Rhino Resource Partners 8-K10 Oct 14Other EventsFinancial data

Company Profile

Document_And_Entity_Informatio

Document And Entity Information	12 Months Ended
Document And Entity Information	Dec. 31, 2013
Document And Entity Information [Abstract]	'
Document Type	'8-K
Amendment Flag	'false
Document Period End Date	31-Dec-13
Entity Registrant Name	'Rhino Resource Partners LP
Entity Central Index Key	'0001490630
Current Fiscal Year End Date	'--12-31
Entity Filer Category	'Accelerated Filer

Consolidated_Statements_Of_Fin

Consolidated Statements Of Financial Position (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
CURRENT ASSETS:	'	'
Cash and cash equivalents	$423	$461
Accounts receivable, net of allowance for doubtful accounts ($0 as of December 31, 2013 and 2012)	25,461	33,560
Inventories	18,580	18,743
Advance royalties, current portion	179	187
Prepaid expenses and other	4,572	4,323
Current assets held for sale	454	'
Total current assets	49,669	57,274
PROPERTY, PLANT AND EQUIPMENT:	'	'
At cost, including coal properties, mine development and construction costs	674,708	653,404
Less accumulated depreciation, depletion and amortization	-249,718	-219,613
Net property, plant and equipment	424,990	433,791
Advance royalties, net of current portion	5,580	4,506
Investment in unconsolidated affiliates	21,243	23,224
Intangible assets, net	1,148	1,228
Other non-current assets	9,640	9,684
Non-current assets held for sale	55,497	30,169
TOTAL	567,767	559,876
CURRENT LIABILITIES:	'	'
Accounts payable	17,710	14,711
Accrued expenses and other	20,567	22,178
Current portion of long-term debt	1,024	2,350
Current portion of asset retirement obligations	1,614	2,255
Current portion of postretirement benefits	334	227
Current liabilities held for sale	5,241	3,319
Total current liabilities	46,490	45,040
NON-CURRENT LIABILITIES:	'	'
Long-term debt, net of current portion	170,022	161,199
Asset retirement obligations, net of current portion	32,837	30,748
Other non-current liabilities	16,220	16,575
Postretirement benefits, net of current portion	5,786	6,520
Non-current liabilities held for sale	41	'
Total non-current liabilities	224,906	215,042
Total liabilities	271,396	260,082
COMMITMENTS AND CONTINGENCIES (NOTE 15)	'	'
PARTNERS' CAPITAL:	'	'
Limited partners	283,339	287,060
General partner	10,801	11,303
Accumulated other comprehensive income	2,231	1,431
Total partners' capital	296,371	299,794
TOTAL	$567,767	$559,876

Consolidated_Statements_Of_Fin1

Consolidated Statements Of Financial Position (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Consolidated Statements Of Financial Position [Abstract]	'	'
Accounts receivable, allowance for doubtful accounts	$0	$0

Consolidated_Statements_Of_Ope

Consolidated Statements Of Operations And Comprehensive Income (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
REVENUES:	'		'		'
Coal sales	$236,601		$304,568		$333,876
Freight and handling revenues	2,159		6,357		5,750
Other revenues	33,505		40,818		27,595
Total revenues	272,265		351,743		367,221
COSTS AND EXPENSES:	'		'		'
Cost of operations (exclusive of depreciation, depletion and amortization shown separately below)	199,705		247,719		267,603
Freight and handling costs	1,294		5,833		4,329
Depreciation, depletion and amortization	39,627		41,274		36,325
Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above)	19,800		20,442		21,815
Asset impairment loss	1,667		0		0
(Gain) on sale/disposal of assets, net	-10,359		-4,890		-3,172
Total costs and expenses	251,734		310,378		326,900
INCOME FROM OPERATIONS	20,531		41,365		40,321
INTEREST AND OTHER INCOME (EXPENSE):	'		'		'
Interest expense and other	-7,898		-7,767		-6,062
Interest income and other	207		92		51
Equity in net (loss)/income of unconsolidated affiliates	-4,729		5,757		2,988
Total interest and other (expense)	-12,420		-1,918		-3,023
INCOME BEFORE INCOME TAXES FROM CONTINUING OPERATIONS	8,111		39,447		37,298
INCOME TAXES	'		'		'
NET INCOME FROM CONTINUING OPERATIONS	8,111		39,447		37,298
DISCONTINUED OPERATIONS	'		'		'
Income from discontinued operations	1,307		88		'
NET INCOME	9,418		39,535		37,298
Other comprehensive income:	'		'		'
Change in actuarial gain under ASC Topic 815	800		-917		1,723
COMPREHENSIVE INCOME	10,218		38,618		39,021
Net income per limited partner unit, diluted:	'		'		'
Distributions paid per limited partner unit	$1.78		$1.85		$1.81
Subordinated Units [Member]	'		'		'
Net income per limited partner unit, diluted:	'		'		'
Distributions paid per limited partner unit	$0		'		'
General Partner Capital [Member]	'		'		'
Partner interest in net income:	'		'		'
Net income from continuing operations	162		789		746
Net income from discontinued operations	26		1		'
Partner's interest in net income	188		790		746
Common Unitholders [Member]	'		'		'
Partner interest in net income:	'		'		'
Net income from continuing operations	4,448		21,374		19,205
Net income from discontinued operations	769		48		'
Partner's interest in net income	5,217		21,422		19,205
Net income per limited partner unit, basic:	'		'		'
Net income per unit from continuing operations	$0.29		$1.39		$1.40
Net income per unit from discontinued operations	$0.04		$0.01		'
Net income per common unit, basic	$0.33		$1.40		$1.40
Net income per limited partner unit, diluted:	'		'		'
Net income per unit from continuing operations	$0.29		$1.39		$1.40
Net income per unit from discontinued operations	$0.04		$0.01		'
Net income per common unit, diluted	$0.33		$1.40		$1.40
Common Unitholders [Member] \| Common Units [Member]	'		'		'
Weighted average number of limited partner units outstanding, basic:	'		'		'
Weighted average number of limited partner units outstanding, basic	15,751	[1]	15,331	[1]	13,725	[1]
Weighted average number of limited partner units outstanding, diluted:	'		'		'
Weighted average number of limited partner units outstanding, diluted	15,760	[1]	15,335	[1]	13,744	[1]
Subordinated Unitholders[Member]	'		'		'
Partner interest in net income:	'		'		'
Net income from continuing operations	3,501		17,284		17,347
Net income from discontinued operations	512		39		'
Partner's interest in net income	$4,013		$17,323		$17,347
Net income per limited partner unit, basic:	'		'		'
Net income per unit from continuing operations	$0.28		$1.39		$1.40
Net income per unit from discontinued operations	$0.04		$0.01		'
Net income per common unit, basic	$0.32		$1.40		$1.40
Net income per limited partner unit, diluted:	'		'		'
Net income per unit from continuing operations	$0.28		$1.39		$1.40
Net income per unit from discontinued operations	$0.04		$0.01		'
Net income per common unit, diluted	$0.32		$1.40		$1.40
Subordinated Unitholders[Member] \| Subordinated Units [Member]	'		'		'
Weighted average number of limited partner units outstanding, basic:	'		'		'
Weighted average number of limited partner units outstanding, basic	12,397	[1]	12,397	[1]	12,397	[1]
Weighted average number of limited partner units outstanding, diluted:	'		'		'
Weighted average number of limited partner units outstanding, diluted	12,397	[1]	12,397	[1]	12,397	[1]

[1]	No distributions were paid on the subordinated units during 2013 or for the three months ended June 30, 2012, September 30, 2012 and December 31, 2012.

Consolidated_Statements_Of_Ope1

Consolidated Statements Of Operations And Comprehensive Income (Parenthetical) (USD $)	12 Months Ended			3 Months Ended			12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Dec. 31, 2013
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Subordinated Units [Member]	Subordinated Units [Member]	Subordinated Units [Member]	Subordinated Units [Member]
Distributions paid per limited partner unit	$1.78	$1.85	$1.81	$0	$0	$0	$0

Consolidated_Statements_Of_Mem

Consolidated Statements Of Members' Equity/Partners' Capital (USD $)	Limited Partner [Member]	Limited Partner [Member]	General Partner Capital [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Total
In Thousands	Common Units [Member]	Subordinated [Member]	General Partner Capital [Member]	Accumulated Other Comprehensive Income/(Loss) [Member]	Total
Balance at Dec. 31, 2010	$133,968	$98,313	$10,323	$625	$243,229
Balance, shares at Dec. 31, 2010	12,400	12,397	'	'	'
Net income	19,205	17,347	746	'	37,298
Distributions to unitholders and general partner	-25,215	-22,449	-972	'	-48,636
General partners' contributions	'	'	1,450	'	1,450
Offering of common units	66,916	'	'	'	66,916
Offering of common units, shares	2,875	'	'	'	'
Offering costs	-560	-9	'	'	-569
Equity-based compensation	-241	'	'	'	-241
Issuance of units under LTIP	767	'	'	'	767
Issuance of units under LTIP, shares	36	'	'	'	'
Change in actuarial gain under ASC Topic 815	'	'	'	1,723	1,723
Balance at Dec. 31, 2011	194,840	93,202	11,547	2,348	301,937
Balance, shares at Dec. 31, 2011	15,311	12,397	'	'	'
Net income	21,422	17,323	790	'	39,535
Distributions to unitholders and general partner	-28,470	-11,901	-1,047	'	-41,418
General partners' contributions	'	'	13	'	13
Offering costs	-7	'	'	'	-7
Issuance of units under LTIP	651	'	'	'	651
Issuance of units under LTIP, shares	39	'	'	'	'
Change in actuarial gain under ASC Topic 815	'	'	'	-917	-917
Balance at Dec. 31, 2012	188,436	98,624	11,303	1,431	299,794
Balance, shares at Dec. 31, 2012	15,350	12,397	'	'	'
Net income	5,217	4,013	188	'	9,418
Distributions to unitholders and general partner	-28,119	'	-1,020	'	-29,139
General partners' contributions	'	'	330	'	330
Offering of common units	14,788	'	'	'	14,788
Offering of common units, shares	1,265	'	'	'	'
Offering costs	-214	'	'	'	-214
Issuance of units under LTIP	594	'	'	'	594
Issuance of units under LTIP, shares	45	'	'	'	'
Change in actuarial gain under ASC Topic 815	'	'	'	800	800
Balance at Dec. 31, 2013	$180,702	$102,637	$10,801	$2,231	$296,371
Balance, shares at Dec. 31, 2013	16,660	12,397	'	'	'

Consolidated_Statements_Of_Cas

Consolidated Statements Of Cash Flows (USD $)	12 Months Ended
Consolidated Statements Of Cash Flows (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'	'
Net income	$9,418,000	$39,535,000	$37,298,000
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Depreciation, depletion and amortization	42,609,000	41,370,000	36,325,000
Accretion on asset retirement obligations	2,356,000	1,896,000	1,956,000
Accretion on interest-free debt	57,000	222,000	210,000
Amortization of deferred revenue	-1,553,000	-929,000	-532,000
Amortization of advance royalties	270,000	244,000	1,104,000
Amortization of debt issuance costs	1,295,000	1,075,000	1,043,000
Amortization of actuarial gain	-145,000	-295,000	0
Provision for doubtful accounts	'	'	-19,000
Equity in net loss/(income) of unconsolidated affiliates	4,729,000	-5,757,000	-2,988,000
Distribution from unconsolidated affiliate	'	2,958,000	3,351,000
Loss on retirement of advance royalties	182,000	100,000	79,000
(Gain) on sale/disposal of assets-net	-10,359,000	-4,878,000	-3,172,000
Loss on impairment of assets	1,667,000	0	0
Equity-based compensation	605,000	873,000	727,000
Changes in assets and liabilities:	'	'	'
Accounts receivable	7,441,000	6,465,000	-7,253,000
Inventories	163,000	-3,114,000	6,000
Advance royalties	-1,517,000	-1,687,000	-905,000
Prepaid expenses and other assets	-1,395,000	1,341,000	-115,000
Accounts payable	-2,036,000	-5,540,000	4,435,000
Accrued expenses and other liabilities	-135,000	6,497,000	-643,000
Asset retirement obligations	-2,240,000	-1,108,000	-4,722,000
Postretirement benefits	318,000	476,000	731,000
Net cash provided by operating activities	51,730,000	79,744,000	66,916,000
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'	'
Additions to property, plant, and equipment	-54,522,000	-61,772,000	-91,856,000
Proceeds from sales/recoveries of property, plant, and equipment	12,489,000	5,479,000	3,415,000
Proceeds from sale of coal properties and related assets and liabilities	'	'	20,000,000
Principal payments received on notes receivable	'	11,945,000	5,780,000
Cash paid from issuance of notes receivable	-205,000	-11,945,000	-5,780,000
Changes in restricted cash	1,079,000	3,000	34,000
Investment in unconsolidated affiliates	-2,749,000	-2,114,000	'
Acquisition of coal companies and other properties	'	'	-119,617,000
Net cash used in investing activities	-43,908,000	-58,404,000	-188,024,000
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'	'
Borrowings on line of credit	185,300,000	212,300,000	338,200,000
Repayments on line of credit	-175,510,000	-192,050,000	-229,670,000
Proceeds from issuance of long-term debt	'	2,973,000	1,379,000
Repayments on long-term debt	-2,350,000	-2,994,000	-3,550,000
Payments on debt issuance costs	-980,000	'	-3,758,000
Proceeds from issuance of common units, net of underwriting costs	14,788,000	'	66,916,000
Payment of offering costs	-214,000	-7,000	-569,000
Net settlement of withholding taxes on employee unit awards vesting	-85,000	-145,000	-281,000
General partner's contributions	330,000	13,000	1,450,000
Distributions to unitholders	-29,139,000	-41,418,000	-48,636,000
Net cash (used in) provided by financing activities	-7,860,000	-21,328,000	121,481,000
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	-38,000	12,000	373,000
CASH AND CASH EQUIVALENTS-Beginning of period	461,000	449,000	76,000
CASH AND CASH EQUIVALENTS-End of period	$423,000	$461,000	$449,000

Organization_And_Basis_Of_Pres

Organization And Basis Of Presentation	12 Months Ended
Organization And Basis Of Presentation	Dec. 31, 2013
Organization And Basis Of Presentation [Abstract]	'
Organization And Basis Of Presentation	'
	1. ORGANIZATION AND BASIS OF PRESENTATION
	Organization—Rhino Resource Partners LP and subsidiaries (the “Partnership”) is a Delaware limited partnership formed on April 19, 2010 to acquire Rhino Energy LLC (the “Predecessor” or the “Operating Company”). The Partnership had no operations during the period from April 19, 2010 (date of inception) to October 5, 2010 (the consummation of the initial public offering (“IPO”) date of the Partnership). The Operating Company and its wholly owned subsidiaries produce and market coal from surface and underground mines in Kentucky, Ohio, West Virginia and Utah. The Partnership also had one underground mine located in Colorado that was permanently idled at the end of 2013 (see Note 6 for further discussion). The majority of the Partnership’s sales are made to electric utilities and other coal-related organizations in the United States. In addition to operating coal properties, the Partnership manages and leases coal properties and collects royalties from such management and leasing activities. In addition to the Partnership’s coal operations, the Partnership has invested in oil and natural gas mineral rights and operations that began to generate revenues in early 2012.
	Initial Public Offering
	On October 5, 2010, Rhino Resource Partners LP completed its IPO of 3,244,000 common units, representing limited partner interests in the Partnership, at a price of $20.50 per common unit. Net proceeds from the offering were approximately $58.3 million, after deducting underwriting discounts and offering expenses of $8.2 million. The Partnership used the net proceeds from this offering, and a related capital contribution by Rhino GP LLC, the Partnership’s general partner (the “General Partner”) of approximately $10.4 million, to repay approximately $69.4 million of outstanding indebtedness under the Operating Company’s credit facility. These net proceeds do not include $9.3 million that was used to reimburse affiliates of the Partnership’s sponsor, Wexford Capital LP (“Wexford Capital”), for capital expenditures incurred with respect to the assets contributed to the Partnership in connection with the offering. In connection with the closing of the IPO, the owners of the Operating Company contributed their membership interests in the Operating Company to the Partnership, and the Partnership issued 12,397,000 subordinated units representing limited partner interests in the Partnership and 9,153,000 common units to Rhino Energy Holdings LLC, an affiliate of Wexford Capital, and issued incentive distribution rights to the General Partner. Upon the closing of the IPO, and as required by the Operating Company’s credit agreement by and among the Operating Company, as borrower, and its subsidiaries as guarantors, and PNC Bank, National Association, as agent, and the other lenders thereto (as amended from time to time, the “Credit Agreement”), the Partnership pledged 100% of the membership interests in the Operating Company to the agent on behalf of itself and the other lenders to secure the Operating Company’s obligations under the Credit Agreement.
	Follow-on Offerings
	On July 18, 2011, the Partnership completed a public offering of 2,875,000 common units, representing limited partner interests in the Partnership, at a price of $24.50 per common unit. Of the common units issued, 375,000 units were issued in connection with the exercise of the underwriters’ option to purchase additional units. Net proceeds from the offering were approximately $66.4 million, after deducting underwriting discounts and offering expenses of approximately $4.1 million. The Partnership used the net proceeds from this offering, and a related capital contribution by the General Partner of approximately $1.4 million, to repay approximately $67.8 million of outstanding indebtedness under the Partnership’s credit facility.
	On September 13, 2013, the Partnership completed a public offering of 1,265,000 common units, representing limited partner interests in the Partnership, at a price of $12.30 per common unit. Of the common units issued, 165,000 units were issued in connection with the exercise of the underwriter’s option to purchase additional units. Net proceeds from the offering were approximately $14.6 million, after deducting underwriting discounts and offering expenses of approximately $1.0 million. The Partnership used the net proceeds from this offering, and a related capital contribution by the General Partner of approximately $0.3 million, to repay approximately $14.9 million of outstanding indebtedness under the Partnership’s credit facility.
	Basis of Presentation and Principles of Consolidation—The accompanying consolidated financial statements include the accounts of Rhino Resource Partners LP and its subsidiaries. Intercompany transactions and balances have been eliminated in consolidation.

Summary_Of_Significant_Account

Summary Of Significant Accounting Policies And General	12 Months Ended
Summary Of Significant Accounting Policies And General	Dec. 31, 2013
Summary Of Significant Accounting Policies And General [Abstract]	'
Summary Of Significant Accounting Policies And General	'
	2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND GENERAL
	Company Environment and Risk Factors. The Partnership, in the course of its business activities, is exposed to a number of risks including: fluctuating market conditions of coal, truck and rail transportation, fuel costs, changing government regulations, unexpected maintenance and equipment failure, employee benefits cost control, changes in estimates of proven and probable coal reserves, as well as the ability of the Partnership to maintain adequate financing, necessary mining permits and control of sufficient recoverable coal properties. In addition, adverse weather and geological conditions may increase mining costs, sometimes substantially.
	Concentrations of Credit Risk. See Note 17 for discussion of major customers. The Partnership does not require collateral or other security on accounts receivable. The credit risk is controlled through credit approvals and monitoring procedures.
	Cash and Cash Equivalents. The Partnership considers all highly liquid investments purchased with original maturities of three months or less to be cash equivalents.
	Inventories. Inventories are stated at the lower of cost, based on a three month rolling average, or market. Inventories primarily consist of coal contained in stockpiles.
	Advance Royalties. The Partnership is required, under certain royalty lease agreements, to make minimum royalty payments whether or not mining activity is being performed on the leased property. These minimum payments may be recoupable once mining begins on the leased property. The Partnership capitalizes the recoupable minimum royalty payments and amortizes the deferred costs once mining activities begin on the units-of-production method or expenses the deferred costs when the Partnership has ceased mining or has made a decision not to mine on such property.
	Note Receivable. At various times during 2012, the Partnership loaned to Rhino Eastern LLC (“Rhino Eastern”), a joint venture with an affiliate of Patriot Coal Corporation (“Patriot”), approximately $11.9 million that was recorded as notes receivable, which bear interest at a fixed rate of 10%. The notes were fully repaid as of December 31, 2012. The Partnership did not provide any loans to Rhino Eastern during 2013.
	During 2013, the Partnership provided a loan based upon its ownership share to Muskie Proppant LLC (“Muskie”) in the amount of $0.2 million that remained outstanding as of December 31, 2013. Muskie is a joint venture established in 2012 with affiliates of Wexford Capital, which was formed to provide sand for fracking operations to drillers in the Utica Shale region and other oil and natural gas basins in the United States. The note bears interest at a rate equal to the lesser of (a) the prime interest rate plus 2.5% per annum, or (b) the maximum rate of interest permitted by applicable law.
	Property, Plant and Equipment. Property, plant, and equipment, including coal properties, oil and natural gas properties, mine development costs and construction costs, are recorded at cost, which includes construction overhead and interest, where applicable. Expenditures for major renewals and betterments are capitalized, while expenditures for maintenance and repairs are expensed as incurred. Mining and other equipment and related facilities are depreciated using the straight-line method based upon the shorter of estimated useful lives of the assets or the estimated life of each mine. Coal properties, as well as oil and natural gas properties, are depleted using the units-of-production method, based on estimated proven and probable reserves. Mine development costs are amortized using the units-of-production method, based on estimated proven and probable reserves. The Partnership assumes zero salvage values for its property, plant and equipment when depreciation and amortization are calculated. Gains or losses arising from sales or retirements are included in current operations.
	Stripping costs incurred in the production phase of a mine for the removal of overburden or waste materials for the purpose of obtaining access to coal that will be extracted are variable production costs that are included in the cost of inventory produced and extracted during the period the stripping costs are incurred. The Partnership defines a surface mine as a location where the Partnership utilizes operating assets necessary to extract coal, with the geographic boundary determined by property control, permit boundaries, and/or economic threshold limits. Multiple pits that share common infrastructure and processing equipment may be located within a single surface mine boundary, which can cover separate coal seams that typically are recovered incrementally as the overburden depth increases. In accordance with the accounting guidance for extractive mining activities, the Partnership defines a mine in production as one from which saleable minerals have begun to be extracted (produced) from an ore body, regardless of the level of production; however, the production phase does not commence with the removal of de minimis saleable mineral material that occurs in conjunction with the removal of overburden or waste material for the purpose of obtaining access to an ore body. The Partnership capitalizes only the development cost of the first pit at a mine site that may include multiple pits.
	For the Partnership’s oil and natural gas investments, the Partnership uses the full cost method of accounting for oil and natural gas operations. Accordingly, all costs, including nonproductive costs and certain general and administrative costs directly associated with acquisition, exploration and development of oil and natural gas properties, are capitalized. Under the full cost method of accounting, the Partnership is required to perform a ceiling test each quarter. The test determines a limit, or cost center ceiling, on the book value of the oil and natural gas properties. Net capitalized costs are limited to the lower of unamortized cost or the cost center ceiling. The cost center ceiling is defined as the sum of (a) estimated future net revenues, discounted at 10% per annum, from proved reserves, based on the 12-month unweighted average of the first-day-of-the-month price during the applicable year, excluding the estimated abandonment costs for properties with asset retirement obligations recorded on the balance sheet, (b) the cost of properties not being amortized, if any, and (c) the lower of cost or market value of unproved properties included in the cost being amortized. If the net book value exceeds the ceiling, an impairment or noncash writedown is required. Such capitalized costs, including the estimated future development costs and site remediation costs of proved undeveloped properties are depleted by an equivalent units-of-production method, converting gas to barrels at the ratio of six Mcf of natural gas to one barrel of oil. No gain or loss is recognized upon the disposal of oil and natural gas properties, unless such dispositions significantly alter the relationship between capitalized costs and proven oil and natural gas reserves. Oil and natural gas properties not subject to amortization are detailed in Note 5. These costs are reviewed quarterly by the Partnership for impairment. If impairment has occurred, the portion of cost in excess of the current value is transferred to the cost of oil and natural gas properties subject to amortization. Factors considered by the Partnership in its impairment assessment include drilling results by the operators on the Partnership’s oil and natural gas properties, the terms of oil and natural gas leases not held by production, and available funds for exploration and development.
	Asset Impairments for Coal Properties, Mine Development Costs and Other Coal Mining Equipment and Related Facilities. The Partnership follows the accounting guidance on the impairment or disposal of property, plant and equipment for its coal mining assets, which requires that projected future cash flows from use and disposition of assets be compared with the carrying amounts of those assets when potential impairment is indicated. When the sum of projected undiscounted cash flows is less than the carrying amount, impairment losses are recognized. In determining such impairment losses, the Partnership must determine the fair value for the coal mining assets in question in accordance with the applicable fair value accounting guidance. Once the fair value is determined, the appropriate impairment loss must be recorded as the difference between the carrying amount of the coal mining assets and their respective fair values. Also, in certain situations, expected mine lives are shortened because of changes to planned operations or changes in coal reserve estimates. When that occurs and it is determined that the mine’s underlying costs are not recoverable in the future, reclamation and mine closing obligations are accelerated and the mine closing accrual is increased accordingly. To the extent it is determined that coal asset carrying values will not be recoverable during a shorter mine life, a provision for such impairment is recognized. During 2013, the Partnership recorded an impairment loss of $1.7 million related to its McClane Canyon mining complex in Colorado. See Note 6 for more information on this impairment loss. There were no impairment losses recorded during the years ended December 31, 2012 and 2011.
	Debt Issuance Costs. Debt issuance costs reflect fees incurred to obtain financing and are amortized (included in interest expense) using the effective interest method over the life of the related debt. Debt issuance costs are included in other non-current assets.
	Asset Retirement Obligations. The accounting guidance for asset retirement obligations addresses asset retirement obligations that result from the acquisition, construction or normal operation of long-lived assets. This guidance requires companies to recognize asset retirement obligations at fair value when the liability is incurred or acquired. Upon initial recognition of a liability, an amount equal to the liability is capitalized as part of the related long-lived asset and allocated to expense over the useful life of the asset. The Partnership has recorded the asset retirement costs for its mining operations in coal properties. In addition, the Partnership has recorded asset retirement costs for its proportionate share of its oil and natural gas investments, which are included in oil and natural gas properties.
	The Partnership estimates its future cost requirements for reclamation of land where it has conducted surface and underground mining operations, based on its interpretation of the technical standards of regulations enacted by the U.S. Office of Surface Mining, as well as state regulations. These costs relate to reclaiming the pit and support acreage at surface mines and sealing portals at underground mines. Other reclamation costs are related to refuse and slurry ponds, as well as holding and related termination/exit costs.
	The Partnership expenses contemporaneous reclamation which is performed prior to final mine closure. The establishment of the end of mine reclamation and closure liability is based upon permit requirements and requires significant estimates and assumptions, principally associated with regulatory requirements, costs and recoverable coal reserves. Annually, the Partnership reviews its end of mine reclamation and closure liability and makes necessary adjustments, including mine plan and permit changes and revisions to cost and production levels to optimize mining and reclamation efficiency. When a mine life is shortened due to a change in the mine plan, mine closing obligations are accelerated, the related accrual is increased and the related asset is reviewed for impairment, accordingly.
	The adjustments to the liability from annual recosting reflect changes in expected timing, cash flow and the discount rate used in the present value calculation of the liability. Each respective year includes a range of discount rates that are dependent upon the timing of the cash flows of the specific obligations. Changes in the Partnership’s asset retirement obligations for the year ended December 31, 2013 were calculated with discount rates that ranged from 2.3% to 5.6%. Changes in the asset retirement obligations for the year ended December 31, 2012 were calculated with discount rates that ranged from 3.2% to 5.3%. Changes in the asset retirement obligations for the year ended December 31, 2011 were calculated with discount rates that ranged from 4.2% to 7.0%. The discount rates changed in each respective year due to changes in applicable market indicators that are used to arrive at an appropriate discount rate. Other recosting adjustments to the liability are made annually based on inflationary cost increases or decreases and changes in the expected operating periods of the mines. The related inflation rate utilized in the recosting adjustments was 2.3 % for 2013 and 2012, and 2.5% for 2011.
	Workers’ Compensation Benefits. Certain of the Partnership’s subsidiaries are liable under federal and state laws to pay workers’ compensation and coal workers’ pneumoconiosis (“black lung”) benefits to eligible employees, former employees and their dependents. The Partnership currently utilizes an insurance program and state workers’ compensation fund participation to secure its on-going obligations depending on the location of the operation. Premium expense for workers’ compensation benefits is recognized in the period in which the related insurance coverage is provided.
	The Partnership’s black lung benefit liability is calculated using the service cost method that considers the calculation of the actuarial present value of the estimated black lung obligation. The actuarial calculations using the service cost method for the Partnership’s black lung benefit liability are based on numerous assumptions including disability incidence, medical costs, mortality, death benefits, dependents and interest rates.
	In addition, the Partnership’s liability for traumatic workers’ compensation injury claims is the estimated present value of current workers' compensation benefits, based on actuarial estimates. The actuarial estimates for the Partnership’s workers’ compensation liability are based on numerous assumptions including claim development patterns, mortality, medical costs and interest rates.
	See Note 12 for more information on the Partnership’s workers’ compensation and black lung liabilities and expense.
	Revenue Recognition. Most of the Partnership’s revenues are generated under long-term coal sales contracts with electric utilities, industrial companies or other coal-related organizations, primarily in the eastern United States. Revenue is recognized and recorded when shipment or delivery to the customer has occurred, prices are fixed or determinable and the title or risk of loss has passed in accordance with the terms of the sales agreement. Under the typical terms of these agreements, risk of loss transfers to the customers at the mine or port, when the coal is loaded on the rail, barge, truck or other transportation source that delivers coal to its destination. Advance payments received are deferred and recognized in revenue as coal is shipped and title has passed.
	Coal sales revenues also result from the sale of brokered coal produced by others. The revenues related to brokered coal sales are included in coal sales revenues on a gross basis and the corresponding cost of the coal from the supplier is recorded in cost of coal sales in accordance with the revenue recognition accounting guidance on principal agent considerations.
	Freight and handling costs paid directly to third‑party carriers and invoiced to coal customers are recorded as freight and handling costs and freight and handling revenues, respectively.
	Other revenues generally consist of coal royalty revenues, limestone sales, coal handling and processing, oil and natural gas revenues, rebates and rental income. Coal royalty revenues are recognized on the basis of tons of coal sold by the Partnership’s lessees and the corresponding gross revenues from those sales. The leases are based on (1) minimum monthly or annual payments, (2) a minimum dollar royalty per ton and/or a percentage of the gross sales price, or (3) a combination of both. Coal royalty revenues are recorded from royalty reports submitted by the lessee, which are reconciled and subject to audit by the Partnership. Most of the Partnership’s lessees are required to make minimum monthly or annual royalty payments that are recoupable over certain time periods, generally two years. If tonnage royalty revenues do not meet the required minimum amount, the difference is paid as a deficiency. These deficiency payments received are recognized as an unearned revenue liability because they are generally recoupable over certain time periods. When a lessee recoups a deficiency payment through production, the recouped amount is deducted from the unearned revenue liability and added to revenue attributable to the coal royalty revenue in the current period. If a lessee does not recoup a deficiency paid during the allocated time period, the recoupment right lost becomes revenue in the current period and is deducted from the liability.
	With respect to other revenues recognized in situations unrelated to the shipment of coal or coal royalties, the Partnership carefully reviews the facts and circumstances of each transaction and does not recognize revenue until the following criteria are met: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the seller’s price to the buyer is fixed or determinable and collectibility is reasonably assured. Advance payments received are deferred and recognized in revenue when earned.
	Equity‑Based Compensation. The Partnership applies the provisions of ASC Topic 718 to account for any unit awards granted to employees or directors. This guidance requires that all share‑based payments to employees or directors, including grants of stock options, be recognized in the financial statements based on their fair value. The General Partner has currently granted restricted units and phantom units to directors and certain employees of the General Partner and Partnership that contain only a service condition. The fair value of each restricted unit and phantom unit award was calculated using the closing price of the Partnership’s common units on the date of grant.
	With the vesting of the first portion of the employees’ awards in early April 2011, the Compensation Committee of the board of directors of the General Partner elected to pay some of the awards in cash or a combination of cash and common units. This election was a change in policy from December 31, 2010 since management had previously planned to settle all employee awards with units upon vesting as per the grant agreements. This policy change resulted in a modification of all employee awards from equity to liability classification as of March 31, 2011 and all new awards granted thereafter. Thus, the employee awards are required to be marked-to-market each reporting period until they are vested. Restricted unit awards granted to directors of the General Partner are considered nonemployee equity‑based awards since the directors are not elected by unitholders. Thus, these director awards are also required to be marked-to-market each reporting period until they are vested. Expense related to unit awards is recorded in the selling, general and administrative line of the Partnership’s consolidated statements of operations and comprehensive income.
	Derivative Financial Instruments. On occasion, the Partnership uses diesel fuel forward contracts to manage the risk of fluctuations in the cost of diesel fuel. The Partnership’s diesel fuel forward contracts qualify for the normal purchase normal sale (“NPNS”) exception prescribed by the accounting guidance on derivatives and hedging, based on management’s intent and ability to take physical delivery of the diesel fuel. The Partnership did not have any diesel fuel forward contracts as of December 31, 2013.
	Investment in Joint Ventures. Investments in joint ventures are accounted for using the consolidation, equity method or cost basis depending upon the level of ownership, the Partnership’s ability to exercise significant influence over the operating and financial policies of the investee and whether the Partnership is determined to be the primary beneficiary of a variable interest entity. Equity investments are recorded at original cost and adjusted periodically to recognize the Partnership’s proportionate share of the investees’ net income or losses after the date of investment. Any losses from the Partnership’s equity method investment are absorbed by the Partnership based upon its proportionate ownership percentage. If losses are incurred that exceed the Partnership’s investment in the equity method entity, then the Partnership must continue to record its proportionate share of losses in excess of its investment. Investments are written down only when there is clear evidence that a decline in value that is other than temporary has occurred.
	In May 2008, the Operating Company entered into a joint venture, Rhino Eastern, with an affiliate of Patriot to acquire the Eagle mining complex. To initially capitalize the Rhino Eastern joint venture, the Operating Company contributed approximately $16.1 million for a 51% ownership interest in the joint venture and accounts for the investment in Rhino Eastern and its results of operations under the equity method. The Partnership considers the operations of this entity to comprise a reporting segment (“Eastern Met”) and has provided additional detail related to this operation in Note 21, “Segment Information.”
	In determining that the Partnership was not the primary beneficiary of the variable interest entity for the years ended December 31, 2013, 2012 and 2011, the Partnership performed a qualitative and quantitative analysis based on the controlling economic interests of the Rhino Eastern joint venture. This included an analysis of the expected economic contributions of the joint venture. The Partnership concluded that it is not the primary beneficiary of Rhino Eastern primarily because of certain contractual arrangements by the joint venture with Patriot and the fact that the Rhino Eastern joint venture is managed by a committee of an equal number of representatives from Patriot and us. Mandatory pro rata additional contributions not to exceed $10 million in the aggregate could be required of the joint venture partners which the Partnership would be obligated to fund based upon its 51% ownership interest.
	As of December 31, 2013 and 2012, the Partnership has recorded its equity method investment of $19.4 million and $21.4 million, respectively, in the Rhino Eastern joint venture as a long-term asset. During 2013, the Partnership contributed additional capital based upon its ownership share to the Rhino Eastern joint venture in the amount of $2.3 million. The Partnership did not contribute any additional capital during 2012. As disclosed in Note 19 “Related Party and Affiliate Transactions”, during 2012 and 2011, the Partnership provided loans to Rhino Eastern totaling approximately $11.9 million and $5.8 million, respectively, which were fully repaid as of December 31, 2012 and 2011.
	On July 9, 2012, Patriot filed for Chapter 11 bankruptcy protection. Patriot successfully exited bankruptcy in December 2013 and normal operations have continued at the Rhino Eastern joint venture.
	In March 2012, the Partnership made an initial investment of approximately $0.1 million in a new joint venture, Timber Wolf Terminals LLC (“Timber Wolf”), with affiliates of Wexford. Timber Wolf was formed to construct and operate a condensate river terminal that will provide barge trans-loading services for parties conducting activities in the Utica Shale region of eastern Ohio. The initial investment was the Partnership’s proportionate minority ownership share to purchase land for the construction site of the condensate river terminal. Timber Wolf had no operating activities during the years ended December 31, 2013 and 2012 and the Partnership will initially include any operating activities of Timber Wolf in its Other category for segment reporting purposes.
	In December 2012, the Partnership made an initial investment of approximately $2.0 million in a new joint venture, Muskie Proppant LLC, with affiliates of Wexford Capital. Muskie was formed to provide sand for fracking operations to drillers in the Utica Shale region and other oil and natural gas basins in the U.S. During 2013, the Partnership contributed additional capital based upon its ownership share to the Muskie joint venture in the amount of $0.5 million. As disclosed in Note 19 “Related Party and Affiliate Transactions”, during 2013 the Partnership provided a loan to Muskie totaling approximately $0.2 million which remained outstanding as of December 31, 2013. In addition, the Partnership recorded its proportionate portion of operating losses for 2013 and 2012, approximately $0.5 million and $0.3 million, respectively, for Muskie. As of December 31, 2013 and 2012, the Partnership has recorded its equity method investment of $1.8 million and $1.7 million, respectively, in the Muskie joint venture as a long-term asset. The Partnership initially included Muskie in its Other category for segment reporting purposes, but Muskie is included in the Partnership’s Oil and Natural Gas segment beginning with December 31, 2013 reporting. See Note 21 for information on the Partnership’s reportable segments.
	Income Taxes. The Partnership is considered a partnership for income tax purposes. Accordingly, the partners report the Partnership’s taxable income or loss on their individual tax returns.
	Loss Contingencies. In accordance with the guidance on accounting for contingencies, the Partnership records loss contingencies at such time that an unfavorable outcome becomes probable and the amount can be reasonably estimated. When the reasonable estimate is a range, the recorded loss is the best estimate within the range. If no amount in the range is a better estimate than any other amount, the minimum amount of the range is recorded. The Partnership discloses information concerning loss contingencies for which an unfavorable outcome is probable. See Note 15, “Commitments and Contingencies,” for a discussion of such matters.
	Management’s Use of Estimates. The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements as well as the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	Recently Issued Accounting Standards. In February 2013, the FASB issued ASU No. 2013-02, “Comprehensive Income (Topic 220) Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”. This ASU requires preparers to report, in one place, information about reclassifications out of accumulated other comprehensive income (“AOCI”). The ASU also requires companies to report changes in AOCI balances. For significant items reclassified out of AOCI to net income in their entirety in the same reporting period, reporting (either on the face of the statement where net income is presented or in the notes) is required about the effect of the reclassifications on the respective line items in the statement where net income is presented. For items that are not reclassified to net income in their entirety in the same reporting period, a cross reference to other disclosures currently required under U.S. GAAP (e.g., pension amounts that are included in inventory) is required in the notes. The above information must be presented in one place (parenthetically on the face of the financial statements by income statement line item or in a note). Public companies must provide the information required by the ASU (e.g., changes in AOCI balances and reclassifications out of AOCI) in interim and annual periods. For public companies, the ASU is effective for fiscal years and interim periods within those years beginning after 15 December 2012, or the first quarter of 2013 for calendar-year companies. The Partnership has included the required disclosures of ASU 2013-02 in this Report on Form 10-K and this ASU did not have a material effect on the Partnership.

Subsequent_Events

Subsequent Events	12 Months Ended
Subsequent Events	Dec. 31, 2013
Subsequent Events [Abstract]	'
Subsequent Events	'
	3. SUBSEQUENT EVENTS
	On January 21, 2014, the Partnership announced a cash distribution of $0.445 per common unit, or $1.78 per unit on an annualized basis. This distribution was paid on February 14, 2014 to all common unit holders of record as of the close of business on January 31, 2014. No distributions were paid on the subordinated units.
	In January 2014, the Partnership received approximately $8.4 million of net proceeds from the sale by Blackhawk Midstream LLC (“Blackhawk”) of its equity interest in two entities, Ohio Gathering Company, LLC and Ohio Condensate Company, LLC, to Summit Midstream Partners, LLC. As part of the joint operating agreement for the Utica Shale investment completed between the Partnership, Gulfport Energy (“Gulfport”) and an affiliate of Wexford Capital (discussed further in Note 4), the Partnership had the right to approximately 5% of the proceeds of the sale by Blackhawk. The Partnership has not completed its accounting analysis for the net proceeds received in this transaction.
	In February 2014, the Partnership signed a binding letter of intent with Gulfport to sell its entire Utica Shale interests for approximately $185 million. The transaction is expected to close by the end of March 2014 subject to customary closing conditions. The Partnership has not completed its accounting analysis for the net proceeds received in this transaction.
	Retrospective Adjustment for Discontinued Operations
	In March 2014, the Partnership completed a purchase and sale agreement (the “Purchase Agreement”) with Gulfport to sell the Partnership’s oil and gas properties in the Utica Shale region for approximately $184.0 million (the “Purchase Price”). The Purchase Agreement was effective as of January 1, 2014 and the Purchase Price was adjusted for any unsettled expenditures made and/or proceeds received from the Partnership’s portion of its Utica Shale properties prior to the effective date. The Partnership’s consolidated statements of operations and comprehensive income have been retrospectively adjusted to reclassify the Partnership’s portion of its Utica Shale operations to discontinued operations for the years ended December 31, 2013 and 2012. The Partnership’s Utica Shale investment did not have any operating activity during the year ended December 31, 2011. The net effect of the reclassification represents a decrease of $1.3 million, or 13.9%, and $0.1 million, or 0.2%, in the Partnership’s previously reported income from continuing operations for the years ended December 31, 2013 and 2012, respectively. The Partnership also reclassified certain current assets, non-current assets, current liabilities and non-current liabilities to “held for sale” categories on the consolidated statements of financial position for the years ended December 31, 2013 and 2012. There was no effect on the Partnership’s previously reported net income, financial condition, or cash flows.

Business_Combinations_And_Othe

Business Combinations And Other Acquisitions	12 Months Ended
Business Combinations And Other Acquisitions	Dec. 31, 2013
Business Combinations And Other Acquisitions [Abstract]	'
Business Combinations And Other Acquisitions	'
	4. BUSINESS COMBINATIONS AND OTHER ACQUISITIONS
	Acquisition of The Elk Horn Coal Company, LLC
	In June 2011, the Partnership completed the acquisition of 100% of the ownership interests in The Elk Horn Coal Company, LLC (“Elk Horn”) for approximately $119.7 million in cash consideration, or approximately $119.6 million net of cash acquired (referred to as the “Elk Horn Acquisition”). Elk Horn is primarily a coal leasing company that owns or controls coal reserves and non-reserve coal deposits and surface acreage in eastern Kentucky. The Elk Horn Acquisition was initially funded with borrowings under the Partnership’s credit facility. The Partnership completed a public offering of common units in July 2011 that provided proceeds the Partnership used to repay existing indebtedness on its credit facility that was incurred from the Elk Horn acquisition. The following table summarizes the assets acquired and liabilities assumed as of the acquisition date:



		(in thousands)
	Cash	$ 58
	Accounts receivable	2,619
	Prepaid expenses and other	94
	Property, plant and equipment	7,466
	Mine development costs	3,000
	Coal properties	111,647
	Intangible assets	654
	Other non-current assets	1,112
	Accounts payable	-79
	Deferred revenues	-2,499
	Accrued expenses and other	-1,691
	Asset retirement obligations	-2,707
	Net assets acquired	$ 119,674
	Total consideration	$ 119,674

	Although the responsibility of valuation remains with the Partnership’s management, the determination of the fair values of the various assets and liabilities acquired were based in part upon studies conducted by third‑party professionals with experience in the appropriate subject matter. The studies related to the value of the property, plant and equipment, coal properties, intangible assets acquired and asset retirement obligations. The table above reflects the allocation of the purchase price to the fair value of the assets acquired and liabilities assumed in the Elk Horn Acquisition, which resulted in no recognition of goodwill or gain on the acquisition. The Partnership’s consolidated statements of operations and comprehensive income do not include revenue, costs or net income from Elk Horn prior to June 10, 2011, the effective date of the acquisition. The post-acquisition revenue of Elk Horn that is included in the Partnership’s results was approximately $13.0 million for the year ended December 31, 2011. The post-acquisition net income of Elk Horn that is included in the Partnership’s results was approximately $7.7 million for the year ended December 31, 2011.
	The following table presents selected unaudited pro forma financial information for the year ended December 31, 2011. The pro forma information was prepared using Elk Horn’s historical financial data and also reflects adjustments based upon assumptions by the Partnership’s management to give effect for certain pro forma items that are directly attributable to the acquisition. These pro forma adjustment items include increased depletion expense related to the step-up in basis for the mineral assets acquired and increased interest expense from borrowings incurred to fund the acquisition. The pro forma adjustments for interest expense and earnings per unit reflect the net amount of the additional borrowings incurred by the Partnership in June 2011 to initially fund the acquisition that were partially offset by proceeds from common units issued in a public offering completed in July 2011. Supplemental pro forma revenue, net earnings and earnings per unit disclosures are as follows.


		Year ended
		31-Dec-11
	Revenues:	(in thousands)
	As reported	$ 367,221
	Pro forma adjustments	9,477
	Pro forma revenues	$ 376,698

	Net Income:
	As reported	$ 38,071
	Pro forma adjustments	3,129
	Pro forma net income	$ 41,200

	Net income per limited partner unit, diluted:
	As reported	$ 1.43
	Pro forma adjustments	$ 0.03
	Pro forma net income per limited partner unit	$ 1.46

	Acquisition of Oil and Gas Mineral Rights
	Beginning in 2011, the Partnership and an affiliate of Wexford Capital participated with Gulfport, a publicly traded company, to acquire interests in a portfolio of oil and natural gas leases in the Utica Shale. During the year ended December 31, 2011, the Partnership completed the acquisitions of interests in a portfolio of leases in the Utica Shale region of eastern Ohio, which consisted of a 10.8% net interest in approximately 80,000 gross acres. During the third quarter of 2012, the Partnership completed an exchange of its initial 10.8% position for a pro rata interest in 125,000 gross acres under lease by Gulfport and an affiliate of Wexford Capital. The non-cash transaction was an exchange of the Partnership’s operating interest for the operating interest owned by another party in order to diversify the Partnership’s risk in its oil and natural gas investment. Thus, the Partnership determined that the non-cash exchange of the Partnership’s ownership interest in the Utica acreage did not result in any gain or loss. Also during the third quarter of 2012, the Partnership’s position was adjusted to a 5% net interest in the 125,000 gross acres, or approximately 6,250 net acres. As of December 31, 2013, the Partnership had invested approximately $31.1 million for its pro rata interest in the Utica Shale portfolio of oil and natural gas leases, which consisted of a 5% interest in a total of approximately 152,300 gross acres, or 7,615 net acres. In addition, per the joint operating agreement completed between the Partnership, Gulfport and an affiliate of Wexford Capital, the Partnership has funded its proportionate share of drilling costs to Gulfport for wells being drilled on the Partnership’s acreage. For the years ended December 31, 2013 and 2012, the Partnership has funded approximately $23.3 million and $5.3 million, respectively, of drilling costs that are included in Oil and natural gas properties in the Partnership’s consolidated statements of financial position. For the year ended December 31, 2013, the Partnership recorded revenue from its Utica Shale investment of approximately $5.6 million in Other revenue and approximately $2.6 million of depletion expense in the Partnership’s consolidated statements of operations and comprehensive income. The Partnership recognized an immaterial amount of revenue and depletion expense from its Utica Shale investment for the year ended December 31, 2012. As described in Note 3, in February 2014, the Partnership signed a binding letter of intent to sell its entire Utica Shale joint interest investment to Gulfport for $185 million, subject to customary closing conditions.
	In March 2012, the Partnership completed a lease agreement with a third party for approximately 1,232 acres that the Partnership previously owned in the Utica Shale region in Harrison County, Ohio. The lease agreement is for an initial five year term with an optional three year renewal period and conveys rights to the third party to perform drilling and operating activities for producing oil, natural gas or other hydrocarbons. As part of the lease agreement, the third party agreed to pay the Partnership the sum of $6,000 per acre as a lease bonus, of which $0.5 million was paid at the signing of the lease agreement. An additional $6.9 million was paid in the second quarter of 2012 totaling approximately $7.4 million of lease bonus payments for the approximately 1,232 acres. In addition, the lease agreement stipulates that the third party shall pay the Partnership a 20% royalty based upon the gross proceeds received from the sale of oil and/or natural gas recovered from the leased property.
	The Partnership analyzed the lease agreement and determined that the lease bonus payments represented a conveyance of these oil and natural gas rights, and should be recognized as a component of the Partnership’s consolidated statements of operations. This determination was based upon the fact that that the lease agreement did not require the Partnership to perform any future obligations to perform or participate in drilling activities and the lease agreement did not result in any pooling of assets that would be used to perform any future drilling activities. In addition, the entire amount of the lease bonus was recognized as Other revenues since the Partnership’s business activities have historically included the leasing of mineral resources, including coal leasing, which have been recorded as Other revenues. For the year ended December 31, 2012, the Partnership recorded $7.4 million related to the initial lease bonus payments within Other revenues in the Partnership’s Northern Appalachia segment.
	In April 2013, the Partnership closed on an agreement with a third party to sell the 20% royalty interest on its owned 1,232 acres in the Utica Shale for approximately $10.5 million. The sale of the royalty interest resulted in a gain of approximately $10.5 million since the Partnership had no cost basis associated with the royalty interest. This gain is included on the (Gain) on sale/disposal of assets—net line of the Partnership’s consolidated statements of operations and comprehensive income.
	In September 2013, the Partnership closed on an agreement with a third party to sell the oil and natural gas mineral rights for approximately 57 acres the Partnership owns in the Utica Shale region in Harrison County, Ohio for approximately $0.6 million. The sale of this acreage resulted in a gain of approximately $0.6 million since the Partnership had no cost basis associated with this property. This gain is included on the (Gain) on sale/disposal of assets—net line of the Partnership’s consolidated statements of operations and comprehensive income.
	During the year ended December 31, 2011, the Partnership completed the acquisition of certain oil and natural gas mineral rights in the Cana Woodford region of western Oklahoma for a total purchase price of approximately $8.1 million. The Partnership recorded an immaterial amount of royalty revenue from its Cana Woodford investment during the years ended December 31, 2013 and 2012.
	Acquisition of Coal Property
	In May 2012, the Partnership completed the purchase of certain rights to coal leases and surface property located in Daviess and McLean counties in western Kentucky for approximately $1.5 million. In addition, the Partnership could potentially be required to pay an additional $3.0 million related to this acquisition if certain conditions are met. Of that amount, $2.0 million was initially recorded in Property, plant and equipment and Accrued expenses related to this acquisition since this additional amount related to the purchase of these assets was probable and estimable. The remaining $1.0 million in potential payments has not been recorded because the conditions requiring payment of this amount have not yet occurred.
	During the third quarter of 2012, the Partnership paid $1.6 million of the $2.0 million that was accrued related to the acquisition since the conditions requiring payment had been met. The remaining balance of $0.4 million was paid in the fourth quarter of 2013 since the conditions requiring payment had been met.
	The coal leases and property are estimated to contain approximately 32.6 million tons of proven and probable coal reserves as of December 31, 2013 that are contiguous to the Green River. The property was initially undeveloped, but fully permitted, and provides the Partnership with access to Illinois Basin coal that is adjacent to a navigable waterway, which could be exported to non-U.S. customers. The Partnership has commenced the construction of a new underground mining operation on this property with production targeted to begin in mid-2014.
	In August 2011, the Partnership purchased non-reserve coal deposits at its Sands Hill operation for approximately $2.5 million, which is estimated to include approximately 2.5 million tons of non-reserve coal deposits.
	In June 2011, the Partnership acquired approximately 32,600 acres and associated surface rights in Randolph and Upshur Counties, West Virginia for approximately $7.5 million. These development stage properties are unpermitted and contain no infrastructure. The property is estimated to contain approximately 8.2 million tons of proven and probable underground metallurgical coal reserves as of December 31, 2013.

Prepaid_Expenses_And_Other_Cur

Prepaid Expenses And Other Current Assets	12 Months Ended
	Dec. 31, 2013
Prepaid Expenses And Other Current Assets [Abstract]	'
Prepaid Expenses And Other Current Assets	'
	5. PREPAID EXPENSES AND OTHER CURRENT ASSETS
	Prepaid expenses and other current assets as of December 31, 2013 and 2012 consisted of the following:


		December 31,
		2013	2012
		(in thousands)
	Other prepaid expenses	$ 951	$ 767
	Prepaid insurance	1,958	1,895
	Prepaid leases	122	121
	Supply inventory	1,221	1,219
	Deposits	320	321
	Total	$ 4,572	$ 4,323

Property_Plant_And_Equipment

Property, Plant And Equipment	12 Months Ended
Property, Plant And Equipment	Dec. 31, 2013
Property, Plant And Equipment [Abstract]	'
Property, Plant And Equipment	'


	6. PROPERTY, PLANT AND EQUIPMENT
	Property, plant and equipment, including coal properties and mine development and construction costs, as of December 31, 2013 and 2012 are summarized by major classification as follows:


				December 31,
		Useful Lives		2013		2012
				(in thousands)
	Land and land improvements			$ 35,078		$ 34,978
	Mining and other equipment and related facilities	2 - 20 Years		302,114		297,615
	Mine development costs	1 - 15 Years		73,344		67,045
	Coal properties	1 - 15 Years		238,975		240,368
	Oil and natural gas properties			8,093		8,182
	Construction work in process			17,104		5,216
	Total			674,708		653,404
	Less accumulated depreciation, depletion and amortization			-249,718		-219,613
	Net			$ 424,990		$ 433,791
	The Partnership’s proportionate share of oil and natural gas properties not subject to amortization as of December 31, 2013 and 2012 are summarized as follows (Note: the Utica Shale oil and natural gas properties detailed below are reclassified within the non-current assets held for sale total included in the consolidated statements of financial position due to the sale of the Partnership’s Utica Shale assets as described in Note 3):


			December 31,
			2013		2012
			(in thousands)
	Acquisition costs		$ 30,430		$ 32,175
	Exploration costs		-		-
	Development costs		-		-
	Total		$ 30,430		$ 32,175
	Depreciation expense for mining and other equipment and related facilities, depletion expense for coal and oil and natural gas properties, amortization expense for mine development costs, amortization expense for intangible assets and amortization expense for asset retirement costs for the years ended December 31, 2013, 2012 and 2011 was as follows:


			Year Ended December 31,
			2013		2012		2011
			(in thousands)
	Depreciation expense-mining and other equipment and related facilities		$ 31,510		$ 32,685		$ 26,467
	Depletion expense for coal properties (1)		5,387		5,784		5,140
	Depletion expense for oil and natural gas properties		47		-		-
	Amortization expense for mine development costs		2,520		2,180		3,322
	Amortization expense for intangible assets		80		80		65
	Amortization expense for asset retirement costs		83		545		1,331
	Total		$ 39,627		$ 41,274		$ 36,325

	(1) Depletion expense for the Partnership’s Utica Shale oil and natural gas properties are reclassified to Income from discontinued operations line in the consolidated statements of operations and comprehensive income due to the sale of the Partnership’s Utica shale assets as described in Note 3.


	Sale of Land Surface Rights
	In December 2012, the Partnership completed the sale of the surface rights to approximately 134 acres located in Harrison County, Ohio for approximately $1.5 million. The Partnership recorded a gain of approximately $1.5 million related to this sale that is included on the (Gain) loss on sale/acquisition of assets, net line of the Partnership’s consolidated statements of operations and comprehensive income.
	Sale of Triad Operations
	In August 2012, the Partnership sold the operations and tangible assets of its roof bolt manufacturing company, Triad Roof Support Systems, LLC (“Triad”), to a third party for $0.5 million of cash consideration. As part of the sale, the Partnership retained the rights to certain intellectual property and entered into an exclusive license and option to purchase agreement for this intellectual property with the same third party for potential additional cash consideration. The Partnership has not recorded any portion of this additional consideration since this amount is contingent upon the third party determining the viability of the related intellectual property to their specifications. In connection with the purchase of Triad in 2009, the Partnership had recorded approximately $0.2 million of goodwill. Since the Partnership disposed of the entire operations and fixed assets of the Triad reporting unit, the goodwill was included in the carrying amount of the Triad reporting unit to determine the $0.2 million gain that was recorded on the sale of this reporting unit. This gain is included on the (Gain) on sale/disposal of assets, net line of the Partnership’s consolidated statements of operations and comprehensive income.
	Sale of Mining Assets
	In December 2012, the Partnership sold certain non-core mining assets located in Pike County, Kentucky to a third party for approximately $0.2 million. The transaction also extinguished certain liabilities related to the assets sold. In relation to the sale of these assets and extinguishment of liabilities, the Partnership recorded a gain of approximately $0.9 million, which was higher than the sales amount due to the extinguishment of the liabilities. This gain is included on the (Gain) on sale/disposal of assets, net line of the Partnership’s consolidated statements of operations and comprehensive income.
	In February 2012, the Partnership sold certain non-core mining assets located in Pike County, Kentucky to a third party for approximately $0.6 million. The transaction also extinguished certain liabilities related to the assets sold. In relation to the sale of these assets and extinguishment of liabilities, the Partnership recorded a gain of approximately $0.9 million, which was higher than the sales amount due to the extinguishment of the liabilities. This gain is included on the (Gain) on sale/disposal of assets, net line of the Partnership’s consolidated statements of operations and comprehensive income.
	In August 2011, the Partnership closed on an agreement to sell and assign certain non-core mining assets and related liabilities located in the Phelps, Kentucky area of the Partnership’s Tug River mining complex for $20 million. The mining assets included leasehold interests and permits to surface and mineral interests that included steam coal reserves and non-reserve coal deposits. Additionally, the sales agreement includes the potential for additional payments of approximately $8.75 million dependent upon the future issuance of certain permits and the commencement of mining activities by the purchaser. These contingent payments are being accounted for as gain contingencies and will be recognized in the future when and if the contingencies are resolved. The transaction also transfers certain liabilities related to the assets sold. In relation to the sale of these assets and transfer of liabilities, the Partnership recorded a gain of approximately $2.4 million, which is included on the (Gain) on sale/disposal of assets, net line of the Partnership’s consolidated statements of operations and comprehensive income.
	Long-Lived Asset Impairment
	During the fourth quarter of 2013, the Partnership’s management made a strategic decision to permanently close the mining operations at its McClane Canyon complex in Colorado. Since the McClane Canyon complex had been idled at the end of 2010, the Partnership had been actively marketing the coal from this complex to potential buyers, but had not been able to obtain suitable sales contracts. Due to the unfavorable long-term prospects for the coal market in the Colorado area and to avoid the ongoing costs that were being incurred to temporarily idle this complex, the Partnership’s management made the decision to permanently close this operation at the end of 2013. While a portion of the equipment from this operation was relocated to other operating locations, the Partnership incurred an impairment charge of approximately $1.7 million during 2013 related to specific property, plant and equipment, which is included on the Asset impairment loss line of the Partnership’s consolidated statements of operations and comprehensive income.

Goodwill_And_Intangible_Assets

Goodwill And Intangible Assets	12 Months Ended
Goodwill And Intangible Assets	Dec. 31, 2013
Goodwill And Intangible Assets [Abstract]	'
Goodwill And Intangible Assets	'
	7. GOODWILL AND INTANGIBLE ASSETS
	ASC Topic 350 addresses financial accounting and reporting for goodwill and other intangible assets subsequent to their acquisition. Under the provisions of ASC Topic 350, goodwill and other intangible assets with indefinite useful lives are not amortized but instead tested for impairment at least annually.
	As discussed in Note 6, the Partnership’s goodwill balance was reduced to zero as a result of the disposal of the Partnership’s Triad operations that were sold during the third quarter of 2012.
	Intangible assets of the Partnership as of December 31, 2013 consisted of the following:


		Gross		Net
		Carrying	Accumulated	Carrying
	Intangible Asset	Amount	Amortization	Amount
		(in thousands)
	Patent	$ 728	$ 207	$ 521
	Developed Technology	78	22	56
	Trade Name	184	23	161
	Customer List	470	60	410
	Total	$ 1,460	$ 312	$ 1,148

	Intangible assets of the Partnership as of December 31, 2012 consisted of the following:


		Gross		Net
		Carrying	Accumulated	Carrying
	Intangible Asset	Amount	Amortization	Amount
		(in thousands)
	Patent	$ 728	$ 164	$ 564
	Developed Technology	78	18	60
	Trade Name	184	14	170
	Customer List	470	36	434
	Total	$ 1,460	$ 232	$ 1,228
	The Partnership considers the patent and developed technology intangible assets to have a useful life of seventeen years.
	In connection with the Elk Horn Acquisition, the Partnership recognized an intangible asset for the trade name valued at $184,000 and a customer list intangible asset valued at $470,000 during 2011. The trade name and customer list intangible assets recognized in the Elk Horn Acquisition do not have any residual value and do not have any renewal or extension terms. The Partnership considers the trade name and customer list intangible assets to have a useful life of twenty years. All of the intangible assets are amortized over their useful life on a straight line basis. Amortization expense for the years ended December 31, 2013, 2012 and 2011 is included in the depreciation, depletion and amortization table included in Note 6.
	The future total amortization expense for each of the five succeeding years related to intangible assets that are currently recorded in the consolidated statement of financial position is estimated to be as follows at December 31, 2013:


			Developed		Customer
		Patent	Technology	Trade Name	List	Total
		(in thousands)
	2014	$ 43	$ 5	$ 9	$ 23	$ 80
	2015	43	5	9	23	80
	2016	43	5	9	23	80
	2017	43	5	9	23	80
	2018	43	5	9	23	80

Other_NonCurrent_Assets

Other Non-Current Assets	12 Months Ended
Other Non-Current Assets	Dec. 31, 2013
Other Non-Current Assets [Abstract]	'
Other Non-Current Assets	'

	8. OTHER NON-CURRENT ASSETS
	Other non-current assets as of December 31, 2013 and 2012 consisted of the following:

		December 31,
		2013	2012
		(in thousands)
	Deposits and other	$ 1,223	$ 1,988
	Debt issuance costs—net	3,535	3,851
	Non-current receivable	4,327	3,829
	Note receivable	206	-
	Deferred expenses	349	16
	Total	$ 9,640	$ 9,684

	Debt issuance costs were $9.0 million and $8.0 million as of December 31, 2013 and 2012, respectively. Accumulated amortization of debt issuance costs were $5.5 million and $4.2 million as of December 31, 2013 and 2012, respectively. As of December 31, 2013 and 2012, the non-current receivable balance of $4.3 million and $3.8 million, respectively, consisted of the amount due from the Partnership’s workers’ compensation insurance providers for potential claims that are the primary responsibility of the Partnership, but are covered under the Partnership’s insurance policies. See Note 12 for a discussion of the $4.3 million and $3.8 million that is also recorded in the Partnership’s other non-current workers’ compensation liabilities.

Accrued_Expenses_And_Other_Cur

Accrued Expenses And Other Current Liabilities	12 Months Ended
Accrued Expenses And Other Current Liabilities	Dec. 31, 2013
Accrued Expenses And Other Current Liabilities [Abstract]	'
Accrued Expenses And Other Current Liabilities	'
	9. ACCRUED EXPENSES AND OTHER CURRENT LIABILITIES
	Accrued expenses and other current liabilities as of December 31, 2013 and 2012 consisted of the following:


		December 31,
		2013	2012
		(in thousands)
	Payroll, bonus and vacation expense	$ 3,573	$ 4,086
	Non-income taxes	2,750	3,318
	Royalty expenses	2,001	2,536
	Accrued interest	760	671
	Health claims	1,036	1,479
	Workers’ compensation & pneumoconiosis	1,190	1,784
	Deferred revenues	3,592	2,788
	Accrued insured litigation claims	2,579	2,783
	Other	3,086	2,733
	Total	$ 20,567	$ 22,178


	The $2.6 million and $2.8 million accrued for insured litigation claims as of December 31, 2013 and 2012, respectively, consists of probable and estimable litigation claims that are the primary obligation of the Partnership. This amount is also due from the Partnership’s insurance providers and is included in Accounts receivable, net of allowance for doubtful accounts on the Partnership’s consolidated statements of financial position. The Partnership presents this amount on a gross asset and liability basis as a right of setoff does not exist per the accounting guidance in ASC Topic 210. This presentation has no impact on the Partnership’s results of operations or cash flows.

Debt

Debt	12 Months Ended
Debt	Dec. 31, 2013
Debt [Abstract]	'
Debt	'


	10. DEBT
	Debt as of December 31, 2013 and 2012 consisted of the following:


		December 31,
		2013	2012
		(in thousands)
	Senior secured credit facility with PNC Bank, N.A.	$ 167,040	$ 157,250
	Note payable to H&L Construction Co., Inc.	800	1,560
	Other notes payable	3,206	4,739
	Total	171,046	163,549
	Less current portion	-1,024	-2,350
	Long-term debt	$ 170,022	$ 161,199

	Senior Secured Credit Facility with PNC Bank, N.A.—The original maximum availability under the credit facility by and among the Operating Company, the guarantors (including the Partnership) and lenders which are parties thereto, and PNC Bank, N.A. as administrative agent was $200.0 million. On June 8, 2011, with the consent of the lenders, the Operating Company exercised the option to increase the amount available to borrow under the credit agreement by $50.0 million to $250.0 million as part of the Elk Horn Acquisition discussed earlier. As part of exercising this option to increase the available amount under the credit agreement, the Operating Company paid a fee of $1.0 million to the lenders, which was recorded in Debt issuance costs in Other non-current assets on the Partnership’s consolidated statements of financial position and in Cash flows from financing activities in the Partnership’s consolidated statements of cash flows.
	On July 29, 2011, the Operating Company and the Partnership, as a guarantor, executed an amended and restated senior secured credit facility with PNC Bank, N.A., as administrative agent, and a group of lenders, which are parties thereto. The maximum availability under the amended and restated credit facility is $300.0 million, with a one-time option to increase the availability by an amount not to exceed $50.0 million. Of the $300.0 million, $75.0 million is available for letters of credit. Borrowings under the facility bear interest, which varies depending upon the levels of certain financial ratios. As part of the agreement, the Operating Company is required to pay a commitment fee on the unused portion of the borrowing availability that also varies depending upon the levels of certain financial ratios. Borrowings on the amended and restated senior secured credit facility are collateralized by all the unsecured assets of the Partnership. The amended and restated senior secured credit facility requires the Partnership to maintain certain minimum financial ratios and contains certain restrictive provisions, including among others, restrictions on making loans, investments and advances, incurring additional indebtedness, guaranteeing indebtedness, creating liens, and selling or assigning stock. The Partnership was in compliance with all covenants contained in the amended and restated senior secured credit facility as of and for the period ended December 31, 2013. The amended and restated senior secured credit facility expires in July 2016.
	As part of executing the amended and restated senior secured credit facility, the Operating Company paid a fee of approximately $2.8 million to the lenders, which was recorded in Debt issuance costs in Other non-current assets on the Partnership’s consolidated statements of financial position and in Cash flows from financing activities in the Partnership’s consolidated statements of cash flows. The Partnership evaluated the accounting guidance in ASC Topic 470, Debt, De-recognition, Line-of-Credit or Revolving-Debt Arrangements, and determined that the balance of the previous deferred financing costs met the requirements to be included with the fees paid for the amended and restated credit facility, with the combined balance of financing costs being deferred and amortized over the five year term of the amended and restated credit facility.
	In April 2013, the Partnership entered into an amendment of its amended and restated senior secured credit facility with PNC Bank, N.A., as administrative agent, and a group of lenders, which are parties thereto. The amendment provided for an increase in the maximum allowed investments in coal-related entities outside of the Partnership (i.e. joint ventures) under the amended and restated senior secured credit facility from $25 million to $40 million. The amendment also altered the maximum leverage ratio allowed under the amended and restated senior secured credit facility and also altered the pricing grid to include applicable interest rates for borrowings, letter of credit fees and commitment fees on unused borrowings based upon the new maximum leverage ratio. The amendment increases the maximum leverage ratio of the amended and restated senior secured credit facility to 3.75 from April 1, 2013 through March 31, 2015, then steps the maximum leverage ratio down to its previous level of 3.0 after December 31, 2015. All other terms of the amended and restated senior secured credit facility were not affected by the amendment. As part of executing the amendment to the amended and restated senior secured credit facility, the Operating Company paid a fee of approximately $1.0 million to the lenders in April 2013, which was recorded in Debt issuance costs in Other non-current assets on the Partnership’s consolidated statements of financial position and in Cash flows from financing activities in the Partnership’s consolidated statements of cash flows.
	At December 31, 2013, the Operating Company had borrowed $162.0 million at a variable interest rate of LIBOR plus 3.00% (3.17% at December 31, 2013) and an additional $5.0 million at a variable interest rate of PRIME plus 2.00% (5.25% at December 31, 2013). In addition, the Operating Company had outstanding letters of credit of $21.5 million at a fixed interest rate of 3.00% at December 31, 2013. Based upon a maximum borrowing capacity of 3.75 times a trailing twelve-month EBITDA calculation (as defined in the credit agreement), the Operating Company had not used $56.1 million of the borrowing availability at December 31, 2013.
	For the year ending December 31, 2013, the Partnership capitalized interest costs of approximately $0.1 million, which was related to the construction of its Pennyrile mine in western Kentucky. The Partnership did not capitalize any interest costs during the years ended December 31, 2012 and 2011.
	Note payable to H&L Construction Co., Inc.—The note payable to H&L Construction Co., Inc. was originally a non-interest bearing note and the Partnership has recorded a discount for imputed interest at a rate of 5.0% on this note that is being amortized over the life of the note using the effective interest method. The note payable matures in January 2015. The note is secured by mineral rights purchased by the Partnership from H&L Construction Co., Inc. with a carrying amount of $11.1 million and $11.3 million at December 31, 2013 and 2012, respectively.
	Principal payments on long-term debt due subsequent to December 31, 2013 are as follows:

		in thousands
	2014	$ 1,049
	2015	210
	2016	167,265
	2017	240
	2018	257
	Thereafter	2,050
	Total principal payments	171,071
	Less imputed interest on interest free notes payable	-25
	Total debt	$ 171,046

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
Asset Retirement Obligations	Dec. 31, 2013
Asset Retirement Obligations [Abstract]	'
Asset Retirement Obligations	'
	11. ASSET RETIREMENT OBLIGATIONS
	The changes in asset retirement obligations for the years ended December 31, 2013, 2012 and 2011 are as follows:


		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Balance at beginning of period (including current portion)	$ 33,003	$ 34,113	$ 35,691
	Accretion expense	2,356	1,896	1,956
	Adjustment resulting from addition of property	-	72	2,707
	Adjustment resulting from disposal of property	-	-968	-3,588
	Adjustments to the liability from annual recosting and other	20	-201	-617
	Liabilities settled	-928	-1,909	-2,036
	Balance at end of period	34,451	33,003	34,113
	Less current portion of asset retirement obligation	-1,614	-2,255	-3,192
	Long-term portion of asset retirement obligation	$ 32,837	$ 30,748	$ 30,921

Workers_Compensation_And_Black

Workers' Compensation And Black Lung	12 Months Ended
Workers' Compensation And Black Lung	Dec. 31, 2013
Workers' Compensation And Black Lung [Abstract]	'
Workers' Compensation And Black Lung	'


	12. WORKERS’ COMPENSATION AND BLACK LUNG

	Certain of the Partnership’s subsidiaries are liable under federal and state laws to pay workers’ compensation and coal workers’ black lung benefits to eligible employees, former employees and their dependents. The Partnership currently utilizes an insurance program and state workers’ compensation fund participation to secure its on-going obligations depending on the location of the operation. Premium expense for workers’ compensation benefits is recognized in the period in which the related insurance coverage is provided.

	Commencing with the December 31, 2013 reporting period, the Partnership’s black lung benefit liability is calculated using the service cost method that considers the calculation of the actuarial present value of the estimated black lung obligation. The Partnership had previously accounted for its black lung benefit liability using an event driven approach under ASC 450, Contingencies. It was determined the Partnership should have accounted for its black lung benefit liability using a service cost approach under ASC 710, Compensation-General, because this approach matches black lung costs over the service lives of the miners who ultimately receive black lung benefits. All prior period information for black lung expense and benefit liability presented in the consolidated financial statements and in this Note has been revised using the service cost method. As of December 31, 2010, this correction resulted in a decrease in partners’ capital of $5.8 million from amounts previously reported. The correction also resulted in a decrease in net income of approximately $0.7 million and approximately $0.8 million for 2012 and 2011, respectively, from amounts previously reported.

	The Partnership’s actuarial calculations using the service cost method for its black lung benefit liability are based on numerous assumptions including disability incidence, medical costs, mortality, death benefits, dependents and interest rates. The Partnership’s liability for traumatic workers’ compensation injury claims is the estimated present value of current workers' compensation benefits, based on actuarial estimates. The Partnership’s actuarial estimates for its workers’ compensation liability are based on numerous assumptions including claim development patterns, mortality, medical costs and interest rates. The discount rate used to calculate the estimated present value of future obligations for black lung was 5.0% and 4.0%, respectively, for December 31, 2013 and 2012 and for workers' compensation was 2.0% at December 31, 2013 and 2012.

	The black lung and workers' compensation expenses for the years ended December 31, 2013, 2012 and 2011 are as follows:


		Year Ended December 31,
		2013	2012	2011
	Black lung benefits:	(in thousands)
	Service cost	$ 736	$ 1,215	$ 156
	Interest cost	469	466	110
	Actuarial (gain)/loss	-1,584	693	1,231
	Total black lung	-379	2,374	1,497
	Workers' compensation expense	2,743	1,018	4,049
	Total expense	$ 2,364	$ 3,392	$ 5,546

	The changes in the black lung benefit liability for the years ended December 31, 2013 and 2012 are as follows:



		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Benefit obligations at beginning of year	$ 8,513	$ 6,392	$ 5,055
	Service cost	736	1,215	156
	Interest cost	469	466	110
	Actuarial (gain)/loss	-1,584	693	1,231
	Benefits and expenses paid	-883	-253	-160
	Benefit obligations at end of year	$ 7,251	$ 8,513	$ 6,392

	The classification of the amounts recognized for the Partnership’s workers’ compensation and black lung benefits liability as of December 31, 2013 and 2012 are as follows:


		December 31,
		2013	2012
		(in thousands)
	Black lung claims	$ 7,251	$ 8,513
	Workers' compensation claims	10,159	9,846
	Total obligations	$ 17,410	$ 18,359
	Less current portion	-1,190	-1,784
	Non-current obligations	$ 16,220	$ 16,575

	The balance for workers’ compensation claims as of December 31, 2013 and 2012 consisted of $4.3 million and $3.8 million, respectively, that is the primary obligation of the Partnership, but this amount is also due from the Partnership’s insurance providers, which is included in Note 8 as non-current receivables, based on the Partnership’s workers’ compensation insurance coverage. The Partnership presents this amount on a gross asset and liability basis since a right of setoff does not exist per the accounting guidance in ASC Topic 210. This presentation has no impact on the Partnership’s results of operations or cash flows.

Employee_Benefits

Employee Benefits	12 Months Ended
Employee Benefits	Dec. 31, 2013
Employee Benefits [Abstract]	'
Employee Benefits	'
	13. EMPLOYEE BENEFITS
	Postretirement Plan—In conjunction with the acquisition of the coal operations of American Electric Power on April 16, 2004, the Operating Company acquired a postretirement benefit plan providing healthcare to eligible employees at its Hopedale operations. The Partnership has no other postretirement plans.
	Summaries of the changes in benefit obligations and funded status of the plan as of the measurement dates of December 31, 2013, 2012 and 2011 are as follows:

			Year Ended December 31,
			2013		2012		2011
			(in thousands)
	Benefit obligation at beginning of period		$ 6,747		$ 5,649		$ 6,641
	Changes in benefit obligations:
	Service costs		385		378		491
	Interest cost		186		231		312
	Benefits paid		-253		-133		-72
	Actuarial (gain)/loss		-945		622		-1,723
	Benefit obligation at end of period		$ 6,120		$ 6,747		$ 5,649
	Fair value of plan assets at end of period		$ -		$ -		$ -
	Funded status		$ (6,120)		$ (6,747)		$ (5,649)

	The classification of net amounts recognized for postretirement benefits as of December 31, 2013 and 2012 are as follows:

			December 31,
			2013		2012
			(in thousands)
	Current liability—postretirement benefits		$ (334)		$ (227)
	Non-current liability—postretirement benefits		-5,786		-6,520
	Net amount recognized		$ (6,120)		$ (6,747)
	The amounts recognized in accumulated other comprehensive income for the years ended December 31, 2013, 2012 and 2011 are as follows:


			Year Ended December 31,
			2013		2012		2011
			(in thousands)
	Balance at beginning of year		$ 1,431		$ 2,348		$ 625
	Actuarial gain (loss)		945		-622		1,723
	Amortization of net actuarial gain		-145		-295		-
	Net actuarial gain		$ 2,231		$ 1,431		$ 2,348
	The amounts reclassified from accumulated other comprehensive income to Cost of operations in the Partnership’s consolidated statements of operations for the years ended December 31, 2013 and 2012 was $0.1 million and $0.3 million, respectively. No amounts were reclassified from accumulated other comprehensive income for the year ended December 31, 2011.


			December 31,
			2013		2012
	Weighted Average assumptions used to determine benefit obligations:
	Discount rate		3.96%		2.80%
	Expected return on plan assets		n/a		n/a








			Year Ended December 31,
			2013		2012		2011
	Weighted Average assumptions used to determine periodic benefit cost:
	Discount rate		2.80%		4.15%		4.75%
	Expected return on plan assets		n/a		n/a		n/a
	Rate of compensation increase		n/a		n/a		n/a

	The components of net periodic benefit cost for the years ended December 31, 2013, 2012 and 2011 are as follows:

			Year Ended December 31,
			2013		2012		2011
			(in thousands)
Service costs		$ 385		$ 378		$ 491
Interest cost		186		231		312
Amortization of (gain)		-145		-295		-
Benefit cost		$ 426		$ 314		$ 803
Amounts expected to be amortized from accumulated other comprehensive income into net periodic benefit cost during the year ending December 31, 2014, are as follows:


		(in thousands)
Net actuarial gain		$ 367
Expected future benefit payments are as follows:


Period		(in thousands)
2014		$ 334
2015		397
2016		538
2017		602
2018		659
2019-2023		$ 4,337
For benefit obligation measurement purposes, a 7.30% annual rate of increase in the per capita cost of covered health care benefits was assumed, gradually decreasing to 4.50% in 2027 and remaining level thereafter.
Net periodic benefit cost is determined using the assumptions as of the beginning of the year, and the funded status is determined using the assumptions as of the end of the year. Effective June 1, 2007, employees hired by the Partnership are not eligible for benefits under the plan.
The expense and liability estimates can fluctuate by significant amounts based upon the assumptions used by the Partnership. As of December 31, 2013, a one-percentage‑point change in assumed health care cost trend rates would have the following effects:


		One-Percentage		One-Percentage
		Point Increase		Point Decrease
		(in thousands)
Effect on total service and interest cost components		$ 58		$ (52)
Effect on postretirement benefit obligation		$ 467		$ (433)


401(k) Plans—The Partnership and certain subsidiaries sponsor defined contribution savings plans for all employees. Under one defined contribution savings plan, the Partnership matches voluntary contributions of participants up to a maximum contribution based upon a percentage of a participant’s salary with an additional matching contribution possible at the Partnership’s discretion. The expense under these plans for the years ended December 31, 2013, 2012 and 2011 was as follows:


		Year Ended December 31,
		2013		2012		2011
		(in thousands)
401(k) plan expense		$ 2,243		$ 2,322		$ 2,245

EquityBased_Compensation

Equity-Based Compensation	12 Months Ended
Equity-Based Compensation	Dec. 31, 2013
Equity-Based Compensation [Abstract]	'
Equity-Based Compensation	'
	14. EQUITY‑BASED COMPENSATION
	In October 2010, the General Partner established the Rhino Long-Term Incentive Plan (the “Plan” or “LTIP”). The Plan is intended to promote the interests of the Partnership by providing to employees, consultants and directors of the General Partner, the Partnership or affiliates of either incentive compensation awards to encourage superior performance. The LTIP provides for grants of restricted units, unit options, unit appreciation rights, phantom units, unit awards, and other unit-based awards. The aggregate number of units initially reserved for issuance under the LTIP is 2,479,400.
	As of December 31, 2013, the General Partner granted phantom units to certain employees and restricted units and unit awards to its directors. A portion of these grants were made in connection with the IPO completed during October 2010, as well as annual restricted unit awards to directors and phantom unit awards granted in the first quarters of 2013 and 2012 to certain employees in connection with the prior fiscal year’s performance. The phantom units granted in the first quarters of 2013 and 2012 vest in equal annual installments over a three year period from the date of grant. The remaining terms and conditions of these phantom unit awards are similar to the phantom units awarded in connection with the Partnership’s IPO. A summary of non-vested LTIP awards as of and for the years ended December 31, 2013, 2012 and 2011 is as follows:


		Common Units	Weighted Average Grant Date Fair Value (per unit)
		(in thousands)
	Non-vested awards at December 31, 2010	135	$ 20.50
	Granted	10	$ 19.90
	Vested	-52	$ 20.47
	Forfeited	-1	$ 20.50

	Non-vested awards at December 31, 2011	92	$ 20.45
	Granted	32	$ 17.40
	Vested	-49	$ 20.12
	Forfeited	-8	$ 20.28

	Non-vested awards at December 31, 2012	67	$ 19.23
	Granted	49	$ 13.50
	Vested	-58	$ 18.88
	Forfeited	-3	$ 16.62

	Non-vested awards at December 31, 2013	55	$ 14.63

	With the vesting of the first portion of the employees’ awards in early April 2011, the Compensation Committee of the board of directors of the General Partner elected to pay some of the awards in cash or a combination of cash and common units. This election was a change in policy since management had previously planned to settle all employee awards with units upon vesting as per the grant agreements. This policy change resulted in a modification of all employee awards from equity to liability classification as of March 31, 2011 and all new awards granted thereafter. The Partnership incurred incremental compensation expense for the year ended December 31, 2011 of approximately $0.1 million due to the modification of these awards. The equity balance of approximately $0.2 million accrued as of December 31, 2010 for the non-vested awards was also reclassified from the Limited partners’ capital account to Accrued expenses and other in the current liability portion in the consolidated statement of financial position as of December 31, 2011. For the years ended December 31, 2013 and 2012, the Partnership did not record any incremental compensation expense due to the modification of the employees’ IPO awards since the market price of the Partnership’s common units was below the IPO grant price. The final tranche of the IPO awards vested in October 2013.
	For the years ended December 31, 2013, 2012 and 2011, the Partnership recorded expense of approximately $0.7 million, approximately $0.9 million and approximately $1.1 million, respectively, for the LTIP awards. All of the non-vested LTIP awards granted during 2013, 2012 and 2011 included, with respect to the phantom unit awards, distribution equivalent rights (or DERs) or unit distribution rights, with respect to restricted unit awards, each of which are rights to accrue quarterly cash distributions in an amount equal to the cash distribution the Partnership makes to unitholders during the vesting period. However, any accrued distributions will be forfeited if the related awards fail to vest according to the relevant vesting conditions of the award.
	For the year ended December 31, 2013, the total fair value of the awards that vested was $0.8 million. As of December 31, 2013, the total unrecognized compensation expense related to the non-vested LTIP awards that are expected to vest was $0.5 million. The expense is expected to be recognized over a weighted‑average period of 1.6 years. As of December 31, 2013, the intrinsic value of the non-vested LTIP awards was $0.6 million.
	During the first quarter of 2014, certain employees received grants of phantom units with tandem DERs under the LTIP program. These awards were granted in connection with fiscal year 2013 performance and vest in equal annual installments over a three-year period from the date of grant. The total value of the awards granted was approximately $0.4 million and the expense related to these awards will be recognized ratably over the three-year vesting period, plus any mark-to-market adjustments.

Commitments_And_Contingencies

Commitments And Contingencies	12 Months Ended
Commitments And Contingencies	Dec. 31, 2013
Commitments And Contingencies [Abstract]	'
Commitments And Contingencies	'
	15. COMMITMENTS AND CONTINGENCIES
	Coal Sales Contracts and Contingencies—As of December 31, 2013, the Partnership had commitments under sales contracts to deliver annually scheduled base quantities of coal as follows:

	Year	Tons (in thousands)	Number of customers
	2014	3,045	19
	2015	1,796	4
	2016	1,100	2
	2017	1,100	2

	Some of the contracts have sales price adjustment provisions, subject to certain limitations and adjustments, based on a variety of factors and indices.
	Purchase Commitments—As of December 31, 2013, the Partnership had a commitment to purchase 2,000 tons of ammonia nitrate at fixed prices from March 2014 through December 2014 for approximately $0.9 million.
	Purchased Coal Expenses—The Partnership incurs purchased coal expense from time to time related to coal purchase contracts. In addition, the Partnership incurs expense from time to time related to coal purchased on the over-the-counter market (“OTC”). Purchase coal expense from coal purchase contracts and expense from OTC purchases for the years ended December 31, 2013, 2012 and 2011 was as follows:


		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Purchased coal expense	$ 3,730	$ 25,637	$ 14,283
	OTC expense	$ 1,271	$ -	$ 14

	Leases—The Partnership leases various mining, transportation and other equipment under operating leases. The Partnership also leases coal reserves under agreements that call for royalties to be paid as the coal is mined. Lease and royalty expense for the years ended December 31, 2013, 2012 and 2011 was as follows:


		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Lease expense	$ 3,161	$ 2,860	$ 2,630
	Royalty expense	$ 11,442	$ 14,474	$ 16,175

	Approximate future minimum lease and royalty payments (not including advance royalties already paid and recorded as assets in the accompanying statements of financial position) are as follows:


	Years Ended December 31,	Royalties	Leases
		(in thousands)
	2014	$ 1,642	$ 1,577
	2015	1,865	1,538
	2016	1,864	1,545
	2017	1,922	1,141
	2018	1,929	193
	Thereafter	9,644	-
	Total minimum royalty and lease payments	$ 18,866	$ 5,994
	Environmental Matters—Based upon current knowledge, the Partnership believes that it is in compliance with environmental laws and regulations as currently promulgated. However, the exact nature of environmental control problems, if any, which the Partnership may encounter in the future cannot be predicted, primarily because of the increasing number, complexity and changing character of environmental requirements that may be enacted by federal and state authorities.
	Legal Matters—The Partnership is involved in various legal proceedings arising in the ordinary course of business due to claims from various third parties, as well as potential citations and fines from the Mine Safety and Health Administration, potential claims from land or lease owners and potential property damage claims from third parties. The Partnership is not party to any other pending litigation that is probable to have a material adverse effect on the financial condition, results of operations or cash flows of the Partnership. Management of the Partnership is also not aware of any significant legal, regulatory or governmental proceedings against or contemplated to be brought against the Partnership.
	Guarantees/Indemnifications and Financial Instruments with Off-Balance Sheet Risk—In the normal course of business, the Partnership is a party to certain guarantees and financial instruments with off-balance sheet risk, such as bank letters of credit and performance or surety bonds. No liabilities related to these arrangements are reflected in the consolidated statements of financial position. The amount of bank letters of credit outstanding with PNC Bank, N.A., as the letter of credit issuer under the Partnership’s credit facility, was $21.5 million as of December 31, 2013. The bank letters of credit outstanding reduce the borrowing capacity under the credit facility. In addition, the Partnership has outstanding surety bonds with third parties of $75.2 million as of December 31, 2013 to secure reclamation and other performance commitments.
	The credit facility is fully and unconditionally, jointly and severally guaranteed by the Partnership and substantially all of its wholly owned subsidiaries. Borrowings under the credit facility are collateralized by the unsecured assets of the Partnership and substantially all of its wholly owned subsidiaries. See Note 10 for a more complete discussion of the Partnership’s debt obligations.
	Joint Venture—Pursuant to the Rhino Eastern joint venture agreement with Patriot, the Partnership is required to contribute additional capital to assist in funding the development and operations of the Rhino Eastern joint venture. During the year ended December 31, 2013, the Partnership made capital contributions to the Rhino Eastern joint venture of approximately $2.3 million based upon its proportionate ownership percentage. The Partnership may be required to contribute additional capital or make loans to Rhino Eastern commensurate with its ownership percentage in subsequent periods.
	The Partnership may contribute additional capital to the Timber Wolf joint venture that was formed in the first quarter of 2012. The Partnership did not make any capital contributions to the Timber Wolf joint venture during the year ended December 31, 2013.
	The Partnership is required to contribute additional capital to the Muskie Proppant joint venture that was formed in the fourth quarter of 2012. During the year ended December 31, 2013, the Partnership made capital contributions to the Muskie Proppant joint venture of approximately $0.5 million based upon its proportionate ownership percentage. In addition, during the year ended December 31, 2013, the Partnership provided a loan based upon its ownership share to Muskie in the amount of $0.2 million that remained outstanding as of December 31, 2013. The Partnership may be required to contribute additional capital or make loans to Muskie commensurate with its ownership percentage in subsequent periods.

Earnings_Per_Unit_EPU

Earnings Per Unit ("EPU")	12 Months Ended
Earnings Per Unit ("EPU")	Dec. 31, 2013
Earnings Per Unit ("EPU") [Abstract]	'
Earnings Per Unit ("EPU")	'
	16. EARNINGS PER UNIT (“EPU”)
	The following table presents a reconciliation of the numerators and denominators of the basic and diluted EPU calculations for the periods ended December 31, 2013, 2012 and 2011:


	Year ended December 31, 2013	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net income:
	Net income from continuing operations	$ 162	$ 4,448	$ 3,501
	Net income from discontinued operations	26	769	512
	Interest in net income	$ 188	$ 5,217	$ 4,013
	Denominator:
	Weighted average units used to compute basic EPU	n/a	15,751	12,397
	Effect of dilutive securities — LTIP awards	n/a	9	-
	Weighted average units used to compute diluted EPU	n/a	15,760	12,397

	Net income per limited partner unit, basic:
	Net income per unit from continuing operations	n/a	$ 0.29	$ 0.28
	Net income per unit from discontinued operations	n/a	0.04	0.04
	Net income per limited partner unit, basic	n/a	$ 0.33	$ 0.32
	Net income per limited partner unit, diluted:




	Year ended December 31, 2012	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net income:
	Net income from continuing operations	$ 789	$ 21,374	$ 17,284
	Net income from discontinued operations	1	48	39
	Interest in net income	$ 790	$ 21,422	$ 17,323
	Denominator:
	Weighted average units used to compute basic EPU	n/a	15,331	12,397
	Effect of dilutive securities — LTIP awards	n/a	4	-
	Weighted average units used to compute diluted EPU	n/a	15,335	12,397

	Net income per limited partner unit, basic:
	Net income per unit from continuing operations	n/a	$ 1.39	$ 1.39
	Net income per unit from discontinued operations	n/a	0.01	0.01
	Net income per limited partner unit, basic	n/a	$ 1.40	$ 1.40
	Net income per limited partner unit, diluted:


	Year ended December 31, 2011	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net income	$ 746	$ 19,205	$ 17,347
	Denominator:
	Weighted average units used to compute basic EPU	n/a	13,725	12,397
	Effect of dilutive securities — LTIP awards	n/a	19	-
	Weighted average units used to compute diluted EPU	n/a	13,744	12,397

	Net income per limited partner unit, basic	n/a	$ 1.40	$ 1.40
	Net income per limited partner unit, diluted	n/a	$ 1.40	$ 1.40


	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 year ended December 31, 2013, approximately 12,000 LTIP granted phantom units were anti-dilutive. There were no anti-dilutive units for the years ended December 31, 2012 and 2011.

Major_Customers

Major Customers	12 Months Ended
Major Customers	Dec. 31, 2013
Major Customers [Abstract]	'
Major Customers	'
	17. MAJOR CUSTOMERS

	The Partnership had revenues or receivables from the following major customers that in each period equaled or exceeded 10% of revenues or receivables (Note: customers with “n/a” had revenue or receivables below the 10% threshold in any period where this is indicated):


		December 31, 2013 Receivable Balance	Year Ended December 31, 2013 Sales	December 31, 2012 Receivable Balance	Year Ended December 31, 2012 Sales	December 31, 2011 Receivable Balance	Year Ended December 31, 2011 Sales
		(in thousands)
	NRG Energy Inc. (fka GenOn Energy, Inc.)	$ 3,046	$ 55,246	$ 3,158	$ 53,661	$ 3,254	$ 56,000
	American Electric Power Company, Inc.	1,434	30,070	3,450	36,308	3,556	43,840
	Indiana Harbor Coke Company, L.P.	n/a	n/a	6,597	40,133	4,259	39,767
	Blackstone Resources, Inc.	n/a	n/a	n/a	n/a	3,553	23,104
	PPL Corporation	n/a	n/a	2,760	37,364	3,038	46,672

Fair_Value_Of_Financial_Instru

Fair Value Of Financial Instruments	12 Months Ended
Fair Value Of Financial Instruments	Dec. 31, 2013
Fair Value Of Financial Instruments [Abstract]	'
Fair Value Of Financial Instruments	'
	18. FAIR VALUE OF FINANCIAL INSTRUMENTS
	The book values of cash and cash equivalents, accounts receivable and accounts payable are considered to be representative of their respective fair values because of the immediate short-term maturity of these financial instruments. The fair value of the Partnership’s senior secured credit facility was determined based upon a market approach and approximates the carrying value at December 31, 2013. The fair value of the Partnership’s senior secured credit facility is a Level 2 measurement.

Related_Party_And_Affiliate_Tr

Related Party And Affiliate Transactions	12 Months Ended
Related Party And Affiliate Transactions	Dec. 31, 2013
Related Party And Affiliate Transactions [Abstract]	'
Related Party And Affiliate Transactions	'
	19. RELATED PARTY AND AFFILIATE TRANSACTIONS


	Related Party	Description	2013	2012	2011
			(in thousands)
	Wexford Capital LP	Expenses for legal, consulting, and advisory services	$ 149	$ 213	$ 263
	Wexford Capital LP	Distributions paid	14,034	27,704	38,602
	Wexford Capital LP	Partner's contribution	330	13	1,450
	Rhino Eastern LLC	Equity in net (loss)/income of unconsolidated affiliate	-4,268	6,014	2,988
	Rhino Eastern LLC	Distributions from unconsolidated affiliate	-	2,958	3,351
	Rhino Eastern LLC	Expenses for legal, health claims, workers' compensation and other expenses	4,666	6,175	4,662
	Rhino Eastern LLC	Receivable for legal, health claims and workers’ compensation and other expenses	999	559	1,974
	Rhino Eastern LLC	Investment in unconsolidated affiliate	19,369	21,367	18,311
	Timber Wolf Terminals LLC	Investment in unconsolidated affiliate	114	114	-
	Muskie Proppants LLC	Investment in unconsolidated affiliate	1,761	1,743	-
	Muskie Proppants LLC	Equity in net (loss) of unconsolidated affiliate	-461	-257	-
	Muskie Proppants LLC	Note receivable from unconsolidated affiliate	206	-	-
	From time to time, employees from Wexford Capital perform legal, consulting, and advisory services to the Partnership. The Partnership incurred expenses of $0.1 million for the year ended December 31, 2013, $0.2 million for the year ended December 31, 2012 and $0.3 million for the year ended December 31, 2011 for legal, consulting, and advisory services performed by Wexford Capital.
	During 2012, the Partnership provided loans to Rhino Eastern, a joint venture between the Partnership and Patriot, totaling approximately $11.9 million that were fully repaid as of December 31, 2012. During 2011, the Partnership provided loans based upon its ownership share to Rhino Eastern totaling approximately $5.8 million that were fully repaid as of December 31, 2011. The Partnership did not provide any loans to Rhino Eastern during 2013.
	From time to time, the Partnership has allocated and paid expenses on behalf of the Rhino Eastern joint venture. During the years ended December 31, 2013, 2012 and 2011, the Partnership paid expenses for legal, health claims and workers’ compensation of $4.7 million, $6.2 million and $4.7 million, respectively, on behalf of Rhino Eastern that were subsequently billed and paid by Rhino Eastern to the Partnership.

Supplemental_Disclosures_Of_Ca

Supplemental Disclosures Of Cash Flow Information	12 Months Ended
Supplemental Disclosures Of Cash Flow Information	Dec. 31, 2013
Supplemental Disclosures Of Cash Flow Information [Abstract]	'
Supplemental Disclosures Of Cash Flow Information	'
	20. SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
	Cash payments for interest were $6.4 million, $6.5 million and $4.3 million for the years ended December 31, 2013, 2012 and 2011, respectively.
	The consolidated statement of cash flows for the year ended December 31, 2013 is exclusive of approximately $10.5 million of property, plant and equipment additions which are recorded in Accounts payable. The consolidated statements of cash flows for the year ended December 31, 2013 also excludes approximately $0.6 million related to the value of LTIP units that were issued to certain employees and directors of the General Partner.
	The consolidated statement of cash flows for the year ended December 31, 2012 is exclusive of approximately $3.6 million of property, plant and equipment additions which are recorded in Accounts payable and $0.4 million related to the amount accrued for the acquisition of the western Kentucky assets discussed in Note 4, which is included in Accrued expenses and other. The consolidated statements of cash flows for the year ended December 31, 2012 also excludes approximately $0.7 million related to the value of LTIP units that were issued to certain employees and directors of the General Partner.
	The consolidated statement of cash flows for the year ended December 31, 2011 is exclusive of approximately $3.2 million of property, plant and equipment additions which are recorded in accounts payable, approximately $5.2 million of property, plant and equipment additions which are included in accrued expenses and other liabilities and approximately $0.8 million related to the value of LTIP units that were issued to certain employees and directors of the General Partner.

Segment_Information

Segment Information	12 Months Ended
Segment Information	Dec. 31, 2013
Segment Information [Abstract]	'
Segment Information	'
	21. SEGMENT INFORMATION
	The Partnership primarily produces and markets coal from surface and underground mines in Kentucky, West Virginia, Ohio and Utah. The Partnership sells primarily to electric utilities in the United States. In addition, with the Elk Horn Acquisition mentioned earlier, the Partnership also leases coal reserves to third parties in exchange for royalty revenues. For the year ended December 31, 2013, the Partnership has five reportable business segments: Central Appalachia (comprised of both surface and underground mines located in Eastern Kentucky and Southern West Virginia, along with the Elk Horn operations), Northern Appalachia (comprised of both surface and underground mines located in Ohio), Rhino Western (comprised of an underground mine in Utah) and Eastern Met (comprised solely of the Rhino Eastern joint venture with Patriot).
	Beginning with 2013 year-end reporting, the Partnership initially included a reportable business segment for its oil and natural gas activities since the total assets for these operations met the quantitative threshold for separate segment reporting. The Oil and Natural Gas segment included the Partnership’s Utica Shale activities, which were sold during the first quarter of 2014 as described in Note 3, as well as the Partnership’s Cana Woodford activities, the Razorback drill pad construction operations and the Muskie joint venture to provide sand for fracking operations. Prior to 2013, the Partnership’s oil and natural gas activities were included in its Other category for segment reporting purposes. Since the majority of the Partnership’s oil and natural gas activities were in the Utica Shale and the Utica Shale financial results have been reclassified in discontinued operations due to their sale, the segment data for the Partnership’s remaining oil and natural gas activities have been reclassified in the Other category for segment reporting purposes for all periods presented since they are not material for separate segment reporting.
	The Partnership’s Other category as reclassified is comprised of the Partnership’s ancillary businesses and its remaining oil and natural gas activities. Held for sale assets are also included in the Other category for segment reporting purposes. The Partnership has not provided disclosure of total expenditures by segment for long-lived assets, as the Partnership does not maintain discrete financial information concerning segment expenditures for long lived assets, and accordingly such information is not provided to the Partnership’s chief operating decision maker. The information provided in the following tables represents the primary measures used to assess segment performance by the Partnership’s chief operating decision maker.
	The Partnership has historically accounted for the Rhino Eastern joint venture (formed in the year ended December 31, 2008) under the equity method. Under the equity method of accounting, the Partnership has historically only presented limited information (net income). The Partnership considers this operation to comprise a separate operating segment and has presented additional operating detail (with corresponding eliminations and adjustments to reflect its percentage of ownership) below. Since this equity method investment met the significance test of ten percent of net income or loss in 2012 and 2013, the Partnership has presented additional summarized financial information for this equity method investment below.
	During 2012, the Partnership changed the method to allocate certain corporate overhead and interest charges to its reportable segments from a method based on production tons to a method based upon the amount invested in fixed assets. The Partnership changed the allocation method as a result of additional investments that the Partnership has made in its non-coal operations. Reportable segment figures presented below have been re-cast for 2011 for comparability purposes.
	Reportable segment results of operations and financial position for the year ended December 31, 2013 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization):


					Eastern Met
		Central Appalachia	Northern Appalachia	Rhino Western	Complete Basis	Equity Method Eliminations	Equity Method Presentation	Other	Total Consolidated
		(in thousands)
	Total assets	$ 293,675	$ 54,906	$ 66,463	$ 44,791	$ (44,791)	$ -	$ 152,723	$ 567,767
	Total revenues	147,430	80,401	38,249	27,853	-27,853	-	6,185	272,265
	DD&A	24,170	8,127	5,476	1,949	-1,949	-	1,854	39,627
	Interest expense	3,927	771	665	17	-17	-	2,535	7,898
	Net Income (loss) from continuing operations	$ (7,132)	$ 26,089	$ (2,378)	$ (8,369)	$ 4,101	$ (4,268)	$ (4,200)	$ 8,111

	Reportable segment results of operations and financial position for the year ended December 31, 2012 are as follows:


					Eastern Met
		Central Appalachia	Northern Appalachia	Rhino Western	Complete Basis	Equity Method Eliminations	Equity Method Presentation	Other	Total Consolidated
		(in thousands)
	Total assets	$ 325,418	$ 57,429	$ 70,822	$ 52,682	$ (52,682)	$ -	$ 106,207	$ 559,876
	Total revenues	183,374	122,024	40,696	55,221	-55,221	-	5,649	351,743
	DD&A	26,220	8,339	4,653	2,098	-2,098	-	2,062	41,274
	Interest expense	4,385	811	717	155	-155	-	1,854	7,767
	Net Income (loss) from continuing operations	$ 3,668	$ 29,565	$ 5,691	$ 11,937	$ (5,923)	$ 6,014	$ (5,491)	$ 39,447

	Reportable segment results of operations and financial position for the year ended December 31, 2011 are as follows:


					Eastern Met
		Central Appalachia	Northern Appalachia	Rhino Western	Complete Basis	Equity Method Eliminations	Equity Method Presentation	Other	Total Consolidated
		(in thousands)
	Total assets	$ 325,746	$ 57,137	$ 72,986	$ 45,219	$ (45,219)	$ -	$ 83,334	$ 539,203
	Total revenues	219,274	119,966	21,688	50,073	-50,073	-	6,293	367,221
	DD&A	22,115	8,160	3,057	2,959	-2,959	-	2,993	36,325
	Interest expense	3,074	687	547	52	-52	-	1,754	6,062
	Net Income (loss)	$ 16,497	$ 27,404	$ (2,596)	$ 5,715	$ (2,727)	$ 2,988	$ (6,995)	$ 37,298

	Additional summarized financial information for the equity method investment as of and for the periods ended December 31, 2013, 2012 and 2011 is as follows:

		2013		2012		2011
		(in thousands)
	Current assets	$ 5,608		$ 12,788		$ 7,880
	Noncurrent assets	39,183		39,805		37,339
	Current liabilities	2,020		6,290		4,361
	Noncurrent liabilities	4,794		4,496		5,098
	Total costs and expenses	36,206		43,140		44,307
	(Loss)/income from operations	-8,353		12,081		5,766

	Additional information on the Partnership’s revenue by product category for the periods ended December 31, 2013, 2012 and 2011 is as follows:


		2013		2012		2011
		(in thousands)
	Met coal revenue	$ 53,721		$ 59,511		$ 79,227
	Steam coal revenue	182,880		245,057		254,649
	Other revenue	35,664		47,175		33,345
	Total revenue	$ 272,265		$ 351,743		$ 367,221

Supplemental_Information_On_Oi

Supplemental Information On Oil And Gas Exploration And Production Activities	12 Months Ended
	Dec. 31, 2013
Supplemental Information On Oil And Gas Exploration And Production Activities [Abstract]	'
Supplemental Information On Oil And Gas Exploration And Production Activities	'
	22. SUPPLEMENTAL INFORMATION ON OIL AND GAS EXPLORATION AND PRODUCTION ACTIVITIES
	The following is revenue and cost information relating to the Partnership’s proportionate share of oil and natural gas operations located entirely in the Utica Shale region of the United States: (Note: the Utica Shale oil and natural gas operations detailed below are reclassified within the non-current assets held for sale total included in the consolidated statements of financial position and Income from discontinued operations in the consolidated statements of income and comprehensive income due to the sale of the Partnership’s Utica Shale assets as described in Note 3)
	Capitalized Costs Related to Oil and Gas Producing Activities

		December 31,
		2013	2012
		(in thousands)
	Proven properties	$ 25,335	$ 6,183
	Unproven properties	30,810	24,083
	Total	56,145	30,266
	Less accumulated depreciation, depletion and amortization	-2,703	-96
	Net	$ 53,442	$ 30,170
	Costs Incurred in Oil and Gas Property Acquisition and Development Activities


		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Acquisition	$ 7,857	$ 5,073	$ 19,874
	Development of proved undeveloped properties	18,022	5,319	-
	Exploratory	-	-	-
	Total	$ 25,879	$ 10,392	$ 19,874



	Results of Operations for Producing Activities
	The following schedule sets forth the Partnership’s proportionate share revenues and expenses related to the production and sale of oil and natural gas.

		Year Ended December 31,
		2013	2012	2011
		(in thousands, except per BOE amounts)
	Revenues	$ 5,626	$ 248	$ -
	Production costs	-1,288	-63	-
	Depletion	-2,607	-96	-
	Results of operations from producing activities	$ 1,731	$ 89	$ -
	Depletion per barrel of oil equivalent (BOE)	$ 15.91	$ 16.73	$ -

Quarterly_Financial_Data

Quarterly Financial Data	12 Months Ended
Quarterly Financial Data	Dec. 31, 2013
Quarterly Financial Data [Abstract]	'
Quarterly Financial Data	'
	23. QUARTERLY FINANCIAL DATA (UNAUDITED)



	(in thousands, except per unit data)	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	2013:00:00
	Revenues	$ 74,467	$ 65,613	$ 69,501	$ 62,684
	Income from operations	2,955	9,546	5,070	2,959
	Net (loss)/ income from continuing operations	-271	5,545	2,149	687
	Income from discontinued operations	94	352	728	133
	Net (loss)/income	$ (177)	$ 5,897	$ 2,877	$ 820
	Basic and diluted net (loss)/income per limited partner unit:
	Common units:
	Net income per unit from continuing operations	$ (0.01)	$ 0.20	$ 0.07	$ 0.02
	Net income per unit from discontinued operations	-	0.01	0.03	0.01
	Net income per common unit, basic and diluted	$ (0.01)	$ 0.21	$ 0.10	$ 0.03
	Subordinated units:
	Net income per unit from continuing operations	$ (0.01)	$ 0.20	$ 0.07	$ 0.02
	Net income per unit from discontinued operations	-	0.01	0.03	0.01
	Net income per subordinated unit, basic and diluted	$ (0.01)	$ 0.21	$ 0.10	$ 0.03
	Weighted average number of limited partner units outstanding, basic:
	Common units	15,354	15,371	15,609	16,659
	Subordinated units	12,397	12,397	12,397	12,397
	Weighted average number of limited partner units outstanding, diluted:
	Common units	15,354	15,379	15,621	16,672
	Subordinated units	12,397	12,397	12,397	12,397



	(in thousands, except per unit data)	First Quarter	Second Quarter	Third Quarter	Fourth Quarter (1)
	2012:00:00
	Revenues	$ 81,882	$ 89,998	$ 93,575	$ 86,288
	Income from operations	8,688	12,599	9,151	10,928
	Net income from continuing operations	8,974	12,996	8,876	8,602
	Income from discontinued operations	-	-	-	88
	Net income	$ 8,974	$ 12,996	$ 8,876	$ 8,690
	Basic and diluted net income per limited partner unit:
	Common units:
	Net income per unit from continuing operations	$ 0.32	$ 0.46	$ 0.31	$ 0.30
	Net income per unit from discontinued operations	-	-	-	0.01
	Net income per common unit, basic and diluted	$ 0.32	$ 0.46	$ 0.31	$ 0.31
	Subordinated units:
	Net income per unit from continuing operations	$ 0.32	$ 0.46	$ 0.31	$ 0.30
	Net income per unit from discontinued operations	-	-	-	0.01
	Net income per subordinated unit, basic and diluted	$ 0.32	$ 0.46	$ 0.31	$ 0.31
	Weighted average number of limited partner units outstanding, basic:
	Common units	15,313	15,329	15,332	15,348
	Subordinated units	12,397	12,397	12,397	12,397
	Weighted average number of limited partner units outstanding, diluted:
	Common units	15,327	15,331	15,333	15,349
	Subordinated units	12,397	12,397	12,397	12,397

	(1) Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnership’s liability and costs for black lung benefits (see note 12 for further details).

Summary_Of_Significant_Account1

Summary Of Significant Accounting Policies And General (Policies)	12 Months Ended
	Dec. 31, 2013
Summary Of Significant Accounting Policies And General [Abstract]	'
Company Environment And Risk Factors	'
	Company Environment and Risk Factors. The Partnership, in the course of its business activities, is exposed to a number of risks including: fluctuating market conditions of coal, truck and rail transportation, fuel costs, changing government regulations, unexpected maintenance and equipment failure, employee benefits cost control, changes in estimates of proven and probable coal reserves, as well as the ability of the Partnership to maintain adequate financing, necessary mining permits and control of sufficient recoverable coal properties. In addition, adverse weather and geological conditions may increase mining costs, sometimes substantially.

Concentrations Of Credit Risk	'
	Concentrations of Credit Risk. See Note 17 for discussion of major customers. The Partnership does not require collateral or other security on accounts receivable. The credit risk is controlled through credit approvals and monitoring procedures.

Cash And Cash Equivalents	'
	Cash and Cash Equivalents. The Partnership considers all highly liquid investments purchased with original maturities of three months or less to be cash equivalents.

Inventories	'
	Inventories. Inventories are stated at the lower of cost, based on a three month rolling average, or market. Inventories primarily consist of coal contained in stockpiles.

Advance Royalties	'
	Advance Royalties. The Partnership is required, under certain royalty lease agreements, to make minimum royalty payments whether or not mining activity is being performed on the leased property. These minimum payments may be recoupable once mining begins on the leased property. The Partnership capitalizes the recoupable minimum royalty payments and amortizes the deferred costs once mining activities begin on the units-of-production method or expenses the deferred costs when the Partnership has ceased mining or has made a decision not to mine on such property.

Note Receivable	'
	Note Receivable. At various times during 2012, the Partnership loaned to Rhino Eastern LLC (“Rhino Eastern”), a joint venture with an affiliate of Patriot Coal Corporation (“Patriot”), approximately $11.9 million that was recorded as notes receivable, which bear interest at a fixed rate of 10%. The notes were fully repaid as of December 31, 2012. The Partnership did not provide any loans to Rhino Eastern during 2013.
	During 2013, the Partnership provided a loan based upon its ownership share to Muskie Proppant LLC (“Muskie”) in the amount of $0.2 million that remained outstanding as of December 31, 2013. Muskie is a joint venture established in 2012 with affiliates of Wexford Capital, which was formed to provide sand for fracking operations to drillers in the Utica Shale region and other oil and natural gas basins in the United States. The note bears interest at a rate equal to the lesser of (a) the prime interest rate plus 2.5% per annum, or (b) the maximum rate of interest permitted by applicable law.

Property, Plant And Equipment	'
	Property, Plant and Equipment. Property, plant, and equipment, including coal properties, oil and natural gas properties, mine development costs and construction costs, are recorded at cost, which includes construction overhead and interest, where applicable. Expenditures for major renewals and betterments are capitalized, while expenditures for maintenance and repairs are expensed as incurred. Mining and other equipment and related facilities are depreciated using the straight-line method based upon the shorter of estimated useful lives of the assets or the estimated life of each mine. Coal properties, as well as oil and natural gas properties, are depleted using the units-of-production method, based on estimated proven and probable reserves. Mine development costs are amortized using the units-of-production method, based on estimated proven and probable reserves. The Partnership assumes zero salvage values for its property, plant and equipment when depreciation and amortization are calculated. Gains or losses arising from sales or retirements are included in current operations.
	Stripping costs incurred in the production phase of a mine for the removal of overburden or waste materials for the purpose of obtaining access to coal that will be extracted are variable production costs that are included in the cost of inventory produced and extracted during the period the stripping costs are incurred. The Partnership defines a surface mine as a location where the Partnership utilizes operating assets necessary to extract coal, with the geographic boundary determined by property control, permit boundaries, and/or economic threshold limits. Multiple pits that share common infrastructure and processing equipment may be located within a single surface mine boundary, which can cover separate coal seams that typically are recovered incrementally as the overburden depth increases. In accordance with the accounting guidance for extractive mining activities, the Partnership defines a mine in production as one from which saleable minerals have begun to be extracted (produced) from an ore body, regardless of the level of production; however, the production phase does not commence with the removal of de minimis saleable mineral material that occurs in conjunction with the removal of overburden or waste material for the purpose of obtaining access to an ore body. The Partnership capitalizes only the development cost of the first pit at a mine site that may include multiple pits.
	For the Partnership’s oil and natural gas investments, the Partnership uses the full cost method of accounting for oil and natural gas operations. Accordingly, all costs, including nonproductive costs and certain general and administrative costs directly associated with acquisition, exploration and development of oil and natural gas properties, are capitalized. Under the full cost method of accounting, the Partnership is required to perform a ceiling test each quarter. The test determines a limit, or cost center ceiling, on the book value of the oil and natural gas properties. Net capitalized costs are limited to the lower of unamortized cost or the cost center ceiling. The cost center ceiling is defined as the sum of (a) estimated future net revenues, discounted at 10% per annum, from proved reserves, based on the 12-month unweighted average of the first-day-of-the-month price during the applicable year, excluding the estimated abandonment costs for properties with asset retirement obligations recorded on the balance sheet, (b) the cost of properties not being amortized, if any, and (c) the lower of cost or market value of unproved properties included in the cost being amortized. If the net book value exceeds the ceiling, an impairment or noncash writedown is required. Such capitalized costs, including the estimated future development costs and site remediation costs of proved undeveloped properties are depleted by an equivalent units-of-production method, converting gas to barrels at the ratio of six Mcf of natural gas to one barrel of oil. No gain or loss is recognized upon the disposal of oil and natural gas properties, unless such dispositions significantly alter the relationship between capitalized costs and proven oil and natural gas reserves. Oil and natural gas properties not subject to amortization are detailed in Note 5. These costs are reviewed quarterly by the Partnership for impairment. If impairment has occurred, the portion of cost in excess of the current value is transferred to the cost of oil and natural gas properties subject to amortization. Factors considered by the Partnership in its impairment assessment include drilling results by the operators on the Partnership’s oil and natural gas properties, the terms of oil and natural gas leases not held by production, and available funds for exploration and development.

Asset Impairments For Coal Properties, Mine Development Costs And Other Coal Mining Equipment And Related Facilities	'
	Asset Impairments for Coal Properties, Mine Development Costs and Other Coal Mining Equipment and Related Facilities. The Partnership follows the accounting guidance on the impairment or disposal of property, plant and equipment for its coal mining assets, which requires that projected future cash flows from use and disposition of assets be compared with the carrying amounts of those assets when potential impairment is indicated. When the sum of projected undiscounted cash flows is less than the carrying amount, impairment losses are recognized. In determining such impairment losses, the Partnership must determine the fair value for the coal mining assets in question in accordance with the applicable fair value accounting guidance. Once the fair value is determined, the appropriate impairment loss must be recorded as the difference between the carrying amount of the coal mining assets and their respective fair values. Also, in certain situations, expected mine lives are shortened because of changes to planned operations or changes in coal reserve estimates. When that occurs and it is determined that the mine’s underlying costs are not recoverable in the future, reclamation and mine closing obligations are accelerated and the mine closing accrual is increased accordingly. To the extent it is determined that coal asset carrying values will not be recoverable during a shorter mine life, a provision for such impairment is recognized. During 2013, the Partnership recorded an impairment loss of $1.7 million related to its McClane Canyon mining complex in Colorado. See Note 6 for more information on this impairment loss. There were no impairment losses recorded during the years ended December 31, 2012 and 2011.

Debt Issuance Costs	'
	Debt Issuance Costs. Debt issuance costs reflect fees incurred to obtain financing and are amortized (included in interest expense) using the effective interest method over the life of the related debt. Debt issuance costs are included in other non-current assets.

Asset Retirement Obligations	'
	Asset Retirement Obligations. The accounting guidance for asset retirement obligations addresses asset retirement obligations that result from the acquisition, construction or normal operation of long-lived assets. This guidance requires companies to recognize asset retirement obligations at fair value when the liability is incurred or acquired. Upon initial recognition of a liability, an amount equal to the liability is capitalized as part of the related long-lived asset and allocated to expense over the useful life of the asset. The Partnership has recorded the asset retirement costs for its mining operations in coal properties. In addition, the Partnership has recorded asset retirement costs for its proportionate share of its oil and natural gas investments, which are included in oil and natural gas properties.
	The Partnership estimates its future cost requirements for reclamation of land where it has conducted surface and underground mining operations, based on its interpretation of the technical standards of regulations enacted by the U.S. Office of Surface Mining, as well as state regulations. These costs relate to reclaiming the pit and support acreage at surface mines and sealing portals at underground mines. Other reclamation costs are related to refuse and slurry ponds, as well as holding and related termination/exit costs.
	The Partnership expenses contemporaneous reclamation which is performed prior to final mine closure. The establishment of the end of mine reclamation and closure liability is based upon permit requirements and requires significant estimates and assumptions, principally associated with regulatory requirements, costs and recoverable coal reserves. Annually, the Partnership reviews its end of mine reclamation and closure liability and makes necessary adjustments, including mine plan and permit changes and revisions to cost and production levels to optimize mining and reclamation efficiency. When a mine life is shortened due to a change in the mine plan, mine closing obligations are accelerated, the related accrual is increased and the related asset is reviewed for impairment, accordingly.
	The adjustments to the liability from annual recosting reflect changes in expected timing, cash flow and the discount rate used in the present value calculation of the liability. Each respective year includes a range of discount rates that are dependent upon the timing of the cash flows of the specific obligations. Changes in the Partnership’s asset retirement obligations for the year ended December 31, 2013 were calculated with discount rates that ranged from 2.3% to 5.6%. Changes in the asset retirement obligations for the year ended December 31, 2012 were calculated with discount rates that ranged from 3.2% to 5.3%. Changes in the asset retirement obligations for the year ended December 31, 2011 were calculated with discount rates that ranged from 4.2% to 7.0%. The discount rates changed in each respective year due to changes in applicable market indicators that are used to arrive at an appropriate discount rate. Other recosting adjustments to the liability are made annually based on inflationary cost increases or decreases and changes in the expected operating periods of the mines. The related inflation rate utilized in the recosting adjustments was 2.3 % for 2013 and 2012, and 2.5% for 2011.

Workers' Compensation Benefits	'
	Workers’ Compensation Benefits. Certain of the Partnership’s subsidiaries are liable under federal and state laws to pay workers’ compensation and coal workers’ pneumoconiosis (“black lung”) benefits to eligible employees, former employees and their dependents. The Partnership currently utilizes an insurance program and state workers’ compensation fund participation to secure its on-going obligations depending on the location of the operation. Premium expense for workers’ compensation benefits is recognized in the period in which the related insurance coverage is provided.
	The Partnership’s black lung benefit liability is calculated using the service cost method that considers the calculation of the actuarial present value of the estimated black lung obligation. The actuarial calculations using the service cost method for the Partnership’s black lung benefit liability are based on numerous assumptions including disability incidence, medical costs, mortality, death benefits, dependents and interest rates.
	In addition, the Partnership’s liability for traumatic workers’ compensation injury claims is the estimated present value of current workers' compensation benefits, based on actuarial estimates. The actuarial estimates for the Partnership’s workers’ compensation liability are based on numerous assumptions including claim development patterns, mortality, medical costs and interest rates.
	See Note 12 for more information on the Partnership’s workers’ compensation and black lung liabilities and expense.

Revenue Recognition	'
	Revenue Recognition. Most of the Partnership’s revenues are generated under long-term coal sales contracts with electric utilities, industrial companies or other coal-related organizations, primarily in the eastern United States. Revenue is recognized and recorded when shipment or delivery to the customer has occurred, prices are fixed or determinable and the title or risk of loss has passed in accordance with the terms of the sales agreement. Under the typical terms of these agreements, risk of loss transfers to the customers at the mine or port, when the coal is loaded on the rail, barge, truck or other transportation source that delivers coal to its destination. Advance payments received are deferred and recognized in revenue as coal is shipped and title has passed.
	Coal sales revenues also result from the sale of brokered coal produced by others. The revenues related to brokered coal sales are included in coal sales revenues on a gross basis and the corresponding cost of the coal from the supplier is recorded in cost of coal sales in accordance with the revenue recognition accounting guidance on principal agent considerations.
	Freight and handling costs paid directly to third‑party carriers and invoiced to coal customers are recorded as freight and handling costs and freight and handling revenues, respectively.
	Other revenues generally consist of coal royalty revenues, limestone sales, coal handling and processing, oil and natural gas revenues, rebates and rental income. Coal royalty revenues are recognized on the basis of tons of coal sold by the Partnership’s lessees and the corresponding gross revenues from those sales. The leases are based on (1) minimum monthly or annual payments, (2) a minimum dollar royalty per ton and/or a percentage of the gross sales price, or (3) a combination of both. Coal royalty revenues are recorded from royalty reports submitted by the lessee, which are reconciled and subject to audit by the Partnership. Most of the Partnership’s lessees are required to make minimum monthly or annual royalty payments that are recoupable over certain time periods, generally two years. If tonnage royalty revenues do not meet the required minimum amount, the difference is paid as a deficiency. These deficiency payments received are recognized as an unearned revenue liability because they are generally recoupable over certain time periods. When a lessee recoups a deficiency payment through production, the recouped amount is deducted from the unearned revenue liability and added to revenue attributable to the coal royalty revenue in the current period. If a lessee does not recoup a deficiency paid during the allocated time period, the recoupment right lost becomes revenue in the current period and is deducted from the liability.
	With respect to other revenues recognized in situations unrelated to the shipment of coal or coal royalties, the Partnership carefully reviews the facts and circumstances of each transaction and does not recognize revenue until the following criteria are met: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the seller’s price to the buyer is fixed or determinable and collectibility is reasonably assured. Advance payments received are deferred and recognized in revenue when earned.

Equity-Based Compensation	'
	Equity‑Based Compensation. The Partnership applies the provisions of ASC Topic 718 to account for any unit awards granted to employees or directors. This guidance requires that all share‑based payments to employees or directors, including grants of stock options, be recognized in the financial statements based on their fair value. The General Partner has currently granted restricted units and phantom units to directors and certain employees of the General Partner and Partnership that contain only a service condition. The fair value of each restricted unit and phantom unit award was calculated using the closing price of the Partnership’s common units on the date of grant.
	With the vesting of the first portion of the employees’ awards in early April 2011, the Compensation Committee of the board of directors of the General Partner elected to pay some of the awards in cash or a combination of cash and common units. This election was a change in policy from December 31, 2010 since management had previously planned to settle all employee awards with units upon vesting as per the grant agreements. This policy change resulted in a modification of all employee awards from equity to liability classification as of March 31, 2011 and all new awards granted thereafter. Thus, the employee awards are required to be marked-to-market each reporting period until they are vested. Restricted unit awards granted to directors of the General Partner are considered nonemployee equity‑based awards since the directors are not elected by unitholders. Thus, these director awards are also required to be marked-to-market each reporting period until they are vested. Expense related to unit awards is recorded in the selling, general and administrative line of the Partnership’s consolidated statements of operations and comprehensive income.

Derivative Financial Instruments	'
	Derivative Financial Instruments. On occasion, the Partnership uses diesel fuel forward contracts to manage the risk of fluctuations in the cost of diesel fuel. The Partnership’s diesel fuel forward contracts qualify for the normal purchase normal sale (“NPNS”) exception prescribed by the accounting guidance on derivatives and hedging, based on management’s intent and ability to take physical delivery of the diesel fuel. The Partnership did not have any diesel fuel forward contracts as of December 31, 2013.

Investment In Joint Ventures	'
	Investment in Joint Ventures. Investments in joint ventures are accounted for using the consolidation, equity method or cost basis depending upon the level of ownership, the Partnership’s ability to exercise significant influence over the operating and financial policies of the investee and whether the Partnership is determined to be the primary beneficiary of a variable interest entity. Equity investments are recorded at original cost and adjusted periodically to recognize the Partnership’s proportionate share of the investees’ net income or losses after the date of investment. Any losses from the Partnership’s equity method investment are absorbed by the Partnership based upon its proportionate ownership percentage. If losses are incurred that exceed the Partnership’s investment in the equity method entity, then the Partnership must continue to record its proportionate share of losses in excess of its investment. Investments are written down only when there is clear evidence that a decline in value that is other than temporary has occurred.
	In May 2008, the Operating Company entered into a joint venture, Rhino Eastern, with an affiliate of Patriot to acquire the Eagle mining complex. To initially capitalize the Rhino Eastern joint venture, the Operating Company contributed approximately $16.1 million for a 51% ownership interest in the joint venture and accounts for the investment in Rhino Eastern and its results of operations under the equity method. The Partnership considers the operations of this entity to comprise a reporting segment (“Eastern Met”) and has provided additional detail related to this operation in Note 21, “Segment Information.”
	In determining that the Partnership was not the primary beneficiary of the variable interest entity for the years ended December 31, 2013, 2012 and 2011, the Partnership performed a qualitative and quantitative analysis based on the controlling economic interests of the Rhino Eastern joint venture. This included an analysis of the expected economic contributions of the joint venture. The Partnership concluded that it is not the primary beneficiary of Rhino Eastern primarily because of certain contractual arrangements by the joint venture with Patriot and the fact that the Rhino Eastern joint venture is managed by a committee of an equal number of representatives from Patriot and us. Mandatory pro rata additional contributions not to exceed $10 million in the aggregate could be required of the joint venture partners which the Partnership would be obligated to fund based upon its 51% ownership interest.
	As of December 31, 2013 and 2012, the Partnership has recorded its equity method investment of $19.4 million and $21.4 million, respectively, in the Rhino Eastern joint venture as a long-term asset. During 2013, the Partnership contributed additional capital based upon its ownership share to the Rhino Eastern joint venture in the amount of $2.3 million. The Partnership did not contribute any additional capital during 2012. As disclosed in Note 19 “Related Party and Affiliate Transactions”, during 2012 and 2011, the Partnership provided loans to Rhino Eastern totaling approximately $11.9 million and $5.8 million, respectively, which were fully repaid as of December 31, 2012 and 2011.
	On July 9, 2012, Patriot filed for Chapter 11 bankruptcy protection. Patriot successfully exited bankruptcy in December 2013 and normal operations have continued at the Rhino Eastern joint venture.
	In March 2012, the Partnership made an initial investment of approximately $0.1 million in a new joint venture, Timber Wolf Terminals LLC (“Timber Wolf”), with affiliates of Wexford. Timber Wolf was formed to construct and operate a condensate river terminal that will provide barge trans-loading services for parties conducting activities in the Utica Shale region of eastern Ohio. The initial investment was the Partnership’s proportionate minority ownership share to purchase land for the construction site of the condensate river terminal. Timber Wolf had no operating activities during the years ended December 31, 2013 and 2012 and the Partnership will initially include any operating activities of Timber Wolf in its Other category for segment reporting purposes.
	In December 2012, the Partnership made an initial investment of approximately $2.0 million in a new joint venture, Muskie Proppant LLC, with affiliates of Wexford Capital. Muskie was formed to provide sand for fracking operations to drillers in the Utica Shale region and other oil and natural gas basins in the U.S. During 2013, the Partnership contributed additional capital based upon its ownership share to the Muskie joint venture in the amount of $0.5 million. As disclosed in Note 19 “Related Party and Affiliate Transactions”, during 2013 the Partnership provided a loan to Muskie totaling approximately $0.2 million which remained outstanding as of December 31, 2013. In addition, the Partnership recorded its proportionate portion of operating losses for 2013 and 2012, approximately $0.5 million and $0.3 million, respectively, for Muskie. As of December 31, 2013 and 2012, the Partnership has recorded its equity method investment of $1.8 million and $1.7 million, respectively, in the Muskie joint venture as a long-term asset. The Partnership initially included Muskie in its Other category for segment reporting purposes, but Muskie is included in the Partnership’s Oil and Natural Gas segment beginning with December 31, 2013 reporting. See Note 21 for information on the Partnership’s reportable segments.

Income Taxes	'
	Income Taxes. The Partnership is considered a partnership for income tax purposes. Accordingly, the partners report the Partnership’s taxable income or loss on their individual tax returns.

Loss Contingencies	'
	Loss Contingencies. In accordance with the guidance on accounting for contingencies, the Partnership records loss contingencies at such time that an unfavorable outcome becomes probable and the amount can be reasonably estimated. When the reasonable estimate is a range, the recorded loss is the best estimate within the range. If no amount in the range is a better estimate than any other amount, the minimum amount of the range is recorded. The Partnership discloses information concerning loss contingencies for which an unfavorable outcome is probable. See Note 15, “Commitments and Contingencies,” for a discussion of such matters.

Management's Use Of Estimates	'
	Management’s Use of Estimates. The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements as well as the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Recently Issued Accounting Standards	'
	Recently Issued Accounting Standards. In February 2013, the FASB issued ASU No. 2013-02, “Comprehensive Income (Topic 220) Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income”. This ASU requires preparers to report, in one place, information about reclassifications out of accumulated other comprehensive income (“AOCI”). The ASU also requires companies to report changes in AOCI balances. For significant items reclassified out of AOCI to net income in their entirety in the same reporting period, reporting (either on the face of the statement where net income is presented or in the notes) is required about the effect of the reclassifications on the respective line items in the statement where net income is presented. For items that are not reclassified to net income in their entirety in the same reporting period, a cross reference to other disclosures currently required under U.S. GAAP (e.g., pension amounts that are included in inventory) is required in the notes. The above information must be presented in one place (parenthetically on the face of the financial statements by income statement line item or in a note). Public companies must provide the information required by the ASU (e.g., changes in AOCI balances and reclassifications out of AOCI) in interim and annual periods. For public companies, the ASU is effective for fiscal years and interim periods within those years beginning after 15 December 2012, or the first quarter of 2013 for calendar-year companies. The Partnership has included the required disclosures of ASU 2013-02 in this Report on Form 10-K and this ASU did not have a material effect on the Partnership.

Business_Combinations_And_Othe1

Business Combinations And Other Acquisitions (Tables) (Elk Horn Coal Company [Member})	12 Months Ended
	Dec. 31, 2013
Elk Horn Coal Company [Member}	'
Business Acquisition [Line Items]	'
Summary Of Assets Acquired And Liabilities Assumed	'

		(in thousands)
	Cash	$ 58
	Accounts receivable	2,619
	Prepaid expenses and other	94
	Property, plant and equipment	7,466
	Mine development costs	3,000
	Coal properties	111,647
	Intangible assets	654
	Other non-current assets	1,112
	Accounts payable	-79
	Deferred revenues	-2,499
	Accrued expenses and other	-1,691
	Asset retirement obligations	-2,707
	Net assets acquired	$ 119,674
	Total consideration	$ 119,674


Business Acquisition, Pro Forma Information	'

		Year ended
		31-Dec-11
	Revenues:	(in thousands)
	As reported	$ 367,221
	Pro forma adjustments	9,477
	Pro forma revenues	$ 376,698

	Net Income:
	As reported	$ 38,071
	Pro forma adjustments	3,129
	Pro forma net income	$ 41,200

	Net income per limited partner unit, diluted:
	As reported	$ 1.43
	Pro forma adjustments	$ 0.03
	Pro forma net income per limited partner unit	$ 1.46

Prepaid_Expenses_And_Other_Cur1

Prepaid Expenses And Other Current Assets (Tables)	12 Months Ended
Prepaid Expenses And Other Current Assets (Tables)	Dec. 31, 2013
Prepaid Expenses And Other Current Assets [Abstract]	'
Schedule Of Prepaid Expenses And Other Current Assets	'

		December 31,
		2013	2012
		(in thousands)
	Other prepaid expenses	$ 951	$ 767
	Prepaid insurance	1,958	1,895
	Prepaid leases	122	121
	Supply inventory	1,221	1,219
	Deposits	320	321
	Total	$ 4,572	$ 4,323

Property_Plant_And_Equipment_T

Property, Plant And Equipment (Tables)	12 Months Ended
Property, Plant And Equipment (Tables)	Dec. 31, 2013
Property, Plant And Equipment [Abstract]	'
Property, Plant And Equipment By Major Classification	'

				December 31,
		Useful Lives		2013		2012
				(in thousands)
	Land and land improvements			$ 35,078		$ 34,978
	Mining and other equipment and related facilities	2 - 20 Years		302,114		297,615
	Mine development costs	1 - 15 Years		73,344		67,045
	Coal properties	1 - 15 Years		238,975		240,368
	Oil and natural gas properties			8,093		8,182
	Construction work in process			17,104		5,216
	Total			674,708		653,404
	Less accumulated depreciation, depletion and amortization			-249,718		-219,613
	Net			$ 424,990		$ 433,791


Oil And Natural Gas Properties Not Subject To Amortization	'

			December 31,
			2013		2012
			(in thousands)
	Acquisition costs		$ 30,430		$ 32,175
	Exploration costs		-		-
	Development costs		-		-
	Total		$ 30,430		$ 32,175


Depreciation, Depletion, And Amortization	'


			Year Ended December 31,
			2013		2012		2011
			(in thousands)
	Depreciation expense-mining and other equipment and related facilities		$ 31,510		$ 32,685		$ 26,467
	Depletion expense for coal properties (1)		5,387		5,784		5,140
	Depletion expense for oil and natural gas properties		47		-		-
	Amortization expense for mine development costs		2,520		2,180		3,322
	Amortization expense for intangible assets		80		80		65
	Amortization expense for asset retirement costs		83		545		1,331
	Total		$ 39,627		$ 41,274		$ 36,325

	(1) Depletion expense for the Partnership’s Utica Shale oil and natural gas properties are reclassified to Income from discontinued operations line in the consolidated statements of operations and comprehensive income due to the sale of the Partnership’s Utica shale assets as described in Note 3.

Goodwill_And_Intangible_Assets1

Goodwill And Intangible Assets (Tables)	12 Months Ended
Goodwill And Intangible Assets (Tables)	Dec. 31, 2013
Goodwill And Intangible Assets [Abstract]	'
Schedule Of Intangible Assets By Major Class	'
	Intangible assets of the Partnership as of December 31, 2013 consisted of the following:


		Gross		Net
		Carrying	Accumulated	Carrying
	Intangible Asset	Amount	Amortization	Amount
		(in thousands)
	Patent	$ 728	$ 207	$ 521
	Developed Technology	78	22	56
	Trade Name	184	23	161
	Customer List	470	60	410
	Total	$ 1,460	$ 312	$ 1,148

	Intangible assets of the Partnership as of December 31, 2012 consisted of the following:


		Gross		Net
		Carrying	Accumulated	Carrying
	Intangible Asset	Amount	Amortization	Amount
		(in thousands)
	Patent	$ 728	$ 164	$ 564
	Developed Technology	78	18	60
	Trade Name	184	14	170
	Customer List	470	36	434
	Total	$ 1,460	$ 232	$ 1,228


Future Amortization Expense	'

			Developed		Customer
		Patent	Technology	Trade Name	List	Total
		(in thousands)
	2014	$ 43	$ 5	$ 9	$ 23	$ 80
	2015	43	5	9	23	80
	2016	43	5	9	23	80
	2017	43	5	9	23	80
	2018	43	5	9	23	80

Other_NonCurrent_Assets_Tables

Other Non-Current Assets (Tables)	12 Months Ended
Other Non-Current Assets (Tables)	Dec. 31, 2013
Other Non-Current Assets [Abstract]	'
Schedule Of Other Non-Current Assets	'

		December 31,
		2013	2012
		(in thousands)
	Deposits and other	$ 1,223	$ 1,988
	Debt issuance costs—net	3,535	3,851
	Non-current receivable	4,327	3,829
	Note receivable	206	-
	Deferred expenses	349	16
	Total	$ 9,640	$ 9,684

Accrued_Expenses_And_Other_Cur1

Accrued Expenses And Other Current Liabilities (Tables)	12 Months Ended
Accrued Expenses And Other Current Liabilities (Tables)	Dec. 31, 2013
Accrued Expenses And Other Current Liabilities [Abstract]	'
Schedule Of Accrued Expenses And Other Current Liabilities	'

		December 31,
		2013	2012
		(in thousands)
	Payroll, bonus and vacation expense	$ 3,573	$ 4,086
	Non-income taxes	2,750	3,318
	Royalty expenses	2,001	2,536
	Accrued interest	760	671
	Health claims	1,036	1,479
	Workers’ compensation & pneumoconiosis	1,190	1,784
	Deferred revenues	3,592	2,788
	Accrued insured litigation claims	2,579	2,783
	Other	3,086	2,733
	Total	$ 20,567	$ 22,178

Debt_Tables

Debt (Tables)	12 Months Ended
Debt (Tables)	Dec. 31, 2013
Debt [Abstract]	'
Schedule Of Debt	'

		December 31,
		2013	2012
		(in thousands)
	Senior secured credit facility with PNC Bank, N.A.	$ 167,040	$ 157,250
	Note payable to H&L Construction Co., Inc.	800	1,560
	Other notes payable	3,206	4,739
	Total	171,046	163,549
	Less current portion	-1,024	-2,350
	Long-term debt	$ 170,022	$ 161,199


Schedule Of Principal Payments On Long-Term Debt	'

		in thousands
	2014	$ 1,049
	2015	210
	2016	167,265
	2017	240
	2018	257
	Thereafter	2,050
	Total principal payments	171,071
	Less imputed interest on interest free notes payable	-25
	Total debt	$ 171,046

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
Asset Retirement Obligations (Tables)	Dec. 31, 2013
Asset Retirement Obligations [Abstract]	'
Schedule Of Asset Retirement Obligations	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Balance at beginning of period (including current portion)	$ 33,003	$ 34,113	$ 35,691
	Accretion expense	2,356	1,896	1,956
	Adjustment resulting from addition of property	-	72	2,707
	Adjustment resulting from disposal of property	-	-968	-3,588
	Adjustments to the liability from annual recosting and other	20	-201	-617
	Liabilities settled	-928	-1,909	-2,036
	Balance at end of period	34,451	33,003	34,113
	Less current portion of asset retirement obligation	-1,614	-2,255	-3,192
	Long-term portion of asset retirement obligation	$ 32,837	$ 30,748	$ 30,921

Workers_Compensation_And_Black1

Workers' Compensation And Black Lung (Tables)	12 Months Ended
Workers' Compensation And Black Lung (Tables)	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]	'
Summary Of Black Lung And Workers' Compensation Expenses	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Service costs	$ 385	$ 378	$ 491
	Interest cost	186	231	312
	Amortization of (gain)	-145	-295	-
	Benefit cost	$ 426	$ 314	$ 803


Classification Of Net Amounts Recognized For Workers' Compensation And Black Lung Benefits	'

		December 31,
		2013	2012
		(in thousands)
	Current liability—postretirement benefits	$ (334)	$ (227)
	Non-current liability—postretirement benefits	-5,786	-6,520
	Net amount recognized	$ (6,120)	$ (6,747)


Workers' Compensation And Black Lung Benefits [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Summary Of Black Lung And Workers' Compensation Expenses	'

		Year Ended December 31,
		2013	2012	2011
	Black lung benefits:	(in thousands)
	Service cost	$ 736	$ 1,215	$ 156
	Interest cost	469	466	110
	Actuarial (gain)/loss	-1,584	693	1,231
	Total black lung	-379	2,374	1,497
	Workers' compensation expense	2,743	1,018	4,049
	Total expense	$ 2,364	$ 3,392	$ 5,546


Classification Of Net Amounts Recognized For Workers' Compensation And Black Lung Benefits	'

		December 31,
		2013	2012
		(in thousands)
	Black lung claims	$ 7,251	$ 8,513
	Workers' compensation claims	10,159	9,846
	Total obligations	$ 17,410	$ 18,359
	Less current portion	-1,190	-1,784
	Non-current obligations	$ 16,220	$ 16,575


Black Lung Benefits [Member]	'
Defined Benefit Plan Disclosure [Line Items]	'
Schedule Of Changes In Benefit Liability	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Benefit obligations at beginning of year	$ 8,513	$ 6,392	$ 5,055
	Service cost	736	1,215	156
	Interest cost	469	466	110
	Actuarial (gain)/loss	-1,584	693	1,231
	Benefits and expenses paid	-883	-253	-160
	Benefit obligations at end of year	$ 7,251	$ 8,513	$ 6,392

Employee_Benefits_Tables

Employee Benefits (Tables)	12 Months Ended
Employee Benefits (Tables)	Dec. 31, 2013
Employee Benefits [Abstract]	'
Summary Of Changes In Benefit Obligations	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Benefit obligation at beginning of period	$ 6,747	$ 5,649	$ 6,641
	Changes in benefit obligations:
	Service costs	385	378	491
	Interest cost	186	231	312
	Benefits paid	-253	-133	-72
	Actuarial (gain)/loss	-945	622	-1,723
	Benefit obligation at end of period	$ 6,120	$ 6,747	$ 5,649
	Fair value of plan assets at end of period	$ -	$ -	$ -
	Funded status	$ (6,120)	$ (6,747)	$ (5,649)


Classification Of Net Amounts Recognized For Postretirement Benefits	'

		December 31,
		2013	2012
		(in thousands)
	Current liability—postretirement benefits	$ (334)	$ (227)
	Non-current liability—postretirement benefits	-5,786	-6,520
	Net amount recognized	$ (6,120)	$ (6,747)


Amounts Recognized In Accumulated Other Comprehensive Income	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Balance at beginning of year	$ 1,431	$ 2,348	$ 625
	Actuarial gain (loss)	945	-622	1,723
	Amortization of net actuarial gain	-145	-295	-
	Net actuarial gain	$ 2,231	$ 1,431	$ 2,348


Weighted Average Assumptions Used To Determine Benefit Obligations	'

		December 31,
		2013	2012
	Weighted Average assumptions used to determine benefit obligations:
	Discount rate	3.96%	2.80%
	Expected return on plan assets	n/a	n/a


Weighted Average Assumptions Used To Determine Net Periodic Benefit Cost	'

		Year Ended December 31,
		2013	2012	2011
	Weighted Average assumptions used to determine periodic benefit cost:
	Discount rate	2.80%	4.15%	4.75%
	Expected return on plan assets	n/a	n/a	n/a
	Rate of compensation increase	n/a	n/a	n/a


Components Of Net Periodic Benefit Cost	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Service costs	$ 385	$ 378	$ 491
	Interest cost	186	231	312
	Amortization of (gain)	-145	-295	-
	Benefit cost	$ 426	$ 314	$ 803


Amounts Expected To Be Amortized From Accumulated Other Comprehensive Income Into Net Periodic Benefit Cost	'

		(in thousands)
	Net actuarial gain	$ 367


Expected Future Benefit Payments	'

	Period	(in thousands)
	2014	$ 334
	2015	397
	2016	538
	2017	602
	2018	659
	2019-2023	$ 4,337


Effect Of One-Percentage-Point Change In Assumed Health Care Cost Trend Rates	'

		One-Percentage	One-Percentage
		Point Increase	Point Decrease
		(in thousands)
	Effect on total service and interest cost components	$ 58	$ (52)
	Effect on postretirement benefit obligation	$ 467	$ (433)


Schedule Of Expense Under Defined Contribution Savings Plans	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	401(k) plan expense	$ 2,243	$ 2,322	$ 2,245

EquityBased_Compensation_Table

Equity-Based Compensation (Tables)	12 Months Ended
Equity-Based Compensation (Tables)	Dec. 31, 2013
Equity-Based Compensation [Abstract]	'
Summary Of Non-Vested LTIP Awards	'

		Common Units	Weighted Average Grant Date Fair Value (per unit)
		(in thousands)
	Non-vested awards at December 31, 2010	135	$ 20.50
	Granted	10	$ 19.90
	Vested	-52	$ 20.47
	Forfeited	-1	$ 20.50

	Non-vested awards at December 31, 2011	92	$ 20.45
	Granted	32	$ 17.40
	Vested	-49	$ 20.12
	Forfeited	-8	$ 20.28

	Non-vested awards at December 31, 2012	67	$ 19.23
	Granted	49	$ 13.50
	Vested	-58	$ 18.88
	Forfeited	-3	$ 16.62

	Non-vested awards at December 31, 2013	55	$ 14.63

Commitments_And_Contingencies_

Commitments And Contingencies (Tables)	12 Months Ended
Commitments And Contingencies (Tables)	Dec. 31, 2013
Commitments And Contingencies [Abstract]	'
Schedule Of Delivery Commitments	'

	Year	Tons (in thousands)	Number of customers
	2014	3,045	19
	2015	1,796	4
	2016	1,100	2
	2017	1,100	2


Schedule Of Purchased Coal Expenses	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Purchased coal expense	$ 3,730	$ 25,637	$ 14,283
	OTC expense	$ 1,271	$ -	$ 14


Schedule Of Lease And Royalty Expense	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Lease expense	$ 3,161	$ 2,860	$ 2,630
	Royalty expense	$ 11,442	$ 14,474	$ 16,175


Future Minimum Lease And Royalty Payments	'

	Years Ended December 31,	Royalties	Leases
		(in thousands)
	2014	$ 1,642	$ 1,577
	2015	1,865	1,538
	2016	1,864	1,545
	2017	1,922	1,141
	2018	1,929	193
	Thereafter	9,644	-
	Total minimum royalty and lease payments	$ 18,866	$ 5,994

Earnings_Per_Unit_EPU_Tables

Earnings Per Unit ("EPU") (Tables)	12 Months Ended
Earnings Per Unit ("EPU") (Tables)	Dec. 31, 2013
Earnings Per Unit ("EPU") [Abstract]	'
Schedule Of Calculation Of Numerator And Denominator In Earnings Per Share	'


	Year ended December 31, 2013	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net income:
	Net income from continuing operations	$ 162	$ 4,448	$ 3,501
	Net income from discontinued operations	26	769	512
	Interest in net income	$ 188	$ 5,217	$ 4,013
	Denominator:
	Weighted average units used to compute basic EPU	n/a	15,751	12,397
	Effect of dilutive securities — LTIP awards	n/a	9	-
	Weighted average units used to compute diluted EPU	n/a	15,760	12,397

	Net income per limited partner unit, basic:
	Net income per unit from continuing operations	n/a	$ 0.29	$ 0.28
	Net income per unit from discontinued operations	n/a	0.04	0.04
	Net income per limited partner unit, basic	n/a	$ 0.33	$ 0.32
	Net income per limited partner unit, diluted:




	Year ended December 31, 2012	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net income:
	Net income from continuing operations	$ 789	$ 21,374	$ 17,284
	Net income from discontinued operations	1	48	39
	Interest in net income	$ 790	$ 21,422	$ 17,323
	Denominator:
	Weighted average units used to compute basic EPU	n/a	15,331	12,397
	Effect of dilutive securities — LTIP awards	n/a	4	-
	Weighted average units used to compute diluted EPU	n/a	15,335	12,397

	Net income per limited partner unit, basic:
	Net income per unit from continuing operations	n/a	$ 1.39	$ 1.39
	Net income per unit from discontinued operations	n/a	0.01	0.01
	Net income per limited partner unit, basic	n/a	$ 1.40	$ 1.40
	Net income per limited partner unit, diluted:


	Year ended December 31, 2011	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net income	$ 746	$ 19,205	$ 17,347
	Denominator:
	Weighted average units used to compute basic EPU	n/a	13,725	12,397
	Effect of dilutive securities — LTIP awards	n/a	19	-
	Weighted average units used to compute diluted EPU	n/a	13,744	12,397

	Net income per limited partner unit, basic	n/a	$ 1.40	$ 1.40
	Net income per limited partner unit, diluted	n/a	$ 1.40	$ 1.40

Major_Customers_Tables

Major Customers (Tables)	12 Months Ended
Major Customers (Tables)	Dec. 31, 2013
Major Customers [Abstract]	'
Major Customers	'

		December 31, 2013 Receivable Balance	Year Ended December 31, 2013 Sales	December 31, 2012 Receivable Balance	Year Ended December 31, 2012 Sales	December 31, 2011 Receivable Balance	Year Ended December 31, 2011 Sales
		(in thousands)
	NRG Energy Inc. (fka GenOn Energy, Inc.)	$ 3,046	$ 55,246	$ 3,158	$ 53,661	$ 3,254	$ 56,000
	American Electric Power Company, Inc.	1,434	30,070	3,450	36,308	3,556	43,840
	Indiana Harbor Coke Company, L.P.	n/a	n/a	6,597	40,133	4,259	39,767
	Blackstone Resources, Inc.	n/a	n/a	n/a	n/a	3,553	23,104
	PPL Corporation	n/a	n/a	2,760	37,364	3,038	46,672

Related_Party_And_Affiliate_Tr1

Related Party And Affiliate Transactions (Tables)	12 Months Ended
Related Party And Affiliate Transactions (Tables)	Dec. 31, 2013
Related Party And Affiliate Transactions [Abstract]	'
Schedule Of Related Party And Affiliate Transactions	'

	Related Party	Description	2013	2012	2011
			(in thousands)
	Wexford Capital LP	Expenses for legal, consulting, and advisory services	$ 149	$ 213	$ 263
	Wexford Capital LP	Distributions paid	14,034	27,704	38,602
	Wexford Capital LP	Partner's contribution	330	13	1,450
	Rhino Eastern LLC	Equity in net (loss)/income of unconsolidated affiliate	-4,268	6,014	2,988
	Rhino Eastern LLC	Distributions from unconsolidated affiliate	-	2,958	3,351
	Rhino Eastern LLC	Expenses for legal, health claims, workers' compensation and other expenses	4,666	6,175	4,662
	Rhino Eastern LLC	Receivable for legal, health claims and workers’ compensation and other expenses	999	559	1,974
	Rhino Eastern LLC	Investment in unconsolidated affiliate	19,369	21,367	18,311
	Timber Wolf Terminals LLC	Investment in unconsolidated affiliate	114	114	-
	Muskie Proppants LLC	Investment in unconsolidated affiliate	1,761	1,743	-
	Muskie Proppants LLC	Equity in net (loss) of unconsolidated affiliate	-461	-257	-
	Muskie Proppants LLC	Note receivable from unconsolidated affiliate	206	-	-

Segment_Information_Tables

Segment Information (Tables)	12 Months Ended
Segment Information (Tables)	Dec. 31, 2013
Segment Information [Abstract]	'
Reportable Segment Results Of Operations	'
	Reportable segment results of operations and financial position for the year ended December 31, 2013 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization):


					Eastern Met
		Central Appalachia	Northern Appalachia	Rhino Western	Complete Basis	Equity Method Eliminations	Equity Method Presentation	Other	Total Consolidated
		(in thousands)
	Total assets	$ 293,675	$ 54,906	$ 66,463	$ 44,791	$ (44,791)	$ -	$ 152,723	$ 567,767
	Total revenues	147,430	80,401	38,249	27,853	-27,853	-	6,185	272,265
	DD&A	24,170	8,127	5,476	1,949	-1,949	-	1,854	39,627
	Interest expense	3,927	771	665	17	-17	-	2,535	7,898
	Net Income (loss) from continuing operations	$ (7,132)	$ 26,089	$ (2,378)	$ (8,369)	$ 4,101	$ (4,268)	$ (4,200)	$ 8,111

	Reportable segment results of operations and financial position for the year ended December 31, 2012 are as follows:


					Eastern Met
		Central Appalachia	Northern Appalachia	Rhino Western	Complete Basis	Equity Method Eliminations	Equity Method Presentation	Other	Total Consolidated
		(in thousands)
	Total assets	$ 325,418	$ 57,429	$ 70,822	$ 52,682	$ (52,682)	$ -	$ 106,207	$ 559,876
	Total revenues	183,374	122,024	40,696	55,221	-55,221	-	5,649	351,743
	DD&A	26,220	8,339	4,653	2,098	-2,098	-	2,062	41,274
	Interest expense	4,385	811	717	155	-155	-	1,854	7,767
	Net Income (loss) from continuing operations	$ 3,668	$ 29,565	$ 5,691	$ 11,937	$ (5,923)	$ 6,014	$ (5,491)	$ 39,447

	Reportable segment results of operations and financial position for the year ended December 31, 2011 are as follows:


					Eastern Met
		Central Appalachia	Northern Appalachia	Rhino Western	Complete Basis	Equity Method Eliminations	Equity Method Presentation	Other	Total Consolidated
		(in thousands)
	Total assets	$ 325,746	$ 57,137	$ 72,986	$ 45,219	$ (45,219)	$ -	$ 83,334	$ 539,203
	Total revenues	219,274	119,966	21,688	50,073	-50,073	-	6,293	367,221
	DD&A	22,115	8,160	3,057	2,959	-2,959	-	2,993	36,325
	Interest expense	3,074	687	547	52	-52	-	1,754	6,062
	Net Income (loss)	$ 16,497	$ 27,404	$ (2,596)	$ 5,715	$ (2,727)	$ 2,988	$ (6,995)	$ 37,298


Equity Method Investments, Summarized Financial Information	'

		2013		2012		2011
		(in thousands)
	Current assets	$ 5,608		$ 12,788		$ 7,880
	Noncurrent assets	39,183		39,805		37,339
	Current liabilities	2,020		6,290		4,361
	Noncurrent liabilities	4,794		4,496		5,098
	Total costs and expenses	36,206		43,140		44,307
	(Loss)/income from operations	-8,353		12,081		5,766


Schedule Of Revenue By Product Category	'

		2013		2012		2011
		(in thousands)
	Met coal revenue	$ 53,721		$ 59,511		$ 79,227
	Steam coal revenue	182,880		245,057		254,649
	Other revenue	35,664		47,175		33,345
	Total revenue	$ 272,265		$ 351,743		$ 367,221

Supplemental_Information_On_Oi1

Supplemental Information On Oil And Gas Exploration And Production Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Supplemental Information On Oil And Gas Exploration And Production Activities [Abstract]	'
Capitalized Costs Related To Oil And Gas Producing Activities	'

		December 31,
		2013	2012
		(in thousands)
	Proven properties	$ 25,335	$ 6,183
	Unproven properties	30,810	24,083
	Total	56,145	30,266
	Less accumulated depreciation, depletion and amortization	-2,703	-96
	Net	$ 53,442	$ 30,170


Costs Incurred In Oil And Gas Property Acquisition And Development Activities	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands)
	Acquisition	$ 7,857	$ 5,073	$ 19,874
	Development of proved undeveloped properties	18,022	5,319	-
	Exploratory	-	-	-
	Total	$ 25,879	$ 10,392	$ 19,874


Results Of Operations For Producing Activities	'

		Year Ended December 31,
		2013	2012	2011
		(in thousands, except per BOE amounts)
	Revenues	$ 5,626	$ 248	$ -
	Production costs	-1,288	-63	-
	Depletion	-2,607	-96	-
	Results of operations from producing activities	$ 1,731	$ 89	$ -
	Depletion per barrel of oil equivalent (BOE)	$ 15.91	$ 16.73	$ -

Quarterly_Financial_Data_Table

Quarterly Financial Data (Tables)	12 Months Ended
Quarterly Financial Data (Tables)	Dec. 31, 2013
Quarterly Financial Data [Abstract]	'
Schedule Of Quarterly Financial Data	'


	(in thousands, except per unit data)	First Quarter	Second Quarter	Third Quarter	Fourth Quarter
	2013:00:00
	Revenues	$ 74,467	$ 65,613	$ 69,501	$ 62,684
	Income from operations	2,955	9,546	5,070	2,959
	Net (loss)/ income from continuing operations	-271	5,545	2,149	687
	Income from discontinued operations	94	352	728	133
	Net (loss)/income	$ (177)	$ 5,897	$ 2,877	$ 820
	Basic and diluted net (loss)/income per limited partner unit:
	Common units:
	Net income per unit from continuing operations	$ (0.01)	$ 0.20	$ 0.07	$ 0.02
	Net income per unit from discontinued operations	-	0.01	0.03	0.01
	Net income per common unit, basic and diluted	$ (0.01)	$ 0.21	$ 0.10	$ 0.03
	Subordinated units:
	Net income per unit from continuing operations	$ (0.01)	$ 0.20	$ 0.07	$ 0.02
	Net income per unit from discontinued operations	-	0.01	0.03	0.01
	Net income per subordinated unit, basic and diluted	$ (0.01)	$ 0.21	$ 0.10	$ 0.03
	Weighted average number of limited partner units outstanding, basic:
	Common units	15,354	15,371	15,609	16,659
	Subordinated units	12,397	12,397	12,397	12,397
	Weighted average number of limited partner units outstanding, diluted:
	Common units	15,354	15,379	15,621	16,672
	Subordinated units	12,397	12,397	12,397	12,397



	(in thousands, except per unit data)	First Quarter	Second Quarter	Third Quarter	Fourth Quarter (1)
	2012:00:00
	Revenues	$ 81,882	$ 89,998	$ 93,575	$ 86,288
	Income from operations	8,688	12,599	9,151	10,928
	Net income from continuing operations	8,974	12,996	8,876	8,602
	Income from discontinued operations	-	-	-	88
	Net income	$ 8,974	$ 12,996	$ 8,876	$ 8,690
	Basic and diluted net income per limited partner unit:
	Common units:
	Net income per unit from continuing operations	$ 0.32	$ 0.46	$ 0.31	$ 0.30
	Net income per unit from discontinued operations	-	-	-	0.01
	Net income per common unit, basic and diluted	$ 0.32	$ 0.46	$ 0.31	$ 0.31
	Subordinated units:
	Net income per unit from continuing operations	$ 0.32	$ 0.46	$ 0.31	$ 0.30
	Net income per unit from discontinued operations	-	-	-	0.01
	Net income per subordinated unit, basic and diluted	$ 0.32	$ 0.46	$ 0.31	$ 0.31
	Weighted average number of limited partner units outstanding, basic:
	Common units	15,313	15,329	15,332	15,348
	Subordinated units	12,397	12,397	12,397	12,397
	Weighted average number of limited partner units outstanding, diluted:
	Common units	15,327	15,331	15,333	15,349
	Subordinated units	12,397	12,397	12,397	12,397

	(1) Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnership’s liability and costs for black lung benefits (see note 12 for further details).

Organization_And_Basis_Of_Pres1

Organization And Basis Of Presentation (Details) (USD $)	0 Months Ended			12 Months Ended
	Sep. 13, 2013	Jul. 18, 2011	Oct. 05, 2010	Dec. 31, 2013	Dec. 31, 2012	Jul. 18, 2012	Dec. 31, 2011
	Sep. 13, 2013	Jul. 18, 2011	Oct. 05, 2010	site	Dec. 31, 2012	Jul. 18, 2012	Dec. 31, 2011
Basis Of Presentation And Organization [Line Items]	'	'	'	'	'	'	'
Number of underground mines permanently idle	'	'	'	1	'	'	'
Limited partnership common units issued	1,265,000	2,875,000	3,244,000	'	'	'	'
Membership interest pledged as collateral	'	'	100.00%	'	'	'	'
Limited partnership common units price	$12.30	$24.50	$20.50	'	'	'	'
Proceeds from issuance of common units	$14,600,000	'	$58,300,000	$14,788,000	'	$66,400,000	$66,916,000
Underwriting discounts and offering expenses	1,000,000	4,100,000	8,200,000	214,000	7,000	'	569,000
Partner contributions	300,000	1,400,000	10,400,000	330,000	13,000	'	1,450,000
Repayments of credit facility	14,900,000	67,800,000	69,400,000	'	'	'	'
Subordinated Units [Member]	'	'	'	'	'	'	'
Basis Of Presentation And Organization [Line Items]	'	'	'	'	'	'	'
Limited partnership common units issued	'	'	12,397,000	'	'	'	'
Common Units [Member]	'	'	'	'	'	'	'
Basis Of Presentation And Organization [Line Items]	'	'	'	'	'	'	'
Limited partnership common units issued	'	'	9,153,000	'	'	'	'
Reimbursement To Wexford Capital [Member]	'	'	'	'	'	'	'
Basis Of Presentation And Organization [Line Items]	'	'	'	'	'	'	'
Proceeds from issuance of common units	'	'	$9,300,000	'	'	'	'
Underwriters Option To Purchase Additional Units [Member]	'	'	'	'	'	'	'
Basis Of Presentation And Organization [Line Items]	'	'	'	'	'	'	'
Limited partnership common units issued	165,000	375,000	'	'	'	'	'

Summary_Of_Significant_Account2

Summary Of Significant Accounting Policies And General (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

3 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

31-May-08

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2012

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Rhino Eastern LLC [Member]

Timber Wolf [Member]

Muskie Proppant [Member]

Minimum [Member]

Maximum [Member]

Summary Of Significant Accounting Policies [Line Items]

Notes receivable

$200,000

$11,900,000

Note receivable, interest rate

10.00%

Spread over prime interest rate

2.50%

Salvage value of property, plant and equipment

Discount percentage, future net cash flows

10.00%

Depletion equivalent units, gas to barrels conversion ratio

Asset impairment loss

1,667,000

Discount rate, present value calculation

2.30%

3.20%

4.20%

5.60%

5.30%

7.00%

Recosting adjustment calculation, inflation rate

2.30%

2.50%

Period for lessee to recoup royalty payments

'2 years

Payments to acquire interest in joint venture

16,100,000

2,300,000

100,000

2,000,000

500,000

Ownership interest in joint venture

51.00%

Loans to joint venture

11,900,000

5,800,000

200,000

Loan repayments from joint venture

11,900,000

5,800,000

Potential additional contribution to joint venture

10,000,000

Equity method investment

19,400,000

21,400,000

1,700,000

1,800,000

1,700,000

Equity in net income (loss) of unconsolidated affiliate

($4,729,000)

$5,757,000

$2,988,000

($500,000)

$300,000

Subsequent_Events_Details

Subsequent Events (Details) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2013

Jan. 31, 2014

Jan. 21, 2014

Dec. 31, 2013

Jan. 21, 2014

Sep. 30, 2013

Feb. 28, 2014

Dec. 31, 2013

Dec. 31, 2012

Mar. 31, 2014

Subordinated Units [Member]

Subsequent Event [Member]

Utica Shale Region Of Ohio [Member]

Blackhawk Midstream, LLC [Member]

Common Units [Member]

Subordinated Units [Member]

Subsequent Event [Member]

Subsequent Event [Line Items]

Cash distribution, date declared

21-Jan-14

Cash distribution

$1.78

$1.85

$1.81

$0.45

Cash distribution, annualized

$1.78

Cash distribution, date of distribution

14-Feb-14

Cash distribution, date of record

31-Jan-14

Proceeds from the sale of interest

8,400,000

Percentage of payout interest

5.00%

Proceeds from sale of acreage

600,000

185,000,000

Purchase price

184,000,000

Net decrease effect of reclassification of income from continuing operations to discontinued operations

$1,300,000

$100,000

Net percentage decrease effect of reclassification of income from continuing operations to discontinued operations

13.90%

0.20%

Business_Combinations_And_Othe2

Business Combinations And Other Acquisitions (Acquisition Of The Elkhorn Coal Company, LLC) (Narrative) (Details) (USD $)

3 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Aug. 31, 2012

Jun. 30, 2011

Dec. 31, 2011

Elk Horn Coal Company [Member}

Business Acquisition [Line Items]

Ownership interest by parent

100.00%

Gross cash consideration

$119,700,000

Cash paid, net of cash acquired

119,600,000

Goodwill

200,000

Revenues

62,684,000

69,501,000

65,613,000

74,467,000

86,288,000

[1]

93,575,000

89,998,000

81,882,000

272,265,000

351,743,000

367,221,000

13,000,000

Net income

$820,000

$2,877,000

$5,897,000

($177,000)

$8,690,000

[1]

$8,876,000

$12,996,000

$8,974,000

$9,418,000

$39,535,000

$37,298,000

$7,700,000

[1]

Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnershipbs liability and costs for black lung benefits (see note 12 for further details

Business_Combinations_And_Othe3

Business Combinations And Other Acquisitions (Acquisition Of Oil And Gas Mineral Rights) (Narrative) (Details) (USD $)

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

Aug. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Dec. 31, 2011

Apr. 30, 2013

Mar. 31, 2012

Jun. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 28, 2014

Utica Shale Region Of Ohio [Member]

Cana Woodford Region Of Western Oklahoma [Member]

Lease Agreement [Member]

Subsequent Event [Member]

acre

Utica Shale Region Of Ohio [Member]

acre

Business Acquisition [Line Items]

Ownership percentage

5.00%

10.80%

Gross acreage

152,300

125,000

80,000

Cumulative investment in pro rata interest in oil and gas leases

$30,430,000

$32,175,000

$31,100,000

Drilling costs

18,022,000

5,319,000

23,300,000

5,300,000

Investment revenue

5,600,000

Net acreage

7,615

6,250

1,232

Depletion

2,607,000

96,000

Lease term

'5 years

Lease renewal term

'3 years

Lease bonus per acre

6,000

Lease revenue

500,000

6,900,000

7,400,000

Royalty percentage

20.00%

Proceeds from the sale of royalty interest

10,500,000

Gain on sale of royalty interest

200,000

10,359,000

4,890,000

3,172,000

10,500,000

Proceeds from sale of acreage

600,000

185,000,000

Acreage sold

Gain on sale of acreage

600,000

Acquisition of mineral rights

$8,100,000

Business_Combinations_And_Othe4

Business Combinations And Other Acquisitions (Acquisition Of Coal Property) (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	31-May-12	Sep. 30, 2012	Dec. 31, 2013	Dec. 31, 2012	Jun. 30, 2012	Aug. 31, 2011	Jun. 30, 2011	Dec. 31, 2013
			Daviess And McLean Counties In Kentucky [Member]	Daviess And McLean Counties In Kentucky [Member]	Daviess And McLean Counties In Kentucky [Member]	Daviess And McLean Counties In Kentucky [Member]	Daviess And McLean Counties In Kentucky [Member]	Sands Hill [Member]	Randolph And Upshur Counties In West Virginia [Member]	Randolph And Upshur Counties In West Virginia [Member]
					T			T	acre	T
Business Acquisition [Line Items]	'	'	'	'	'	'	'	'	'	'
Acquisition of mineral rights	'	'	$1,500,000	$1,600,000	'	$400,000	'	$2,500,000	$7,500,000	'
Contingent additional payments	'	'	3,000,000	'	'	'	'	'	'	'
Accrued expenses	20,567,000	22,178,000	'	'	'	'	2,000,000	'	'	'
Potential payment not recorded as currently not probable	'	'	'	'	'	'	$1,000,000	'	'	'
Coal tonnage	'	'	'	'	32,600,000	'	'	2,500,000	'	8,200,000
Net acreage	'	'	'	'	'	'	'	'	32,600	'

Business_Combinations_And_Othe5

Business Combinations And Other Acquisitions (Summary Of Assets Acquired And Liabilities Assumed) (Details) (Elk Horn Coal Company [Member}, USD $)	Jun. 30, 2011
In Thousands, unless otherwise specified	Jun. 30, 2011
Elk Horn Coal Company [Member}	'
Business Acquisition [Line Items]	'
Cash	$58
Accounts receivable	2,619
Prepaid expenses and other	94
Property, plant and equipment	7,466
Mine development costs	3,000
Coal properties	111,647
Intangible assets	654
Other non-current assets	1,112
Accounts payable	-79
Deferred revenues	-2,499
Accrued expenses and other	-1,691
Asset retirement obligations	-2,707
Net assets acquired	119,674
Total consideration	$119,674

Business_Combinations_And_Othe6

Business Combinations And Other Acquisitions (Business Acquisition, Pro Forma Information) (Details) (Elk Horn Coal Company [Member}, USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2011
Business Acquisition [Line Items]	'
Revenues	$367,221
Net Income	38,071
Net income per limited partner unit, diluted	$1.43
Pro Forma [Member]	'
Business Acquisition [Line Items]	'
Revenues	376,698
Net Income	41,200
Net income per limited partner unit, diluted	$1.46
Pro Forma Adjustments [Member]	'
Business Acquisition [Line Items]	'
Revenues	9,477
Net Income	$3,129
Net income per limited partner unit, diluted	$0.03

Prepaid_Expenses_And_Other_Cur2

Prepaid Expenses And Other Current Assets (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Prepaid Expenses And Other Current Assets [Abstract]	'	'
Other prepaid expenses	$951	$767
Prepaid insurance	1,958	1,895
Prepaid leases	122	121
Supply inventory	1,221	1,219
Deposits	320	321
Total prepaid expenses and other	$4,572	$4,323

Property_Plant_And_Equipment_N

Property, Plant And Equipment (Narrative) (Details) (USD $)	1 Months Ended	12 Months Ended			1 Months Ended
	Aug. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012	Feb. 29, 2012	Aug. 31, 2011	Dec. 31, 2012
					Pike County, Kentucky [Member]	Pike County, Kentucky [Member]	Phelps, Kentucky [Member]	Sale Of Land Surface Rights [Member]
								acre
Property, Plant and Equipment [Line Items]	'	'	'	'	'	'	'	'
Acreage sold	'	'	'	'	'	'	'	134
Proceeds from sale of other assets	'	'	'	'	$200,000	$600,000	$20,000,000	$1,500,000
Gain on disposition of assets	200,000	10,359,000	4,890,000	3,172,000	900,000	900,000	2,400,000	1,500,000
Proceeds from sale of business	500,000	'	'	'	'	'	'	'
Gain contingency unrecorded amount	'	'	'	'	'	'	8,750,000	'
Asset impairment loss	'	$1,667,000	$0	$0	'	'	'	'

Property_Plant_And_Equipment_P

Property, Plant And Equipment (Property, Plant And Equipment By Major Classification) (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

In Thousands, unless otherwise specified

Land And Land Improvements [Member]

Mining And Other Equipment And Related Facilities [Member]

Mine Development Costs [Member]

Coal Properties [Member]

Oil And Natural Gas Properties [Member]

Construction Work In Process [Member]

Minimum [Member]

Maximum [Member]

Mining And Other Equipment And Related Facilities [Member]

Mine Development Costs [Member]

Coal Properties [Member]

Mining And Other Equipment And Related Facilities [Member]

Mine Development Costs [Member]

Coal Properties [Member]

Property, Plant and Equipment [Line Items]

Useful Lives

'2 years

'1 year

'20 years

'15 years

Total

$674,708

$653,404

$35,078

$34,978

$302,114

$297,615

$73,344

$67,045

$238,975

$240,368

$8,093

$8,182

$17,104

$5,216

Less accumulated depreciation, depletion and amortization

-249,718

-219,613

Net

$424,990

$433,791

Property_Plant_And_Equipment_O

Property, Plant And Equipment (Oil And Natural Gas Properties Not Subject To Amortization) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Property, Plant And Equipment [Abstract]	'	'
Acquisition costs	$30,430	$32,175
Total	$30,430	$32,175

Property_Plant_And_Equipment_D

Property, Plant And Equipment (Depreciation, Depletion And Amortization) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Property, Plant and Equipment [Line Items]	'		'		'
Depreciation, depletion and amortization	$39,627		$41,274		$36,325
Mining And Other Equipment And Related Facilities [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Depreciation, depletion and amortization	31,510		32,685		26,467
Coal Properties [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Depreciation, depletion and amortization	5,387	[1]	5,784	[1]	5,140	[1]
Oil And Natural Gas Properties [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Depreciation, depletion and amortization	47		'		'
Mine Development Costs [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Depreciation, depletion and amortization	2,520		2,180		3,322
Intangible Assets [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Depreciation, depletion and amortization	80		80		65
Asset Retirement Costs [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Depreciation, depletion and amortization	$83		$545		$1,331

[1]	Depletion expense for the Partnershipbs Utica Shale oil and natural gas properties are reclassified to Income from discontinued operations line in the consolidated statements of operations and comprehensive income due to the sale of the Partnershipbs Utica shale assets as described in Note 3.

Goodwill_And_Intangible_Assets2

Goodwill And Intangible Assets (Narrative) (Details) (USD $)	Sep. 30, 2012	Aug. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2011	Dec. 31, 2011	Dec. 31, 2011
			Patent And Developed Technology [Member]	Trade Name And Customer List [Member]	Elk Horn Coal Company [Member}	Elk Horn Coal Company [Member}	Elk Horn Coal Company [Member}
						Trade Name [Member]	Customer List [Member]
Acquired Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'	'	'
Goodwill	$0	$200,000	'	'	$0	'	'
Acquired intangible asset value	'	'	'	'	'	$184,000	$470,000
Intangible assets, useful life	'	'	'17 years	'20 years	'	'	'

Goodwill_And_Intangible_Assets3

Goodwill And Intangible Assets (Schedule Of Intangible Assets By Major Class) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	$1,460	$1,460
Accumulated Amortization	312	232
Net Carrying Amount	1,148	1,228
Patent [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	728	728
Accumulated Amortization	207	164
Net Carrying Amount	521	564
Developed Technology [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	78	78
Accumulated Amortization	22	18
Net Carrying Amount	56	60
Trade Name [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	184	184
Accumulated Amortization	23	14
Net Carrying Amount	161	170
Customer List [Member]	'	'
Finite-Lived Intangible Assets [Line Items]	'	'
Gross Carrying Amount	470	470
Accumulated Amortization	60	36
Net Carrying Amount	$410	$434

Goodwill_And_Intangible_Assets4

Goodwill And Intangible Assets (Future Amortization Expense) (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2013
Acquired Finite-Lived Intangible Assets [Line Items]	'
2014	$80
2015	80
2016	80
2017	80
2018	80
Patent [Member]	'
Acquired Finite-Lived Intangible Assets [Line Items]	'
2014	43
2015	43
2016	43
2017	43
2018	43
Developed Technology [Member]	'
Acquired Finite-Lived Intangible Assets [Line Items]	'
2014	5
2015	5
2016	5
2017	5
2018	5
Trade Name [Member]	'
Acquired Finite-Lived Intangible Assets [Line Items]	'
2014	9
2015	9
2016	9
2017	9
2018	9
Customer List [Member]	'
Acquired Finite-Lived Intangible Assets [Line Items]	'
2014	23
2015	23
2016	23
2017	23
2018	$23

Other_NonCurrent_Assets_Narrat

Other Non-Current Assets (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Other Non-Current Assets [Abstract]	'	'
Debt issuance costs, gross	$9,000,000	$8,000,000
Accumulated amortization of debt issuance costs	5,500,000	4,200,000
Workers' compensation insurance receivable	$4,327,000	$3,829,000

Other_NonCurrent_Assets_Schedu

Other Non-Current Assets (Schedule Of Other Non-Current Assets) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Other Non-Current Assets [Abstract]	'	'
Deposits and other	$1,223	$1,988
Debt issuance costs-net	3,535	3,851
Non-current receivable	4,327	3,829
Note receivable	206	'
Deferred expenses	349	16
Total	$9,640	$9,684

Accrued_Expenses_And_Other_Cur2

Accrued Expenses And Other Current Liabilities (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Accrued Expenses And Other Current Liabilities [Abstract]	'	'
Payroll, bonus and vacation expense	$3,573	$4,086
Non income taxes	2,750	3,318
Royalty expenses	2,001	2,536
Accrued interest	760	671
Health claims	1,036	1,479
Workers' compensation & pneumoconiosis	1,190	1,784
Deferred revenues	3,592	2,788
Accrued insured litigation claims	2,579	2,783
Other	3,086	2,733
Total	$20,567	$22,178

Debt_Senior_Secured_Credit_Fac

Debt (Senior Secured Credit Facility With PNC Bank, N.A.) (Narrative) (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

24 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Jul. 31, 2011

Jun. 30, 2011

Dec. 31, 2013

Jul. 31, 2011

Dec. 31, 2013

Apr. 30, 2013

Jun. 30, 2011

Dec. 31, 2013

Jul. 31, 2011

Dec. 31, 2016

Mar. 31, 2015

PNC Bank, N.A. [Member]

PNC Bank, N.A. Amendment [Member]

Letters of Credit [Member]

Scenario, Forecast [Member]

LIBOR [Member]

PRIME [Member]

PNC Bank, N.A. [Member]

PNC Bank, N.A. Amendment [Member]

Line of Credit Facility [Line Items]

Credit facility, maximum available

$200,000,000

$300,000,000

$250,000,000

$75,000,000

Credit facility, increase in borrowing capacity

50,000,000

Amendment fee

1,000,000

Line of credit facility option to increase maximum borrowing capacity

50,000,000

Line of credit facility, expiration date

1-Jul-16

Debt issuance costs

2,800,000

Amortization period of debt issuance costs

'5 years

Line of credit facility, maximum investment in joint ventures

25,000,000

40,000,000

Line of credit facility, maximum leverage ratio

300.00%

375.00%

Line of credit facility, amount outstanding

167,040,000

157,250,000

162,000,000

5,000,000

21,500,000

Incremental interest rate above variable rate

3.00%

2.00%

Effective interest rate

5.00%

3.17%

5.25%

Outstanding letters of credit

21,500,000

Long-term debt, percentage bearing fixed interest, percentage

3.00%

Maximum borrowing capacity measured as a multiple of EBITDA

375.00%

EBITDA measurement period for determining maximum borrowing capacity

'12 months

Line of credit facility, remaining borrowing capacity

56,100,000

Interest costs capitalized

$100,000

Debt_Note_Payable_To_HL_Constr

Debt (Note Payable To H&L Construction) (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Debt [Abstract]	'	'
Imputed interest discount rate	5.00%	'
Note payable maturity date	1-Jan-15	'
Mineral rights owned and pledged as collateral, carrying amount	$11.10	$11.30

Debt_Schedule_Of_Debt_Details

Debt (Schedule Of Debt) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Debt [Abstract]	'	'
Senior secured credit facility with PNC Bank, N.A.	$167,040	$157,250
Notes payable to H&L Construction Co., Inc.	800	1,560
Other notes payable	3,206	4,739
Total	171,046	163,549
Less current portion	-1,024	-2,350
Long-term debt	$170,022	$161,199

Debt_Schedule_Of_Principal_Pay

Debt (Schedule Of Principal Payments On Long-Term Debt) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Debt [Abstract]	'	'
2014	$1,049	'
2015	210	'
2016	167,265	'
2017	240	'
2018	257	'
Thereafter	2,050	'
Total principal payments	171,071	'
Less imputed interest on interest free notes payable	-25	'
Total	$171,046	$163,549

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Asset Retirement Obligations [Abstract]	'	'	'
Balance at beginning of period (including current portion)	$33,003	$34,113	$35,691
Accretion expense	2,356	1,896	1,956
Adjustment resulting from addition of property	'	72	2,707
Adjustment resulting from disposal of property	'	-968	-3,588
Adjustments to liability from annual recosting and other	20	-201	-617
Liabilities settled	-928	-1,909	-2,036
Balance at end of period	34,451	33,003	34,113
Less current portion of asset retirement obligation	-1,614	-2,255	-3,192
Long-term portion of asset retirement obligation	$32,837	$30,748	$30,921

Workers_Compensation_And_Black2

Workers' Compensation And Black Lung (Narrative) (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Defined Benefit Plan Disclosure [Line Items]

Partners' capital

$296,371

$299,794

$296,371

$299,794

$301,937

$243,229

Net income

820

2,877

5,897

-177

8,690

[1]

8,876

12,996

8,974

9,418

39,535

37,298

Workers' compensation insurance receivable

4,327

3,829

4,327

3,829

Black Lung Benefits [Member]

Defined Benefit Plan Disclosure [Line Items]

Discount rate

5.00%

4.00%

Workers Compensation [Member]

Defined Benefit Plan Disclosure [Line Items]

Discount rate

2.00%

Restatement Adjustment [Member]

Defined Benefit Plan Disclosure [Line Items]

Partners' capital

-5,800

Net income

($700)

($800)

[1]

Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnershipbs liability and costs for black lung benefits (see note 12 for further details

Workers_Compensation_And_Black3

Workers' Compensation And Black Lung (Summary Of Black Lung And Workers' Compensation Expenses) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Service cost	$385	$378	$491
Interest cost	186	231	312
Actuarial (gain)/loss	-945	622	-1,723
Total	426	314	803
Black Lung Benefits [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Service cost	736	1,215	156
Interest cost	469	466	110
Actuarial (gain)/loss	-1,584	693	1,231
Total	-379	2,374	1,497
Workers Compensation [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Total	2,743	1,018	4,049
Workers' Compensation And Black Lung Benefits [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Total	$2,364	$3,392	$5,546

Workers_Compensation_And_Black4

Workers' Compensation And Black Lung (Schedule Of Changes In Benefit Liability) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Benefit obligation at beginning of period	$6,747	$5,649	$6,641
Service cost	385	378	491
Interest cost	186	231	312
Actuarial (gain)/loss	-945	622	-1,723
Benefits and expenses paid	-253	-133	-72
Benefit obligation at end of period	6,120	6,747	5,649
Black Lung Benefits [Member]	'	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Benefit obligation at beginning of period	8,513	6,392	5,055
Service cost	736	1,215	156
Interest cost	469	466	110
Actuarial (gain)/loss	-1,584	693	1,231
Benefits and expenses paid	-883	-253	-160
Benefit obligation at end of period	$7,251	$8,513	$6,392

Workers_Compensation_And_Black5

Workers' Compensation And Black Lung (Classification Of Net Amounts Recognized For Workers' Compensation And Black Lung Benefits) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]	'	'
Less current portion	($334)	($227)
Non-current obligations	5,786	6,520
Black Lung Benefits [Member]	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Total obligations	7,251	8,513
Workers Compensation [Member]	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Total obligations	10,159	9,846
Workers' Compensation And Black Lung Benefits [Member]	'	'
Defined Benefit Plan Disclosure [Line Items]	'	'
Total obligations	17,410	18,359
Less current portion	-1,190	-1,784
Non-current obligations	$16,220	$16,575

Employee_Benefits_Narrative_De

Employee Benefits (Narrative) (Details) (USD $)	12 Months Ended
Employee Benefits (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Benefits [Abstract]	'	'	'
Amounts reclassified from accumulated other comprehensive income	$145,000	$295,000	$0
Annual rate of increase in the per capita cost of covered health care benefits	7.30%	'	'
Annual rate of increase in the per capita cost of covered health care benefits in 2027	4.50%	'	'
Per capita cost of covered health care benefits, year of level increase	'2027	'	'
Description of per capita cost of covered health care benefits increase	'For benefit obligation measurement purposes, a 7.30% annual rate of increase in the per capita cost of covered health care benefits was assumed, gradually decreasing to 4.50% in 2027 and remaining level thereafter.	'	'

Employee_Benefits_Summary_Of_C

Employee Benefits (Summary Of Changes In Benefit Obligations) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Benefits [Abstract]	'	'	'
Benefit obligation at beginning of period	$6,747	$5,649	$6,641
Change in benefit obligations: Service costs	385	378	491
Change in benefit obligations: Interest cost	186	231	312
Change in benefit obligations: Benefits paid	-253	-133	-72
Change in benefit obligations: Actuarial loss/(gain)	-945	622	-1,723
Benefit obligation at end of period	6,120	6,747	5,649
Funded status	($6,120)	($6,747)	($5,649)

Employee_Benefits_Classificati

Employee Benefits (Classification Of Net Amounts Recognized For Postretirement Benefits) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Employee Benefits [Abstract]	'	'
Current liability - postretirement benefits	($334)	($227)
Non-current liability - postretirement benefits	-5,786	-6,520
Net amount recognized	($6,120)	($6,747)

Employee_Benefits_Amounts_Reco

Employee Benefits (Amounts Recognized In Accumulated Other Comprehensive Income) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Benefits [Abstract]	'	'	'
Balance at beginning of year	$1,431,000	$2,348,000	$625,000
Actuarial gain (loss)	945,000	-622,000	1,723,000
Amortization of actuarial gain	-145,000	-295,000	0
Net actuarial gain	$2,231,000	$1,431,000	$2,348,000

Employee_Benefits_Weighted_Ave

Employee Benefits (Weighted Average Assumptions Used To Determine Benefit Obligations) (Details)	Dec. 31, 2013	Dec. 31, 2012
Employee Benefits [Abstract]	'	'
Discount rate	3.96%	2.80%

Employee_Benefits_Weighted_Ave1

Employee Benefits (Weighted Average Assumptions Used To Determine Periodic Benefit Cost) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Benefits [Abstract]	'	'	'
Discount rate	2.80%	4.15%	4.75%

Employee_Benefits_Components_O

Employee Benefits (Components Of Net Periodic Benefit Cost) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Benefits [Abstract]	'	'	'
Service costs	$385,000	$378,000	$491,000
Interest cost	186,000	231,000	312,000
Amortization of (gain)	-145,000	-295,000	0
Total	$426,000	$314,000	$803,000

Employee_Benefits_Amounts_Expe

Employee Benefits (Amounts Expected To Be Amortized From Accumulated Other Comprehensive Income Into Net Periodic Benefit Cost) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Employee Benefits [Abstract]	'
Net actuarial gain	$367

Employee_Benefits_Expected_Fut

Employee Benefits (Expected Future Benefit Payments) (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified	Dec. 31, 2013
Employee Benefits [Abstract]	'
2014	$334
2015	397
2016	538
2017	602
2018	659
2019-2023	$4,337

Employee_Benefits_Effect_Of_On

Employee Benefits (Effect Of One-Percentage-Point Change In Assumed Health Care Cost Trend Rates) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Employee Benefits [Abstract]	'
One-Percentage Point Increase, Effect on total service and interest cost components	$58
One-Percentage Point Decrease, Effect on total service and interest cost components	-52
One-Percentage Point Increase, Effect on postretirement benefit obligation	467
One-Percentage Point Decrease, Effect on postretirement benefit obligation	($433)

Employee_Benefits_Schedule_Of_

Employee Benefits (Schedule Of Expense Under Defined Contribution Savings Plans) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Benefits [Abstract]	'	'	'
401(k) plan expense	$2,243	$2,322	$2,245

EquityBased_Compensation_Narra

Equity-Based Compensation (Narrative) (Details) (USD $)	12 Months Ended				3 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Mar. 31, 2014
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Scenario, Forecast [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]	'	'	'	'	'
Number of units reserved for future issuance	2,479,400	'	'	'	'
Vesting period	'3 years	'	'	'	'3 years
Incremental compensation expense	'	'	$0.10	'	'
Equity accrual reclassified to expenses	'	'	'	0.2	'
Share based compensation expense	0.7	0.9	1.1	'	'
Total fair value of awards that vested	0.8	'	'	'	'
Total unrecognized compensation expense	0.5	'	'	'	'
Weighted average period of recognition	'1 year 7 months 6 days	'	'	'	'
Intrinsic value of non-vested awards	0.6	'	'	'	'
Total fair value of awards granted	'	'	'	'	$0.40

EquityBased_Compensation_Summa

Equity-Based Compensation (Summary Of Non-Vested LTIP Awards) (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Equity-Based Compensation [Abstract]	'	'	'
Common Units, Non-vested awards, Beginning balance	67	92	135
Common Units, Granted	49	32	10
Common Units, Vested	-58	-49	-52
Common Units, Forfeited	-3	-8	-1
Common Units, Non-vested awards, Ending balance	55	67	92
Weighted Average Grant Date Fair Value (per unit), Non-vested awards, Beginning balance	$19.23	$20.45	$20.50
Weighted Average Grant Date Fair Value (per unit), Granted	$13.50	$17.40	$19.90
Weighted Average Grant Date Fair Value (per unit), Vested	$18.88	$20.12	$20.47
Weighted Average Grant Date Fair Value (per unit), Forfeited	$16.62	$20.28	$20.50
Weighted Average Grant Date Fair Value (per unit), Non-vested awards, Ending balance	$14.63	$19.23	$20.45

Commitments_And_Contingencies_1

Commitments And Contingencies (Narrative) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
			Surety Bonds [Member]	Ammonia Nitrate [Member]	Rhino Eastern [Member]	Timber Wolf [Member]	Muskie Proppant [Member]	Letters of Credit [Member]
				T				PNC Bank, N.A. [Member]
Commitments And Contingencies [Line Items]	'	'	'	'	'	'	'	'
Purchase commitment, tons	'	'	'	2,000	'	'	'	'
Purchase commitments	'	'	'	$900,000	'	'	'	'
Line of credit facility, amount outstanding	167,040,000	157,250,000	'	'	'	'	'	21,500,000
Long-term debt	171,046,000	163,549,000	75,200,000	'	'	'	'	'
Payments to acquire interest in joint venture	'	'	'	'	2,300,000	0	500,000	'
Loans to joint venture	'	'	'	'	'	'	$200,000	'

Commitments_And_Contingencies_2

Commitments And Contingencies (Schedule Of Delivery Commitments) (Details)	12 Months Ended
	Dec. 31, 2013
	customer
	T
Commitments And Contingencies [Abstract]	'
Tons, 2014	3,045,000
Tons, 2015	1,796,000
Tons, 2016	1,100,000
Tons 2017	1,100,000
Number of customers, 2014	19
Number of customers, 2015	4
Number of customers, 2016	2
Number of customers, 2017	2

Commitments_And_Contingencies_3

Commitments And Contingencies (Schedule Of Purchased Coal Expenses) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Commitments And Contingencies [Abstract]	'	'	'
Purchased coal expense	$3,730	$25,637	$14,283
OTC expense	$1,271	'	$14

Commitments_And_Contingencies_4

Commitments And Contingencies (Schedule Of Lease And Royalty Expense) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Commitments And Contingencies [Abstract]	'	'	'
Lease expense	$3,161	$2,860	$2,630
Royalty expense	$11,442	$14,474	$16,175

Commitments_And_Contingencies_5

Commitments And Contingencies (Future Minimum Lease And Royalty Payments) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Commitments And Contingencies [Abstract]	'
Royalties, 2014	$1,642
Royalties, 2015	1,865
Royalties, 2016	1,864
Royalties, 2017	1,922
Royalties, 2018	1,929
Royalties, Thereafter	9,644
Total minimum royalty payments	18,866
Leases, 2014	1,577
Leases, 2015	1,538
Leases, 2016	1,545
Leases, 2017	1,141
Leases, 2018	193
Total minimum lease payments	$5,994

Earnings_Per_Unit_EPU_Narrativ

Earnings Per Unit ("EPU") (Narrative) (Details)	12 Months Ended
Earnings Per Unit ("EPU") (Narrative) (Details)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings Per Unit ("EPU") [Abstract]	'	'	'
Anti-dilutive LTIP phantom units	12,000	0	0

Earnings_Per_Unit_EPU_Schedule

Earnings Per Unit ("EPU") (Schedule Of Calculation Of Numerator And Denominator In Earnings Per Share) (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Earnings Per Unit [Line Items]

Net income from continuing operations

$687

$2,149

$5,545

($271)

$8,602

[1]

$8,876

$12,996

$8,974

$8,111

$39,447

$37,298

Net income from discontinued operations

133

728

352

[1]

1,307

NET INCOME

820

2,877

5,897

-177

8,690

[1]

8,876

12,996

8,974

9,418

39,535

37,298

General Partner Capital [Member]

Earnings Per Unit [Line Items]

Net income from continuing operations

162

789

Net income from discontinued operations

NET INCOME

188

790

746

Common Unitholders [Member]

Earnings Per Unit [Line Items]

Net income from continuing operations

4,448

21,374

Net income from discontinued operations

769

NET INCOME

5,217

21,422

19,205

Weighted average units used to compute basic EPU

15,751

15,331

13,725

Effect of dilutive securities - LTIP awards

Weighted average units used to compute diluted EPU

15,760

15,335

13,744

Net income per unit from continuing operations

$0.29

$1.39

Net income per unit from discontinued operations

$0.04

$0.01

Net income per limited partner unit, basic

$0.33

$1.40

Net income per limited partner unit, diluted

$1.40

Subordinated Unitholders[Member]

Earnings Per Unit [Line Items]

Net income from continuing operations

3,501

17,284

Net income from discontinued operations

512

NET INCOME

$4,013

$17,323

$17,347

Weighted average units used to compute basic EPU

12,397

Weighted average units used to compute diluted EPU

12,397

Net income per unit from continuing operations

$0.28

$1.39

Net income per unit from discontinued operations

$0.04

$0.01

Net income per limited partner unit, basic

$0.32

$1.40

Net income per limited partner unit, diluted

$1.40

[1]

Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnershipbs liability and costs for black lung benefits (see note 12 for further details

Major_Customers_Details

Major Customers (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Revenue, Major Customer [Line Items]

Receivable balance

$25,461

$33,560

$25,461

$33,560

Revenue

62,684

69,501

65,613

74,467

86,288

[1]

93,575

89,998

81,882

272,265

351,743

367,221

NRG Energy, Inc. (fka GenOn Energy, Inc.) [Member]

Revenue, Major Customer [Line Items]

Receivable balance

3,046

3,158

3,046

3,158

3,254

Revenue

55,246

53,661

56,000

American Electric Power Company, Inc. [Member]

Revenue, Major Customer [Line Items]

Receivable balance

1,434

3,450

1,434

3,450

3,556

Revenue

30,070

36,308

43,840

Indiana Harbor Coke Company, L.P. [Member]

Revenue, Major Customer [Line Items]

Receivable balance

6,597

4,259

Revenue

40,133

39,767

Blackstone Resources, Inc. [Member]

Revenue, Major Customer [Line Items]

Receivable balance

3,553

Revenue

23,104

PPL Corporation [Member]

Revenue, Major Customer [Line Items]

Receivable balance

2,760

3,038

Revenue

$37,364

$46,672

[1]

Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnershipbs liability and costs for black lung benefits (see note 12 for further details

Related_Party_And_Affiliate_Tr2

Related Party And Affiliate Transactions (Narrative) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Wexford Capital LP [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Expenses for legal, consulting, advisory services, health claims, workers' compensation and other expenses	$149,000	$213,000	$263,000
Rhino Eastern LLC [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Expenses for legal, consulting, advisory services, health claims, workers' compensation and other expenses	4,666,000	6,175,000	4,662,000
Loans to joint venture	'	11,900,000	5,800,000
Loan repayments from joint venture	'	$11,900,000	$5,800,000

Related_Party_And_Affiliate_Tr3

Related Party And Affiliate Transactions (Schedule Of Related Party And Affiliate Transactions) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]	'	'	'
Partner's contribution	$330	$13	$1,450
Equity in net income (loss) of unconsolidated affiliate	-4,729	5,757	2,988
Return of capital from unconsolidated affiliate	'	2,958	3,351
Investment in unconsolidated affiliates	21,243	23,224	'
Note receivable from unconsolidated affiliate	200	11,900	'
Wexford Capital LP [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Expenses for legal, consulting, advisory services, health claims, workers' compensation and other expenses	149	213	263
Distributions paid	14,034	27,704	38,602
Partner's contribution	330	13	1,450
Rhino Eastern LLC [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Expenses for legal, consulting, advisory services, health claims, workers' compensation and other expenses	4,666	6,175	4,662
Equity in net income (loss) of unconsolidated affiliate	-4,268	6,014	2,988
Distribution from unconsolidated affiliate	'	2,958	3,351
Receivable for legal, health claims and workers' compensation and other expenses	999	559	1,974
Investment in unconsolidated affiliates	19,369	21,367	18,311
Timber Wolf [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Investment in unconsolidated affiliates	114	114	'
Muskie Proppant [Member]	'	'	'
Related Party Transaction [Line Items]	'	'	'
Equity in net income (loss) of unconsolidated affiliate	-461	-257	'
Investment in unconsolidated affiliates	1,761	1,743	'
Note receivable from unconsolidated affiliate	$206	'	'

Supplemental_Disclosures_Of_Ca1

Supplemental Disclosures Of Cash Flow Information (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Other Significant Noncash Transactions [Line Items]	'	'	'
Interest paid	$6.40	$6.50	$4.30
Units Issued [Member]	'	'	'
Other Significant Noncash Transactions [Line Items]	'	'	'
Value of units issued	0.6	0.7	0.8
Recorded In Accounts Payable [Member]	'	'	'
Other Significant Noncash Transactions [Line Items]	'	'	'
Property additions	10.5	3.6	3.2
Recorded In Accrued Expenses And Other Liabilities [Member]	'	'	'
Other Significant Noncash Transactions [Line Items]	'	'	'
Property additions	'	$0.40	$5.20

Segment_Information_Narrative_

Segment Information (Narrative) (Details)	12 Months Ended
	Dec. 31, 2013
	segment
Segment Information [Abstract]	'
Number of reportable business segments	5

Segment_Information_Reportable

Segment Information (Reportable Segment Results Of Operations) (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information [Line Items]

Total assets

$567,767

$559,876

$567,767

$559,876

$539,203

Total revenues

62,684

69,501

65,613

74,467

86,288

[1]

93,575

89,998

81,882

272,265

351,743

367,221

DD&A

39,627

41,274

36,325

Interest expense

7,898

7,767

6,062

Net Income (loss) from continuing operations

8,111

39,447

37,298

Central Appalachia [Member]

Segment Reporting Information [Line Items]

Total assets

293,675

325,418

293,675

325,418

325,746

Total revenues

147,430

183,374

219,274

DD&A

24,170

26,220

22,115

Interest expense

3,927

4,385

3,074

Net Income (loss) from continuing operations

-7,132

3,668

16,497

Northern Appalachia [Member]

Segment Reporting Information [Line Items]

Total assets

54,906

57,429

54,906

57,429

57,137

Total revenues

80,401

122,024

119,966

DD&A

8,127

8,339

8,160

Interest expense

771

811

687

Net Income (loss) from continuing operations

26,089

29,565

27,404

Rhino Western [Member]

Segment Reporting Information [Line Items]

Total assets

66,463

70,822

66,463

70,822

72,986

Total revenues

38,249

40,696

21,688

DD&A

5,476

4,653

3,057

Interest expense

665

717

547

Net Income (loss) from continuing operations

-2,378

5,691

-2,596

Complete Basis [Member] | Eastern Met [Member]

Segment Reporting Information [Line Items]

Total assets

44,791

52,682

44,791

52,682

45,219

Total revenues

27,853

55,221

50,073

DD&A

1,949

2,098

2,959

Interest expense

155

Net Income (loss) from continuing operations

-8,369

11,937

5,715

Equity Method Eliminations [Member] | Eastern Met [Member]

Segment Reporting Information [Line Items]

Total assets

-44,791

-52,682

-44,791

-52,682

-45,219

Total revenues

-27,853

-55,221

-50,073

DD&A

-1,949

-2,098

-2,959

Interest expense

-17

-155

-52

Net Income (loss) from continuing operations

4,101

-5,923

-2,727

Equity Method Presentation [Member] | Eastern Met [Member]

Segment Reporting Information [Line Items]

Net Income (loss) from continuing operations

-4,268

6,014

2,988

Other [Member]

Segment Reporting Information [Line Items]

Total assets

152,723

106,207

152,723

106,207

83,334

Total revenues

6,185

5,649

6,293

DD&A

1,854

2,062

2,993

Interest expense

2,535

1,854

1,754

Net Income (loss) from continuing operations

($4,200)

($5,491)

($6,995)

[1]

Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnershipbs liability and costs for black lung benefits (see note 12 for further details

Segment_Information_Equity_Met

Segment Information (Equity Method Investments, Summarized Financial Information) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Segment Information [Abstract]	'	'	'
Current assets	$5,608	$12,788	$7,880
Noncurrent assets	39,183	39,805	37,339
Current liabilities	2,020	6,290	4,361
Noncurrent liabilities	4,794	4,496	5,098
Total costs and expenses	36,206	43,140	44,307
(Loss)/income from operations	($8,353)	$12,081	$5,766

Segment_Information_Schedule_O

Segment Information (Schedule Of Revenue By Product Category) (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Segment Reporting Information [Line Items]

Revenue

$62,684

$69,501

$65,613

$74,467

$86,288

[1]

$93,575

$89,998

$81,882

$272,265

$351,743

$367,221

Met Coal [Member]

Segment Reporting Information [Line Items]

Revenue

53,721

59,511

79,227

Steam Coal [Member]

Segment Reporting Information [Line Items]

Revenue

182,880

245,057

254,649

Other [Member]

Segment Reporting Information [Line Items]

Revenue

$35,664

$47,175

$33,345

[1]

Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnershipbs liability and costs for black lung benefits (see note 12 for further details

Supplemental_Information_On_Oi2

Supplemental Information On Oil And Gas Exploration And Production Activities (Capitalized Costs Related To Oil And Gas Producing Activities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Supplemental Information On Oil And Gas Exploration And Production Activities [Abstract]	'	'
Proven properties	$25,335	$6,183
Unproven properties	30,810	24,083
Total	56,145	30,266
Less accumulated depreciation, depletion and amortization	-2,703	-96
Net	$53,442	$30,170

Supplemental_Information_On_Oi3

Supplemental Information On Oil And Gas Exploration And Production Activities (Costs Incurred In Oil And Gas Property Acquisition And Development Activities) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Supplemental Information On Oil And Gas Exploration And Production Activities [Abstract]	'	'	'
Acquisition	$7,857	$5,073	$19,874
Development of proved undeveloped properties	18,022	5,319	'
Total	$25,879	$10,392	$19,874

Supplemental_Information_On_Oi4

Supplemental Information On Oil And Gas Exploration And Production Activities (Results Of Operations For Producing Activities) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Supplemental Information On Oil And Gas Exploration And Production Activities [Abstract]	'	'
Revenues	$5,626	$248
Production costs	-1,288	-63
Depletion	-2,607	-96
Results of operations from producing activities	$1,731	$89
Depletion per barrel of oil equivalent (BOE)	15.91	16.73

Quarterly_Financial_Data_Detai

Quarterly Financial Data (Details) (USD $)

3 Months Ended

12 Months Ended

In Thousands, except Per Share data, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Revenues

$62,684

$69,501

$65,613

$74,467

$86,288

[1]

$93,575

$89,998

$81,882

$272,265

$351,743

$367,221

Income from operations

2,959

5,070

9,546

2,955

10,928

[1]

9,151

12,599

8,688

20,531

41,365

40,321

Net (loss)/ income from continuing operations

687

2,149

5,545

-271

8,602

[1]

8,876

12,996

8,974

8,111

39,447

37,298

Income from discontinued operations

133

728

352

[1]

1,307

Net Income (loss)

$820

$2,877

$5,897

($177)

$8,690

[1]

$8,876

$12,996

$8,974

$9,418

$39,535

$37,298

Common Unitholders [Member]

Basic and diluted net income per limited partner unit:

Net income per unit from continuing operations

$0.02

$0.07

$0.20

($0.01)

$0.30

[1]

$0.31

$0.46

$0.32

Net income per unit from discontinued operations

$0.01

$0.03

$0.01

[1]

Net income per common unit, basic and diluted

$0.03

$0.10

$0.21

($0.01)

$0.31

[1]

$0.31

$0.46

$0.32

Weighted average number of limited partner units outstanding, basic:

Weighted average number of limited partner units outstanding, basic

16,659

15,609

15,371

15,354

15,348

[1]

15,332

15,329

15,313

Weighted average number of limited partner units outstanding, diluted:

Weighted average number of limited partner units outstanding, diluted

16,672

15,621

15,379

15,354

15,349

[1]

15,333

15,331

15,327

Subordinated Unitholders[Member]

Basic and diluted net income per limited partner unit:

Net income per unit from continuing operations

$0.02

$0.07

$0.20

($0.01)

$0.30

[1]

$0.31

$0.46

$0.32

Net income per unit from discontinued operations

$0.01

$0.03

$0.01

[1]

Net income per common unit, basic and diluted

$0.03

$0.10

$0.21

($0.01)

$0.31

[1]

$0.31

$0.46

$0.32

Weighted average number of limited partner units outstanding, basic:

Weighted average number of limited partner units outstanding, basic

12,397

[1]

12,397

Weighted average number of limited partner units outstanding, diluted:

Weighted average number of limited partner units outstanding, diluted

12,397

[1]

12,397

[1]

Fourth quarter 2012 data was revised from the amounts previously reported to correctly report the Partnershipbs liability and costs for black lung benefits (see note 12 for further details