicitation) that would have the effect of eliminating the “change of control” provisions of the FELP notes and FELP’s existing credit facilities with respect to the exercise of the option. Murray Management Services Agreement On April 16, 2015, a MSA was executed between FEGP and Murray American Coal, Inc. (the ”Manager”), a wholly-owned subsidiary of Murray Energy, pursuant to which the Manager will provide certain management and administration services to FELP for a quarterly fee of $3.5 million ($14.0 million on an annual basis), subject to contractual adjustments. To the extent that FELP or FEGP directly incurs costs for any services covered under the MSA, then the Manager’s quarterly fee is reduced accordingly. Also, to the extent that the Manager utilizes outside service providers to perform any of the services under the MSA, then the Manager is responsible for those outside service provider costs. The initial term of the MSA extends through December 31, 2022 and is subject to termination provisions. After taking into account the contractual adjustments for direct costs incurred by FELP, the amount of net expense due to the Manager for the three months ended March 31, 2016 was $2.1 million. Murray Energy Transport Lease and Overriding Royalty Agreements On April 16, 2015, American Century Transport LLC (“American Transport”), a newly created subsidiary of the Partnership, entered into a purchase and sale agreement (the “PSA”) with American Energy Corporation (“American Energy”), a subsidiary of Murray Energy, pursuant to which American Energy sold to American Transport certain mining and transportation assets for $63.0 million. Concurrent with the PSA, American Transport entered into a lease agreement (the “Transport Lease”) with American Energy pursuant to which (i) American Transport will lease to American Energy a tract of real property, two coal preparation plants and related coal handling facilities at the Transport Mine situated in Belmont and Monroe Counties, Ohio and (ii) American Transport will receive from American Energy a fee ranging from $1.15 to $1.75 for every ton of coal mined, processed and/or transported using such assets, subject to a quarterly recoupable minimum fee of $1.7 million. The Transport Lease is being accounted for as a direct financing lease. The total remaining minimum payments under the Transport Lease was $97.0 million at March 31, 2016, with unearned income equal to $36.6 million. The unearned income will be reflected as other revenue over the term of the lease using the effective interest method. Any amounts in excess of the contractual minimums will be recorded as other revenue when earned. As of March 31, 2016, the outstanding Transport Lease financing receivable was $60.4 million, of which $2.6 million was classified as current in the condensed consolidated balance sheet. Also, on April 16, 2015, American Century Minerals LLC (“Minerals”), a newly created subsidiary of the Partnership, entered into an overriding royalty agreement (“ORRA”) with Murray Energy subsidiaries’ American Energy and Consolidated Land Company (collectively, “AEC”), pursuant to which AEC granted to Minerals an overriding royalty interest ranging from $0.30 to $0.50 for each ton of coal mined, removed and sold from certain coal reserves situated near the Century Mine in Belmont and Monroe Counties, Ohio for $12.0 million. The ORRA is subject to a minimum recoupable quarterly fee of $0.5 million. This overriding royalty was accounted for as a financing arrangement. The payments the Partnership receives with respect to the ORRA will be reflected partially as a return of the initial investment (reduction in the affiliate financing receivable) and partially as other revenue over the life of the agreement using the effective interest method. Any amounts in excess of the contractual minimums will be recorded as other revenue when earned. The total remaining minimum payments under the ORRA was $33.6 million at March 31, 2016, with unearned income equal to $21.8 million. As of March 31, 2016, the outstanding ORRA financing receivable was $11.8 million, of which $0.2 million was classified as current in the condensed consolidated balance sheet. Other Murray Transactions During the three months ended March 31, 2016, we purchased $0.4 million in equipment, supplies and rebuild services from affiliates of Murray Energy. During the three months ended March 31, 2016, our affiliate, Coalfield Construction, provided $0.3 million in equipment, supplies and rebuild services to affiliates of Murray Energy. During the three months ended March 31, 2016, we purchased $0.6 million in coal from Murray Energy and its affiliates to meet quality specifications under certain customer contracts. During the three months ended March 31, 2016, Murray Energy transported coal under our transportation agreement with a third-party rail company resulting in usage fees owed to the third-party rail company of $3.6 million. These usage fees were billed to Murray Energy, resulting in no impact to our condensed consolidated statement of operations. The usage of the railway line with this third-party rail company by Murray Energy counts toward the minimum annual throughput volume requirement with the third-party rail company, thereby reducing the Partnership’s exposure to contractual liquidated damage charges. During the three months ended March 31, 2016, we earned $0.5 million in other revenues for Murray Energy’s usage of our Sitran terminal. 2021 Senior Notes On August 23, 2013, Cline Resource and Development Company (“CRDC”) acquired $16.5 million of outstanding principal amount of our 2021 Senior Notes (the “Original Purchase”). During September and October 2013, CRDC sold the Original Purchase primarily to affiliates, including $8.0 million to Chris Cline, $4.0 million to an entity controlled by John F. Dickinson, a director of our general partner’s board of directors until December 31, 2015, and $3.2 million to Michael Beyer, the former chief executive officer of the Partnership. Additional amounts were acquired independently in 2015 by Chris Cline and The Cline Trust Company LLC, as discussed below. As of March 31, 2016 and December 31, 2015, Chris Cline owned $44.5 million of the outstanding principal on our 2021 Senior Notes. Chris Cline acquired $8.0 million in principal of the Original Purchase and, during the year ended December 31, 2015, acquired an additional $36.5 million in principal from third parties in open market transactions. During the three months ended March 31, 2016 and 2015, $0 and $0.6 million, respectively, of interest on the 2021 Senior Notes was paid to Chris Cline. As of March 31, 2016 and December 31, 2015, $2.2 million and $1.3 million, respectively, of interest on the 2021 Senior Notes was accrued to the benefit of Chris Cline. As of March 31, 2016 and December 31, 2015, The Cline Trust Company LLC owned $10.0 million in principal of our 2021 Senior Notes, all of which was acquired during the year ended December 31, 2015. No interest has been paid to The Cline Trust Company LLC. As of March 31, 2016 and December 31, 2015, $0.5 million and $0.3 million of interest on the 2021 Senior Notes was accrued to the benefit of The Cline Trust Company LLC. The entity controlled by Mr. Dickinson, who resigned as a director of our general partner’s board of directors on December 31, 2015, owned $4.0 million of the outstanding principal on our 2021 Senior Notes as of December 31, 2015, all of which was acquired from the Original Purchase. During the three months ended March 31, 2015, $0.3 million of interest on the 2021 Senior Notes was paid to Mr. Dickinson. As of December 31, 2015, $0.1 million of interest on the 2021 Senor Notes was accrued to the benefit of the entity controlled by Mr. Dickinson. Also, Michael Beyer, who resigned in May 2015, acquired $3.2 million in principal from the Original Purchase. Mr. Beyer disposed of his 2021 Senior Notes in September of 2015. Mr. Beyer was no longer an affiliate of the Partnership subsequent to his termination date. For the three months ended March 31, 2015, $0.3 million in interest was paid to Mr. Beyer. Mineral Reserve Leases Our mines have a series of mineral reserve leases with Colt, LLC (“Colt”) and Ruger, LLC (“Ruger”), subsidiaries of Foresight Reserves. Each of these leases have initial terms of 10 years with six renewal periods of five years each, at the election of the lessees, and generally require the lessees to pay the greater of $3.40 per ton or 8.0% of the gross sales price, as defined in the respective agreements, of such coal. We also have overriding royalty agreements with Ruger pursuant to which we pay royalties equal to 8.0% of the gross selling price, as defined in the agreements. Each of these mineral reserve leases generally requires a minimum annual royalty payment, which is recoupable only against actual production royalties from future tons mined during the period of 10 years following the date on which any such royalty is paid. We also lease mineral reserves under lease agreements with subsidiaries of NRP, including WPP, HOD, and Independence Energy, LLC (“Independence”). The initial terms of these agreements vary, however, and each carries an option by the lessee to extend the leases until all merchantable and mineable coal has been mined and removed. Royalty payments under these arrangements are generally determined based on the greater of a minimum per ton amount (ranging from $2.50 per ton to $5.40 per ton) or a percentage of the gross sales price (generally 8.0% - 9.0%), as defined in the respective agreements. We are also subject under certain of these mineral reserve agreements to overriding royalties and/or wheelage fees. Our mineral reserve leases with NRP subsidiaries generally also require minimum quarterly or annual royalties which are generally recoupable on future tons mined and sold during the preceding five-year period from the excess tonnage royalty payments on a first paid, first recouped basis. In July 2015, we provided notice to WPP declaring a force majeure event at our Hillsboro mine due to elevated carbon monoxide levels as a result of a mine fire, which has required the stoppage of mining operations since March 2015. As a result of the force majeure event, we have not made $23.6 million in minimum deficiency payments to WPP in accordance with the force majeure provisions of the royalty agreement. WPP is asserting that the stoppage of mining operations as a result of the mine fire does not constitute an event of force majeure under the royalty agreement (see Note 18). As of March 31, 2016 and December 31, 2015, we have established a $43.2 million and $46.3 million reserve, respectively, against contractual prepaid royalties between Hillsboro and WPP given that the recoupment of certain prior minimum royalty payments was improbable given the remaining recoupment period available and forecasted demand for Hillsboro coal based on current and forecasted near-term market conditions. During the three months ended March 31, 2016, the recoupment period of $3.1 million in prepaid royalties between Hillsboro and WPP expired, resulting in the write-off of the prepaid royalty and the corresponding reserve. We continually evaluate our ability to recoup prepaid royalty balances which includes, among other things, assessing mine production plans, sales commitments, current and forecasted future coal market conditions, and remaining years available for recoupment. Convent Marine Terminal Amendment In August 2011, an affiliated company owned by Foresight Reserves acquired the IC RailMarine Terminal in Convent, Louisiana. This terminal, commonly referred to as the Convent Marine Terminal (“CMT”), is owned by Raven Energy LLC (“Raven”), an entity once controlled and beneficially owned by Christopher Cline. The terminal is designed to ship and receive commodities via rail, river barge and ocean vessel. We have a materials handling and storage agreement for throughput at the terminal under which we pay fees based on the tonnages of coal we move through the terminal, subject to minimum annual take-or-pay volume commitments. Effective May 1, 2015, the Partnership amended its materials handling and storage agreement with Raven to reduce the minimum annual throughput volume at CMT to 5.0 million tons and to extend the duration of the contract by one year to 2022. In August 2015, The Cline Group sold Raven to an entity under which it does not have significant influence; therefore the business activities with Raven are no longer considered affiliate transactions subsequent to the sale date. Limited Partnership Agreement The Partnership’s general partner manages the Partnership’s operations and activities as specified in the partnership agreement. The general partner of the Partnership is managed by its board of directors. Foresight Reserves and Murray Energy have the right to select the directors of the general partner. The members of the board of directors of the general partner are not elected by the unitholders and are not subject to reelection by the unitholders. The officers of the general partner manage the day-to-day affairs of the Partnership’s business. The partnership agreement provides that the Partnership will reimburse its general partner for all direct and indirect expenses incurred or payments made by the general partner on behalf of the Partnership. The following table summarizes certain affiliate amounts included in our condensed consolidated balance sheets: Affiliated Company Balance Sheet Location March 31, 2016 December 31, 2015 (In Thousands) Foresight Reserves and affiliated entities Due from affiliates - current $ 123 $ 145 Murray Energy and affiliated entities Due from affiliates - current 3,923 16,316 NRP and affiliated entities Due from affiliates - current 84 154 Total $ 4,130 $ 16,615 Murray Energy and affiliated entities Financing receivables - affiliate - current $ 2,741 $ 2,689 Total $ 2,741 $ 2,689 Murray Energy and affiliated entities Due from affiliates - noncurrent $ 1,843 $ 2,691 Total $ 1,843 $ 2,691 Murray Energy and affiliated entities Financing receivables - affiliate - noncurrent $ 69,434 $ 70,139 Total $ 69,434 $ 70,139 Foresight Reserves and affiliated entities Prepaid royalties - current and noncurrent $ 67,832 $ 69,555 NRP and affiliated entities Prepaid royalties - current and noncurrent 404 — Total $ 68,236 $ 69,555 Foresight Reserves and affiliated entities Due to affiliates - current $ 2,595 $ 1,054 Murray Energy and affiliated entities Due to affiliates - current 3,880 5,020 NRP and affiliated entities Due to affiliates - current 1,792 2,462 Total $ 8,267 $ 8,536 A summary of certain expenses (income) incurred with affiliated entities is as follows for the three months ended March 31, 2016 and 2015: Three Months Ended March 31, 2016 March 31, 2015 (In Thousands) Coal sales – Murray Energy and affiliated entities (1) $ 30 $ — Overriding royalty and lease revenues – Murray Energy and affiliated entities (2) $ (2,470 ) $ — Terminal revenues - Murray Energy and affiliated entities (2) $ (518 ) $ — Royalty expense – (3) $ 2,843 $ 9,006 Royalty expense – Foresight Reserves and affiliated entities (3) $ 3,447 $ 2,630 Loadout services – NRP and affiliated entities (3) $ 1,723 $ 2,325 Purchased goods and services – Murray Energy and affiliated entities (4) $ 392 $ — Purchased coal - Murray Energy and affiliated entities (5) $ 550 $ — Terminal fees – Foresight Reserves and affiliated entities (6) $ — $ 9,264 Management services – Murray Energy and affiliated entities (7) $ 2,078 $ — Administrative fee income – Foresight Reserves and affiliated entities (8) $ — $ (47 ) Principal location in the condensed consolidated financial statements: (1) – Coal sales (2) – Other revenues (3) – Cost of coal produced (excluding depreciation, depletion and amortization) (4) – Cost of coal produced (excluding depreciation, depletion and amortization) and property, plant and equipment, as applicable (5) – Cost of coal purchased (6) – Transportation (7) – Selling, general and administrative (8) – Other operating income, net We also purchased $2.1 million and $4.3 million in mining supplies from an affiliated joint venture under a supply agreement during the three months ended March 31, 2016 and 2015, respectively (see Note 14).

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	3 Months Ended
	Mar. 31, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Variable Interest Entities (VIEs)	14. Variable Interest Entities (VIEs) Our financial statements include VIEs for which the Partnership or one of its subsidiaries is the primary beneficiary. Among those VIEs consolidated by the Partnership and its subsidiaries are Mach Mining, LLC; M-Class Mining, LLC; MaRyan Mining LLC; Patton Mining LLC; Viking Mining LLC; Coal Field Construction Company LLC; Coal Field Repair Services LLC; and LD Labor Company LLC (collectively, the “Contractor VIEs”). Each of the Contractor VIEs holds a contract to provide one or more of the following services to a Partnership subsidiary: contract mining, processing and loading services, or construction and maintenance services. Each of the Contractor VIEs generally receives a nominal per ton fee ($0.01 to $0.02 per ton) above its cost of operations as compensation for services performed. All of these entities were determined not to have sufficient equity at risk and are therefore VIEs. The Partnership was determined to be the primary beneficiary of each of these entities given it controls these entities under a contractual cost-plus arrangement. During each of the three months ended March 31, 2016 and 2015, in aggregate, the Contractor VIEs earned income of $0.1 million under the contractual arrangements with the Partnership which was recorded as net income attributable to noncontrolling interests in the condensed consolidated statements of operations. In January 2016, we contributed $2.5 million to a new entity, Foresight Surety LLC (“Foresight Surety”), whose purpose was to obtain and maintain a letter of credit for the benefit of one of our surety bond providers. We hold all of the economic units of Foresight Surety and a professional service provider with which we have had a long-standing relationship holds all of the voting rights in Foresight Surety. Foresight Surety is a VIE given that the holder of all of the economic rights has no ability to exercise power over it. We were determined to be the primary beneficiary of Foresight Surety, and therefore consolidate Foresight Surety, as the professional service provider with all of the voting rights was determined to be acting as our de facto agent and therefore we would aggregate voting power. In February 2016, Foresight Surety obtained a $2.5 million letter of credit with a lender for the benefit of one of our surety bond providers. The letter of credit is secured by the $2.5 million of cash we contributed to Foresight Surety. On August 23, 2013, FELLC effected a reorganization pursuant to which certain transportation assets were distributed to its members (the “2013 Reorganization”). Among the assets distributed were Adena and Hillsboro Transport. Subsequent to the 2013 Reorganization, both of these entities were identified as VIEs and continued to be consolidated by FELLC. During the first quarter of 2015, Adena and Hillsboro Transport were contributed to the Partnership by Foresight Reserves and a member of management and are therefore no longer consolidated as VIEs (see Note 1). The liabilities recognized as a result of consolidating the VIEs do not necessarily represent additional claims on the general assets of the Partnership outside of the VIEs; rather, they represent claims against the specific assets of the consolidated VIEs. Conversely, assets recognized as a result of consolidating these VIEs do not necessarily represent additional assets that could be used to satisfy claims against the Partnership’s general assets. There are no restrictions on the VIE assets that are reported in the Partnership’s general assets. The total consolidated VIE assets and liabilities reflected in the Partnership’s condensed consolidated balance sheets are as follows: March 31, 2016 December 31, 2015 (In Thousands) Assets: Current assets (1) $ 3,743 $ 4,933 Long-term assets 2,500 — Total assets (1) $ 6,243 $ 4,933 Liabilities: Current liabilities $ 13,798 $ 12,835 Long-term liabilities 2,715 2,955 Total liabilities $ 16,513 $ 15,790 (1) – Includes cash and cash equivalents of $2,980 and $4,332 as of March 31, 2016 and December 31, 2015, respectively. In May 2013, an affiliate owned by The Cline Group and a third-party supplier of mining supplies formed a joint venture whose purpose is the manufacture and sale of supplies primarily for use by the Partnership in the conduct of its mining operations. The agreement obligates the Partnership’s coal mines to purchase at least 90% of their aggregate annual requirements for certain mining supplies from the supplier parties, subject to exceptions as set forth in the agreement. The initial term of the amended agreement is five years and expires in April 2018. The supplies sold under this arrangement result in an agreed-upon, fixed-profit percentage for the joint venture. This joint venture was determined to be a VIE given that the equity holders do not have the obligation to absorb the expected losses or the right to receive the expected residual returns of the joint venture as a result of the Partnership effectively guaranteeing a fixed-profit percentage on the supplies it purchases from the joint venture. We are not the primary beneficiary of this joint venture and, therefore, do not consolidate the joint venture, given that the power over the joint venture is conveyed through the board of directors of the joint venture and no party controls the board of directors.

Equity-Based Compensation

Equity-Based Compensation	3 Months Ended
	Mar. 31, 2016
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Equity-Based Compensation	15. Equity-Based Compensation Long-Term Incentive Plan The Partnership has a Long-Term Incentive Plan ("LTIP") for employees, directors, officers and certain key third-parties (collectively, the "Participants") which allows for the issuance of equity-based compensation. The LTIP awards granted thus far are phantom units, which upon satisfaction of vesting requirements, entitle the LTIP participant to receive FELP units. The board of directors of FEGP authorized 7.0 million common units to be granted under the LTIP, with 6.2 million remaining units available for issuance as of March 31, 2016. Our equity-based compensation expense, net of estimated forfeitures, was $4.0 million and $8.2 million during the three months ended March 31, 2016 and 2015, respectively. Included in the selling, general and administrative expense for the three months ended March 31, 2015 was $7.1 million of stock compensation expense for 215,954 common units and 215,796 subordinated units issued to the former chief executive officer of the Partnership which were fully-vested on the date of grant. Approximately 92.6% of the Partnership's equity-based compensation during the three months ended March 31, 2016 was reported in the condensed consolidated statement of operations as transition and reorganization costs, 1.3% as selling, general and administrative expenses and the remaining 6.1% recorded as cost of coal produced. All non-vested phantom awards include tandem distribution incentive rights, which provide for the right to accrue quarterly cash distributions in an amount equal to the cash distributions the Partnership makes to unitholders during the vesting period and will be settled in cash upon vesting. The Partnership has $0.6 million accrued for this liability as of March 31, 2016. Any distributions accrued to a Participants’ account will be forfeited if the related phantom award fails to vest according to the relevant vesting conditions. A summary of LTIP award activity for the three months ended March 31, 2016 is as follows: Number Weighted Grant per Non-vested grants at January 1, 2016 1,711,341 $ 7.21 Granted - $ - Vested (392 ) $ 20.00 Forfeited - $ - Non-vested grants at March 31, 2016 1,710,949 $ 7.21

Earnings per Limited Partner Un

Earnings per Limited Partner Unit	3 Months Ended
	Mar. 31, 2016
Earnings Per Share [Abstract]
Earnings per Limited Partner Unit	16. Earnings per Limited Partner Unit Limited partners’ interest in net (loss) income attributable to the Partnership and basic and diluted earnings per unit reflect net income attributable to the Partnership. We compute earnings per unit (“EPU”) using the two-class method for master limited partnerships as prescribed in ASC 260, Earnings Per Share The Partnership’s net income (loss) is allocated to the limited partners, including the holders of the subordinated units, in accordance with their respective ownership percentages, after giving effect to any special income or expense allocations and incentive distributions paid to the general partner, if any. The IDR holders have the right to receive increasing percentages of quarterly distributions from operating surplus after certain distribution levels defined in the partnership agreement have been achieved. The general partner has no obligation to make distributions; therefore, undistributed earnings of the Partnership are not allocated to the IDR holder. Basic EPU is computed by dividing net earnings attributable to unitholders by the weighted-average number of units outstanding during each period. Diluted EPU reflects the potential dilution of common equivalent units that could occur if equity participation units are converted into common units. The following table illustrates the Partnership’s calculation of net (loss) income per common and subordinated unit for the three month periods indicated: Three Months Ended March 31, 2016 2015 Common Units Subordinated Units Total Common Units Subordinated Units Total (In Thousands, Except Per Unit Data) Numerator: Net (loss) income available to limited partner units $ (20,890 ) $ (20,814 ) $ (41,704 ) $ 21,158 $ 21,125 $ 42,283 Denominator: Weighted-average units to calculate basic EPU 65,193 64,955 130,148 64,971 64,871 129,842 Less: effect of dilutive securities (1) — — — — — — Weighted-average units to calculate diluted EPU 65,193 64,955 130,148 64,971 64,871 129,842 Basic net (loss) income per unit $ (0.32 ) $ (0.32 ) $ (0.32 ) $ 0.33 $ 0.33 $ 0.33 Diluted net (loss) income per unit $ (0.32 ) $ (0.32 ) $ (0.32 ) $ 0.33 $ 0.33 $ 0.33 (1) - Diluted EPU gives effect to all dilutive potential common units outstanding during the period using the treasury stock method. Diluted EPU excludes all dilutive potential units calculated under the treasury stock method if their effect is anti-dilutive. For the three months ended March 31, 2016 and 2015, approximately 1.7 million and 0.7 million phantom units, respectively, were anti-dilutive, and therefore excluded from the diluted EPU calculation.

Fair Value of Financial Instrum

Fair Value of Financial Instruments	3 Months Ended
	Mar. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	17. Fair Value of Financial Instruments The table below sets forth, by level, the Partnership’s net financial assets and liabilities for which fair value is measured on a recurring basis: Fair Value at March 31, 2016 Total Level 1 Level 2 Level 3 (In Thousands) Coal derivative contracts $ 40,840 $ — $ 40,840 $ — Diesel derivative contracts (773 ) — (773 ) — Total $ 40,067 $ — $ 40,067 $ — Fair Value at December 31, 2015 Total Level 1 Level 2 Level 3 (In Thousands) Coal derivative contracts $ 48,623 $ — $ 48,623 $ — Diesel derivative contracts (1,029 ) — (1,029 ) — Total $ 47,594 $ — $ 47,594 $ — The Partnership’s commodity derivative contracts are valued based on direct broker quotes and corroborated with market pricing data. The classification and amount of the Partnership’s financial instruments measured at fair value on a recurring basis, which are presented on a gross basis in the condensed consolidated balance sheets as of March 31, 2016 and December 31, 2015, are as follows: Fair Value at March 31, 2016 Current – Long-Term – Coal Derivative Assets Accrued Expenses Other Long-Term Liabilities (In Thousands) Coal derivative contracts $ 24,195 $ 16,645 $ — $ — Diesel derivative contracts — — (773 ) — Total $ 24,195 $ 16,645 $ (773 ) $ — Fair Value at December 31, 2015 Current – Long-Term – Coal Derivative Assets Accrued Expenses Other Long-Term Liabilities (In Thousands) Coal derivative contracts $ 26,596 $ 22,027 $ — $ — Diesel derivative contracts — — (1,029 ) — Total $ 26,596 $ 22,027 $ (1,029 ) $ — During the three months ended March 31, 2016 and 2015, there were no assets or liabilities that were transferred between Level 1 and Level 2 nor did the Partnership have any Level 3 assets or liabilities measured at fair value during these periods. Long-Term Debt The fair value of long-term debt as of March 31, 2016 and December 31, 2015 was $1,072.5 million and $1,244.3 million, respectively. The fair value of long-term debt was calculated based on the amount of future cash flows associated with each debt instrument discounted at the Partnership’s current estimated credit-adjusted borrowing rate for similar debt instruments with comparable terms. This is considered a Level 3 fair value measurement.

Contingencies

Contingencies	3 Months Ended
	Mar. 31, 2016
Commitments And Contingencies Disclosure [Abstract]
Contingencies	18. Contingencies In May 2015, the trustee for the holders of our 2021 Senior Notes filed suit in the Delaware Court of Chancery against the issuers and guarantors of the 2021 Senior Notes (collectively, the “FE Defendants”) alleging that Murray Energy’s acquisition of a 34% interest in FEGP and of an option to purchase an additional 46% interest in FEGP triggered a change of control of the 2021 Senior Notes pursuant to its Indenture, thereby requiring the FE Defendants to make an offer to purchase the 2021 Senior Notes at 101% of the principal amount tendered plus any accrued and unpaid interest thereon. On December 4, 2015, the Delaware Court of Chancery issued a memorandum opinion granting the trustee’s motion for judgment on the pleadings and denying the FE Defendants’ motion for judgment on the pleadings. In its memorandum opinion, the Delaware Court of Chancery ruled, in part, that Murray Energy’s acquisition constituted a change of control under the terms of the Indenture, and that the FE Defendants had breached the Indenture by not making an offer to purchase the 2021 Senior Notes. The Delaware Court of Chancery thereafter denied the FE Defendants’ motion for reargument. On January 7, 2016, at the parties’ joint request, the Delaware Court of Chancery entered an order staying further proceedings until January 18, 2016. Through subsequent orders, the stay has been extended through May 17, 2016. As a result of the Delaware Court of Chancery’s memorandum opinion, we are in default of the Indenture as well as all of our other long-term debt and capital lease obligations because of either a similar change of control provision or cross-default provisions within these agreements. See Notes 3, 10 and 19 for additional discussion on the ramifications of this memorandum opinion. In January 2016, certain plaintiffs filed suit against us In January 2016, WPP sent a demand letter to Macoupin claiming it had misapplied the royalty recoupment provision involving a coal mining lease and a rail infrastructure lease resulting in underpayments of $3.3 million. In April 2016, WPP and HOD filed a complaint in the Circuit Court of Macoupin County, Illinois. We do not believe that the royalty recoupment provision was misapplied. While we believe that the language of the agreements and the parties’ course of performance thereunder support Macoupin’s position, should we not prevail, we would be responsible for paying WPP for any recoupment taken that is found to contravene the language of the agreements. In July 2015, we provided notice to WPP, a subsidiary of NRP, declaring a force majeure event at our Hillsboro mine due to a combustion event. As a result of the force majeure event, as of March 31, 2016, we have not made $23.6 million in minimum deficiency payments to WPP in accordance with the force majeure provisions of the royalty agreement. On November 24, 2015, WPP filed a Complaint in the Circuit Court of Montgomery County, Illinois, alleging that (i) the stoppage of mining operations as a result of the mine fire does not constitute an event of force majeure under the royalty agreement, (ii) Hillsboro’s reliance on the force majeure language is a breach of the royalty agreement and (iii) WPP was fraudulently induced by Hillsboro to enter into the royalty agreement in the first instance. WPP seeks an award of punitive damages and attorneys’ fees under its fraud claim. While we believe this is a force majeure event, as contemplated by the royalty agreement, and that the fraud claim is without merit, should we not prevail, we would be responsible for funding any minimum deficiency payment amounts during the shutdown period to WPP and potentially additional fees. In January 2014, the Illinois Environmental Protection Agency (the “IEPA”) issued Sugar Camp a violation notice regarding construction of an underground injection well without issuance of an appropriate permit (“January Notice”). On December 31, 2015, the IEPA completed its draft permit for the operation of the UIC wells at issue, and the public comment period ended February 1, 2016. During the interim period, Sugar Camp has operated and continues to operate the injection wells under a temporary permit issued by IEPA. Sugar Camp, IEPA, and the Illinois Attorney General agreed to a settlement of the January Notice in March 2016, and they have collectively asked the Pollution Control Board to approve the settlement, which entails payment of an immaterial civil penalty but notes that Sugar Camp does not admit to the violation. In November 2012, six citizens filed requests for administrative review of Revision No. 1 to Permit No. 399 for the Hillsboro mine. Revision No. 1 allowed for conversion of the currently permitted coal refuse disposal facility from a non-impounding to an impounding structure. Shortly after the filing of Revision No. 1, one citizen withdrew his request. Following a hearing on both the Illinois Department of Natural Resources’ (“IDNR”) and Hillsboro’s motion to dismiss, the hearing officer dismissed the claims of two of the remaining five petitioners and also limited some of the issues remaining for administrative review. In June 2014, two of the remaining three petitioners dismissed their requests. A final hearing on the merits began in June 2015. The hearing officer granted Hillsboro’s motion for reconsideration of his decision denying its motion for summary decision on two grounds. The hearing officer’s decision on reconsideration disposed of the entire administrative proceeding in Hillsboro’s favor. On October 5, 2015, the petitioner filed an appeal of the hearing officer’s decision in the Circuit Court of Montgomery County, Illinois. Hillsboro intends to continue its defense of the issuance of the permit in the Circuit Court proceeding. Certain railcar lessors have asserted claims under their railcar leases with us for damage to railcars allegedly caused by our use of the railcars during the lease terms. We are currently investigating these claims and intend to defend these matters vigorously. We are also party to various other litigation matters, in most cases involving ordinary and routine claims incidental to our business. We cannot reasonably estimate the ultimate legal and financial liability with respect to all pending litigation matters. However, we believe, based on our examination of such matters, that the ultimate liability will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. As of March 31, 2016, we have $2.2 million accrued, in aggregate, for various litigation matters. Performance Bonds We had outstanding surety bonds with third parties of $80.0 million as of March 31, 2016 to secure reclamation and other performance commitments. In February 2016, we were required to post cash collateral of $2.5 million to our surety bond provider.

Subsequent Events

Subsequent Events	3 Months Ended
	Mar. 31, 2016
Subsequent Events [Abstract]
Subsequent Events	19. Subsequent Events Subsequent events described elsewhere in Notes 1, 3, 10 and 18. Transaction Support Agreement with Consenting Lenders On April 18, 2016, we entered into the Lender TSA with Consenting Lenders under the Credit Agreement, pursuant to which the Consenting Lenders have agreed, subject to the terms and conditions within the Lender TSA, to support a proposed global restructuring of the Partnership’s indebtedness, including a proposed Amendment of the ● (i) a $75.0 million reduction in aggregate lender commitments under the revolving credit facility upon the effectiveness of the Amendment (with an additional $25.0 million reduction to occur on December 31, 2016); (ii) a 1.00% increase in the interest rates applicable to borrowings under the Credit Agreement; (iii) implementation of an “excess cash flow sweep” provision (to be applicable in the second half of 2016 and in 2017), requiring prepayment of the term loans thereunder with 50% of “excess cash flow” (to be defined in a manner consistent with the existing Credit Agreement definition, subject to any mutually agreed upon modifications); (iv) modification of the consolidated interest coverage ratio and senior secured leverage ratio financial covenants to make such covenants applicable to both the term loan facility and the revolving credit facility (instead of only the revolving credit facility); (v) modification of the senior secured leverage ratio applicable to the financial maintenance covenant to be as follows: (a) 3.8 to 1 through the end of 2016; (b) 4.0 to 1 during 2017; (c) 3.8 to 1 during 2018; (d) 3.5 to 1 during 2019; and (e) 3.25 to 1 during 2020; (vi) the prohibition of certain restricted payments in 2016, 2017 and the first six months of 2018 (or such later date as the revolving credit facility is refinanced) (subject to limited tax-related exceptions in 2017 and thereafter); (vii) implementation of an “anti-hoarding” covenant, prohibiting borrowings under the revolving credit facility (other than letters of credit) when FELLC’s unrestricted cash exceeds $35.0 million; (viii) other modifications to the Credit Agreement for the purpose of implementing the other transactions contemplated in the proposed Restructuring; and (ix) other modifications to the covenants, representations and warranties, events of default and other provisions of the Credit Agreement described in the amendment term sheet; ● FELLC has agreed to pay each Consenting Lender, on the effective date of the proposed Amendment, an amendment fee in an aggregate amount (after giving effect to transactions contemplated in the proposed Restructuring) equal to 1.00% of the aggregate amount of revolving credit facility commitments of, and, without duplication, 1.00% of all loans, including term loans, owed to, such Consenting Lender under the Credit Agreement at such date (after giving effect to the revolving credit facility reduction). Under the Lender TSA, we have also agreed to seek to enter into a transaction support agreement or similar agreement with holders of at least 66.67% of the principal amount of the 2021 Senior Notes in support of the transactions contemplated in the proposed Restructuring on or before May 17, 2016. The Consenting Lenders have agreed that as of the effective date of the Amendment of the Credit Agreement, the Consenting Lenders will waive all defaults and events of default under the Credit Agreement continuing immediately prior to the consummation of the Restructuring (except any payment-related defaults or events of default). However, the Lender TSA is subject to termination under numerous provisions as defined in the Lender TSA, including, but not limited to: (i) mutual consent of the parties; (ii) the commencement of a Partnership voluntary or involuntary bankruptcy (iii) failure to consummate the transactions contemplated by the Lender TSA on or before July 15, 2016 or, in any case, by an outside date of November 4, 2016; (iv) the Partnership’s proposal or support of a proposal to pursue an alternative restructuring; (v) the Partnership failing to enter into a transaction support agreement or similar agreement with holders of at least 66.67% of the principal amount of the 2021 Senior Notes on or before May 17, 2016; (vi) the termination or expiration of the other lender forbearance agreements or the termination or expiration of any other transaction support agreement or similar agreement entered into by the Partnership in support of the Restructuring; (vii) any deviation from the material terms of the transactions contemplated by the Lender TSA in any definitive document for the Restructuring that is adverse to the Consenting Lenders or a material breach by the Partnership of the Lender TSA that is not cured; and (viii) the occurrence of an Event of Default under the Credit Agreement (other than a payment default or in respect of financial covenants). Certain of the foregoing termination events may be waived or modified by a majority of the Consenting Lenders; other termination events, including the outside date of November 4, 2016, may not be waived or modified without the consent of each Consenting Lender. Terms of the Proposed Restructuring. The proposed Restructuring consists of a series of proposed transactions which are the subject of ongoing negotiations amongst the various stakeholders of the Partnership and its affiliates, including the following proposed transactions: ● The proposed Amendment to the Credit Agreement described above; ● The proposed purchase by investors in Foresight Reserves of up to $106 million aggregate principal amount of outstanding 2021 Senior Notes currently held by non-affiliates of the Partnership, in a cash tender offer at a price equal to 100% of the principal amount thereof; ● The proposed exchange (the “2021 Senior Notes Exchange”) of the outstanding 2021 Senior Notes for: (i) up to $300 million aggregate principal amount of second-lien senior convertible PIK notes (with a maturity date of April 7, 2017 and a 15.0% per annum PIK coupon); and (ii) up to $300 million aggregate principal amount of second-lien senior secured notes due August 2021 (with a 9.0% per annum cash coupon for the first two years, a 10.0% per annum cash coupon thereafter plus, in each case, an additional 1.0% per annum PIK coupon), plus an additional principal amount resulting from the capitalization of accrued and unpaid interest on the 2021Senior Notes. Up to $180 million in aggregate principal amount of the second-lien senior convertible PIK notes would be issued to the Partnership’s principal equityholders in exchange for 2021 Senior Notes held (or purchased from other holders of the 2021 Senior Notes in the tender offer described above) by such equityholders. The Partnership’s current proposal to the noteholders contemplates that 2021 Senior Notes held by the Partnership’s principal equityholders in excess of $180 million would be exchanged for second-lien secured notes by August 2021. ● The Partnership’s current proposal to the noteholders contemplates that each class of proposed new notes would have covenants and events of default substantially similar to the 2021 Senior Notes (subject to revisions to implement the second-lien nature of such notes). The second-lien senior convertible PIK notes, if not redeemed under certain circumstances by their maturity date, would convert into 75% of the fully diluted equity of the Partnership (in the form of common units). If the second-lien senior convertible PIK notes are redeemed under certain circumstances by their maturity date, the Partnership would issue warrants to purchase up to 7.5% of the Partnership’s common equity (in the form of common units); ● The proposed execution of a new intercreditor agreement among the first-lien creditors and the proposed new second-lien creditors; ● The proposed execution of one or more release agreements among the Partnership, its principal equityholders and holders of the 2021 Senior Notes; ● Certain proposed operational and corporate governance changes, including the appointment of a Chief Financial Officer of the Partnership’s general partner that is not affiliated with its significant equityholders, the appointment of a board observer mutually agreed upon by the holders of the 2021 Senior Notes and the Partnership and the establishment of a “Synergy and Conflicts Committee” tasked with review and oversight of affiliate transactions; and ● Proposed modifications or amendments to the Partnership’s other operational and financing documents, including equipment financings, as may be necessary to address existing defaults and/or events of default and permit the other proposed Restructuring transactions.

New Accounting Standards (Polic

New Accounting Standards (Policies)	3 Months Ended
	Mar. 31, 2016
Accounting Policies [Abstract]
New Accounting Standards	I n February 2015, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2015-02, Amendments to the Consolidation Analysis . ASU 2015-02 changes the requirements and analysis required when determining the reporting entity’s need to consolidate an entity, including modifying the evaluation of limited partnership variable interest status, the presumption that a general partner should consolidate a limited partnership and the consolidation criterion applied by a reporting entity involved with variable interest entities. We adopted ASU 2015-02 during the first quarter of 2016 and it did not have an impact on our historical consolidation conclusions. In April 2015, the FASB issued ASU 2015-06, Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs In February 2016, the FASB issued ASU 2016-02, Leases, In March 2016, the FASB issued ASU No. 2016-09, Compensation – Stock Compensation (Topic 718) No other new accounting pronouncement issued or effective during the fiscal year which was not previously disclosed in our Annual Report on Form 10-K had, or is expected to have, a material impact on our consolidated financial statements or related disclosures.

Commodity Derivative Contracts

Commodity Derivative Contracts (Tables)	3 Months Ended
	Mar. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Summary of (Loss )/Gain on Commodity Derivative Contracts	A summary of the unrealized and realized (losses) gains recorded on commodity derivative contracts for the three months ended March 31, 2016 and 2015 is as follows: Three Months Ended March 31, 2016 March 31, 2015 (In Thousands) Unrealized (loss) gain on commodity derivative contracts and prior cumulative unrealized gains realized during the period $ (5,642 ) $ 15,782 Realized gain on commodity derivative contracts 5,119 13,285 (Loss) gain on commodity derivative contracts $ (523 ) $ 29,067

Accounts Receivable (Tables)

Accounts Receivable (Tables)	3 Months Ended
	Mar. 31, 2016
Receivables [Abstract]
Schedule of Accounts Receivable	Accounts receivable consist of the following: March 31, 2016 December 31, 2015 (In Thousands) Trade accounts receivable $ 38,620 $ 56,013 Other receivables 5,803 5,312 Total accounts receivable $ 44,423 $ 61,325

Inventories (Tables)

Inventories (Tables)	3 Months Ended
	Mar. 31, 2016
Inventory Disclosure [Abstract]
Schedule of Inventories	Inventories consist of the following: March 31, 2016 December 31, 2015 (In Thousands) Parts and supplies $ 22,555 $ 24,276 Raw coal 4,997 1,906 Clean coal 37,645 24,470 Total inventories $ 65,197 $ 50,652

Property, Plant, Equipment an30

Property, Plant, Equipment and Development, Net (Tables)	3 Months Ended
	Mar. 31, 2016
Property Plant And Equipment [Abstract]
Schedule of Property, Plant, Equipment and Development, Net	Property, plant, equipment and development, net consist of the following: March 31, 2016 December 31, 2015 (In Thousands) Land, land rights and mineral rights $ 99,626 $ 99,676 Machinery and equipment 1,142,504 1,140,256 Machinery and equipment under capital leases 126,401 126,401 Buildings and structures 248,587 248,946 Development costs 752,641 750,177 Other 9,370 9,369 Property, plant, equipment and development 2,379,129 2,374,825 Less: accumulated depreciation, depletion and amortization (981,914 ) (941,632 ) Property, plant, equipment and development, net $ 1,397,215 $ 1,433,193

Accrued Expenses and Other Cu31

Accrued Expenses and Other Current Liabilities (Tables)	3 Months Ended
	Mar. 31, 2016
Payables And Accruals [Abstract]
Schedule of Accrued Expenses and Other Current Liabilities	Accrued expenses and other current liabilities consist of the following: March 31, 2016 December 31, 2015 (In Thousands) Employee compensation, benefits and payroll taxes $ 11,194 $ 12,393 Taxes other than income 7,284 6,560 Liquidated damages (non-affiliate) 6,745 6,404 Royalties (non-affiliate) 2,889 3,707 Other 6,321 6,761 Total accrued expenses and other current liabilities $ 34,433 $ 35,825

Long-Term Debt and Capital Le32

Long-Term Debt and Capital Lease Obligations (Tables)	3 Months Ended
	Mar. 31, 2016
Debt Disclosure [Abstract]
Schedule of Long-Term Debt and Capital Lease Obligations	Long-term debt and capital lease obligations consist of the following: March 31, 2016 December 31, 2015 (In Thousands) 2021 Senior Notes $ 600,000 $ 600,000 Revolving Credit Facility 352,500 352,500 Term Loan 297,750 297,750 Trade A/R Securitization 21,200 41,000 5.78% longwall financing arrangement 50,423 50,423 5.555% longwall financing arrangement 46,406 51,563 Capital lease obligations 56,770 62,710 Subtotal - Total long-term debt and capital lease obligations principal outstanding 1,425,049 1,455,946 Unamortized deferred financing costs and debt discounts (20,175 ) (21,380 ) Total long-term debt and capital lease obligations 1,404,874 1,434,566 Less: current portion (1,404,874 ) (1,434,566 ) Non-current portion of long-term debt and capital lease obligations $ — $ —

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Changes in Carrying Amount of Asset Retirement Obligations	The change in the carrying amount of our asset retirement obligations was as follows for the three months ended March 31, 2016: March 31, 2016 (In Thousands) Balance at January 1, 2016 (including current portion) $ 43,295 Accretion expense 844 Expenditures for reclamation activities (80 ) Balance at March 31, 2016 (including current portion) 44,059 Less: current portion of asset retirement obligations (18 ) Noncurrent portion of asset retirement obligations $ 44,041

Related-Party Transactions (Tab

Related-Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2016
Related Party Transactions [Abstract]
Summary of Certain Affiliate Amounts Included in Condensed Consolidated Balance Sheets	The following table summarizes certain affiliate amounts included in our condensed consolidated balance sheets: Affiliated Company Balance Sheet Location March 31, 2016 December 31, 2015 (In Thousands) Foresight Reserves and affiliated entities Due from affiliates - current $ 123 $ 145 Murray Energy and affiliated entities Due from affiliates - current 3,923 16,316 NRP and affiliated entities Due from affiliates - current 84 154 Total $ 4,130 $ 16,615 Murray Energy and affiliated entities Financing receivables - affiliate - current $ 2,741 $ 2,689 Total $ 2,741 $ 2,689 Murray Energy and affiliated entities Due from affiliates - noncurrent $ 1,843 $ 2,691 Total $ 1,843 $ 2,691 Murray Energy and affiliated entities Financing receivables - affiliate - noncurrent $ 69,434 $ 70,139 Total $ 69,434 $ 70,139 Foresight Reserves and affiliated entities Prepaid royalties - current and noncurrent $ 67,832 $ 69,555 NRP and affiliated entities Prepaid royalties - current and noncurrent 404 — Total $ 68,236 $ 69,555 Foresight Reserves and affiliated entities Due to affiliates - current $ 2,595 $ 1,054 Murray Energy and affiliated entities Due to affiliates - current 3,880 5,020 NRP and affiliated entities Due to affiliates - current 1,792 2,462 Total $ 8,267 $ 8,536
Summary of Certain Expenses (Income) Incurred With Affiliated Entities	A summary of certain expenses (income) incurred with affiliated entities is as follows for the three months ended March 31, 2016 and 2015: Three Months Ended March 31, 2016 March 31, 2015 (In Thousands) Coal sales – Murray Energy and affiliated entities (1) $ 30 $ — Overriding royalty and lease revenues – Murray Energy and affiliated entities (2) $ (2,470 ) $ — Terminal revenues - Murray Energy and affiliated entities (2) $ (518 ) $ — Royalty expense – (3) $ 2,843 $ 9,006 Royalty expense – Foresight Reserves and affiliated entities (3) $ 3,447 $ 2,630 Loadout services – NRP and affiliated entities (3) $ 1,723 $ 2,325 Purchased goods and services – Murray Energy and affiliated entities (4) $ 392 $ — Purchased coal - Murray Energy and affiliated entities (5) $ 550 $ — Terminal fees – Foresight Reserves and affiliated entities (6) $ — $ 9,264 Management services – Murray Energy and affiliated entities (7) $ 2,078 $ — Administrative fee income – Foresight Reserves and affiliated entities (8) $ — $ (47 ) Principal location in the condensed consolidated financial statements: (1) – Coal sales (2) – Other revenues (3) – Cost of coal produced (excluding depreciation, depletion and amortization) (4) – Cost of coal produced (excluding depreciation, depletion and amortization) and property, plant and equipment, as applicable (5) – Cost of coal purchased (6) – Transportation (7) – Selling, general and administrative (8) – Other operating income, net

Variable Interest Entities (V35

Variable Interest Entities (VIEs) (Tables)	3 Months Ended
	Mar. 31, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Summary of Consolidated VIE Assets and Liabilities	The liabilities recognized as a result of consolidating the VIEs do not necessarily represent additional claims on the general assets of the Partnership outside of the VIEs; rather, they represent claims against the specific assets of the consolidated VIEs. Conversely, assets recognized as a result of consolidating these VIEs do not necessarily represent additional assets that could be used to satisfy claims against the Partnership’s general assets. There are no restrictions on the VIE assets that are reported in the Partnership’s general assets. The total consolidated VIE assets and liabilities reflected in the Partnership’s condensed consolidated balance sheets are as follows: March 31, 2016 December 31, 2015 (In Thousands) Assets: Current assets (1) $ 3,743 $ 4,933 Long-term assets 2,500 — Total assets (1) $ 6,243 $ 4,933 Liabilities: Current liabilities $ 13,798 $ 12,835 Long-term liabilities 2,715 2,955 Total liabilities $ 16,513 $ 15,790 (1) – Includes cash and cash equivalents of $2,980 and $4,332 as of March 31, 2016 and December 31, 2015, respectively.

Equity-Based Compensation (Tabl

Equity-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2016
Phantom Share Units (PSUs)
Summary of Non-vested LTIP Award Activity	A summary of LTIP award activity for the three months ended March 31, 2016 is as follows: Number Weighted Grant per Non-vested grants at January 1, 2016 1,711,341 $ 7.21 Granted - $ - Vested (392 ) $ 20.00 Forfeited - $ - Non-vested grants at March 31, 2016 1,710,949 $ 7.21

Earnings per Limited Partner 37

Earnings per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2016
Earnings Per Share [Abstract]
Summary of Partnership's Calculation of Net Income per Common and Subordinated Unit	The following table illustrates the Partnership’s calculation of net (loss) income per common and subordinated unit for the three month periods indicated: Three Months Ended March 31, 2016 2015 Common Units Subordinated Units Total Common Units Subordinated Units Total (In Thousands, Except Per Unit Data) Numerator: Net (loss) income available to limited partner units $ (20,890 ) $ (20,814 ) $ (41,704 ) $ 21,158 $ 21,125 $ 42,283 Denominator: Weighted-average units to calculate basic EPU 65,193 64,955 130,148 64,971 64,871 129,842 Less: effect of dilutive securities (1) — — — — — — Weighted-average units to calculate diluted EPU 65,193 64,955 130,148 64,971 64,871 129,842 Basic net (loss) income per unit $ (0.32 ) $ (0.32 ) $ (0.32 ) $ 0.33 $ 0.33 $ 0.33 Diluted net (loss) income per unit $ (0.32 ) $ (0.32 ) $ (0.32 ) $ 0.33 $ 0.33 $ 0.33 (1) - Diluted EPU gives effect to all dilutive potential common units outstanding during the period using the treasury stock method. Diluted EPU excludes all dilutive potential units calculated under the treasury stock method if their effect is anti-dilutive. For the three months ended March 31, 2016 and 2015, approximately 1.7 million and 0.7 million phantom units, respectively, were anti-dilutive, and therefore excluded from the diluted EPU calculation.

Fair Value of Financial Instr38

Fair Value of Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value of Net Financial Assets and Liabilities Measured on Recurring Basis	The table below sets forth, by level, the Partnership’s net financial assets and liabilities for which fair value is measured on a recurring basis: Fair Value at March 31, 2016 Total Level 1 Level 2 Level 3 (In Thousands) Coal derivative contracts $ 40,840 $ — $ 40,840 $ — Diesel derivative contracts (773 ) — (773 ) — Total $ 40,067 $ — $ 40,067 $ — Fair Value at December 31, 2015 Total Level 1 Level 2 Level 3 (In Thousands) Coal derivative contracts $ 48,623 $ — $ 48,623 $ — Diesel derivative contracts (1,029 ) — (1,029 ) — Total $ 47,594 $ — $ 47,594 $ —
Fair Value of Gross Financial Assets and Liabilities Measured on a Recurring Basis	The classification and amount of the Partnership’s financial instruments measured at fair value on a recurring basis, which are presented on a gross basis in the condensed consolidated balance sheets as of March 31, 2016 and December 31, 2015, are as follows: Fair Value at March 31, 2016 Current – Long-Term – Coal Derivative Assets Accrued Expenses Other Long-Term Liabilities (In Thousands) Coal derivative contracts $ 24,195 $ 16,645 $ — $ — Diesel derivative contracts — — (773 ) — Total $ 24,195 $ 16,645 $ (773 ) $ — Fair Value at December 31, 2015 Current – Long-Term – Coal Derivative Assets Accrued Expenses Other Long-Term Liabilities (In Thousands) Coal derivative contracts $ 26,596 $ 22,027 $ — $ — Diesel derivative contracts — — (1,029 ) — Total $ 26,596 $ 22,027 $ (1,029 ) $ —

Organization, Nature of Busin39

Organization, Nature of Business and Basis of Presentation - Additional Information (Details) - USD ($) $ in Millions	Jun. 23, 2014	Mar. 31, 2016	May. 31, 2015	Apr. 16, 2015	Mar. 31, 2015
Schedule Of Organization Nature Of Business And Basis Of Presentation [Line Items]
Percentage of ownership interests contributed					100.00%
Aggregate net book value of contributed companies		$ 60.6
Murray Energy Transaction
Schedule Of Organization Nature Of Business And Basis Of Presentation [Line Items]
Percentage of outstanding limited partner units issued				50.00%
Foresight Energy GP Limited Liability Company | Murray Energy Transaction
Schedule Of Organization Nature Of Business And Basis Of Presentation [Line Items]
Percentage of voting interests acquired			34.00%	34.00%
Foresight Energy LLC | Foresight Reserves, LP
Schedule Of Organization Nature Of Business And Basis Of Presentation [Line Items]
Ownership percentage prior	99.333%
Foresight Energy LLC | Member of Management
Schedule Of Organization Nature Of Business And Basis Of Presentation [Line Items]
Ownership percentage prior	0.667%

New Accounting Standards - Addi

New Accounting Standards - Additional Information (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
ASU 2015-03
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Reclassification of deferred financing costs to long term debt and capital lease obligation	$ 15.9

Debt Defaults and Liquidity - A

Debt Defaults and Liquidity - Additional Information (Details) - USD ($)	Jan. 27, 2016	Dec. 18, 2015	Jan. 31, 2016	Mar. 31, 2016	Feb. 16, 2016
Debt Instrument [Line Items]
Debt restructuring costs				$ 9,710,000
Interest coverage ratio				244.00%
Senior secured leverage ratio				283.00%
Minimum
Debt Instrument [Line Items]
Interest coverage ratio				200.00%
Maximum
Debt Instrument [Line Items]
Senior secured leverage ratio				275.00%
2021 Senior Notes
Debt Instrument [Line Items]
Debt instrument interest percentage				7.875%
Accrued interest					$ 23,600,000
Percentage of debt amount owned or managed by certain holders		75.00%
Securitization Forbearance Agreement
Debt Instrument [Line Items]
Maximum borrowings capacity under credit facility	$ 50,000,000		$ 50,000,000
Long-term line of credit	$ 41,000,000		$ 41,000,000
Outstanding balance eligible percentage	70.00%		70.00%

Transition and Reorganization42

Transition and Reorganization Costs - Additional Information (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)
Transition And Reorganization Costs [Line Items]
Transition and reorganization costs	$ 5,940
Murray Management Services Agreement | Murray Energy Corporation
Transition And Reorganization Costs [Line Items]
Contribution of net assets to Foresight Energy LP	2,000
Equity-based compensation for accelerated vesting of certain equity awards	3,700
Other one-time charges	$ 200

Commodity Derivative Contract43

Commodity Derivative Contracts - Additional Information (Details) $ in Thousands, gal in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016Tgal	Mar. 31, 2015USD ($)	Dec. 31, 2015Tgal
Derivative Instruments And Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount, Mass | T	1,000,000		1,100,000
Settlement of certain commodity derivative contracts | $		$ 3,319
Swap Agreements
Derivative Instruments And Hedging Activities Disclosures [Line Items]
Derivative, Nonmonetary Notional Amount, Volume | gal	0.8		1

Commodity Derivative Contract44

Commodity Derivative Contracts - Summary of (Loss)/Gain on Commodity derivative contracts (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Unrealized (loss) gain on commodity derivative contracts and prior cumulative unrealized gains realized during the period	$ (5,642)	$ 15,782
Realized gain on commodity derivative contracts	5,119	13,285
(Loss) gain on commodity derivative contracts	$ (523)	$ 29,067

Accounts Receivable - Schedule

Accounts Receivable - Schedule of Accounts Receivable (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Receivables [Abstract]
Trade accounts receivable	$ 38,620	$ 56,013
Other receivables	5,803	5,312
Total accounts receivable	$ 44,423	$ 61,325

Inventories - Schedule of Inven

Inventories - Schedule of Inventories (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Inventory [Line Items]
Parts and supplies	$ 22,555	$ 24,276
Total inventories	65,197	50,652
Raw coal
Inventory [Line Items]
Coal	4,997	1,906
Clean coal
Inventory [Line Items]
Coal	$ 37,645	$ 24,470

Property, Plant, Equipment an47

Property, Plant, Equipment and Development, Net (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Property Plant And Equipment [Abstract]
Land, land rights and mineral rights	$ 99,626	$ 99,676
Machinery and equipment	1,142,504	1,140,256
Machinery and equipment under capital leases	126,401	126,401
Buildings and structures	248,587	248,946
Development costs	752,641	750,177
Other	9,370	9,369
Property, plant, equipment and development	2,379,129	2,374,825
Less: accumulated depreciation, depletion and amortization	(981,914)	(941,632)
Property, plant, equipment and development, net	$ 1,397,215	$ 1,433,193

Accrued Expenses and Other Cu48

Accrued Expenses and Other Current Liabilities - Schedule of Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Payables And Accruals [Abstract]
Employee compensation, benefits and payroll taxes	$ 11,194	$ 12,393
Taxes other than income	7,284	6,560
Liquidated damages (non-affiliate)	6,745	6,404
Royalties (non-affiliate)	2,889	3,707
Other	6,321	6,761
Total accrued expenses and other current liabilities	$ 34,433	$ 35,825

Long-Term Debt and Capital Le49

Long-Term Debt and Capital Lease Obligations (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Long-term debt	$ 1,425,049	$ 1,455,946
Capital lease obligations	56,770	62,710
Unamortized deferred financing costs and debt discounts	(20,175)	(21,380)
Total long-term debt and capital lease obligations	1,404,874	1,434,566
Less: current portion	(1,404,874)	(1,434,566)
2021 Senior Notes
Debt Instrument [Line Items]
Long-term debt	600,000	600,000
Term Loan
Debt Instrument [Line Items]
Long-term debt	297,750	297,750
Trade A/R Securitization
Debt Instrument [Line Items]
Long-term debt	21,200	41,000
5.78% longwall financing arrangement
Debt Instrument [Line Items]
Long-term debt	50,423	50,423
5.555% longwall financing arrangement
Debt Instrument [Line Items]
Long-term debt	46,406	51,563
Revolving Credit Facility
Debt Instrument [Line Items]
Revolving Credit Facility	$ 352,500	$ 352,500

Long-Term Debt and Capital Le50

Long-Term Debt and Capital Lease Obligations (Parenthetical) (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
5.78% longwall financing arrangement
Debt Instrument [Line Items]
Debt instrument interest percentage	5.78%	5.78%
5.555% longwall financing arrangement
Debt Instrument [Line Items]
Debt instrument interest percentage	5.555%	5.555%
2021 Senior Notes
Debt Instrument [Line Items]
Debt instrument maturity year	2,021	2,021
Debt instrument interest percentage	7.875%

Long-Term Debt and Capital Le51

Long-Term Debt and Capital Lease Obligations - Additional Information (Details) - USD ($)	Feb. 16, 2016	Jan. 27, 2016	Jan. 31, 2016	Mar. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Accrued interest				$ 37,343,000	$ 24,574,000
Interest coverage ratio				244.00%
Senior secured loans leverage ratio				283.00%
Loss on extinguishment of debt				$ 107,000
Revolving Credit Facility
Debt Instrument [Line Items]
Minimum required interest coverage ratio				200.00%
Maximum required senior secured loans leverage ratio				275.00%
Expected increase in borrowing rate				2.00%
Weighted average interest rate				5.60%
Outstanding letters of credit				$ 6,500,000
2021 Senior Notes
Debt Instrument [Line Items]
Interest payment grace period	30 days
Accrued interest	$ 23,600,000
Offer date to purchase debt notes				May 18, 2015
Term Loan
Debt Instrument [Line Items]
Interest rate on borrowings				7.50%
Securitization Forbearance Agreement
Debt Instrument [Line Items]
Interest rate on borrowings				5.50%
Maximum borrowings capacity under credit facility		$ 50,000,000	$ 50,000,000
Long-term line of credit		$ 41,000,000	$ 41,000,000
Outstanding balance eligible percentage		70.00%	70.00%
Loss on extinguishment of debt				$ 100,000

Sale-Leaseback Financing Arra52

Sale-Leaseback Financing Arrangements - Affiliate - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Sale Leaseback Transaction [Line Items]
Sale-leaseback financing arrangements	$ 193,434		$ 193,434
Sale-lease back transaction, accrued interest expense	$ 37,343		24,574
Macoupin
Sale Leaseback Transaction [Line Items]
Sale-leaseback transaction, description	In 2009, Macoupin sold certain of its coal reserves and rail facilities to WPP, LLC (“WPP”), a subsidiary of Natural Resource Partners, LP (“NRP”), and leased them back. The gross proceeds from this transaction were $143.5 million.
Proceeds from sale-leaseback financing arrangement	$ 143,500
Sale-leaseback financing arrangements	$ 143,500
Sale-leaseback transaction, imputed interest rate	13.90%
Sale-lease back transaction, interest expense	$ 4,400	$ 5,100
Sale-lease back transaction, accrued interest expense	$ 4,600		2,100
Sugar Camp
Sale Leaseback Transaction [Line Items]
Sale-leaseback transaction, description	In 2012, Sugar Camp sold certain rail facilities to HOD, LLC (“HOD”), a subsidiary of NRP, and leased them back. The gross proceeds from this transaction were $50.0 million.
Proceeds from sale-leaseback financing arrangement	$ 50,000
Sale-leaseback financing arrangements	$ 50,000
Sale-leaseback transaction, imputed interest rate	13.20%
Sale-lease back transaction, interest expense	$ 1,400	$ 1,500
Sale-lease back transaction, accrued interest expense	$ 4,600		$ 2,100

Asset Retirement Obligations -

Asset Retirement Obligations - Changes in Carrying Amount of Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Beginning balance	$ 43,295
Accretion expense	844	$ 567
Expenditures for reclamation activities	(80)
Ending balance	44,059
Less: current portion of asset retirement obligations	(18)
Noncurrent portion of asset retirement obligations	$ 44,041		$ 43,277

Related-Party Transactions - Ad

Related-Party Transactions - Additional Information (Details) shares in Millions

May. 01, 2015T / yr

Apr. 16, 2015USD ($)Facility$ / T

Oct. 31, 2013USD ($)

Sep. 30, 2013USD ($)

Mar. 31, 2016USD ($)Renewal$ / Tshares

Mar. 31, 2015USD ($)

Feb. 16, 2016USD ($)

Dec. 31, 2015USD ($)

Jul. 31, 2015USD ($)

May. 31, 2015

Aug. 23, 2013USD ($)

Related Party Transaction [Line Items]

Financing receivables - affiliates

$ 2,741,000

$ 2,689,000

Cost of coal purchased

550,000

$ 106,000

Minimum deficiency payment not made

23,600,000

Prepaid royalty reserve

43,200,000

46,300,000

Recoupment of prepaid royalty reserve expired

3,100,000

2021 Senior Notes

Related Party Transaction [Line Items]

Accrued interest

$ 23,600,000

Murray Management Services Agreement

Related Party Transaction [Line Items]

Management and administration expenses, net

2,100,000

Transport and Overriding Royalty Agreements

Related Party Transaction [Line Items]

Total remaining minimum payments of transportation lease

97,000,000

Unearned income from financing leasing services

36,600,000

Outstanding financing receivable

60,400,000

Financing receivables - affiliates

2,600,000

ORRA

Related Party Transaction [Line Items]

Outstanding financing receivable

11,800,000

Financing receivables - affiliates

200,000

Remaining minimum payments under agreement

33,600,000

Unearned income under agreement

$ 21,800,000

Murray Energy Transaction

Related Party Transaction [Line Items]

Proceeds from sale of voting interest

$ 1,370,000,000

Percentage of outstanding limited partner units issued

50.00%

Percentage of voting interests issued

46.00%

46.00%

Natural Resource Partners Limited Partner

Related Party Transaction [Line Items]

General partner ownership interest

31.00%

Limited partners ownership interest

4.00%

Limited Partner In Natural Resource Partners Limited Liability

Related Party Transaction [Line Items]

Number of common limited partner units owned | shares

20.3

Foresight Energy GP Limited Liability Company | Murray Energy Transaction

Related Party Transaction [Line Items]

Percentage of voting interests acquired

34.00%

34.00%

Option Price Value

$ 25,000,000

Stock Option Exercise Period

5 years

Foresight Energy Limited Liability IDRS | Murray Energy Transaction

Related Party Transaction [Line Items]

Percentage of voting interests acquired

77.50%

Murray American Coal Inc

Related Party Transaction [Line Items]

Management and administration services, quarterly payment

$ 3,500,000

Management and administration services, annual payment

14,000,000

Purchase of equipment, supplies and rebuild services

$ 300,000

American Energy Corporation | Transport and Overriding Royalty Agreements

Related Party Transaction [Line Items]

Proceeds from sale of equipment

$ 63,000,000

Number of coal preparation plants and related cost handling facilities | Facility

2

American Energy Corporation | Transport and Overriding Royalty Agreements | Minimum

Related Party Transaction [Line Items]

Fees per ton of coal mined processed and/or transported using leased assets | $ / T

1.15

Quarterly minimum Fees for coal mined processed and/or transported using leased assets

$ 1,700,000

American Energy Corporation | Transport and Overriding Royalty Agreements | Maximum

Related Party Transaction [Line Items]

Fees per ton of coal mined processed and/or transported using leased assets | $ / T

1.75

American Energy And Consolidated Land Company | Transport and Overriding Royalty Agreements

Related Party Transaction [Line Items]

Cash paid for overriding royalty rights

$ 12,000,000

American Energy And Consolidated Land Company | Transport and Overriding Royalty Agreements | Minimum

Related Party Transaction [Line Items]

Cash paid for overriding royalty rights

$ 500,000

Overriding royalty interest granted per unit | $ / T

0.30

American Energy And Consolidated Land Company | Transport and Overriding Royalty Agreements | Maximum

Related Party Transaction [Line Items]

Overriding royalty interest granted per unit | $ / T

0.50

Murray Energy And Affiliated Entities

Related Party Transaction [Line Items]

Purchase of equipment, supplies and rebuild services

[1]

392,000

Cost of coal purchased

[2]

550,000

Loadout services

3,600,000

Other revenues

500,000

Cline Resource and Development Company | 2021 Senior Notes

Related Party Transaction [Line Items]

Debt Instrument, face amount

$ 16,500,000

Chris Cline | 2021 Senior Notes

Related Party Transaction [Line Items]

Debt Instrument, face amount

36,500,000

8,000,000

Original purchase sold to the affiliates

$ 8,000,000

$ 8,000,000

Outstanding principal amount

44,500,000

44,500,000

Interest paid to affiliated parties

0

600,000

Accrued interest

2,200,000

1,300,000

John F Dickinson | 2021 Senior Notes

Related Party Transaction [Line Items]

Debt Instrument, face amount

4,000,000

Original purchase sold to the affiliates

4,000,000

4,000,000

Outstanding principal amount

4,000,000

Interest paid to affiliated parties

300,000

Accrued interest

100,000

Michael Beyer | 2021 Senior Notes

Related Party Transaction [Line Items]

Debt Instrument, face amount

$ 3,200,000

Original purchase sold to the affiliates

$ 3,200,000

$ 3,200,000

Interest paid to affiliated parties

300,000

The Cline Trust Company LLC | 2021 Senior Notes

Related Party Transaction [Line Items]

Debt Instrument, face amount

10,000,000

10,000,000

Interest paid to affiliated parties

0

0

Accrued interest

$ 500,000

$ 300,000

Colt LLC

Related Party Transaction [Line Items]

Lease term

10 years

Number of renewals | Renewal

6

Lessor renewal term

5 years

Lease payment per ton | $ / T

3.40

Percentage of gross price

8.00%

Ruger LLC

Related Party Transaction [Line Items]

Lease term

10 years

Number of renewals | Renewal

6

Lessor renewal term

5 years

Lease payment per ton | $ / T

3.40

Percentage of gross price

8.00%

Ruger LLC | Royalties

Related Party Transaction [Line Items]

Percentage of gross price

8.00%

NRP and Affiliated Entities

Related Party Transaction [Line Items]

Minimum deficiency payment not made

$ 23,600,000

NRP and Affiliated Entities | Minimum

Related Party Transaction [Line Items]

Lease payment per ton | $ / T

2.50

Percentage of gross price

8.00%

NRP and Affiliated Entities | Maximum

Related Party Transaction [Line Items]

Lease payment per ton | $ / T

5.40

Percentage of gross price

9.00%

Raven Energy LLC | Convent Marine Terminal Amendment | Adjusted Amount

Related Party Transaction [Line Items]

Minimum annual throughput volume | T / yr

5,000,000

Extended contract term

1 year

Extended contract expiry year

2,022

Affiliated Joint Venture

Related Party Transaction [Line Items]

Purchase of mining supplies from affiliates

$ 2,100,000

$ 4,300,000

[1]

Cost of coal produced (excluding depreciation, depletion and amortization) and property, plant and equipment, as applicable

[2]

Cost of coal purchased

Related-Party Transactions - Su

Related-Party Transactions - Summary of Certain Affiliate Amounts Included in Condensed Consolidated Balance Sheets (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
Due from affiliates - current	$ 4,130	$ 16,615
Financing receivables - affiliate - current	2,741	2,689
Due from affiliates - noncurrent	1,843	2,691
Financing receivables - affiliate - noncurrent	69,434	70,139
Due to affiliates - current	8,267	8,536
Affiliates
Related Party Transaction [Line Items]
Prepaid royalties - current and noncurrent	68,236	69,555
Foresight Reserves and Affiliated Entities | Affiliates
Related Party Transaction [Line Items]
Due from affiliates - current	123	145
Prepaid royalties - current and noncurrent	67,832	69,555
Due to affiliates - current	2,595	1,054
Murray Energy And Affiliated Entities | Affiliates
Related Party Transaction [Line Items]
Due from affiliates - current	3,923	16,316
Financing receivables - affiliate - current	2,741	2,689
Due from affiliates - noncurrent	1,843	2,691
Financing receivables - affiliate - noncurrent	69,434	70,139
Due to affiliates - current	3,880	5,020
NRP and Affiliated Entities | Affiliates
Related Party Transaction [Line Items]
Due from affiliates - current	84	154
Prepaid royalties - current and noncurrent	404
Due to affiliates - current	$ 1,792	$ 2,462

Related-Party Transactions - 56

Related-Party Transactions - Summary of Certain Expenses (Income) Incurred With Affiliated Entities (Details) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Related Party Transaction [Line Items]
Coal sales		$ 163,097	$ 238,915
Cost of coal purchased		550	106
Murray Energy And Affiliated Entities
Related Party Transaction [Line Items]
Coal sales	[1]	30
Overriding royalty and lease revenues	[2]	(2,470)
Terminal revenues	[2]	(518)
Purchase of equipment, supplies and rebuild services	[3]	392
Cost of coal purchased	[4]	550
Management services	[5]	2,078
NRP and Affiliated Entities
Related Party Transaction [Line Items]
Royalty expense	[6]	2,843	9,006
Loadout services	[6]	1,723	2,325
Foresight Reserves and Affiliated Entities
Related Party Transaction [Line Items]
Royalty expense	[6]	$ 3,447	2,630
Terminal fees	[7]		9,264
Administrative fee income	[8]		$ (47)
[1]	Coal sales
[2]	Other revenues
[3]	Cost of coal produced (excluding depreciation, depletion and amortization) and property, plant and equipment, as applicable
[4]	Cost of coal purchased
[5]	Selling, general and administrative
[6]	Cost of coal produced (excluding depreciation, depletion and amortization)
[7]	Transportation
[8]	Other operating income, net

Variable Interest Entities (V57

Variable Interest Entities (VIEs) - Additional Information (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2016USD ($)$ / T	Mar. 31, 2015USD ($)	Feb. 29, 2016USD ($)	Jan. 31, 2016USD ($)
Variable Interest Entity [Line Items]
Net income attributable to noncontrolling interests	$ 97	$ 410
Contractor VIEs
Variable Interest Entity [Line Items]
Minimum fee received per ton of coal mined or processed | $ / T	0.01
Maximum fee paid per ton of coal mined or processed | $ / T	0.02
Net income attributable to noncontrolling interests	$ 100	$ 100
Foresight Surety LLC
Variable Interest Entity [Line Items]
Payment to VIE				$ 2,500
Foresight Surety LLC | Letter of Credit
Variable Interest Entity [Line Items]
Debt Instrument, face amount			$ 2,500
letter of credit, cash collateral			$ 2,500
VIEs which the Partnership is not the Primary Beneficiary
Variable Interest Entity [Line Items]
Percentage of annual mining supply requirements purchased	90.00%
Initial term of agreement as amended	5 years
Amended agreement term expiration date	2018-04

Variable Interest Entities (V58

Variable Interest Entities (VIEs) - Summary of Consolidated VIE Assets and Liabilities (Details) - USD ($) $ in Thousands		Mar. 31, 2016	Dec. 31, 2015
Assets
Current assets		$ 193,051	$ 210,340
Total assets		1,763,006	1,821,183
Liabilities:
Current liabilities		1,536,870	1,558,693
Total liabilities		1,781,001	1,802,300
Variable Interest Entity, Primary Beneficiary
Assets
Current assets	[1]	3,743	4,933
Long-term assets		2,500
Total assets	[1]	6,243	4,933
Liabilities:
Current liabilities		13,798	12,835
Long-term liabilities		2,715	2,955
Total liabilities		$ 16,513	$ 15,790
[1]	– Includes cash and cash equivalents of $2,980 and $4,332 as of March 31, 2016 and December 31, 2015, respectively.

Variable Interest Entities (V59

Variable Interest Entities (VIEs) - Summary of Consolidated VIE Assets and Liabilities (Parenthetical) (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014
Variable Interest Entity [Line Items]
Cash and cash equivalents	$ 16,220	$ 17,538	$ 30,790	$ 26,509
Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Cash and cash equivalents	$ 2,980	$ 4,332

Equity-Based Compensation - Add

Equity-Based Compensation - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Compensation expense	$ 4,000	$ 8,200
Equity-based compensation	$ 3,992	8,231
Transition And Reorganization Costs
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Partnership's equity-based compensation	92.60%
Selling, General and Administrative Expenses
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Partnership's equity-based compensation	1.30%
Cost of Coal Sales
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Partnership's equity-based compensation	6.10%
Former Chief Executive Officer | Selling, General and Administrative Expenses
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Equity-based compensation		$ 7,100
LTIP Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate number of common units authorized	7,000,000
Share based compensation arrangement by share based payment award number of shares available for issuance	6,200,000
Number of Units, Granted	0
LTIP Awards | Former Chief Executive Officer | Common Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of Units, Granted		215,954
LTIP Awards | Former Chief Executive Officer | Subordinated Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of Units, Granted		215,796
LTIC Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Accrued expenses and other current liabilities to partners capital	$ 600

Equity-Based Compensation - Sum

Equity-Based Compensation - Summary of Non-vested LTIP Award Activity (Details) - LTIP Awards	3 Months Ended
	Mar. 31, 2016$ / sharesshares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Non-vested grants, Beginning	1,711,341
Number of Units, Granted	0
Number of Units, Vested	(392)
Non-vested grants, Ending	1,710,949
Non-vested grants, Beginning | $ / shares	$ 7.21
Weighted Average Grant Date Fair Value per Unit, Vested | $ / shares	20
Non-vested grants, Ending | $ / shares	$ 7.21

Earnings per Limited Partner 62

Earnings per Limited Partner Unit - Summary of Partnership's Calculation of Net (Loss) Income per Common and Subordinated Unit (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Distribution Made To Limited Partner [Line Items]
Net (loss) income available to limited partner units	$ (41,704)	$ 42,283
Weighted-average units to calculate basic EPU	130,148	129,842
Weighted-average units to calculate diluted EPU	130,148	129,842
Basic net (loss) income per unit	$ (0.32)	$ 0.33
Diluted net (loss) income per unit	$ (0.32)	$ 0.33
Common Units
Distribution Made To Limited Partner [Line Items]
Net (loss) income available to limited partner units	$ (20,890)	$ 21,158
Weighted-average units to calculate basic EPU	65,193	64,971
Weighted-average units to calculate diluted EPU	65,193	64,971
Basic net (loss) income per unit	$ (0.32)	$ 0.33
Diluted net (loss) income per unit	$ (0.32)	$ 0.33
Subordinated Units
Distribution Made To Limited Partner [Line Items]
Net (loss) income available to limited partner units	$ (20,814)	$ 21,125
Weighted-average units to calculate basic EPU	64,955	64,871
Weighted-average units to calculate diluted EPU	64,955	64,871
Basic net (loss) income per unit	$ (0.32)	$ 0.33
Diluted net (loss) income per unit	$ (0.32)	$ 0.33

Earnings per Limited Partner 63

Earnings per Limited Partner Unit - Summary of Partnership's Calculation of Net (Loss) Income per Common and Subordinated Unit (Parenthetical) (Details) - shares shares in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Phantom Share Units (PSUs)
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Anti-dilutive securities excluded from computation of earnings per share, amount	1.7	0.7

Fair Value of Financial Instr64

Fair Value of Financial Instruments - Fair Value of Net Financial Assets and Liabilities (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Coal derivative contracts	$ 40,840	$ 48,623
Diesel derivative contracts	(773)	(1,029)
Total	40,067	47,594
Fair Value, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Coal derivative contracts	40,840	48,623
Diesel derivative contracts	(773)	(1,029)
Total	$ 40,067	$ 47,594

Fair Value of Financial Instr65

Fair Value of Financial Instruments - Fair Value of Gross Financial Assets and Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2016	Dec. 31, 2015
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Current – Coal Derivative Assets	$ 24,195	$ 26,596
Long-Term – Coal Derivative Assets	16,645	22,027
Other Long-Term Liabilities	6,656	6,896
Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Current – Coal Derivative Assets	24,195	26,596
Long-Term – Coal Derivative Assets	16,645	22,027
Diesel derivative contracts	(773)	(1,029)
Fair Value, Measurements, Recurring | Coal Derivative Contracts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Current – Coal Derivative Assets	24,195	26,596
Long-Term – Coal Derivative Assets	16,645	22,027
Fair Value, Measurements, Recurring | Diesel Derivative Contracts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Diesel derivative contracts	$ (773)	$ (1,029)

Fair Value Measures and Disclos

Fair Value Measures and Disclosures - Additional Information (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair value of Long-Term Debt (Level III)	$ 1,072.5	$ 1,244.3

Contingencies - Additional Info

Contingencies - Additional Information (Details) - USD ($) $ in Millions	Mar. 31, 2016	Feb. 29, 2016	Jan. 31, 2016	May. 31, 2015	Apr. 16, 2015
Loss Contingencies [Line Items]
Minimum deficiency payment not made	$ 23.6
Accrued litigation expense	2.2
Outstanding performance bonds	$ 80
Macoupin
Loss Contingencies [Line Items]
Possible loss contingencies			$ 3.3
Employee Termination | Maximum
Loss Contingencies [Line Items]
Possible loss contingencies			$ 2
Surety Bond
Loss Contingencies [Line Items]
Cash collateral of surety bond		$ 2.5
Murray Energy Transaction
Loss Contingencies [Line Items]
Percentage of voting interests issued				46.00%	46.00%
Murray Energy Transaction | 2021 Senior Notes
Loss Contingencies [Line Items]
Redemption value on senior notes				101.00%
Murray Energy Transaction | Foresight Energy GP Limited Liability Company
Loss Contingencies [Line Items]
Percentage of voting interests acquired				34.00%	34.00%

Subsequent Events - Additional

Subsequent Events - Additional Information (Details) - USD ($)	Dec. 31, 2016	Apr. 18, 2016	Mar. 31, 2016
2021 Senior Notes
Subsequent Event [Line Items]
Debt instrument interest percentage			7.875%
Proposed Amendment of Credit Agreement | Second Lien Senior Convertible PIK Notes
Subsequent Event [Line Items]
Debt instrument maturity date			Apr. 7, 2017
Proposed Amendment of Credit Agreement | Scenario, Forecast | Revolving Credit Facility
Subsequent Event [Line Items]
Reduction in credit facility	$ 25,000,000
Subsequent Event | Proposed Amendment of Credit Agreement
Subsequent Event [Line Items]
Senior secured leverage ratio during 2016		3.80%
Senior secured leverage ratio during 2017		4.00%
Senior secured leverage ratio during 2018		3.80%
Senior secured leverage ratio during 2019		3.50%
Senior secured leverage ratio during 2020		3.25%
Percentage of net loans and credit agreements		1.00%
Subsequent Event | Proposed Amendment of Credit Agreement | Term Loan
Subsequent Event [Line Items]
Cash flow excess percentage		50.00%
Subsequent Event | Proposed Amendment of Credit Agreement | 2021 Senior Notes
Subsequent Event [Line Items]
Debt holding percentage		66.67%
Debt Instrument, face amount		$ 180,000,000
Proposed purchase price percentage of debt principal		100.00%
Subsequent Event | Proposed Amendment of Credit Agreement | 2021 Senior Notes | Non Affiliates Partnership
Subsequent Event [Line Items]
Debt Instrument, face amount		$ 106,000,000
Subsequent Event | Proposed Amendment of Credit Agreement | Second Lien Senior Convertible PIK Notes
Subsequent Event [Line Items]
Debt Instrument, face amount		$ 300,000,000
Debt instrument interest percentage		15.00%
Percentage of fully diluted shares		75.00%
Percentage of warrants to purchase of common stock		7.50%
Subsequent Event | Proposed Amendment of Credit Agreement | Second-lien senior secured notes due August 2021
Subsequent Event [Line Items]
Debt Instrument, face amount		$ 300,000,000
Debt instrument cash coupon percentage first two year		9.00%
Debt instrument cash coupon percentage thereafter		10.00%
Debt Instrument PIK coupon percentage		1.00%
Subsequent Event | Proposed Amendment of Credit Agreement | Revolving Credit Facility
Subsequent Event [Line Items]
Reduction in credit facility		$ 75,000,000
Increase in interest rate		1.00%
Percentage of amendment fee		1.00%
Subsequent Event | Proposed Amendment of Credit Agreement | Revolving Credit Facility | Foresight Energy LLC
Subsequent Event [Line Items]
Unrestricted cash		$ 35,000,000