Foresight Energy (FELPQ) 10-Q 14 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	8-May-15
Document And Entity Information [Line Items]
Entity Registrant Name	Foresight Energy LP
Entity Central Index Key	1540729
Document Type	10-Q
Document Period End Date	31-Mar-15
Amendment Flag	FALSE
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Document Fiscal Year Focus	2015
Trading Symbol	FELP
Document Fiscal Period Focus	Q1
Common Units
Document And Entity Information [Line Items]
Entity Units Outstanding		65,059,477
Subordinated Units
Document And Entity Information [Line Items]
Entity Units Outstanding		64,954,691

Unaudited_Condensed_Consolidat

Unaudited Condensed Consolidated Balance Sheets (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$30,790	$26,509
Accounts receivable	80,464	80,911
Due from affiliates	164	532
Inventories	131,862	92,075
Prepaid expenses	2,277	2,157
Prepaid royalties	6,901	8,380
Deferred longwall costs	24,063	23,224
Coal derivative assets	44,924	36,080
Other current assets	5,551	6,302
Total current assets	326,996	276,170
Property, plant, equipment and development, net	1,507,498	1,522,488
Prepaid royalties	62,215	59,967
Coal derivative assets	34,428	24,957
Other assets	32,181	32,070
Total assets	1,963,318	1,915,652
Current liabilities:
Current portion of long-term debt and capital lease obligations	91,972	44,143
Accrued interest	14,229	25,136
Accounts payable	56,705	60,206
Accrued expenses and other current liabilities	33,181	37,820
Due to affiliates	10,831	15,107
Total current liabilities	206,918	182,412
Long-term debt and capital lease obligations	1,335,630	1,316,528
Sale-leaseback financing arrangements	193,434	193,434
Asset retirement obligations	31,389	31,373
Other long-term liabilities	5,874	5,508
Total liabilities	1,773,245	1,729,255
Limited partners' capital (deficit):
Total limited partners' capital	191,795	127,756
Total partners' capital (deficit)	190,073	186,397
Noncontrolling interests	-1,722	7,931
Total liabilities and partners' capital	1,963,318	1,915,652
Common Units
Limited partners' capital (deficit):
Total limited partners' capital	270,235	238,925
Subordinated Units
Limited partners' capital (deficit):
Total limited partners' capital	-78,440	-111,169
Predecessor equity
Limited partners' capital (deficit):
Total partners' capital (deficit)		$50,710

Unaudited_Condensed_Consolidat1

Unaudited Condensed Consolidated Balance Sheets (Parenthetical)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Common Units
Capital units, Outstanding	65,059	64,831
Subordinated Units
Capital units, Outstanding	64,955	64,739

Unaudited_Condensed_Consolidat2

Unaudited Condensed Consolidated Statements of Operations (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Coal sales	$238,915	$242,723
Costs and expenses:
Cost of coal produced (excluding depreciation, depletion and amortization)	110,588	92,948
Cost of coal purchased	106	205
Transportation	47,359	58,561
Depreciation, depletion and amortization	38,818	35,935
Accretion on asset retirement obligations	567	405
Selling, general and administrative	14,466	9,038
Gain on commodity derivative contracts	-29,067	-15,401
Other operating income, net	-13,979	-698
Operating income	70,057	61,730
Other expenses:
Interest expense, net	27,341	29,604
Net income	42,716	32,126
Less: net income attributable to noncontrolling interests	410	625
Net income attributable to controlling interests	42,306	31,501
Less: net income attributable to predecessor equity	23
Net income subsequent to initial public offering available to limited partner units - basic and diluted:
Net income subsequent to initial public offering attributable to limited partner units	42,283
Weighted average limited partner units outstanding - basic and diluted:
Distribution declared per limited partner unit	$0.36
Subordinated Units
Net income subsequent to initial public offering available to limited partner units - basic and diluted:
Net income subsequent to initial public offering attributable to limited partner units	21,125
Net income subsequent to initial public offering per limited partner unit - basic and diluted	$0.33
Weighted average limited partner units outstanding - basic and diluted:
Weighted average limited partner units outstanding - basic and diluted	64,871
Common Units
Net income subsequent to initial public offering available to limited partner units - basic and diluted:
Net income subsequent to initial public offering attributable to limited partner units	$21,158
Net income subsequent to initial public offering per limited partner unit - basic and diluted	$0.33
Weighted average limited partner units outstanding - basic and diluted:
Weighted average limited partner units outstanding - basic and diluted	64,971

Unaudited_Condensed_Consolidat3

Unaudited Condensed Consolidated Statement of Partners' Capital (Deficit) (USD $)	Total	Noncontrolling Interest	Predecessor equity	Limited Partners	Limited Partners
In Thousands, except Share data				Common Units	Subordinated Units
Beginning Balance at Dec. 31, 2014	$186,397	$7,931	$50,710	$238,925	($111,169)
Beginning Balance (in units) at Dec. 31, 2014				64,831,312	64,738,895
Net income	42,716	410	23	21,158	21,125
Contribution of net assets to Foresight Energy LP		-9,898	-50,733	25,643	34,988
Cash distributions	-46,970	-165		-23,421	-23,384
Equity-based compensation	8,231			8,231
Issuance of equity-based awards				228,165	215,796
Distribution equivalent rights on LTIP awards	-193			-193
Net settlement of withholding taxes on issued LTIP awards	-108			-108
Ending Balance at Mar. 31, 2015	$190,073	($1,722)		$270,235	($78,440)
Ending Balance (in units) at Mar. 31, 2015				65,059,477	64,954,691

Unaudited_Condensed_Consolidat4

Unaudited Condensed Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities
Net income	$42,716	$32,126
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	38,818	35,935
Equity-based compensation	8,231	375
Unrealized gain on commodity derivative contracts	-15,782	-12,910
Other	-1,114	3,012
Changes in operating assets and liabilities:
Accounts receivable	447	-28,547
Due from/to affiliates, net	-3,908	5,678
Inventories	-30,078	-1,990
Prepaid expenses and other current assets	-208	3,357
Prepaid royalties	-769	-510
Commodity derivative contract assets and liabilities, net	-1,980	-1,782
Accounts payable	-3,501	687
Accrued interest	-10,907	-8,759
Accrued expenses and other current liabilities	-5,056	2,290
Other	-1,790	-27
Net cash provided by operating activities	15,119	28,935
Cash flows from investing activities
Investment in property, plant, equipment and development	-33,277	-65,191
Settlement of coal derivative contracts	3,319
Net cash used in investing activities	-29,958	-65,191
Cash flows from financing activities
Net increase in borrowings under revolving credit facility	30,000	21,000
Net increase in borrowings under A/R securitization program	47,500
Proceeds from other long-term debt		29,719
Payments on other long-term debt and capital lease obligations	-10,860	-9,382
Distributions paid	-46,970	-2,304
Debt issuance costs paid	-439	-347
Other	-111
Net cash provided by financing activities	19,120	38,686
Net increase in cash and cash equivalents	4,281	2,430
Cash and cash equivalents, beginning of period	26,509	24,787
Cash and cash equivalents, end of period	30,790	27,217
Supplemental information:
Interest paid, net of amounts capitalized	$36,620	$36,481

Organization_Nature_of_Busines

Organization, Nature of Business and Basis of Presentation	3 Months Ended
	Mar. 31, 2015
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 management owned 0.667%. In January 2012, Foresight Energy LP (“FELP”), a Delaware limited partnership, and Foresight Energy GP LLC (“general partner” or “FEGP”), a Delaware limited liability company, were formed. FELP was formed to own FELLC and FEGP was formed to be the general partner of FELP. Prior to June 23, 2014, FELP had no operating or cash flow activity, and no recorded net assets.
	On June 23, 2014, in connection with the initial public offering (“IPO”) of 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 at FELLC’s historical cost.  FELP has been managed by 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”) (see Note 3).  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 prior to the Contribution Date (see Note 13) 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’ equity. Similarly, the equity values of Hillsboro Transport and Adena were reclassified from noncontrolling equity to limited partners’ equity on the Contribution Date.
	As used hereafter in this report, the terms “Foresight Energy LP,” “FELP,” the “Partnership,” “we,” “us” or like terms, refer to the combined 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 financial results of Foresight Energy LP, the Contributed Companies and FELLC, and VIEs for which FELLC or its subsidiaries are the primary beneficiary.
	On April 16, 2015, Murray Energy Corporation (“Murray Energy”) and Foresight Reserves completed a transaction whereby Murray Energy acquired an economic interest in FEGP and FELP (see Note 18).
	The Partnership operates in a single reportable segment and currently operates 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”). Effective June 1, 2014, the second longwall system at our Sugar Camp complex transitioned from the development stage to the production stage and from that date forward was recognized in our results of operations. 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 unaudited 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 consolidated financial position, results of operations and cash flows for all periods presented. In preparing the unaudited 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, 2014 included in our Annual Report on Form 10-K filed with the SEC on March 10, 2015. The results of operations for the three months ended March 31, 2015 are not necessarily indicative of results that can be expected for any future period, including the year ending December 31, 2015.

New_Accounting_Standards

New Accounting Standards	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
New Accounting Standards	2. New Accounting Standards
	In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. ASU 2014-08 changes the requirements for reporting discontinued operations by updating the criteria for determining discontinued operations and modifies the disclosure requirements of both discontinued operations and certain other disposals not defined as discontinued operations. ASU 2014-08 was adopted during the current period quarter and did not have an impact on our condensed consolidated financial statements.
	In February 2015, the FASB issued ASU 2015-02, Consolidation.  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, presumption that a general partner should consolidate a limited partnership and the consolidation criterion applied by a reporting entity involved with variable interest entities.  ASU 2015-02 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015 and shall be applied retrospectively to each period presented.  Early adoption is permitted.  We are currently evaluating the effect of adopting ASU 2015-02.
	In April 2015, the FASB issued ASU 2015-06, Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions.  ASU 2015-06 specifies that for purposes of calculating historical earnings per unit under the two-class method, the earnings of a transferred business before the date of a dropdown transaction should not be allocated to the limited partnership and therefore earnings per unit of the limited partners would not change as a result of the dropdown transaction.  ASU 2015-06 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015 and shall be applied retrospectively to each period presented.  We do not expect that ASU 2015-06 will have a significant impact on our consolidated financial statements or related disclosures.
	In April 2015, the FASB issued ASU No. 2015-03, Interest - Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs.  ASU 2015-03 requires, effective for fiscal year and interim periods beginning after December 15, 2015, that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Retrospective application is required and early adoption is permitted.  The adoption of ASU 2015-03 is not expected to have a significant impact on our consolidated financial statements or related disclosures.
	No other new accounting pronouncement issued or effective during the fiscal year which were 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.

Foresight_Reserves_Contributio

Foresight Reserves Contributions	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Foresight Reserves Contributions	3. Foresight Reserves Contributions
	During the first quarter of 2015, Foresight Reserves and a member of management contributed to FELP, for no consideration, the following entities:
	·	Sitran – a barge terminal on the Ohio River,
	·	Hillsboro Transport - Hillsboro Energy’s coal loadout facility,
	·	Adena - an entity that provides certain water and other miscellaneous rights to the FELP mines, and
	·	Akin Energy - an entity holding certain permits and development costs for a natural gas power generation facility.
	As previously noted, because Sitran and Akin Energy were under common control, the Partnership’s historical financial statements have been retrospectively adjusted to combine their financial position at historical cost and their results of operations. 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). Hillsboro Transport and Adena were previously consolidated by the Partnership as VIEs therefore the contribution did not trigger a change in reporting entity (see Note 13). On the Contribution Date, the net book values of the Contributed Companies were reclassified from either predecessor equity or noncontrolling interest equity, as applicable, to limited partners’ equity in the statement of partners’ capital (pro rata between the common and subordinated units based on the number of units held by the contributing parties on the Contribution Date). The aggregate net book value of the Contributed Companies on the Contribution Date was $60.6 million.

Commodity_Derivative_Contracts

Commodity Derivative Contracts	3 Months Ended
	Mar. 31, 2015
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Commodity Derivative Contracts	4. Commodity Derivative Contracts
	We have commodity price risk for our coal sales as a result of changes in the market value of our coal. To minimize this risk, we enter into long-term, fixed price coal supply sales agreements and coal derivative contracts. As of March 31, 2015 and December 31, 2014, we had outstanding coal derivative contracts to fix the selling price on 3.1 million tons and 3.4 million tons, respectively. Swaps are designed so that we receive or make 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 exported to 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 consolidated balance sheets (see Note 16).
	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. To limit our exposure to diesel fuel price volatility, we have entered into swap agreements with financial institutions, which provides a fixed price per unit for the volume of purchases being hedged. As of March 31, 2015, we had swap agreements outstanding to hedge the variable cash flows related to 27% and 14% of anticipated diesel fuel exposure for the remainder of 2015 and calendar year 2016, respectively. 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 record the fair value of all positions with a given counterparty on a gross basis in the condensed consolidated balance sheets (see Note 16).
	We have master netting arrangements with all of our counterparties that allow for the settlement of contracts in an asset position with contracts in a liability position. 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 gains recorded on commodity derivative contracts for the three months ended March 31, 2015 and 2014 is as follows:
		Three Months Ended
		31-Mar-15		31-Mar-14
		(In Thousands)
	Unrealized gain on commodity derivative contracts	$	15,782	$	12,910
	Realized gain on commodity derivative contracts		13,285		2,491
	Gain on commodity derivative contracts	$	29,067	$	15,401
	We received $3.3 million in proceeds during the three months ended March 31, 2015 from the settlement of derivatives that were recorded as an investing activity in the condensed consolidated statement of cash flows because the derivative contracts were settled prior to the delivery date of the underlying sales contracts.

Accounts_Receivable

Accounts Receivable	3 Months Ended
	Mar. 31, 2015
Accounts Receivable Net [Abstract]
Accounts Receivable	5. Accounts Receivable
	Accounts receivable consist of the following:
		March 31,		December 31,
		2015		2014
		(In Thousands)
	Trade accounts receivable	$	58,976	$	72,835
	Other receivables		21,488		8,076
	Total accounts receivable	$	80,464	$	80,911
	Other receivables include $10.8 million from a legal settlement with Murray Energy, of which $10.0 million was collected in April 2015 (see Note 17).

Inventories

Inventories	3 Months Ended
	Mar. 31, 2015
Inventory Disclosure [Abstract]
Inventories	6. Inventories
	Inventories consist of the following:
		March 31,		December 31,
		2015		2014
		(In Thousands)
	Parts and supplies	$	33,282	$	32,156
	Raw coal		7,408		6,200
	Clean coal		91,172		53,719
	Total inventories	$	131,862	$	92,075

Property_Plant_Equipment_and_D

Property, Plant, Equipment and Development, Net	3 Months Ended
	Mar. 31, 2015
Property Plant And Equipment [Abstract]
Property, Plant, Equipment and Development, Net	7. Property, Plant, Equipment and Development, Net
	Property, plant, equipment and development, net consist of the following:
		March 31,			December 31,
		2015			2014
		(In Thousands)
	Land, land rights and mineral rights	$	110,992		$	108,892
	Machinery and equipment		1,111,785			1,094,631
	Machinery and equipment under capital leases		126,401			126,401
	Buildings and structures		248,064			246,617
	Development costs		724,875			713,301
	Other		9,915			9,239
	Property, plant, equipment and development		2,332,032			2,299,081
	Less: accumulated depreciation, depletion and amortization		(824,534	)		(776,593	)
	Property, plant, equipment and development, net	$	1,507,498		$	1,522,488

Accrued_Expenses_and_Other_Cur

Accrued Expenses and Other Current Liabilities	3 Months Ended
	Mar. 31, 2015
Accrued Liabilities And Other Liabilities [Abstract]
Accrued Expenses and Other Current Liabilities	8. Accrued Expenses and Other Current Liabilities
	Accrued expenses and other current liabilities consist of the following:
		March 31,		December 31,
		2015		2014
		(In Thousands)
	Employee compensation, benefits and payroll taxes	$	12,643	$	13,163
	Taxes other than income		6,406		5,668
	Asset retirement obligations		4,207		4,207
	Royalties (non-affiliate)		3,296		2,975
	Liquidated damages (non-affiliate)		1,328		7,315
	Other		5,301		4,492
	Total accrued expenses and other current liabilities	$	33,181	$	37,820

LongTerm_Debt_and_Capital_Leas

Long-Term Debt and Capital Lease Obligations	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt and Capital Lease Obligations	9. Long-Term Debt and Capital Lease Obligations
	Long-term debt and capital lease obligations consist of the following:
		March 31,			December 31,
		2015			2014
		(In Thousands)
	2021 Senior Notes	$	596,322		$	596,213
	Term Loan		235,907			235,822
	Revolving Credit Facility		349,500			319,500
	Trade A/R Securitization		47,500			—
	5.78% longwall financing arrangement		61,628			61,628
	5.555% longwall financing arrangement		56,719			61,875
	Capital lease obligations		80,026			85,633
	Total long-term debt and capital lease obligations		1,427,602			1,360,671
	Less: current portion		(91,972	)		(44,143	)
	Long-term debt and capital lease obligations	$	1,335,630		$	1,316,528
	Revolving Credit Facility
	The Revolving Credit Facility has a total borrowing capacity of $500.0 million. At March 31, 2015, we had borrowings of $349.5 million outstanding under the Revolving Credit Facility and $6.5 million outstanding in letters of credit. There was $144.0 million of remaining capacity under the Revolving Credit Facility as of March 31, 2015 and the weighted-average effective interest rate on borrowings was 3.5%.
	On May 7, 2015, we received a commitment letter from a participating lender in our credit agreement to increase the total commitments under the credit agreement by $100 million. We expect to close this transaction in the second quarter.
	Trade A/R Securitization
	In January 2015, Foresight Energy LP and certain of its wholly-owned subsidiaries, entered into a $70 million receivables securitization program (the “Securitization Program”).  Under this Securitization Program, our subsidiaries sell all of their customer trade receivables (the “Receivables”), on a revolving basis, to Foresight Receivables LLC, a wholly-owned and consolidated special purpose subsidiary of Foresight Energy LP (the “SPV”).  The SPV then pledges its interests in the Receivables to the securitization program lenders, which either make loans or issue letters of credit to, or on behalf of, the SPV.  The maximum amount of advances and letters of credit outstanding under the program may not exceed $70 million. The amount eligible for borrowing is determined by the qualified receivable balances outstanding.  The Securitization Program has a three-year maturity and expires on January 12, 2018.  The borrowings under the Securitization Program are variable-rate and the Securitization Program also carries a commitment fee for unutilized commitments. As of March 31, 2015, we had borrowings outstanding of $47.5 million under the Securitization Program included within the current portion of long-term debt.

SaleLeaseback_Financing_Arrang

Sale-Leaseback Financing Arrangements	3 Months Ended
	Mar. 31, 2015
Leases Capital [Abstract]
Sale-Leaseback Financing Arrangements	10. Sale-Leaseback Financing Arrangements
	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 and were used for capital expenditures. 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 and were used for capital expenditures, to pay down debt and for general corporate purposes. NRP is an affiliated entity to the Partnership (see Note 12). In both transactions, because we had continuing involvement in the assets sold, the transactions were treated as sale-leaseback financing arrangements. In 2013, an agreement was reached between FELLC, Foresight Reserves and HOD that allows for the existing agreement with Sugar Camp to be amended in the future to include coal produced from Sugar Camp’s second longwall on what is expected to be materially consistent terms as the original agreement. Pursuant to such an amendment occurring, the consideration paid by HOD for including coal produced by Sugar Camp’s second longwall was to be paid directly to Foresight Reserves. In April 2015, in connection with Murray Energy acquiring ownership interests in the Partnership and its general partner (see Note 18), Foresight Reserves assigned its right to receive the proceeds from HOD back to the Partnership (net of any taxes incurred by Foresight Reserves on the transaction).
	As of March 31, 2015, the outstanding principal balance on the Macoupin and Sugar Camp sale-leaseback financing arrangements was $143.5 million and $50.0 million, respectively.
	The implied effective interest rate as of March 31, 2015 on the Macoupin sale-leaseback financing arrangement and the Sugar Camp sale-leaseback financing arrangement were 13.9% and 13.8%, 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 statements of operations could be significant. Interest expense recorded on the Macoupin sale-leaseback was $5.1 million and $4.7 million for the three months ended March 31, 2015 and 2014, respectively. Interest expense recorded on the Sugar Camp sale-leaseback was $1.5 million and $1.7 million for the three months ended March 31, 2015 and 2014, respectively. As of March 31, 2015 and December 31, 2014, interest totaling $6.4 million and $5.6 million, respectively, was accrued in the condensed consolidated balance sheets for the Sugar Camp and Macoupin sale-leaseback financing arrangements.

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	11. Asset Retirement Obligations
	The change in the carrying amount of asset retirement obligations was as follows for the three months ended March 31, 2015:
		March 31,
		2015
		(In Thousands)
	Balance at January 1, 2015 (including current portion)	$	35,580
	Accretion expense		567
	Expenditures for reclamation activities		(551	)
	Balance at March 31, 2015 (including current portion)		35,596
	Less: current portion of asset retirement obligations		(4,207	)
	Noncurrent portion of asset retirement obligations	$	31,389

RelatedParty_Transactions

Related-Party Transactions	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Related-Party Transactions	12. 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. 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 10, 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.
	In April 2015, Murray Energy acquired from Foresight Reserves and a member of management a 34% voting interest in the Partnership’s general partner, all of the Partnership’s subordinated units and a 77.5% ownership interest in the Partnership’s incentive distribution rights. In connection with this transaction, Murray Energy and the Partnership entered into a series of transactions and contractual relationships as related parties.  See Note 18 for further discussion.
	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 govern 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. No amounts were incurred by the general partner or reimbursed under the partnership agreement during the three months ended March 31, 2015.
	The following table presents the affiliate amounts included in our condensed consolidated balance sheets:
	Affiliated Company		Balance Sheet Location		March 31,				December 31,
					2015				2014
					(In Thousands)
	Foresight Reserves and affiliated entities		Due from affiliates		$	117			$	345
	NRP and affiliated entities		Due from affiliates			47				187
	Total				$	164			$	532
	Foresight Reserves and affiliated entities		Due to affiliates		$	4,436			$	7,959
	NRP and affiliated entities		Due to affiliates			6,395				7,148
	Total				$	10,831			$	15,107
	Foresight Reserves and affiliated entities		Prepaid royalties		$	51,924			$	53,671
	NRP and affiliated entities		Prepaid royalties			13,164				11,071
	Total				$	65,088			$	64,742
	A summary of expenses (income) incurred with affiliated entities is as follows for the three months ended March 31, 2015 and 2014:
		Three Months Ended
		31-Mar-15				31-Mar-14
		(In Thousands)
	Royalty expense – NRP and affiliated entities(1)	$	9,006			$	12,434
	Royalty expense – Foresight Reserves and affiliated entities(1)	$	2,630			$	1,318
	Loadout services – NRP and affiliated entities(1)	$	2,325			$	2,593
	Terminal fees – Foresight Reserves and affiliated entities(2)	$	9,264			$	10,888
	Administrative fee income – Foresight	$	(47	)		$	(75	)
	Reserves and affiliated entities(3)
	Location in the condensed consolidated statements of operations:
	(1) – Cost of coal produced (excluding depreciation, depletion and amortization)
	(2) – Transportation
	(3) – Other operating income, net
	We also purchased $4.3 million and $3.4 million in mining supplies from an affiliated joint venture under a supply agreement during the three months ended March 31, 2015 and 2014, respectively (see Note 13).

Variable_Interest_Entities_VIE

Variable Interest Entities (VIEs)	3 Months Ended
	Mar. 31, 2015
Variable Interest Entity Nonconsolidated Carrying Amount Assets And Liabilities [Abstract]
Variable Interest Entities (VIEs)	13. 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, 2015 and 2014, 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.
	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 (see Note 3) and are therefore no longer consolidated as VIEs. The aggregate net book values of Adena and Hillsboro Transport of $9.9  million were reclassified from noncontrolling interest equity to limited partners’ equity on the contribution date.
	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,		December 31,
		2015		2014
		(In Thousands)
	Assets:
	Current assets	$	2,628	$	4,939
	Long-term assets		—		1,554
	Total assets	$	2,628	$	6,493
	Liabilities:
	Current liabilities	$	13,581	$	10,145
	Long-term liabilities		1,676		1,131
	Total liabilities	$	15,257	$	11,276
	In May 2013, an affiliate owned by Chris Cline 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.

EquityBased_Compensation

Equity-Based Compensation	3 Months Ended
	Mar. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Equity-Based Compensation	14. 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 the Partnership authorized 7.0 million common units to be granted under the LTIP, with 6.4 million units available for grant as of March 31, 2015.
	In February 2015, the board of directors approved equity grants to the Partnership’s chief executive officer consisting of 215,954 common units and 215,796 subordinated units under the LTIP. The awards were fully-vested as of the grant date. As a result of the immediate vesting, compensation expense of $7.1 million was recorded and included in selling, general and administrative expenses in our unaudited condensed consolidated statement of operations during the three months ended March 31, 2015.
	In March 2015, the Partnership granted 130,919 phantom awards to Participants under the LTIP which cliff-vest, subject to continued employment, at the end of the three-year service period.  Compensation expense for these awards is recognized on a straight-line basis over the requisite service period, net of estimated forfeitures. Upon vesting, the Participants will receive limited partner units plus accumulated distributions as set forth below.
	During the three months ended March 31, 2015, our equity-based compensation expense was $8.2 million, net of estimated forfeitures.  Approximately 92% of the Partnership's equity-based compensation during this period was reported through selling, general and administrative expenses in the condensed consolidated statement of operations with the remaining 8% recorded through 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 $0.4 million accrued for this liability as of March 31, 2015.  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, 2015 is as follows:
		Number of Units			Weighted Average
					Grant Date Fair Value
					per Unit
	Non-vested grants at January 1, 2015		601,109		$	19.99
	Granted		562,669		$	16.36
	Vested		(450,500	)	$	16.66
	Forfeited		(3,304	)	$	20
	Non-vested grants at March 31, 2015		709,974		$	19.23

Earnings_per_Limited_Partner_U

Earnings per Limited Partner Unit	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Earnings per Limited Partner Unit	15. Earnings per Limited Partner Unit
	Limited partners’ interest in net income attributable to the Partnership and basic and diluted earnings per unit reflect net income attributable to the Partnership from the closing date of the IPO. We compute earnings per unit (“EPU”) using the two-class method for master limited partnerships as prescribed in ASC 260, Earnings Per Share. The two-class method requires that securities that meet the definition of a participating security be considered for inclusion in the computation of basic EPU. In addition to the common and subordinated units, we have also identified the general partner interest and IDRs as participating securities. Under the two-class method, EPU is calculated as if all of the earnings for the period were distributed under the terms of the partnership agreement, regardless of whether the general partner has discretion over the amount of distributions to be made in any particular period, whether those earnings would actually be distributed during a particular period from an economic or practical perspective, or whether the general partner has other legal or contractual limitations on its ability to pay distributions that would prevent it from distributing all of the earnings for a particular period.
	The Partnership’s net income 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 income per common and subordinated unit for the periods indicated:
		Common Unitholders		Subordinated Unitholders		Total
	Three months ended March 31, 2015	(In Thousands, Except Per Unit Data)
	Numerator:
	Net income available to limited partner units	$	21,158	$	21,125	$	42,283
	Denominator:
	Weighted-average units to calculate basic EPU		64,971		64,871		129,842
	Less: effect of dilutive securities (1)		—		—		—
	Weighted-average units to calculate diluted EPU		64,971		64,871		129,842
	Basic net income per unit	$	0.33	$	0.33	$	0.33
	Diluted net income per unit	$	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, 2015, approximately 0.7 million phantom units were anti-dilutive, and therefore excluded from the diluted EPU calculation.

Fair_Value_of_Financial_Instru

Fair Value of Financial Instruments	3 Months Ended
	Mar. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	16. 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, 2015
		Total			Level 1		Level 2			Level 3
		(In Thousands)
	Coal derivative contracts	$	79,352		$	—	$	79,352		$	—
	Diesel derivative contracts		(553	)		—		(553	)		—
	Total	$	78,799		$	—	$	78,799		$	—
		Fair Value at December 31, 2014
		Total			Level 1		Level 2			Level 3
		(In Thousands)
	Coal derivative contracts	$	61,037		$	—	$	61,037		$	—
	Total	$	61,037		$	—	$	61,037		$	—
	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, 2015 and December 31, 2014, are as follows:
		Fair Value at March 31, 2015
		Current – Coal Derivative Assets			Long-Term –  Coal Derivative Assets		Accrued Expenses			Other Long-Term Liabilities
		(In Thousands)
	Coal derivative contracts	$	44,924		$	34,428	$	—		$	—
	Diesel derivative contracts		—			—		(403	)		(150	)
	Total	$	44,924		$	34,428	$	(403	)	$	(150	)
		Fair Value at December 31, 2014
		Current – Coal Derivative Assets			Long-Term –  Coal Derivative Assets		Accrued Expenses			Other Long-Term Liabilities
		(In Thousands)
	Coal derivative contracts	$	36,080		$	24,957	$	—		$	—
	Total	$	36,080		$	24,957	$	—		$	—
	The following is a reconciliation of the beginning and ending balances for assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the three months ended March 31, 2014:
		Liability Award
		(In Thousands)
	Balance at January 1, 2014	$	11,700
	Recorded fair value losses (gains):
	Included in earnings		690
	Purchases, issuances and settlements		(12,390	)
	Balance at March 31, 2014	$	—
	The liability award represents a phantom equity award (“Liability Award”) to a retired executive for which the value was determined based on the fair value, as defined in the agreement, of Foresight Reserves as of the employee’s retirement date and was adjusted for distributions made to Foresight Reserves’ members. This Liability Award fully vested in 2010 and was granted principally for services performed to develop the Partnership’s longwall mines. Prior to March 31, 2014, the Liability Award was Level 3 in the fair value hierarchy given Foresight Reserves was a private company; therefore, there was no liquid market to determine the fair value of Foresight Reserves’ equity. The fair value of the Liability Award was determined using a discounted cash flow model and corroborated with recent equity transactions at Foresight Reserves. Effective March 31, 2014, the Liability Award amount was negotiated between the Partnership and the employee to be $12.4 million; therefore, the value of this liability was contracted and therefore no longer a Level 3 liability. As of March 31, 2015, $0.4 million of the unpaid balance is recorded in accrued expenses and other current liabilities for required payments over the next year, and the remaining $3.7 million is recorded in other long-term liabilities, which will be paid out ratably through 2024. The note payable to the retired executive currently bears interest at 3.45%.
	During the three months ended March 31, 2015 and 2014, there were no assets or liabilities that were transferred between Level 1 and Level 2.
	Long-Term Debt
	The fair value of long-term debt as of March 31, 2015 and December 31, 2014 was $1,355.7 million and $1,279.7 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, 2015
Commitments And Contingencies Disclosure [Abstract]
Contingencies	17. Contingencies
	In March 2015, we entered into a settlement agreement with Murray Energy resolving litigation between the Partnership and Murray Energy for an aggregate payment of $14.0 million to the Partnership. Of the $14.0 million settlement amount, $10.0 million was due and payable to us immediately and the remainder is due in increments of $1.0 million over each of the next four years. We recorded the $13.5 million net present value of the settlement amount to other operating income, net in the condensed consolidated statement of operations.
	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”). Sugar Camp is working with the IEPA to finalize its permit application, which has been in process since May 2013. The IEPA has determined not to enter into a compliance commitment agreement with respect to the January Notice and has provided notice to Sugar Camp that the January Notice will be referred to the Illinois Attorney General for enforcement.  While Sugar Camp believes this referral may result in the assessment of a penalty of an amount yet to be determined, there can be no assurances that an acceptable agreement will be reached. Failure to reach a satisfactory agreement with the Illinois Attorney General with respect to the January Notice could result in the assessment of fines or penalties or a suspension of injecting underground at the affected operations until a final resolution is obtained.
	Sugar Camp is working with the IEPA to implement a sustainable solution for the future disposal of water at the mine in compliance with its permits. Sugar Camp has spent $34 million on water treatment infrastructure to prospectively comply with its permits.
	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 motions 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 is now scheduled to occur in June 2015.
	FELLC acquired the Shay No. 1 Mine at Macoupin (“Shay Mine”) in 2009. Prior to this acquisition, in 2003, ExxonMobil Coal USA, Inc. (“Exxon”), the prior owner of the Shay Mine, enrolled the mine in the IEPA’s Site Remediation Program (“SRP”) to address some concerns regarding groundwater contamination from the refuse areas. In 2011, Macoupin proposed, and the IEPA accepted, a compliance commitment agreement (“CCA”) with remediation steps designed to respond to the groundwater contamination concerns. Further, in May 2013, Macoupin submitted a corrective action plan (“CAP”) with groundwater modeling to the IEPA to address the long-term compliance and corrective measures planned for the cleanup of groundwater contamination issues. In June 2013, the IEPA referred the CCA to the Illinois Attorney General’s Office for enforcement on the basis that the compliance period for the CCA extended for too long of a period for the IEPA to monitor. The CAP has been approved by the IEPA and Macoupin reached an agreement in principle with the Illinois Attorney General which, upon finalization of a consent decree, will result in the CAP being implemented.   As of March 31, 2015, the Partnership had accrued $7.0 million for this matter as an asset retirement obligation as it relates to ongoing mining operations at Macoupin. However, there can be no assurance that the ultimate costs will not exceed this amount.
	In addition, in 2013, the IDNR renewed a permit for the refuse disposal area. An environmental group submitted a Request for Administrative Review of this permit renewal. However, in March 2015, the environmental group voluntarily dismissed all remaining legal challenges to the permit renewal, ending the administrative proceeding.
	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, 2015, we have $1.2 million accrued, in aggregate, for various litigation matters.
	Performance Bonds
	We had outstanding surety bonds with third parties of $56.2 million as of March 31, 2015 to secure reclamation and other performance commitments. The Partnership is not required to post collateral for these bonds.

Subsequent_Events

Subsequent Events	3 Months Ended
	Mar. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	18. Subsequent Events
	Murray Energy Transaction
	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 IDRs 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 the certain conditions to exercise 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.
	In connection with this transaction, Michael J. Beyer (“Mr. Beyer”) will resign from his position as President and Chief Executive Officer of FEGP and as a director on the board of directors of FEGP, effective May 30, 2015. Robert D. Moore (“Mr. Moore”) was appointed President and Chief Executive Officer of FEGP to replace Mr. Beyer, effective May 31, 2015, and to the board of directors, effective April 16, 2015. Mr. Moore has served as the Executive Vice President, Chief Operating Officer and Chief Financial Officer of Murray Energy since September 2007 and will continue to serve these roles for Murray Energy.
	Murray Management Services Agreement
	On April 16, 2015, a management services agreement (“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 quarterly compensation of $3.5 million, subject to contractual adjustments. The initial term of the MSA extends through December 31, 2022 and is subject to termination provisions.
	Murray Energy Transport 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 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. On April 16, 2015, American Transport entered into a lease agreement 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 minimum fee of $1,731,250.
	Also, on April 16, 2015, American Century Minerals LLC (“Minerals”), a newly created subsidiary of the Partnership, entered into an overriding royalty agreement with American Energy and Consolidated Land Company (“Consolidated” and, together with American Energy, “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 overriding royalty agreement is subject to a minimum quarterly payment of $493,750.
	Convent Marine Terminal Amendment
	Effective May 1, 2015, the Partnership amended its material handling agreement with Raven Energy LLC, an affiliate owned by Chris Cline, to reduce the minimum annual throughput volume at Convent Marine Terminal to 5.0 million tons per year over the remaining duration of the contract, retroactive to January 1, 2015.
	Hillsboro Mine
	On March 26, 2015, carbon monoxide readings in excess of actionable levels (a mine-specific carbon monoxide threshold requiring mine management to evacuate the mine) were detected at Hillsboro. All underground employees were safely evacuated. The Mine Safety and Health Administration approved reentry into the mine on May 6, 2015 to complete an evaluation of the affected area and the longwall. No damage to our mining equipment was noted. We are monitoring the mine’s carbon monoxide levels and currently do not have an approved plan for the commencement of mining operations. Coal deliveries have not been interrupted as a result of this event as sufficient inventory existed at the mine.
	Declared Distribution
	On May 7, 2015, we declared a quarterly distribution of $0.37 per unit to all unitholders of record on May 18, 2015.
	Other than as described above and in Note 9 and 10, there have been no other subsequent events requiring disclosure.

New_Accounting_Standards_Polic

New Accounting Standards (Policies)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
New Accounting Standards	In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. ASU 2014-08 changes the requirements for reporting discontinued operations by updating the criteria for determining discontinued operations and modifies the disclosure requirements of both discontinued operations and certain other disposals not defined as discontinued operations. ASU 2014-08 was adopted during the current period quarter and did not have an impact on our condensed consolidated financial statements.
	In February 2015, the FASB issued ASU 2015-02, Consolidation.  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, presumption that a general partner should consolidate a limited partnership and the consolidation criterion applied by a reporting entity involved with variable interest entities.  ASU 2015-02 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015 and shall be applied retrospectively to each period presented.  Early adoption is permitted.  We are currently evaluating the effect of adopting ASU 2015-02.
	In April 2015, the FASB issued ASU 2015-06, Effects on Historical Earnings per Unit of Master Limited Partnership Dropdown Transactions.  ASU 2015-06 specifies that for purposes of calculating historical earnings per unit under the two-class method, the earnings of a transferred business before the date of a dropdown transaction should not be allocated to the limited partnership and therefore earnings per unit of the limited partners would not change as a result of the dropdown transaction.  ASU 2015-06 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2015 and shall be applied retrospectively to each period presented.  We do not expect that ASU 2015-06 will have a significant impact on our consolidated financial statements or related disclosures.
	In April 2015, the FASB issued ASU No. 2015-03, Interest - Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs.  ASU 2015-03 requires, effective for fiscal year and interim periods beginning after December 15, 2015, that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Retrospective application is required and early adoption is permitted.  The adoption of ASU 2015-03 is not expected to have a significant impact on our consolidated financial statements or related disclosures.
	No other new accounting pronouncement issued or effective during the fiscal year which were 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_Contracts1

Commodity Derivative Contracts (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Summary of (Gain)/Loss on Coal Derivatives	A summary of the unrealized and realized gains recorded on commodity derivative contracts for the three months ended March 31, 2015 and 2014 is as follows:
		Three Months Ended
		31-Mar-15		31-Mar-14
		(In Thousands)
	Unrealized gain on commodity derivative contracts	$	15,782	$	12,910
	Realized gain on commodity derivative contracts		13,285		2,491
	Gain on commodity derivative contracts	$	29,067	$	15,401

Accounts_Receivable_Tables

Accounts Receivable (Tables)	3 Months Ended
	Mar. 31, 2015
Accounts Receivable Net [Abstract]
Schedule of Accounts Receivable	Accounts receivable consist of the following:
		March 31,		December 31,
		2015		2014
		(In Thousands)
	Trade accounts receivable	$	58,976	$	72,835
	Other receivables		21,488		8,076
	Total accounts receivable	$	80,464	$	80,911

Inventories_Tables

Inventories (Tables)	3 Months Ended
	Mar. 31, 2015
Inventory Disclosure [Abstract]
Schedule of Inventories	Inventories consist of the following:
		March 31,		December 31,
		2015		2014
		(In Thousands)
	Parts and supplies	$	33,282	$	32,156
	Raw coal		7,408		6,200
	Clean coal		91,172		53,719
	Total inventories	$	131,862	$	92,075

Property_Plant_Equipment_and_D1

Property, Plant, Equipment and Development, Net (Tables)	3 Months Ended
	Mar. 31, 2015
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,			December 31,
		2015			2014
		(In Thousands)
	Land, land rights and mineral rights	$	110,992		$	108,892
	Machinery and equipment		1,111,785			1,094,631
	Machinery and equipment under capital leases		126,401			126,401
	Buildings and structures		248,064			246,617
	Development costs		724,875			713,301
	Other		9,915			9,239
	Property, plant, equipment and development		2,332,032			2,299,081
	Less: accumulated depreciation, depletion and amortization		(824,534	)		(776,593	)
	Property, plant, equipment and development, net	$	1,507,498		$	1,522,488

Accrued_Expenses_and_Other_Cur1

Accrued Expenses and Other Current Liabilities (Tables)	3 Months Ended
	Mar. 31, 2015
Accrued Liabilities And Other Liabilities [Abstract]
Schedule of Accrued Expenses and Other Current Liabilities	Accrued expenses and other current liabilities consist of the following:
		March 31,		December 31,
		2015		2014
		(In Thousands)
	Employee compensation, benefits and payroll taxes	$	12,643	$	13,163
	Taxes other than income		6,406		5,668
	Asset retirement obligations		4,207		4,207
	Royalties (non-affiliate)		3,296		2,975
	Liquidated damages (non-affiliate)		1,328		7,315
	Other		5,301		4,492
	Total accrued expenses and other current liabilities	$	33,181	$	37,820

LongTerm_Debt_and_Capital_Leas1

Long-Term Debt and Capital Lease Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
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,			December 31,
		2015			2014
		(In Thousands)
	2021 Senior Notes	$	596,322		$	596,213
	Term Loan		235,907			235,822
	Revolving Credit Facility		349,500			319,500
	Trade A/R Securitization		47,500			—
	5.78% longwall financing arrangement		61,628			61,628
	5.555% longwall financing arrangement		56,719			61,875
	Capital lease obligations		80,026			85,633
	Total long-term debt and capital lease obligations		1,427,602			1,360,671
	Less: current portion		(91,972	)		(44,143	)
	Long-term debt and capital lease obligations	$	1,335,630		$	1,316,528

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Changes in Carrying Amount of Asset Retirement Obligations	The change in the carrying amount of asset retirement obligations was as follows for the three months ended March 31, 2015:
		March 31,
		2015
		(In Thousands)
	Balance at January 1, 2015 (including current portion)	$	35,580
	Accretion expense		567
	Expenditures for reclamation activities		(551	)
	Balance at March 31, 2015 (including current portion)		35,596
	Less: current portion of asset retirement obligations		(4,207	)
	Noncurrent portion of asset retirement obligations	$	31,389

RelatedParty_Transactions_Tabl

Related-Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2015
Related Party Transactions [Abstract]
Summary of Affiliate Amounts Included in Condensed Consolidated Balance Sheets	The following table presents the affiliate amounts included in our condensed consolidated balance sheets:
	Affiliated Company		Balance Sheet Location		March 31,				December 31,
					2015				2014
					(In Thousands)
	Foresight Reserves and affiliated entities		Due from affiliates		$	117			$	345
	NRP and affiliated entities		Due from affiliates			47				187
	Total				$	164			$	532
	Foresight Reserves and affiliated entities		Due to affiliates		$	4,436			$	7,959
	NRP and affiliated entities		Due to affiliates			6,395				7,148
	Total				$	10,831			$	15,107
	Foresight Reserves and affiliated entities		Prepaid royalties		$	51,924			$	53,671
	NRP and affiliated entities		Prepaid royalties			13,164				11,071
	Total				$	65,088			$	64,742
Summary of Expenses (Income) Incurred With Affiliated Entities	A summary of expenses (income) incurred with affiliated entities is as follows for the three months ended March 31, 2015 and 2014:
		Three Months Ended
		31-Mar-15				31-Mar-14
		(In Thousands)
	Royalty expense – NRP and affiliated entities(1)	$	9,006			$	12,434
	Royalty expense – Foresight Reserves and affiliated entities(1)	$	2,630			$	1,318
	Loadout services – NRP and affiliated entities(1)	$	2,325			$	2,593
	Terminal fees – Foresight Reserves and affiliated entities(2)	$	9,264			$	10,888
	Administrative fee income – Foresight	$	(47	)		$	(75	)
	Reserves and affiliated entities(3)
	Location in the condensed consolidated statements of operations:
	(1) – Cost of coal produced (excluding depreciation, depletion and amortization)
	(2) – Transportation
	(3) – Other operating income, net

Variable_Interest_Entities_VIE1

Variable Interest Entities (VIEs) (Tables)	3 Months Ended
	Mar. 31, 2015
Variable Interest Entity Nonconsolidated Carrying Amount Assets And Liabilities [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,		December 31,
		2015		2014
		(In Thousands)
	Assets:
	Current assets	$	2,628	$	4,939
	Long-term assets		—		1,554
	Total assets	$	2,628	$	6,493
	Liabilities:
	Current liabilities	$	13,581	$	10,145
	Long-term liabilities		1,676		1,131
	Total liabilities	$	15,257	$	11,276

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	3 Months Ended
	Mar. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Summary of Non-vested LTIP Award Activity	A summary of LTIP award activity for the three months ended March 31, 2015 is as follows:
		Number of Units			Weighted Average
					Grant Date Fair Value
					per Unit
	Non-vested grants at January 1, 2015		601,109		$	19.99
	Granted		562,669		$	16.36
	Vested		(450,500	)	$	16.66
	Forfeited		(3,304	)	$	20
	Non-vested grants at March 31, 2015		709,974		$	19.23

Earnings_per_Limited_Partner_U1

Earnings per Limited Partner Unit (Tables)	3 Months Ended
	Mar. 31, 2015
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 income per common and subordinated unit for the periods indicated:
		Common Unitholders		Subordinated Unitholders		Total
	Three months ended March 31, 2015	(In Thousands, Except Per Unit Data)
	Numerator:
	Net income available to limited partner units	$	21,158	$	21,125	$	42,283
	Denominator:
	Weighted-average units to calculate basic EPU		64,971		64,871		129,842
	Less: effect of dilutive securities (1)		—		—		—
	Weighted-average units to calculate diluted EPU		64,971		64,871		129,842
	Basic net income per unit	$	0.33	$	0.33	$	0.33
	Diluted net income per unit	$	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, 2015, approximately 0.7 million phantom units were anti-dilutive, and therefore excluded from the diluted EPU calculation.

Fair_Value_of_Financial_Instru1

Fair Value of Financial Instruments (Tables)	3 Months Ended
	Mar. 31, 2015
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, 2015
		Total			Level 1		Level 2			Level 3
		(In Thousands)
	Coal derivative contracts	$	79,352		$	—	$	79,352		$	—
	Diesel derivative contracts		(553	)		—		(553	)		—
	Total	$	78,799		$	—	$	78,799		$	—
		Fair Value at December 31, 2014
		Total			Level 1		Level 2			Level 3
		(In Thousands)
	Coal derivative contracts	$	61,037		$	—	$	61,037		$	—
	Total	$	61,037		$	—	$	61,037		$	—
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, 2015 and December 31, 2014, are as follows:
		Fair Value at March 31, 2015
		Current – Coal Derivative Assets			Long-Term –  Coal Derivative Assets		Accrued Expenses			Other Long-Term Liabilities
		(In Thousands)
	Coal derivative contracts	$	44,924		$	34,428	$	—		$	—
	Diesel derivative contracts		—			—		(403	)		(150	)
	Total	$	44,924		$	34,428	$	(403	)	$	(150	)
		Fair Value at December 31, 2014
		Current – Coal Derivative Assets			Long-Term –  Coal Derivative Assets		Accrued Expenses			Other Long-Term Liabilities
		(In Thousands)
	Coal derivative contracts	$	36,080		$	24,957	$	—		$	—
	Total	$	36,080		$	24,957	$	—		$	—
Fair Value Liabilities Measured on Recurring Basis with Unobservable Input Reconciliation
	The following is a reconciliation of the beginning and ending balances for assets and liabilities measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the three months ended March 31, 2014:
		Liability Award
		(In Thousands)
	Balance at January 1, 2014	$	11,700
	Recorded fair value losses (gains):
	Included in earnings		690
	Purchases, issuances and settlements		(12,390	)
	Balance at March 31, 2014	$	—

Organization_Nature_of_Busines1

Organization, Nature of Business and Basis of Presentation - Additional Information (Details)	3 Months Ended
	Mar. 31, 2015
Schedule Of Organization Nature Of Business And Basis Of Presentation [Line Items]
Percentage of ownership interests distributed	100.00%
Foresight Energy LLC | Foresight Reserves, LP
Schedule Of Organization Nature Of Business And Basis Of Presentation [Line Items]
Ownership percentage prior to 6/23/2014	99.33%
Foresight Energy LLC | Member of Management
Schedule Of Organization Nature Of Business And Basis Of Presentation [Line Items]
Ownership percentage prior to 6/23/2014	0.67%

Foresight_Reserves_Contributio1

Foresight Reserves Contributions - Additional Information (Details) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Equity [Abstract]
Aggregate net book value of contributed companies	$60.60

Commodity_Derivative_Contracts2

Commodity Derivative Contracts - Additional Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
	T	T
Derivative Instruments And Hedging Activities Disclosures [Line Items]
Outstanding coal derivative contracts	3,100,000	3,400,000
Proceeds from settlement of derivatives	$3.30
Swap Agreements [Member]
Derivative Instruments And Hedging Activities Disclosures [Line Items]
Percentage of anticipated diesel fuel exposure for remainder of fiscal year.	27.00%
Percentage of anticipated diesel fuel exposure for two years.	14.00%

Commodity_Derivative_Contracts3

Commodity Derivative Contracts - Summary of (Gain)/Loss on Coal Derivatives (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Unrealized gain on commodity derivative contracts	$15,782	$12,910
Realized gain on commodity derivative contracts	13,285	2,491
Gain on commodity derivative contracts	$29,067	$15,401

Accounts_Receivable_Schedule_o

Accounts Receivable - Schedule of Accounts Receivable (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Accounts Receivable Net [Abstract]
Trade accounts receivable	$58,976	$72,835
Other receivables	21,488	8,076
Total accounts receivable	$80,464	$80,911

Accounts_Receivable_Additional

Accounts Receivable - Additional Information (Details) (Murray Energy, USD $)	1 Months Ended
In Millions, unless otherwise specified	Apr. 30, 2015	Mar. 31, 2015
Accounts Receivable [Line Items]
Legal settlement receivable		$10.80
Subsequent Event
Accounts Receivable [Line Items]
Proceeds from legal settlement	$10

Inventories_Schedule_of_Invent

Inventories - Schedule of Inventories (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Inventory [Line Items]
Parts and supplies	$33,282	$32,156
Total inventories	131,862	92,075
Raw coal
Inventory [Line Items]
Coal	7,408	6,200
Clean coal
Inventory [Line Items]
Coal	$91,172	$53,719

Property_Plant_Equipment_and_D2

Property, Plant, Equipment and Development, Net (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Property Plant And Equipment [Abstract]
Land, land rights and mineral rights	$110,992	$108,892
Machinery and equipment	1,111,785	1,094,631
Machinery and equipment under capital leases	126,401	126,401
Buildings and structures	248,064	246,617
Development costs	724,875	713,301
Other	9,915	9,239
Property, plant, equipment and development	2,332,032	2,299,081
Less: accumulated depreciation, depletion and amortization	-824,534	-776,593
Property, plant, equipment and development, net	$1,507,498	$1,522,488

Accrued_Expenses_and_Other_Cur2

Accrued Expenses and Other Current Liabilities - Schedule of Accrued Expenses and Other Current Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Accrued Liabilities And Other Liabilities [Abstract]
Employee compensation, benefits and payroll taxes	$12,643	$13,163
Taxes other than income	6,406	5,668
Asset retirement obligations	4,207	4,207
Royalties (non-affiliate)	3,296	2,975
Liquidated damages (non-affiliate)	1,328	7,315
Other	5,301	4,492
Total accrued expenses and other current liabilities	$33,181	$37,820

LongTerm_Debt_and_Capital_Leas2

Long-Term Debt and Capital Lease Obligations (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Debt Instrument [Line Items]
Capital lease obligations	$80,026	$85,633
Total long-term debt and capital lease obligations	1,427,602	1,360,671
Less: current portion	-91,972	-44,143
Long-term debt and capital lease obligations	1,335,630	1,316,528
2021 Senior Notes
Debt Instrument [Line Items]
Long-term debt	596,322	596,213
Term Loan
Debt Instrument [Line Items]
Long-term debt	235,907	235,822
Trade A/R Securitization
Debt Instrument [Line Items]
Long-term debt	47,500
5.78% longwall financing arrangement
Debt Instrument [Line Items]
Long-term debt	61,628	61,628
5.555% longwall financing arrangement
Debt Instrument [Line Items]
Long-term debt	56,719	61,875
Revolving Credit Facility
Debt Instrument [Line Items]
Long-term debt	$349,500	$319,500

LongTerm_Debt_and_Capital_Leas3

Long-Term Debt and Capital Lease Obligations (Parenthetical) (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
2021 Senior Notes
Debt Instrument [Line Items]
Debt instrument maturity year	2021	2021
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	5.56%	5.56%

LongTerm_Debt_and_Capital_Leas4

Long-Term Debt and Capital Lease Obligations - Additional Information (Details) (USD $)	1 Months Ended	0 Months Ended
	Jan. 31, 2015	7-May-15	Mar. 31, 2015	Dec. 31, 2014
Trade A/R Securitization
Debt Instrument [Line Items]
Maximum borrowings capacity under credit facility	$70,000,000
Amount of borrowings outstanding under revolving credit facility			47,500,000
Debt Instrument, Term	3 years
Maturity date of borrowings	12-Jan-18
Revolving Credit Facility
Debt Instrument [Line Items]
Maximum borrowings capacity under credit facility			500,000,000
Amount of borrowings outstanding under revolving credit facility			349,500,000	319,500,000
Outstanding letters of credit			6,500,000
Remaining borrowing capacity under revolving credit facility			144,000,000
Weighted average interest rate			3.50%
Revolving Credit Facility | Subsequent Event
Debt Instrument [Line Items]
Amount available to increase commitment under credit facility		$100,000,000

SaleLeaseback_Financing_Arrang1

Sale-Leaseback Financing Arrangements - Additional Information (Details) (USD $)	3 Months Ended		12 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2009	Dec. 31, 2012	Dec. 31, 2014
Sale Leaseback Transaction [Line Items]
Sale-leaseback financing arrangements	$193,434,000				$193,434,000
Sale-lease back transaction, accrued interest expense	14,229,000				25,136,000
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 (bWPPb), a subsidiary of Natural Resource Partners, LP (bNRPb), and leased them back. The gross proceeds from this transaction were $143.5 million and were used for capital expenditures.
Proceeds from sale-leaseback financing arrangement			143,500,000
Sale-leaseback financing arrangements	143,500,000
Sale-leaseback transaction, imputed interest rate	13.90%
Sale-lease back transaction, interest expense	5,100,000	4,700,000
Sale-lease back transaction, accrued interest expense	6,400,000				5,600,000
Sugar Camp
Sale Leaseback Transaction [Line Items]
Sale-leaseback transaction, description	In 2012, Sugar Camp sold certain rail facilities to HOD, LLC (bHODb), a subsidiary of NRP, and leased them back. The gross proceeds from this transaction were $50.0 million and were used for capital expenditures, to pay down debt and for general corporate purposes.
Proceeds from sale-leaseback financing arrangement				50,000,000
Sale-leaseback financing arrangements	50,000,000
Sale-leaseback transaction, imputed interest rate	13.80%
Sale-lease back transaction, interest expense	1,500,000	1,700,000
Sale-lease back transaction, accrued interest expense	$6,400,000				$5,600,000

Asset_Retirement_Obligations_C

Asset Retirement Obligations - Changes in Carrying Amount of Asset Retirement Obligations (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Beginning balance	$35,580
Accretion expense	567	405
Expenditures for reclamation activities	-551
Ending balance	35,596
Less: current portion of asset retirement obligations	-4,207		-4,207
Noncurrent portion of asset retirement obligations	$31,389		$31,373

RelatedParty_Transactions_Addi

Related-Party Transactions - Additional Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Apr. 30, 2015	Apr. 16, 2015
Related Party Transaction [Line Items]
Purchase of mining supplies from affiliates	$4.30	$3.40
General Partner
Related Party Transaction [Line Items]
Percentage of beneficial interested owned by Cline and affiliates	31.00%
General Partner | Subsequent Event | Murray Energy Transaction
Related Party Transaction [Line Items]
Percentage of voting interests acquired			34.00%
Limited Partners
Related Party Transaction [Line Items]
Percentage of beneficial interested owned by Cline and affiliates	4.00%
Partnershipbs subordinated | Subsequent Event | Murray Energy Transaction
Related Party Transaction [Line Items]
Percentage of voting interests acquired				77.50%

RelatedParty_Transactions_Summ

Related-Party Transactions - Summary of Affiliate Amounts Included in Condensed Consolidated Balance Sheets (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Related Party Transaction [Line Items]
Due from affiliates	$164	$532
Due to affiliates	10,831	15,107
Prepaid royalties	6,901	8,380
Affiliates
Related Party Transaction [Line Items]
Due from affiliates	164	532
Due to affiliates	10,831	15,107
Prepaid royalties	65,088	64,742
Foresight Reserves and Affiliated Entities | Affiliates
Related Party Transaction [Line Items]
Due from affiliates	117	345
Due to affiliates	4,436	7,959
Prepaid royalties	51,924	53,671
NRP and Affiliated Entities | Affiliates
Related Party Transaction [Line Items]
Due from affiliates	47	187
Due to affiliates	6,395	7,148
Prepaid royalties	$13,164	$11,071

RelatedParty_Transactions_Summ1

Related-Party Transactions - Summary of Expenses (Income) Incurred With Affiliated Entities (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
NRP and Affiliated Entities
Related Party Transaction [Line Items]
Royalty expense	$9,006	[1]	$12,434	[1]
Loadout services	2,325	[1]	2,593	[1]
Foresight Reserves and Affiliated Entities
Related Party Transaction [Line Items]
Royalty expense	2,630	[1]	1,318	[1]
Terminal fees	9,264	[2]	10,888	[2]
Administrative fee income	($47)	[3]	($75)	[3]
[1]	Cost of coal produced (excluding depreciation, depletion and amortization)
[2]	Transportation
[3]	Other operating income, net

Variable_Interest_Entities_VIE2

Variable Interest Entities (VIEs) - Additional Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Adena And Hillboro Transport Assets
Variable Interest Entity [Line Items]
Incentive distribution rightsb equity contributed to Partnership Interest	$9.90
Contractor VIEs
Variable Interest Entity [Line Items]
Minimum fee received per ton of coal mined or processed	0.01
Maximum fee paid per ton of coal mined or processed	0.02
Net income attributable to noncontrolling interests	$0.10	$0.10
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_VIE3

Variable Interest Entities (VIEs) - Summary of Consolidated VIE Assets and Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Assets
Current assets	$326,996	$276,170
Total assets	1,963,318	1,915,652
Liabilities:
Current liabilities	206,918	182,412
Total liabilities	1,773,245	1,729,255
Variable Interest Entity, Primary Beneficiary
Assets
Current assets	2,628	4,939
Long-term assets		1,554
Total assets	2,628	6,493
Liabilities:
Current liabilities	13,581	10,145
Long-term liabilities	1,676	1,131
Total liabilities	$15,257	$11,276

EquityBased_Compensation_Addit

Equity-Based Compensation - Additional Information (Details) (USD $)	3 Months Ended	1 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2015	Feb. 28, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Compensation expense	$8.20
Limited partners cash distributions payable	0.4	0.4
Selling, General and Administrative Expenses
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Compensation expense	$7.10
Partnership's equity-based compensation	92.00%	92.00%
Cost of Coal Sales
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Partnership's equity-based compensation	8.00%	8.00%
LTIP Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate number of common units authorized	7,000,000	7,000,000
Number of units granted	6,400,000	6,400,000
Number of Units, Granted	562,669
LTIP Awards | Phantom Share Units (PSUs)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of Units, Granted		130,919
LTIP Awards | Common Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of Units, Granted			215,954
LTIP Awards | Subordinated Units
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of Units, Granted			215,796

EquityBased_Compensation_Summa

Equity-Based Compensation - Summary of Non-vested LTIP Award Activity (Details) (LTIP Awards, USD $)	3 Months Ended
	Mar. 31, 2015
LTIP Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Non-vested grants, Beginning	601,109
Number of Units, Granted	562,669
Number of Units, Vested	-450,500
Number of Units, Forfeited	-3,304
Non-vested grants, Ending	709,974
Non-vested grants, Beginning	$19.99
Weighted Average Grant Date Fair Value per Unit, Granted	$16.36
Weighted Average Grant Date Fair Value per Unit, Vested	$16.66
Weighted Average Grant Date Fair Value per Unit, Forfeited	$20
Non-vested grants, Ending	$19.23

Earnings_per_Limited_Partner_U2

Earnings per Limited Partner Unit - Summary of Partnership's Calculation of Net Income per Common and Subordinated Unit (Details) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015
Distribution Made To Limited Partner [Line Items]
Net income subsequent to initial public offering attributable to limited partner units	$42,283
Weighted-average units to calculate basic EPU	129,842
Weighted-average units to calculate diluted EPU	129,842
Basic net income per unit	$0.33
Diluted net income per unit	$0.33
Common Units
Distribution Made To Limited Partner [Line Items]
Net income subsequent to initial public offering attributable to limited partner units	21,158
Weighted-average units to calculate basic EPU	64,971
Weighted-average units to calculate diluted EPU	64,971
Basic net income per unit	$0.33
Diluted net income per unit	$0.33
Subordinated Units
Distribution Made To Limited Partner [Line Items]
Net income subsequent to initial public offering attributable to limited partner units	$21,125
Weighted-average units to calculate basic EPU	64,871
Weighted-average units to calculate diluted EPU	64,871
Basic net income per unit	$0.33
Diluted net income per unit	$0.33

Earnings_per_Limited_Partner_U3

Earnings per Limited Partner Unit - Summary of Partnership's Calculation of Net Income per Common and Subordinated Unit (Parenthetical) (Details) (Phantom Share Units (PSUs))	3 Months Ended
In Millions, unless otherwise specified	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	0.7

Fair_Value_of_Financial_Instru2

Fair Value of Financial Instruments - Fair Value of Net Financial Assets and Liabilities (Details) (Fair Value, Measurements, Recurring, USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total	$78,799	$61,037
Fair Value, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total	78,799	61,037
Coal Derivative Contracts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Coal derivative contracts	79,352	61,037
Coal Derivative Contracts | Fair Value, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Coal derivative contracts	79,352	61,037
Diesel Derivative Contracts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Diesel derivative contracts	-553
Diesel Derivative Contracts | Fair Value, Level 2
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Diesel derivative contracts	($553)

Fair_Value_of_Financial_Instru3

Fair Value of Financial Instruments - Fair Value of Gross Financial Assets and Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Current b Coal Derivative Assets	$44,924	$36,080
Long-Term b Coal Derivative Assets	34,428	24,957
Other Long-Term Liabilities	-5,874	-5,508
Fair Value, Measurements, Recurring
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Current b Coal Derivative Assets	44,924	36,080
Long-Term b Coal Derivative Assets	34,428	24,957
Accrued Expenses	-403
Other Long-Term Liabilities	-150
Fair Value, Measurements, Recurring | Coal Derivative Contracts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Current b Coal Derivative Assets	44,924	36,080
Long-Term b Coal Derivative Assets	34,428	24,957
Fair Value, Measurements, Recurring | Diesel Derivative Contracts
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Accrued Expenses	-403
Other Long-Term Liabilities	($150)

Fair_Value_Measures_and_Disclo

Fair Value Measures and Disclosures - Fair Value Measurement of Reconciliation of Beginning and Ending Balances for Assets and Liabilities (Details) (Fair Value, Measurements, Recurring, Liability Award, USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015
Fair Value, Measurements, Recurring | Liability Award
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liability balance, beginning	$11,700
Recorded fair value losses (gains):
Included in earnings	690
Purchases, issuances and settlements	-12,390
Liability balance, ending	$0

Fair_Value_Measures_and_Disclo1

Fair Value Measures and Disclosures - Additional Information (Details) (USD $)	0 Months Ended
	Mar. 31, 2014	Mar. 31, 2015	Dec. 31, 2014
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Assets or liabilities transferred between level 1 and level 2	$0	$0
Fair value of Long-Term Debt (Level III)		1,355,700,000	1,279,700,000
Accrued Expenses and Other Current Liabilities
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Other notes payable		400,000
Other Noncurrent Liabilities
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Other notes payable		3,700,000
Liability Award
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Interest rate on other notes payable		3.45%
Phantom Share Units (PSUs)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Liability award that was contracted and removed from Level III measurement	$12,400,000

Contingencies_Additional_Infor

Contingencies - Additional Information (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Loss Contingencies [Line Items]
Litigation settlement, amount	$14,000,000
Litigation settlement amount receivable, current	10,000,000
Litigation settlement amount receivable in, 2016	1,000,000
Litigation settlement amount receivable in, 2017	1,000,000
Litigation settlement amount receivable in, 2018	1,000,000
Litigation settlement amount receivable in, 2019	1,000,000
Net present value of settlement amount	13,500,000
Asset retirement obligations	35,596,000	35,580,000
Accrued litigation expense	1,200,000
Surety Bond
Loss Contingencies [Line Items]
Outstanding performance bonds	56,200,000
Shay Mine
Loss Contingencies [Line Items]
Asset retirement obligations	7,000,000
Sugar Camp
Loss Contingencies [Line Items]
Expected Capital expenditures under Sugar Camp compliance commitment agreement	$34,000,000

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Details) (USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	7-May-15	Apr. 16, 2015	1-May-15
				T
Subsequent Event [Line Items]
Distribution declared per limited partner unit	$0.36
Subsequent Event
Subsequent Event [Line Items]
Distribution declared per limited partner unit		$0.37
Declared Distribution, date of record		18-May-15
Subsequent Event | Murray Management Services Agreement | Murray American Coal Inc | Selling, General and Administrative Expenses
Subsequent Event [Line Items]
Management and administration services, quarterly payment			$3,500,000
Subsequent Event | Transport and Overriding Royalty Agreements | American Energy Corporation
Subsequent Event [Line Items]
Proceeds from sale of assets			63,000,000
Number of coal preparation plants and related cost handling facilities			2
Subsequent Event | Transport and Overriding Royalty Agreements | American Energy Corporation | Minimum
Subsequent Event [Line Items]
Fees per ton of coal mined processed and/or transported using leased assets			1.15
Subsequent Event | Transport and Overriding Royalty Agreements | American Energy Corporation | Minimum | Scenario Quarterly Amounts
Subsequent Event [Line Items]
Fees for coal mined processed and/or transported using leased assets			1,731,250
Subsequent Event | Transport and Overriding Royalty Agreements | American Energy Corporation | Maximum
Subsequent Event [Line Items]
Fees per ton of coal mined processed and/or transported using leased assets			1.75
Subsequent Event | Transport and Overriding Royalty Agreements | American Energy And Consolidated Land Company
Subsequent Event [Line Items]
Cash paid for overriding royalty rights			12,000,000
Subsequent Event | Transport and Overriding Royalty Agreements | American Energy And Consolidated Land Company | Minimum
Subsequent Event [Line Items]
Overriding royalty interest granted per unit			0.3
Subsequent Event | Transport and Overriding Royalty Agreements | American Energy And Consolidated Land Company | Minimum | Scenario Quarterly Amounts
Subsequent Event [Line Items]
Cash paid for overriding royalty rights			493,750
Subsequent Event | Transport and Overriding Royalty Agreements | American Energy And Consolidated Land Company | Maximum
Subsequent Event [Line Items]
Overriding royalty interest granted per unit			0.5
Subsequent Event | Convent Marine Terminal Amendment | Raven Energy LLC | Adjusted Amount
Subsequent Event [Line Items]
Minimum annual throughput volume				5,000,000
Subsequent Event | Murray Energy Transaction
Subsequent Event [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%
Subsequent Event | Murray Energy Transaction | General Partner
Subsequent Event [Line Items]
Percentage of voting interests acquired			34.00%
Option Price Value			$25,000,000
Stock Option Exercise Period			5 years
Subsequent Event | Murray Energy Transaction | Partnershipbs subordinated
Subsequent Event [Line Items]
Percentage of voting interests acquired			77.50%