Rhino Resource Partners 10-Q6 May 152015 Q1 Quarterly reportFinancial data

Company Profile

Document_And_Entity_Informatio

Document And Entity Information	3 Months Ended
Document And Entity Information	Mar. 31, 2015	1-May-15
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Entity Registrant Name	Rhino Resource Partners LP
Entity Central Index Key	1490630
Current Fiscal Year End Date	-19
Entity Filer Category	Accelerated Filer
Common Units [Member]
Entity Common Stock Shares Outstanding		16,705,721
Subordinated Units [Member]
Entity Common Stock Shares Outstanding		12,397,000

Condensed_Consolidated_Stateme

Condensed Consolidated Statements Of Financial Position (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
CURRENT ASSETS:
Cash and cash equivalents	$205	$626
Accounts receivable, net of allowance for doubtful accounts ($930 as of March 31, 2015 and $724 as of December 31, 2014)	23,867	22,467
Inventories	14,970	13,030
Advance royalties, current portion	912	1,032
Prepaid expenses and other	2,592	3,974
Total current assets	42,546	41,129
PROPERTY, PLANT AND EQUIPMENT:
At cost, including coal properties, mine development and construction costs	670,977	663,662
Less accumulated depreciation, depletion and amortization	-280,439	-280,225
Net property, plant and equipment	390,538	383,437
Advance royalties, net of current portion	6,349	1,363
Investment in unconsolidated affiliates	7,412	20,653
Intangible assets	1,047	1,067
Other non-current assets	16,014	16,410
Non-current assets held for sale	9,279	9,279
TOTAL	473,185	473,338
CURRENT LIABILITIES:
Accounts payable	10,736	10,924
Accrued expenses and other	19,528	17,334
Current portion of long-term debt	214	210
Current portion of asset retirement obligations	1,555	1,431
Current portion of postretirement benefits	425	425
Total current liabilities	32,458	30,324
NON-CURRENT LIABILITIES:
Long-term debt, net of current portion	57,949	57,222
Asset retirement obligations, net of current portion	29,981	28,452
Other non-current liabilities	28,141	27,942
Postretirement benefits, net of current portion	6,252	6,223
Non-current liabilities held for sale	2,250	2,250
Total non-current liabilities	124,573	122,089
Total liabilities	157,031	152,413
COMMITMENTS AND CONTINGENCIES (NOTE 13)
PARTNERS' CAPITAL:
Limited partners	303,965	308,586
General partner	10,861	10,966
Accumulated other comprehensive income	1,328	1,373
Total partners' capital	316,154	320,925
TOTAL	$473,185	$473,338

Consensed_Consolidated_Stateme

Consensed Consolidated Statements Of Financial Position (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Consolidated Statements Of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$930	$724

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements Of Operations And Comprehensive Income (USD $)	3 Months Ended
Share data in Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
REVENUES:
Coal sales	$45,556,000		$51,235,000
Freight and handling revenues	539,000		338,000
Other revenues	10,089,000		8,369,000
Total revenues	56,184,000		59,942,000
COSTS AND EXPENSES:
Cost of operations (exclusive of depreciation, depletion and amortization shown separately below)	46,151,000		46,399,000
Freight and handling costs	535,000		301,000
Depreciation, depletion and amortization	8,852,000		9,232,000
Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above)	4,416,000		5,557,000
(Gain) on sale/disposal of assets-net	-22,000		-679,000
Total costs and expenses	59,932,000		60,810,000
(LOSS) FROM OPERATIONS	-3,748,000		-868,000
INTEREST AND OTHER (EXPENSE)/INCOME:
Interest expense	-957,000		-3,184,000
Interest income and other	2,000		3,000
Equity in net income/(loss) of unconsolidated affiliates	141,000		-917,000
Total interest and other (expense)	-814,000		-4,098,000
NET (LOSS) BEFORE INCOME TAXES FROM CONTINUING OPERATIONS	-4,562,000		-4,966,000
INCOME TAXES
NET (LOSS) FROM CONTINUING OPERATIONS	-4,562,000		-4,966,000
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations	721,000		130,511,000
NET (LOSS)/INCOME	-3,841,000		125,545,000
Other comprehensive income:
Amortization of actuarial gain under ASC Topic 715	-44,000		-92,000
COMPREHENSIVE (LOSS)/INCOME	-3,885,000		125,453,000
Net (loss)/income per limited partner unit, diluted:
Distributions paid per limited partner unit	$0.05	[1]	$0.45	[1]
Common Units [Member]
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations	($0.15)		($0.17)
Net income per unit from discontinued operations	$0.02		$4.40
Net (loss)/income per common unit, basic	($0.13)		$4.23
Net (loss)/income per limited partner unit, diluted:
Net (loss)/income per unit from continuing operations	($0.15)		($0.17)
Net income per unit from discontinued operations	$0.02		$4.40
Net (loss)/income per common unit, diluted	($0.13)		$4.23
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic	16,692		16,667
Weighted average number of limited partner units outstanding, diluted:
Weighted average number of limited partner units outstanding, diluted	16,692		16,673
Subordinated Units [Member]
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations	($0.15)		($0.17)
Net income per unit from discontinued operations	$0.02		$4.40
Net (loss)/income per common unit, basic	($0.13)		$4.23
Net (loss)/income per limited partner unit, diluted:
Net (loss)/income per unit from continuing operations	($0.15)		($0.17)
Net income per unit from discontinued operations	$0.02		$4.40
Net (loss)/income per common unit, diluted	($0.13)		$4.23
Distributions paid per limited partner unit	$0		$0
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic	12,397		12,397
Weighted average number of limited partner units outstanding, diluted:
Weighted average number of limited partner units outstanding, diluted	12,397		12,397
General Partner [Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS) FROM CONTINUING OPERATIONS	-91,000		-99,000
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations	14,000		2,610,000
NET (LOSS)/INCOME	-77,000		2,511,000
Common Unitholders [Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS) FROM CONTINUING OPERATIONS	-2,569,000		-2,795,000
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations	402,000		73,343,000
NET (LOSS)/INCOME	-2,167,000		70,548,000
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations	($0.15)		($0.17)
Net income per unit from discontinued operations	$0.02		$4.40
Net (loss)/income per limited partner unit, diluted:
Net (loss)/income per unit from continuing operations	($0.15)		($0.17)
Net income per unit from discontinued operations	$0.02		$4.40
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic	16,692		16,667
Weighted average number of limited partner units outstanding, diluted:
Weighted average number of limited partner units outstanding, diluted	16,692		16,673
Subordinated Unitholders[Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS) FROM CONTINUING OPERATIONS	-1,902,000		-2,072,000
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations	305,000		54,558,000
NET (LOSS)/INCOME	($1,597,000)		$52,486,000
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations	($0.15)		($0.17)
Net income per unit from discontinued operations	$0.02		$4.40
Net (loss)/income per limited partner unit, diluted:
Net (loss)/income per unit from continuing operations	($0.15)		($0.17)
Net income per unit from discontinued operations	$0.02		$4.40
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic	12,397		12,397
Weighted average number of limited partner units outstanding, diluted:
Weighted average number of limited partner units outstanding, diluted	12,397		12,397

[1]	No distributions were paid on the subordinated units for the three months ended March 31, 2015 and 2014

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements Of Operations And Comprehensive Income (Parenthetical) (USD $)	3 Months Ended
	Mar. 31, 2015		Mar. 31, 2014
Distributions paid per limited partner unit	$0.05	[1]	$0.45	[1]
Subordinated Units [Member]
Distributions paid per limited partner unit	$0		$0

[1]	No distributions were paid on the subordinated units for the three months ended March 31, 2015 and 2014

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements Of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Net (loss)/income	($3,841)	$125,545
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	8,852	9,232
Accretion on asset retirement obligations	534	589
Accretion on interest-free debt	51
Amortization of deferred revenue	-529	-327
Amortization of advance royalties	169	35
Amortization of debt issuance costs	239	1,410
Amortization of actuarial gain	-44	-92
Provision for doubtful accounts	206
Equity in net (income)/(loss) of unconsolidated affiliates	-141	917
Distribution from unconsolidated affiliate	196
Loss on retirement of advance royalties	8
(Gain) on sale/disposal of assets-net	-744	-130,778
Equity-based compensation	8	89
Changes in assets and liabilities:
Accounts receivable	-1,082	719
Inventories	-1,941	1,758
Advance royalties	-336	-282
Prepaid expenses and other assets	1,127	1,593
Accounts payable	-1,009	2,487
Accrued expenses and other liabilities	412	-783
Asset retirement obligations	-116	-326
Postretirement benefits	28	67
Net cash provided by operating activities	2,047	11,853
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant, and equipment	-3,063	-28,065
Proceeds from sales of property, plant, and equipment	800	189,088
Return of capital from unconsolidated affiliates	35
Investment in unconsolidated affiliates		-1,269
Net cash provided by/(used in) investing activities	-2,228	159,754
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on line of credit	33,050	50,900
Repayments on line of credit	-32,370	-213,710
Repayments on long-term debt		-254
Distributions to unitholders	-921	-7,722
General partner's contributions	1	3
Net settlement of employee withholding taxes on unit awards vested		-44
Payments on debt issuance costs		-104
Payment of offering costs		-2
Net cash used in financing activities	-240	-170,933
NET (DECREASE)/INCREASE IN CASH AND CASH EQUIVALENTS	-421	674
CASH AND CASH EQUIVALENTS-Beginning of period	626	423
CASH AND CASH EQUIVALENTS-End of period	$205	$1,097

Basis_Of_Presentation_And_Orga

Basis Of Presentation And Organization	3 Months Ended
Basis Of Presentation And Organization	Mar. 31, 2015
Basis Of Presentation And Organization [Abstract]
Basis Of Presentation And Organization	1. BASIS OF PRESENTATION AND ORGANIZATION
	Basis of Presentation and Principles of Consolidation— The accompanying unaudited interim financial statements include the accounts of Rhino Resource Partners LP and its subsidiaries (the “Partnership”). Intercompany transactions and balances have been eliminated in consolidation.
	Unaudited Interim Financial Information—The accompanying unaudited interim financial statements have been prepared in accordance with generally accepted accounting principles for interim financial information. The condensed consolidated statement of financial position as of March 31, 2015, condensed consolidated statements of operations and comprehensive income for the three months ended March 31, 2015 and 2014 and the condensed consolidated statements of cash flows for the three months ended March 31, 2015 and 2014 include all adjustments (consisting of normal recurring adjustments) which the Partnership considers necessary for a fair presentation of the financial position, operating results and cash flows for the periods presented. The condensed consolidated statement of financial position as of December 31, 2014 was derived from audited financial statements, but does not include all disclosures required by accounting principles generally accepted in the United States of America (“U.S.”). The Partnership filed its Annual Report on Form 10-K for the year ended December 31, 2014 with the Securities and Exchange Commission (“SEC”), which included all information and notes necessary for such presentation. The results of operations for the interim period are not necessarily indicative of the results to be expected for the year or any future period. These unaudited interim financial statements should be read in conjunction with the audited financial statements included in the Partnership’s Annual Report on Form 10-K for the year ended December 31, 2014 filed with the SEC.
	Organization—Rhino Resource Partners LP is a Delaware limited partnership formed on April 19, 2010 to acquire Rhino Energy LLC (the “Predecessor” or the “Operating Company”). 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 majority of sales are made to domestic utilities and other coal-related organizations in the United States. In addition to operating coal properties, the Operating Company manages and leases coal properties and collects royalties from such management and leasing activities.
	In addition to its coal operations, the Partnership has invested in oil and natural gas properties, mineral rights and other oil and gas infrastructure-related activities that generate revenues for the Partnership.

Summary_Of_Significant_Account

Summary Of Significant Accounting Policies And General	3 Months Ended
Summary Of Significant Accounting Policies And General	Mar. 31, 2015
Summary Of Significant Accounting Policies And General [Abstract]
Summary Of Significant Accounting Policies And General	2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND GENERAL
	Investments in Unconsolidated Affiliates. Investments in other entities 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 LLC (“Rhino Eastern”), with an affiliate of Patriot Coal Corporation (“Patriot”) to acquire the Eagle mining complex. To initially capitalize the joint venture, the Operating Company contributed approximately $16.1 million for a 51% ownership interest in the joint venture. The Partnership accounted for the investment in the joint venture and its results of operations under the equity method. The Partnership considered the operations of this entity to comprise a reporting segment (“Eastern Met”) and has provided additional detail related to this operation in Note 18, “Segment Information.” In January 2015, the Partnership completed a Membership Transfer Agreement (the “Transfer Agreement”) with an affiliate of Patriot that terminated the Rhino Eastern joint venture. Pursuant to the Transfer Agreement, Patriot sold and assigned its 49% membership interest in the Rhino Eastern joint venture to the Partnership and, in consideration of this transfer, Patriot received certain fixed assets, leased equipment and coal reserves associated with the mining area previously operated by the Rhino Eastern joint venture. Patriot also assumed substantially all of the active workforce related to the Eagle mining area that was previously employed by the Rhino Eastern joint venture. The Partnership retained approximately 34 million tons of coal reserves that are not related to the Eagle mining area as well as a prepaid advanced royalty balance. As part of the closing of the Transfer Agreement, the Partnership and Patriot agreed to a dissolution payment based upon a final working capital adjustment calculation as defined in the Transfer Agreement. As of December 31, 2014, the Partnership recorded an impairment charge of approximately $5.9 million related to its investment in the Rhino Eastern joint venture based upon the fair value of the assets received and liabilities assumed in the dissolution of the joint venture compared to the Partnership’s carrying amount of its investment in the joint venture. Refer to Note 17 for further information on the financial statement impact of the Rhino Eastern dissolution completed in January 2015.
	In December 2012, the Partnership made an initial investment of approximately $2.0 million in a new joint venture, Muskie Proppant LLC (“Muskie”), with affiliates of Wexford Capital LP (“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 United States. The Partnership accounted for the investment in the joint venture and results of operations under the equity method. The Partnership recorded its proportionate share of the operating losses for Muskie for the three months ended March 31, 2014 of approximately $42,000. During the three months ended March 31, 2014, the Partnership contributed additional capital based upon its ownership share to the Muskie joint venture in the amount of $0.2 million. During 2013 the Partnership provided a loan to Muskie totaling approximately $0.2 million which was fully repaid in November 2014 in conjunction with the Partnership’s contribution of its interest in Muskie to Mammoth Energy Partners LP (“Mammoth”), which is discussed below.
	In November 2014, the Partnership contributed its investment interest in Muskie to Mammoth in return for a limited partner interest in Mammoth. Mammoth was formed to own various companies that provide services to companies who engage in the exploration and development of North American onshore unconventional oil and natural gas reserves. Mammoth’s companies provide services that include completion and production services, contract land and directional drilling services and remote accommodation services. The non-cash transaction was a contribution of the Partnership’s investment interest in the Muskie entity for an investment interest in Mammoth. Thus, the Partnership determined that the non-cash exchange of the Partnership’s ownership interest in Muskie did not result in any gain or loss. As of March 31, 2015, the Partnership has recorded its investment in Mammoth of $1.9 million as a long-term asset, which the Partnership has accounted for as a cost method investment based upon its ownership percentage. The Partnership has included its investment in Mammoth and its prior investment in Muskie in its Other category for segment reporting purposes.
	In September 2014, the Partnership made an initial investment of $5.0 million in a new joint venture, Sturgeon Acquisitions LLC (“Sturgeon”), with affiliates of Wexford Capital and Gulfport Energy (“Gulfport”), a publicly traded company. Sturgeon subsequently acquired 100% of the outstanding equity interests of certain limited liability companies located in Wisconsin that provide frac sand for oil and natural gas drillers in the United States. The Partnership accounts for the investment in the joint venture and results of operations under the equity method. The Partnership recorded its proportionate share of the operating income for Sturgeon for the three months ended March 31, 2015 of approximately $0.1 million. The Partnership has included the operating activities of Sturgeon in its Other category for segment reporting purposes.
	Recently Issued Accounting Standards. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”). ASU 2014-09 clarifies the principles for recognizing revenue and establishes a common revenue standard for U.S. financial reporting purposes. The guidance in ASU 2014-09 affects any entity that either enters into contracts with customers to transfer goods or services or enters into contracts for the transfer of nonfinancial assets unless those contracts are within the scope of other standards (for example, insurance contracts or lease contracts). ASU 2014-09 supersedes the revenue recognition requirements in ASC 605, Revenue Recognition, and most industry-specific accounting guidance. Additionally, ASU 2014-09 supersedes some cost guidance included in ASC 605-35, Revenue Recognition—Construction-Type and Production-Type Contracts. In addition, the existing requirements for the recognition of a gain or loss on the transfer of nonfinancial assets that are not in a contract with a customer (for example, assets within the scope of ASC 360, Property, Plant, and Equipment, and intangible assets within the scope of ASC 350, Intangibles—Goodwill and Other) are amended to be consistent with the guidance on recognition and measurement (including the constraint on revenue) in ASU 2014-09. ASU 2014-09 is effective for public entities for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Early application of ASU 2014-09 is not permitted. However, in April 2015 the FASB proposed a one-year deferral of the effective date of ASU 2014-09, which is currently going through the comment period process The Partnership is currently evaluating the requirements of this new accounting guidance.
	In January 2015, the FASB issued ASU 2015-01, “Income Statement-Extraordinary and Unusual Items”. Accounting Standards Codification 225-20, Income Statement—Extraordinary and Unusual Items, required that an entity separately classify, present, and disclose extraordinary events and transactions. ASU 2015-01 eliminates the concept of extraordinary items. The amendments in ASU 2015-01 are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. A reporting entity may apply the amendments prospectively. A reporting entity also may apply the amendments retrospectively to all prior periods presented in the financial statements. Early adoption is permitted provided that the guidance is applied from the beginning of the fiscal year of adoption. The effective date is the same for both public business entities and all other entities. The adoption of ASU 2015-01 on January 1, 2016 is not expected to have a material impact on the Partnership’s financial statements.
	In February 2015, the FASB issued ASU 2015-02, “Consolidation”. ASU 2015-02 affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. Specifically, the amendments of ASU 2015-02: a) modify the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, b) eliminate the presumption that a general partner should consolidate a limited partnership, c) affect the consolidation analysis of reporting entities that are involved with VIEs, particularly those that have fee arrangements and related party relationships and d) provide a scope exception from consolidation guidance for reporting entities with interests in legal entities that are required to comply with or operate in accordance with requirements that are similar to those in Rule 2a-7 of the Investment Company Act of 1940 for registered money market funds. ASU 2015-02 is effective for public business entities for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted, including adoption in an interim period. If an entity early adopts the amendments in an interim period, any adjustments should be reflected as of the beginning of the fiscal year that includes that interim period. A reporting entity may apply the amendments in this Update using a modified retrospective approach by recording a cumulative-effect adjustment to equity as of the beginning of the fiscal year of adoption. A reporting entity also may apply the amendments retrospectively. The adoption of ASU 2015-02 on January 1, 2016 is not expected to have a material impact on the Partnership’s financial statements.
	In April 2015, the FASB issued ASU 2015-03, “Interest—Imputation of Interest (Subtopic 835-30)-Simplifying the Presentation of Debt Issuance Costs”. ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Prior to ASU 2015-03, debt issuance costs have been presented in the balance sheet as a deferred charge, or asset. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this ASU. For public business entities, ASU 2015-03 is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption of ASU 2105-03 is permitted for financial statements that have not been previously issued. In addition, ASU 2015-03 requires entities to apply the new guidance on a retrospective basis, wherein the balance sheet of each individual period presented should be adjusted to reflect the period-specific effects of applying the new guidance. The Partnership is currently evaluating the requirements of this new accounting guidance.

Discontinued_Operations

Discontinued Operations	3 Months Ended
Discontinued Operations	Mar. 31, 2015
Discontinued Operations [Abstract]
Discontinued Operations	3. DISCONTINUED OPERATIONS
	Divestiture of Utica Shale Oil and Natural Gas Assets
	The Partnership and an affiliate of Wexford Capital participated with Gulfport to acquire interests in a portfolio of oil and natural gas leases in the Utica Shale. 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 gas leases, which consisted of a 5% interest in a total of approximately 152,300 gross acres, or approximately 7,615 net acres. In addition, per the joint operating agreement among the Partnership, Gulfport and an affiliate of Wexford Capital, the Partnership had funded its proportionate share of drilling costs to Gulfport for wells being drilled on the Partnership’s acreage. As of December 31, 2013, the Partnership had funded approximately $23.3 million of drilling costs.
	In March 2014, the Partnership completed a purchase and sale agreement (the “Purchase Agreement”) with Gulfport to sell the Partnership’s oil and natural 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. At the closing of the Purchase Agreement, the Partnership was immediately due approximately $179.0 million, net of any adjustments described above, and the remaining approximately $5.0 million was scheduled to be paid within approximately 90 days of March 20, 2014, subject to ongoing legal title work related to specific properties. In December 2014, the Partnership settled the remaining $5.0 million due from Gulfport based upon net amounts payable from the Partnership to Gulfport prior to the effective date of the Purchase Agreement as well as amounts due the Partnership related to legal reviews of the properties subject to the Purchase Agreement and other unsettled items due to the Partnership prior to the effective date of the Purchase Agreement. The net effect of this settlement resulted in the Partnership paying Gulfport approximately $46,000 in December 2014. The Partnership recorded a gain of approximately $121.7 million during the three months ended March 31, 2014 related to this sale, which is recorded in Income from discontinued operations in the unaudited condensed consolidated statements of operations and comprehensive income. The gain from the Utica Shale transaction is included in the (Gain) on sale/disposal of assets—net line in the operating activities section of the Partnership’s unaudited condensed consolidated statements of cash flows. The proceeds from the Utica Shale transaction are included in the Proceeds from sales of property, plant, and equipment line in the investing activities section of the Partnership’s unaudited condensed consolidated statements of cash flows.

	Other Oil and Natural Gas Activities
	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 discussed above, the Partnership had the right to approximately 5% of the proceeds of the sale by Blackhawk. In February 2015, the Partnership received approximately $0.7 million in additional proceeds from the sale by Blackhawk that had been held in escrow. For the three months ended March 31, 2015 and 2014, the Partnership recorded the $0.7 million and $8.4 million, respectively, in Income from discontinued operations in the unaudited condensed consolidated statements of operations and comprehensive income. The gains from the Blackhawk transaction are included in the (Gain) on sale/disposal of assets—net line in the operating activities section of the Partnership’s unaudited condensed consolidated statements of cash flows. The proceeds from the Blackhawk transaction are included in the Proceeds from sales of property, plant, and equipment line in the investing activities section of the Partnership’s unaudited condensed consolidated statements of cash flows.

Prepaid_Expenses_And_Other_Cur

Prepaid Expenses And Other Current Assets	3 Months Ended
Prepaid Expenses And Other Current Assets	Mar. 31, 2015
Prepaid Expenses And Other Current Assets [Abstract]
Prepaid Expenses And Other Current Assets	4. PREPAID EXPENSES AND OTHER CURRENT ASSETS
	Prepaid expenses and other current assets as of March 31, 2015 and December 31, 2014 consisted of the following:

		March 31,	December 31,
		2015	2014
		(in thousands)
	Other prepaid expenses	$ 636	$ 827
	Prepaid insurance	923	2,063
	Prepaid leases	70	87
	Supply inventory	794	827
	Deposits	169	170
	Total Prepaid expenses and other	$ 2,592	$ 3,974

Property_Plant_And_Equipment

Property, Plant And Equipment	3 Months Ended
Property, Plant And Equipment	Mar. 31, 2015
Property, Plant And Equipment [Abstract]
Property, Plant And Equipment

	5. PROPERTY, PLANT AND EQUIPMENT
	Property, plant and equipment, including coal properties and mine development and construction costs, as of March 31, 2015 and December 31, 2014 are summarized by major classification as follows:

		Useful Lives		31-Mar-15		31-Dec-14
				(in thousands)
	Land and land improvements			$ 18,800		$ 18,845
	Mining and other equipment and related facilities	2 - 20 Years		339,125		336,951
	Mine development costs	1 - 15 Years		76,571		79,536
	Coal properties	1 - 15 Years		222,265		215,325
	Oil and natural gas properties			8,093		8,093
	Construction work in process			6,123		4,912
	Total			670,977		663,662
	Less accumulated depreciation, depletion and amortization			-280,439		-280,225
	Net			$ 390,538		$ 383,437


	Depreciation expense for mining and other equipment and related facilities, depletion expense for coal properties 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 three months ended March 31, 2015 and 2014 were as follows:

			Three Months Ended March 31,
			2015		2014
			(in thousands)
	Depreciation expense-mining and other equipment and related facilities		$ 7,577		$ 7,532
	Depletion expense for coal properties and oil and natural gas properties		808		1,194
	Amortization expense for mine development costs		522		424
	Amortization expense for intangible assets		20		21
	Amortization expense for asset retirement costs		-75		61
	Total depreciation, depletion and amortization		$ 8,852		$ 9,232

	Long-Lived Asset Impairment

	The Partnership has a steam coal surface mine operation in eastern Kentucky (referred to as “Bevins Branch”) in its Central Appalachia segment that was idled during mid-2014 as that location’s contract with its single customer expired at that time. The Partnership is finalizing the contractual agreement with a third party to assume the Bevins Branch operation. The contractual agreement has the third party assume the Bevins Branch operation where the only financial compensation the Partnership will receive is a future override royalty and the assumption of the reclamation obligations by the buyer. The closing of the transaction would also allow the Partnership to avoid the ongoing maintenance costs of this operation. The Partnership reviewed the Bevins Branch operation as of December 31, 2014 in accordance with the accounting guidance for long-lived asset impairment and recorded total asset impairment and related charges of $8.3 million for the Bevins Branch operation for the year ended December 31, 2014. The Partnership has reported the remaining assets and any related liabilities as held for sale on its unaudited condensed consolidated statements of financial position as of March 31, 2015.

Goodwill_And_Intangible_Assets

Goodwill And Intangible Assets	3 Months Ended
Goodwill And Intangible Assets	Mar. 31, 2015
Goodwill And Intangible Assets [Abstract]
Goodwill And Intangible Assets	6. GOODWILL AND INTANGIBLE ASSETS
	Accounting Standards Codification (“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 no longer amortized but instead tested for impairment at least annually.
	Intangible assets as of March 31, 2015 consisted of the following:


		Gross		Net
		Carrying	Accumulated	Carrying
	Intangible Asset	Amount	Amortization	Amount
		(in thousands)
	Patent	$ 728	$ 261	$ 467
	Developed Technology	78	28	50
	Trade Name	184	35	149
	Customer List	470	89	381
	Total	$ 1,460	$ 413	$ 1,047
	Intangible assets as of December 31, 2014 consisted of the following:

		Gross		Net
		Carrying	Accumulated	Carrying
	Intangible Asset	Amount	Amortization	Amount
		(in thousands)
	Patent	$ 728	$ 250	$ 478
	Developed Technology	78	27	51
	Trade Name	184	33	151
	Customer List	470	83	387
	Total	$ 1,460	$ 393	$ 1,067
	The Partnership considers the patent and developed technology intangible assets to have a useful life of seventeen years and 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 three months ended March 31, 2015 and 2014 is included in the depreciation, depletion and amortization table included in Note 5. The future total amortization expense for each of the five succeeding years related to intangible assets that are currently recorded in the unaudited condensed consolidated statement of financial position is estimated to be as follows at March 31, 2015:

			Developed		Customer
		Patent	Technology	Trade Name	List	Total
		(in thousands)
	2015 (from Apr 1 to Dec 31)	$ 32	$ 3	$ 7	$ 18	$ 60
	2016	43	5	9	23	80
	2017	43	5	9	23	80
	2018	43	5	9	23	80
	2019	43	5	9	23	80

Other_NonCurrent_Assets

Other Non-Current Assets	3 Months Ended
Other Non-Current Assets	Mar. 31, 2015
Other Non-Current Assets [Abstract]
Other Non-Current Assets	7. OTHER NON-CURRENT ASSETS
	Other non-current assets as of March 31, 2015 and December 31, 2014 consisted of the following:

		March 31,	December 31,
		2015	2014
		(in thousands)
	Deposits and other	$ 203	$ 347
	Debt issuance costs—net	1,274	1,513
	Non-current receivable	14,237	14,237
	Deferred expenses	300	313
	Total	$ 16,014	$ 16,410

	Debt issuance costs were approximately $9.1 million as of March 31, 2015 and December 31, 2014. Accumulated amortization of debt issuance costs were approximately $7.8 million and approximately $7.6 million as of March 31, 2015 and December 31, 2014, respectively. In March 2014, the Partnership entered into a second amendment of its amended and restated senior secured credit facility that reduced the borrowing capacity to $200 million. As part of executing the second amendment to the amended and restated senior secured credit facility, the Operating Company paid a fee of approximately $0.1 million to the lenders in March 2014, which was recorded as an addition to Debt issuance costs. In addition, the Partnership wrote-off approximately $1.1 million of its unamortized debt issuance costs since the second amendment reduced the borrowing capacity under the amended and restated senior secured credit facility. See Note 9 for further information on the amendment to the amended and restated senior secured credit facility.

	The non-current receivable balance of $14.2 million as of March 31, 2015 and December 31, 2014 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. The $14.2 million is also included in the Partnership’s accrued workers’ compensation benefits liability balance, which is included in the non-current liabilities section of the Partnership’s unaudited condensed consolidated statements of financial position. 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.

Accrued_Expenses_And_Other_Cur

Accrued Expenses And Other Current Liabilities	3 Months Ended
Accrued Expenses And Other Current Liabilities	Mar. 31, 2015
Accrued Expenses And Other Current Liabilities [Abstract]
Accrued Expenses And Other Current Liabilities	8. ACCRUED EXPENSES AND OTHER CURRENT LIABILITIES
	Accrued expenses and other current liabilities as of March 31, 2015 and December 31, 2014 consisted of the following:

		March 31,	December 31,
		2015	2014
		(in thousands)
	Payroll, bonus and vacation expense	$ 2,940	$ 2,876
	Non income taxes	3,571	4,323
	Royalty expenses	2,195	1,772
	Accrued interest	418	385
	Health claims	1,141	1,270
	Workers’ compensation & pneumoconiosis	1,500	1,500
	Deferred revenues	4,155	4,050
	Accrued insured litigation claims	1,013	489
	Other	2,595	669
	Total	$ 19,528	$ 17,334

	The $1.0 million and $0.5 million accrued for insured litigation claims as of March 31, 2015 and December 31, 2014, respectively, consists of probable and estimable litigation claims that are the primary obligation of the Partnership. The amount accrued for litigation claims 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 unaudited condensed 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.

	The increase in the amount of other accrued liabilities as of March 31, 2015 compared to December 31, 2014 primarily relates to liabilities accrued as part of the Rhino Eastern dissolution completed in January 2015, which is discussed further in Notes 2 and 17.

Debt

Debt	3 Months Ended
Debt	Mar. 31, 2015
Debt [Abstract]
Debt

	9. DEBT
	Debt as of March 31, 2015 and December 31, 2014 consisted of the following:


		March 31,	December 31,
		2015	2014
		(in thousands)
	Senior secured credit facility with PNC Bank, N.A.	$ 55,130	$ 54,450
	Other notes payable	3,033	2,982
	Total	58,163	57,432
	Less current portion	-214	-210
	Long-term debt	$ 57,949	$ 57,222

	Senior Secured Credit Facility with PNC Bank, N.A.—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 was $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 was available for letters of credit. As described below, in March 2014 the amended and restated credit facility was amended and the borrowing capacity under the facility was reduced to $200 million, with the amount available for letters of credit unchanged. 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 of 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 March 31, 2015. The amended and restated senior secured credit facility was previously set to expire in July 2016, but the term was extended to July 2017 pursuant to the third amendment of the facility, which is described further in Note 19.
	In March 2014, the Partnership entered into a second 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. This second amendment permitted the Partnership to sell certain assets to Gulfport, as described in Note 3, which previously constituted a portion of the collateral under the amended and restated senior secured credit facility. This second amendment also reduced the borrowing capacity under the amended and restated senior secured credit facility to a maximum of $200 million and altered the maximum leverage ratio to 3.5 from January 1, 2014 through September 30, 2015. The maximum leverage ratio decreases to 3.25 from October 1, 2015 through December 31, 2015 and then decreases to 3.0 after December 31, 2015. In addition, the second amendment adjusted the maximum investments (other than by the Partnership) in hydrocarbons, hydrocarbon interests and assets and activities related to hydrocarbons, in each case, excluding coal, in an aggregate amount not to exceed $50 million. As part of executing the second amendment to the amended and restated senior secured credit facility, the Operating Company paid a fee of approximately $0.1 million to the lenders in March 2014, which was recorded in Debt issuance costs in Other non-current assets on the Partnership’s unaudited condensed consolidated statements of financial position. In addition, the Partnership recorded a non-cash charge of approximately $1.1 million to write-off a portion of its unamortized debt issuance costs since the second amendment reduced the borrowing capacity under the amended and restated senior secured credit facility, which was recorded in Interest expense on the Partnership’s unaudited condensed consolidated statements of operations and comprehensive income.
	In April 2015, the Partnership entered into a third 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. This third amendment is described further in Note 19.
	At March 31, 2015, the Operating Company had borrowed $54.4 million at a variable interest rate of LIBOR plus 2.50% (2.68% at March 31, 2015) and an additional $0.7 million at a variable interest rate of PRIME plus 1.50% (4.75% at March 31, 2015). In addition, the Operating Company had outstanding letters of credit of approximately $16.0 million at a fixed interest rate of 2.50% at March 31, 2015. Based upon a maximum borrowing capacity of 3.5 times a trailing twelve-month EBITDA calculation (as defined in the credit agreement), the Operating Company had available borrowing capacity of approximately $4.4 million at March 31, 2015.

Asset_Retirement_Obligations

Asset Retirement Obligations	3 Months Ended
Asset Retirement Obligations	Mar. 31, 2015
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	10. ASSET RETIREMENT OBLIGATIONS
	The changes in asset retirement obligations for the three months ended March 31, 2015 and the year ended December 31, 2014 are as follows:

		31-Mar-15	31-Dec-14
		(in thousands)
	Balance at beginning of period (including current portion)	$ 29,883	$ 34,451
	Accretion expense	534	2,281
	Adjustment resulting from addition of property	1,235	-
	Adjustment resulting from disposal of property (1)	-	-2,310
	Adjustments to the liability from annual recosting and other	-	-1,324
	Reclassification to held for sale	-	-2,250
	Liabilities settled	-116	-965
	Balance at end of period	31,536	29,883
	Less current portion of asset retirement obligation	-1,555	-1,431
	Long-term portion of asset retirement obligation	$ 29,981	$ 28,452


	(1) The ($2.3) million adjustment for the year ended December 31, 2014 primarily relates to the transfer of certain mining permits to a third party that relieved the Partnership of the asset retirement obligations related to these permits.

Employee_Benefits

Employee Benefits	3 Months Ended
Employee Benefits	Mar. 31, 2015
Employee Benefits [Abstract]
Employee Benefits	11. EMPLOYEE BENEFITS
	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.
	Net periodic benefit cost for the three months ended March 31, 2015 and 2014 are as follows:

		Three months ended March 31,
		2015	2014
		(in thousands)
	Service costs	$ 67	$ 74
	Interest cost	51	59
	Amortization of (gain)	-44	-92
	Total	$ 74	$ 41
	For the three months ended March 31, 2015 and 2014, net periodic benefit costs, including the amortization of actuarial gain included in the table above, are included in Cost of operations in the Partnership’s unaudited condensed consolidated statements of operations and comprehensive income.
	401(k) Plans—The Operating Company and certain subsidiaries sponsor defined contribution savings plans for all employees. Under one defined contribution savings plan, the Operating Company 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 Operating Company’s discretion. The expense under these plans for the three months ended March 31, 2015 and 2014 is included in Cost of operations in the Partnership’s unaudited condensed consolidated statements of operations and comprehensive income and was as follows:

		Three months ended March 31,
		2015	2014
		(in thousands)
	401(k) plan expense	$ 558	$ 568

EquityBased_Compensation

Equity-Based Compensation	3 Months Ended
Equity-Based Compensation	Mar. 31, 2015
Equity-Based Compensation [Abstract]
Equity-Based Compensation	12. 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.
	As of March 31, 2015, the General Partner had granted phantom units to certain employees and restricted units and unit awards to its directors. These grants consisted of annual restricted unit awards to directors and phantom unit awards with tandem distribution equivalent rights (“DERs”) granted in the first quarters from 2012 through 2015 to certain employees in connection with the prior year’s performance. The DERs consist of rights to accrue quarterly cash distributions in an amount equal to the cash distribution the Partnership makes to unitholders during the vesting period. These awards are subject to service based vesting conditions and any accrued distributions will be forfeited if the related awards fail to vest according to the relevant service based vesting conditions.
	A total of 33,948 phantom units were granted in the first quarter of 2015 and these awards 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 equivalent to the terms described above. The total fair value of the awards granted in the first quarter of 2015 was approximately $0.1 million at the grant date and the fair value of these awards was approximately $0.1 million as of March 31, 2015. The expense related to these awards will be recognized ratably over the three year vesting period, plus any mark-to-market adjustments, and the amount of expense recognized in the three months ended March 31, 2015 related to these awards was immaterial.
	The Partnership accounts for its unit-based awards as liabilities with applicable mark-to-market adjustments at each reporting period because the Compensation Committee of the board of directors of the General Partner has historically elected to pay some of the awards in cash in lieu of issuing common units.

Commitments_And_Contingencies

Commitments And Contingencies	3 Months Ended
Commitments And Contingencies	Mar. 31, 2015
Commitments And Contingencies [Abstract]
Commitments And Contingencies	13. COMMITMENTS AND CONTINGENCIES
	Coal Sales Contracts and Contingencies—As of March 31, 2015, the Partnership had commitments under sales contracts to deliver annually scheduled base quantities of coal as follows:

	Year	Tons (in thousands)	Number of customers
	2015 Q2-Q4	2,677	18
	2016	2,611	7
	2017	1,650	3

	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 March 31, 2015, the Partnership had approximately 0.8 million gallons remaining on a commitment to purchase diesel fuel at fixed prices through December 2015 for approximately $1.8 million.
	Purchased Coal Expenses—The Partnership incurs purchased coal expense from time to time related to coal purchase contracts. Purchased coal expense from coal purchase contracts for the three months ended March 31, 2015 and 2014 are included in Cost of operations in the Partnership’s unaudited condensed consolidated statements of operations and comprehensive income and were as follows:

		Three months ended March 31,
		2015	2014
		(in thousands)
	Purchased coal expense	$ (26)	$ 1,850
	OTC expense	$ -	$ -

	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 three months ended March 31, 2015 and 2014 are included in Cost of operations in the Partnership’s unaudited condensed consolidated statements of operations and comprehensive income and was as follows:

		Three months ended March 31,
		2015	2014
		(in thousands)
	Lease expense	$ 1,121	$ 799
	Royalty expense	$ 2,834	$ 2,760

	Joint Ventures—The Partnership may contribute additional capital to the Timber Wolf joint venture that was formed in the first quarter of 2012. The Partnership made an initial capital contribution of approximately $0.1 million during the year ended December 31, 2012 based upon its proportionate ownership interest.
	The Partnership may contribute additional capital to the Sturgeon joint venture that was formed in the third quarter of 2014. The Partnership made an initial capital contribution of $5.0 million during the third quarter ended September 30, 2014 based upon its proportionate ownership interest.

Earnings_Per_Unit_EPU

Earnings Per Unit ("EPU")	3 Months Ended
Earnings Per Unit ("EPU")	Mar. 31, 2015
Earnings Per Unit ("EPU") [Abstract]
Earnings Per Unit ("EPU")


	14. EARNINGS PER UNIT (“EPU”)

	The following tables present a reconciliation of the numerators and denominators of the basic and diluted EPU calculations for the periods ended March 31, 2015 and 2014:


	Three months ended March 31, 2015	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net (loss)/income:
	Net (loss) from continuing operations	$ (91)	$ (2,569)	$ (1,902)
	Net income from discontinued operations	14	402	305
	Total interest in net (loss)	$ (77)	$ (2,167)	$ (1,597)
	Denominator:
	Weighted average units used to compute basic EPU	n/a	16,692	12,397
	Effect of dilutive securities — LTIP awards:
	Dilutive securities for net (loss) from continuing operations	n/a	-	-
	Dilutive securities for net income from discontinued operations	n/a	-	-
	Total dilutive securities	n/a	-	-
	Weighted average units used to compute diluted EPU	n/a	16,692	12,397

	Net (loss)/income per limited partner unit, basic
	Net (loss) per unit from continuing operations	n/a	$ (0.15)	$ (0.15)
	Net income per unit from discontinued operations	n/a	0.02	0.02
	Net (loss) per common unit, basic	n/a	$ (0.13)	$ (0.13)
	Net (loss)/income per limited partner unit, diluted
	Net (loss) per unit from continuing operations	n/a	$ (0.15)	$ (0.15)
	Net income per unit from discontinued operations	n/a	0.02	0.02
	Net (loss) per common unit, diluted	n/a	$ (0.13)	$ (0.13)









	Three months ended March 31, 2014	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net (loss)/income:
	Net (loss) from continuing operations	$ (99)	$ (2,795)	$ (2,072)
	Net income from discontinued operations	2,610	73,343	54,558
	Total interest in net income	$ 2,511	$ 70,548	$ 52,486
	Denominator:
	Weighted average units used to compute basic EPU	n/a	16,667	12,397
	Effect of dilutive securities — LTIP awards:
	Dilutive securities for net (loss) from continuing operations	n/a	-	-
	Dilutive securities for net income from discontinued operations	n/a	6	-
	Total dilutive securities	n/a	6	-
	Weighted average units used to compute diluted EPU	n/a	16,673	12,397

	Net (loss)/income per limited partner unit, basic
	Net income per unit from continuing operations	n/a	$ (0.17)	$ (0.17)
	Net income per unit from discontinued operations	n/a	4.40	4.40
	Net income per common unit, basic	n/a	$ 4.23	$ 4.23
	Net (loss)/income per limited partner unit, diluted
	Net income per unit from continuing operations	n/a	$ (0.17)	$ (0.17)
	Net income per unit from discontinued operations	n/a	4.40	4.40
	Net income per common unit, diluted	n/a	$ 4.23	$ 4.23




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. Since the Partnership incurred a total net loss for the three months ended March 31, 2015, all potential dilutive units were excluded from the diluted EPU calculation for this period because when an entity incurs a net loss in a period, potential dilutive units shall not be included in the computation of diluted EPU since their effect will always be anti-dilutive. For the three months ended March 31, 2014, approximately 6,000 LTIP granted phantom units were anti-dilutive.

Major_Customers

Major Customers	3 Months Ended
Major Customers	Mar. 31, 2015
Major Customers [Abstract]
Major Customers

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

		31-Mar	Three months	Three months
		2015	ended	ended
		Receivable	31-Mar	31-Mar
		Balance	2015 Sales	2014 Sales
		(in thousands)
	NRG Energy, Inc. (fka GenOn Energy, Inc.)	$ 2,569	$ 8,563	$ 6,820
	PPL Corporation	1,511	7,206	n/a

Fair_Value_Of_Financial_Instru

Fair Value Of Financial Instruments	3 Months Ended
Fair Value Of Financial Instruments	Mar. 31, 2015
Fair Value Of Financial Instruments [Abstract]
Fair Value Of Financial Instruments
	16. 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 March 31, 2015. The fair value of the Partnership’s senior secured credit facility is a Level 2 measurement.

	For the year ended December 31, 2014, the Partnership had nonrecurring fair value measurements related to its assets and liabilities held for sale. These assets and liabilities were the result of the Partnership’s long-lived impairment actions conducted during the fourth quarter of 2014. The fair value of the assets and liabilities held for sale at December 31, 2014 were based upon the highest and best use of the respective nonfinancial assets and liabilities. The Partnership had approximately $6.9 million in land value related to its Red Cliff assets that were classified as held for sale at December 31, 2014. The fair value of the Partnership’s land held for sale at December 31, 2014 is a Level 2 measurement. Additionally, the Partnership had approximately $2.4 million of assets and $2.2 million of liabilities held for sale at December 31, 2014 related to the Bevins Branch operation discussed in Note 5. The fair values of the Partnership’s assets and liabilities held for sale at December 31, 2014 for the Bevins Branch operation are Level 3 measurements. As of March 31, 2015, the Partnership’s nonrecurring fair value measurements related to its assets and liabilities held for sale had not changed from December 31, 2014.

Supplemental_Disclosures_Of_Ca

Supplemental Disclosures Of Cash Flow Information	3 Months Ended
	Mar. 31, 2015
Supplemental Disclosures Of Cash Flow Information [Abstract]
Supplemental Disclosures Of Cash Flow Information	17. SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
	The unaudited condensed consolidated statement of cash flows for the three months ended March 31, 2015 excludes approximately $0.8 million of property additions, which are recorded in accounts payable.

	In January 2015, the Partnership dissolved the Rhino Eastern joint venture with Patriot. As part of the dissolution, the Partnership retained coal reserves, a prepaid advanced royalty balance and other assets and liabilities. In addition, the Partnership and Patriot agreed to a dissolution payment as part of the dissolution based upon a final working capital adjustment calculation, which is a liability of the Partnership. The Partnership recorded the dissolution of the joint venture by removing the investment in the Rhino Eastern unconsolidated subsidiary and recording the specific assets and liabilities retained in the dissolution. The dissolution of the Rhino Eastern joint venture completed in January 2015 had no impact on the Partnership’s unconsolidated statements of operations and comprehensive income for the three months ended March 31, 2015. The unaudited condensed consolidated statement of cash flows for the three months ended March 31, 2015 excludes the removal of the investment in the unconsolidated subsidiary and the recognition of the retained assets and liabilities, which are detailed in the table below.



		(in thousands)
	Coal properties (incl asset retirement costs)	$ 12,104
	Advance royalties, net of current portion	4,706
	Other non-current assets - acquired	229
	Other non-current assets - written off	-642
	Accrued expenses and other	-2,012
	Asset retirement obligations	-1,235
	Net assets acquired	13,150
	Investment in unconsolidated affiliates-Rhino Eastern - written off	$ (13,150)


	The unaudited condensed consolidated statement of cash flows for the three months ended March 31, 2014 excludes approximately $3.0 million of property additions, which are recorded in accounts payable, and approximately $0.2 million related to the value of phantom and restricted units that were issued to certain employees and directors of the General Partner.

Segment_Information

Segment Information	3 Months Ended
Segment Information	Mar. 31, 2015
Segment Information [Abstract]
Segment Information	18. SEGMENT INFORMATION
	The Partnership 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. The Partnership also leases coal reserves to third parties in exchange for royalty revenues. For the three months ended March 31, 2015, the Partnership had four reportable segments: Central Appalachia (comprised of both surface and underground mines located in Eastern Kentucky and Southern West Virginia, along with the Elk Horn coal leasing operations), Northern Appalachia (comprised of both surface and underground mines located in Ohio), Rhino Western (comprised of an underground mine in Utah) and Illinois Basin (comprised of an underground mine in western Kentucky).
	The Partnership’s Other category is comprised of the Partnership’s ancillary businesses and its remaining oil and natural gas activities. 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 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 had historically only presented limited information (net income). The Partnership considered this operation to comprise a separate operating segment prior to its dissolution in January 2015. With the dissolution of the Rhino Eastern joint venture in January 2015, the Partnership had no operating activities for this joint venture for the three months ended March 31, 2015.
	Reportable segment results of operations for the three months ended March 31, 2015 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization):



		Central	Northern	Rhino	Illinois		Total
		Appalachia	Appalachia	Western	Basin	Other	Consolidated
		(in thousands)
	Total revenues	$ 22,250	$ 17,330	$ 8,460	$ 7,179	$ 965	$ 56,184
	DD&A	3,948	1,846	1,610	1,214	234	8,852
	Interest expense	392	114	63	118	270	957
	Net income (loss) from continuing operations	$ (231)	$ 1,180	$ (1,296)	$ (4,541)	$ 326	$ (4,562)

	Reportable segment results of operations for the three months ended March 31, 2014 are as follows:


						Eastern Met
							Equity	Equity
		Central	Northern	Rhino	Illinois	Complete	Method	Method		Total
		Appalachia	Appalachia	Western	Basin	Basis	Eliminations	Presentation	Other	Consolidated
		(in thousands)
	Total revenues	$ 30,561	$ 18,764	$ 9,586	$ -	$ 7,529	$ (7,529)	$ -	$ 1,031	$ 59,942
	DD&A	5,402	1,878	1,418	207	500	-500	-	327	9,232
	Interest expense	1,053	177	150	118	15	-15	-	1,686	3,184
	Net income (loss) from continuing operations	$ (3,818)	$ 1,104	$ (346)	$ (99)	$ (1,717)	$ 841	$ (876)	$ (931)	$ (4,966)

Subsequent_Events

Subsequent Events	3 Months Ended
Subsequent Events	Mar. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	19. SUBSEQUENT EVENTS
	On April 20, 2015, the Partnership announced a cash distribution of $0.02 per common unit, or $0.08 per unit on an annualized basis. This distribution will be paid on May 15, 2015 to all common unit holders of record as of the close of business on April 30, 2015. No distributions will be paid on the subordinated units. The Partnership’s common units accrue arrearages every quarter when the distribution level is below the minimum level of $0.445 per unit, as outlined in the Partnership agreement. The Partnership’s distributions for the quarters ended September 30, 2014, December 31, 2014 and March 31, 2015 were below the minimum level and the current amount of accumulated arrearages as of March 31, 2015 related to the common unit distribution is approximately $21.0 million.
	In April 2015, the Partnership entered into a third 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 third amendment extends the expiration date of the amended and restated credit agreement to July 2017. The extension is contingent upon the Partnership’s leverage ratio being less than or equal to 2.75 to 1.0 and the Partnership having liquidity greater than or equal to $15 million for either quarter ending December 31, 2015 or March 31, 2016. If both of these conditions are not satisfied for either period, the expiration date of the amended and restated credit agreement will revert to July 2016. The third amendment also reduces the borrowing capacity under the credit facility to a maximum of $100 million and reduces the amount available for letters of credit to $50 million. The third amendment also provides that the disposition of any assets by the Partnership consisting of net cash proceeds up to an aggregate $35 million shall reduce the total commitments under the facility on a dollar-for-dollar basis by up to a total of $10 million, and any dispositions of assets in excess of $35 million in the aggregate shall reduce commitments under the facility on a dollar-for-dollar basis. The third amendment alters the maximum leverage ratio to 3.75 to 1.0 through September 30, 2015. The maximum leverage ratio decreases to 3.5 to 1.0 from October 1, 2015 through December 31, 2015 and then decreases to 3.25 to 1.0 from January 1, 2016 through March 31, 2016. The maximum leverage ratio decreases to 3.0 to 1.0 after March 31, 2016. Notwithstanding the above, the leverage ratio shall be reduced by 0.25 for every $10 million of gross cash proceeds received by the Partnership from the sale of any assets; provided, however, that in no event shall the maximum permitted leverage ratio be reduced below 3.00 to 1.0. The third amendment limits the Partnership’s quarterly distributions to a maximum of $0.035 per unit unless (i) the pro forma leverage ratio of the Partnership, immediately prior to and after giving effect to such distribution, is less than or equal to 3.0 to 1.0 and (ii) the amount of borrowings available under the credit facility, immediately prior to and after giving effect to such distribution, is at least $20 million. In addition, the third amendment removes the interest coverage ratio covenant and replaces it with a minimum fixed charge coverage ratio, which consists of the ratio of consolidated EBITDA minus maintenance capital expenditures to fixed charges. Fixed charges are defined in the third amendment to include the sum of cash interest expense, scheduled principal installments on indebtedness (as adjusted for prepayments), dividends and distributions. Commencing with the quarter ending September 30, 2015, the fixed charge coverage ratio for the trailing four quarters must be a minimum of 1.1 to 1.0. The third amendment also limits any investments made by the Partnership, including investments in hydrocarbons, to $10 million provided that the leverage ratio is less than or equal to 3.0 to 1.0 and the borrowers’ available liquidity is at least $20 million. The third amendment does not permit the Partnership to issue any new equity of the Partnership unless the proceeds of such equity issuance are used to reduce the outstanding borrowings under the facility. Issuances of equity under the Partnership’s long-term incentive plan are excluded from this requirement. The third amendment limits the amount of the Partnership’s capital expenditures to $20.0 million for fiscal year 2015 and limits capital expenditures to $27.5 million for each fiscal year after 2015. However, to the extent that capital expenditures for any fiscal year are less than indicated above, the Partnership may increase the following year’s capital expenditures by the lesser of such unused amount or $5.0 million.

Summary_Of_Significant_Account1

Summary Of Significant Accounting Policies And General (Policies)	3 Months Ended
	Mar. 31, 2015
Summary Of Significant Accounting Policies And General [Abstract]
Investments In Unconsolidated Affiliates	Investments in Unconsolidated Affiliates. Investments in other entities 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 LLC (“Rhino Eastern”), with an affiliate of Patriot Coal Corporation (“Patriot”) to acquire the Eagle mining complex. To initially capitalize the joint venture, the Operating Company contributed approximately $16.1 million for a 51% ownership interest in the joint venture. The Partnership accounted for the investment in the joint venture and its results of operations under the equity method. The Partnership considered the operations of this entity to comprise a reporting segment (“Eastern Met”) and has provided additional detail related to this operation in Note 18, “Segment Information.” In January 2015, the Partnership completed a Membership Transfer Agreement (the “Transfer Agreement”) with an affiliate of Patriot that terminated the Rhino Eastern joint venture. Pursuant to the Transfer Agreement, Patriot sold and assigned its 49% membership interest in the Rhino Eastern joint venture to the Partnership and, in consideration of this transfer, Patriot received certain fixed assets, leased equipment and coal reserves associated with the mining area previously operated by the Rhino Eastern joint venture. Patriot also assumed substantially all of the active workforce related to the Eagle mining area that was previously employed by the Rhino Eastern joint venture. The Partnership retained approximately 34 million tons of coal reserves that are not related to the Eagle mining area as well as a prepaid advanced royalty balance. As part of the closing of the Transfer Agreement, the Partnership and Patriot agreed to a dissolution payment based upon a final working capital adjustment calculation as defined in the Transfer Agreement. As of December 31, 2014, the Partnership recorded an impairment charge of approximately $5.9 million related to its investment in the Rhino Eastern joint venture based upon the fair value of the assets received and liabilities assumed in the dissolution of the joint venture compared to the Partnership’s carrying amount of its investment in the joint venture. Refer to Note 17 for further information on the financial statement impact of the Rhino Eastern dissolution completed in January 2015.
	In December 2012, the Partnership made an initial investment of approximately $2.0 million in a new joint venture, Muskie Proppant LLC (“Muskie”), with affiliates of Wexford Capital LP (“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 United States. The Partnership accounted for the investment in the joint venture and results of operations under the equity method. The Partnership recorded its proportionate share of the operating losses for Muskie for the three months ended March 31, 2014 of approximately $42,000. During the three months ended March 31, 2014, the Partnership contributed additional capital based upon its ownership share to the Muskie joint venture in the amount of $0.2 million. During 2013 the Partnership provided a loan to Muskie totaling approximately $0.2 million which was fully repaid in November 2014 in conjunction with the Partnership’s contribution of its interest in Muskie to Mammoth Energy Partners LP (“Mammoth”), which is discussed below.
	In November 2014, the Partnership contributed its investment interest in Muskie to Mammoth in return for a limited partner interest in Mammoth. Mammoth was formed to own various companies that provide services to companies who engage in the exploration and development of North American onshore unconventional oil and natural gas reserves. Mammoth’s companies provide services that include completion and production services, contract land and directional drilling services and remote accommodation services. The non-cash transaction was a contribution of the Partnership’s investment interest in the Muskie entity for an investment interest in Mammoth. Thus, the Partnership determined that the non-cash exchange of the Partnership’s ownership interest in Muskie did not result in any gain or loss. As of March 31, 2015, the Partnership has recorded its investment in Mammoth of $1.9 million as a long-term asset, which the Partnership has accounted for as a cost method investment based upon its ownership percentage. The Partnership has included its investment in Mammoth and its prior investment in Muskie in its Other category for segment reporting purposes.
	In September 2014, the Partnership made an initial investment of $5.0 million in a new joint venture, Sturgeon Acquisitions LLC (“Sturgeon”), with affiliates of Wexford Capital and Gulfport Energy (“Gulfport”), a publicly traded company. Sturgeon subsequently acquired 100% of the outstanding equity interests of certain limited liability companies located in Wisconsin that provide frac sand for oil and natural gas drillers in the United States. The Partnership accounts for the investment in the joint venture and results of operations under the equity method. The Partnership recorded its proportionate share of the operating income for Sturgeon for the three months ended March 31, 2015 of approximately $0.1 million. The Partnership has included the operating activities of Sturgeon in its Other category for segment reporting purposes.

Recently Issued Accounting Standards	Recently Issued Accounting Standards. In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”). ASU 2014-09 clarifies the principles for recognizing revenue and establishes a common revenue standard for U.S. financial reporting purposes. The guidance in ASU 2014-09 affects any entity that either enters into contracts with customers to transfer goods or services or enters into contracts for the transfer of nonfinancial assets unless those contracts are within the scope of other standards (for example, insurance contracts or lease contracts). ASU 2014-09 supersedes the revenue recognition requirements in ASC 605, Revenue Recognition, and most industry-specific accounting guidance. Additionally, ASU 2014-09 supersedes some cost guidance included in ASC 605-35, Revenue Recognition—Construction-Type and Production-Type Contracts. In addition, the existing requirements for the recognition of a gain or loss on the transfer of nonfinancial assets that are not in a contract with a customer (for example, assets within the scope of ASC 360, Property, Plant, and Equipment, and intangible assets within the scope of ASC 350, Intangibles—Goodwill and Other) are amended to be consistent with the guidance on recognition and measurement (including the constraint on revenue) in ASU 2014-09. ASU 2014-09 is effective for public entities for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Early application of ASU 2014-09 is not permitted. However, in April 2015 the FASB proposed a one-year deferral of the effective date of ASU 2014-09, which is currently going through the comment period process The Partnership is currently evaluating the requirements of this new accounting guidance.
	In January 2015, the FASB issued ASU 2015-01, “Income Statement-Extraordinary and Unusual Items”. Accounting Standards Codification 225-20, Income Statement—Extraordinary and Unusual Items, required that an entity separately classify, present, and disclose extraordinary events and transactions. ASU 2015-01 eliminates the concept of extraordinary items. The amendments in ASU 2015-01 are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. A reporting entity may apply the amendments prospectively. A reporting entity also may apply the amendments retrospectively to all prior periods presented in the financial statements. Early adoption is permitted provided that the guidance is applied from the beginning of the fiscal year of adoption. The effective date is the same for both public business entities and all other entities. The adoption of ASU 2015-01 on January 1, 2016 is not expected to have a material impact on the Partnership’s financial statements.
	In February 2015, the FASB issued ASU 2015-02, “Consolidation”. ASU 2015-02 affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. Specifically, the amendments of ASU 2015-02: a) modify the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, b) eliminate the presumption that a general partner should consolidate a limited partnership, c) affect the consolidation analysis of reporting entities that are involved with VIEs, particularly those that have fee arrangements and related party relationships and d) provide a scope exception from consolidation guidance for reporting entities with interests in legal entities that are required to comply with or operate in accordance with requirements that are similar to those in Rule 2a-7 of the Investment Company Act of 1940 for registered money market funds. ASU 2015-02 is effective for public business entities for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2015. Early adoption is permitted, including adoption in an interim period. If an entity early adopts the amendments in an interim period, any adjustments should be reflected as of the beginning of the fiscal year that includes that interim period. A reporting entity may apply the amendments in this Update using a modified retrospective approach by recording a cumulative-effect adjustment to equity as of the beginning of the fiscal year of adoption. A reporting entity also may apply the amendments retrospectively. The adoption of ASU 2015-02 on January 1, 2016 is not expected to have a material impact on the Partnership’s financial statements.
	In April 2015, the FASB issued ASU 2015-03, “Interest—Imputation of Interest (Subtopic 835-30)-Simplifying the Presentation of Debt Issuance Costs”. ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Prior to ASU 2015-03, debt issuance costs have been presented in the balance sheet as a deferred charge, or asset. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this ASU. For public business entities, ASU 2015-03 is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption of ASU 2105-03 is permitted for financial statements that have not been previously issued. In addition, ASU 2015-03 requires entities to apply the new guidance on a retrospective basis, wherein the balance sheet of each individual period presented should be adjusted to reflect the period-specific effects of applying the new guidance. The Partnership is currently evaluating the requirements of this new accounting guidance.

Prepaid_Expenses_And_Other_Cur1

Prepaid Expenses And Other Current Assets (Tables)	3 Months Ended
Prepaid Expenses And Other Current Assets (Tables)	Mar. 31, 2015
Prepaid Expenses And Other Current Assets [Abstract]
Schedule Of Prepaid Expenses And Other Current Assets
		March 31,	December 31,
		2015	2014
		(in thousands)
	Other prepaid expenses	$ 636	$ 827
	Prepaid insurance	923	2,063
	Prepaid leases	70	87
	Supply inventory	794	827
	Deposits	169	170
	Total Prepaid expenses and other	$ 2,592	$ 3,974

Property_Plant_And_Equipment_T

Property, Plant And Equipment (Tables)	3 Months Ended
Property, Plant And Equipment (Tables)	Mar. 31, 2015
Property, Plant And Equipment [Abstract]
Property, Plant And Equipment By Major Classification
		Useful Lives		31-Mar-15		31-Dec-14
				(in thousands)
	Land and land improvements			$ 18,800		$ 18,845
	Mining and other equipment and related facilities	2 - 20 Years		339,125		336,951
	Mine development costs	1 - 15 Years		76,571		79,536
	Coal properties	1 - 15 Years		222,265		215,325
	Oil and natural gas properties			8,093		8,093
	Construction work in process			6,123		4,912
	Total			670,977		663,662
	Less accumulated depreciation, depletion and amortization			-280,439		-280,225
	Net			$ 390,538		$ 383,437




Depreciation, Depletion, And Amortization
			Three Months Ended March 31,
			2015		2014
			(in thousands)
	Depreciation expense-mining and other equipment and related facilities		$ 7,577		$ 7,532
	Depletion expense for coal properties and oil and natural gas properties		808		1,194
	Amortization expense for mine development costs		522		424
	Amortization expense for intangible assets		20		21
	Amortization expense for asset retirement costs		-75		61
	Total depreciation, depletion and amortization		$ 8,852		$ 9,232

Goodwill_And_Intangible_Assets1

Goodwill And Intangible Assets (Tables)	3 Months Ended
Goodwill And Intangible Assets (Tables)	Mar. 31, 2015
Goodwill And Intangible Assets [Abstract]
Schedule Of Intangible Assets By Major Class
	Intangible assets as of March 31, 2015 consisted of the following:


		Gross		Net
		Carrying	Accumulated	Carrying
	Intangible Asset	Amount	Amortization	Amount
		(in thousands)
	Patent	$ 728	$ 261	$ 467
	Developed Technology	78	28	50
	Trade Name	184	35	149
	Customer List	470	89	381
	Total	$ 1,460	$ 413	$ 1,047
	Intangible assets as of December 31, 2014 consisted of the following:

		Gross		Net
		Carrying	Accumulated	Carrying
	Intangible Asset	Amount	Amortization	Amount
		(in thousands)
	Patent	$ 728	$ 250	$ 478
	Developed Technology	78	27	51
	Trade Name	184	33	151
	Customer List	470	83	387
	Total	$ 1,460	$ 393	$ 1,067


Future Amortization Expense
			Developed		Customer
		Patent	Technology	Trade Name	List	Total
		(in thousands)
	2015 (from Apr 1 to Dec 31)	$ 32	$ 3	$ 7	$ 18	$ 60
	2016	43	5	9	23	80
	2017	43	5	9	23	80
	2018	43	5	9	23	80
	2019	43	5	9	23	80

Other_NonCurrent_Assets_Tables

Other Non-Current Assets (Tables)	3 Months Ended
Other Non-Current Assets (Tables)	Mar. 31, 2015
Other Non-Current Assets [Abstract]
Schedule Of Other Non-Current Assets
		March 31,	December 31,
		2015	2014
		(in thousands)
	Deposits and other	$ 203	$ 347
	Debt issuance costs—net	1,274	1,513
	Non-current receivable	14,237	14,237
	Deferred expenses	300	313
	Total	$ 16,014	$ 16,410

Accrued_Expenses_And_Other_Cur1

Accrued Expenses And Other Current Liabilities (Tables)	3 Months Ended
Accrued Expenses And Other Current Liabilities (Tables)	Mar. 31, 2015
Accrued Expenses And Other Current Liabilities [Abstract]
Schedule Of Accrued Expenses And Other Current Liabilities
		March 31,	December 31,
		2015	2014
		(in thousands)
	Payroll, bonus and vacation expense	$ 2,940	$ 2,876
	Non income taxes	3,571	4,323
	Royalty expenses	2,195	1,772
	Accrued interest	418	385
	Health claims	1,141	1,270
	Workers’ compensation & pneumoconiosis	1,500	1,500
	Deferred revenues	4,155	4,050
	Accrued insured litigation claims	1,013	489
	Other	2,595	669
	Total	$ 19,528	$ 17,334

Debt_Tables

Debt (Tables)	3 Months Ended
Debt (Tables)	Mar. 31, 2015
Debt [Abstract]
Schedule Of Debt
		March 31,	December 31,
		2015	2014
		(in thousands)
	Senior secured credit facility with PNC Bank, N.A.	$ 55,130	$ 54,450
	Other notes payable	3,033	2,982
	Total	58,163	57,432
	Less current portion	-214	-210
	Long-term debt	$ 57,949	$ 57,222

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	3 Months Ended
Asset Retirement Obligations (Tables)	Mar. 31, 2015
Asset Retirement Obligations [Abstract]
Schedule Of Asset Retirement Obligations
		31-Mar-15	31-Dec-14
		(in thousands)
	Balance at beginning of period (including current portion)	$ 29,883	$ 34,451
	Accretion expense	534	2,281
	Adjustment resulting from addition of property	1,235	-
	Adjustment resulting from disposal of property (1)	-	-2,310
	Adjustments to the liability from annual recosting and other	-	-1,324
	Reclassification to held for sale	-	-2,250
	Liabilities settled	-116	-965
	Balance at end of period	31,536	29,883
	Less current portion of asset retirement obligation	-1,555	-1,431
	Long-term portion of asset retirement obligation	$ 29,981	$ 28,452


	(1) The ($2.3) million adjustment for the year ended December 31, 2014 primarily relates to the transfer of certain mining permits to a third party that relieved the Partnership of the asset retirement obligations related to these permits.

Employee_Benefits_Tables

Employee Benefits (Tables)	3 Months Ended
Employee Benefits (Tables)	Mar. 31, 2015
Employee Benefits [Abstract]
Components Of Net Periodic Benefit Cost
		Three months ended March 31,
		2015	2014
		(in thousands)
	Service costs	$ 67	$ 74
	Interest cost	51	59
	Amortization of (gain)	-44	-92
	Total	$ 74	$ 41


Schedule Of Expense Under Defined Contribution Savings Plans
		Three months ended March 31,
		2015	2014
		(in thousands)
	401(k) plan expense	$ 558	$ 568

Commitments_And_Contingencies_

Commitments And Contingencies (Tables)	3 Months Ended
Commitments And Contingencies (Tables)	Mar. 31, 2015
Commitments And Contingencies [Abstract]
Schedule Of Delivery Commitments
	Year	Tons (in thousands)	Number of customers
	2015 Q2-Q4	2,677	18
	2016	2,611	7
	2017	1,650	3


Schedule Of Purchased Coal Expenses
		Three months ended March 31,
		2015	2014
		(in thousands)
	Purchased coal expense	$ (26)	$ 1,850
	OTC expense	$ -	$ -


Schedule Of Lease And Royalty Expense
		Three months ended March 31,
		2015	2014
		(in thousands)
	Lease expense	$ 1,121	$ 799
	Royalty expense	$ 2,834	$ 2,760

Earnings_Per_Unit_EPU_Tables

Earnings Per Unit ("EPU") (Tables)	3 Months Ended
Earnings Per Unit ("EPU") (Tables)	Mar. 31, 2015
Earnings Per Unit ("EPU") [Abstract]
Schedule Of Calculation Of Numerator And Denominator In Earnings Per Share

	Three months ended March 31, 2015	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net (loss)/income:
	Net (loss) from continuing operations	$ (91)	$ (2,569)	$ (1,902)
	Net income from discontinued operations	14	402	305
	Total interest in net (loss)	$ (77)	$ (2,167)	$ (1,597)
	Denominator:
	Weighted average units used to compute basic EPU	n/a	16,692	12,397
	Effect of dilutive securities — LTIP awards:
	Dilutive securities for net (loss) from continuing operations	n/a	-	-
	Dilutive securities for net income from discontinued operations	n/a	-	-
	Total dilutive securities	n/a	-	-
	Weighted average units used to compute diluted EPU	n/a	16,692	12,397

	Net (loss)/income per limited partner unit, basic
	Net (loss) per unit from continuing operations	n/a	$ (0.15)	$ (0.15)
	Net income per unit from discontinued operations	n/a	0.02	0.02
	Net (loss) per common unit, basic	n/a	$ (0.13)	$ (0.13)
	Net (loss)/income per limited partner unit, diluted
	Net (loss) per unit from continuing operations	n/a	$ (0.15)	$ (0.15)
	Net income per unit from discontinued operations	n/a	0.02	0.02
	Net (loss) per common unit, diluted	n/a	$ (0.13)	$ (0.13)









	Three months ended March 31, 2014	General Partner	Common Unitholders	Subordinated Unitholders
	Numerator:	(in thousands, except per unit data)
	Interest in net (loss)/income:
	Net (loss) from continuing operations	$ (99)	$ (2,795)	$ (2,072)
	Net income from discontinued operations	2,610	73,343	54,558
	Total interest in net income	$ 2,511	$ 70,548	$ 52,486
	Denominator:
	Weighted average units used to compute basic EPU	n/a	16,667	12,397
	Effect of dilutive securities — LTIP awards:
	Dilutive securities for net (loss) from continuing operations	n/a	-	-
	Dilutive securities for net income from discontinued operations	n/a	6	-
	Total dilutive securities	n/a	6	-
	Weighted average units used to compute diluted EPU	n/a	16,673	12,397

	Net (loss)/income per limited partner unit, basic
	Net income per unit from continuing operations	n/a	$ (0.17)	$ (0.17)
	Net income per unit from discontinued operations	n/a	4.40	4.40
	Net income per common unit, basic	n/a	$ 4.23	$ 4.23
	Net (loss)/income per limited partner unit, diluted
	Net income per unit from continuing operations	n/a	$ (0.17)	$ (0.17)
	Net income per unit from discontinued operations	n/a	4.40	4.40
	Net income per common unit, diluted	n/a	$ 4.23	$ 4.23

Major_Customers_Tables

Major Customers (Tables)	3 Months Ended
Major Customers (Tables)	Mar. 31, 2015
Major Customers [Abstract]
Major Customers
		31-Mar	Three months	Three months
		2015	ended	ended
		Receivable	31-Mar	31-Mar
		Balance	2015 Sales	2014 Sales
		(in thousands)
	NRG Energy, Inc. (fka GenOn Energy, Inc.)	$ 2,569	$ 8,563	$ 6,820
	PPL Corporation	1,511	7,206	n/a

Supplemental_Disclosures_Of_Ca1

Supplemental Disclosures Of Cash Flow Information (Tables)	3 Months Ended
Supplemental Disclosures Of Cash Flow Information (Tables)	Mar. 31, 2015
Supplemental Cash Flow Elements [Abstract]
Schedule Of Cash Flow, Supplemental Disclosures
		(in thousands)
	Coal properties (incl asset retirement costs)	$ 12,104
	Advance royalties, net of current portion	4,706
	Other non-current assets - acquired	229
	Other non-current assets - written off	-642
	Accrued expenses and other	-2,012
	Asset retirement obligations	-1,235
	Net assets acquired	13,150
	Investment in unconsolidated affiliates-Rhino Eastern - written off	$ (13,150)

Segment_Information_Tables

Segment Information (Tables)	3 Months Ended
Segment Information (Tables)	Mar. 31, 2015
Segment Information [Abstract]
Reportable Segment Results Of Operations	Reportable segment results of operations for the three months ended March 31, 2015 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization):



		Central	Northern	Rhino	Illinois		Total
		Appalachia	Appalachia	Western	Basin	Other	Consolidated
		(in thousands)
	Total revenues	$ 22,250	$ 17,330	$ 8,460	$ 7,179	$ 965	$ 56,184
	DD&A	3,948	1,846	1,610	1,214	234	8,852
	Interest expense	392	114	63	118	270	957
	Net income (loss) from continuing operations	$ (231)	$ 1,180	$ (1,296)	$ (4,541)	$ 326	$ (4,562)

	Reportable segment results of operations for the three months ended March 31, 2014 are as follows:


						Eastern Met
							Equity	Equity
		Central	Northern	Rhino	Illinois	Complete	Method	Method		Total
		Appalachia	Appalachia	Western	Basin	Basis	Eliminations	Presentation	Other	Consolidated
		(in thousands)
	Total revenues	$ 30,561	$ 18,764	$ 9,586	$ -	$ 7,529	$ (7,529)	$ -	$ 1,031	$ 59,942
	DD&A	5,402	1,878	1,418	207	500	-500	-	327	9,232
	Interest expense	1,053	177	150	118	15	-15	-	1,686	3,184
	Net income (loss) from continuing operations	$ (3,818)	$ 1,104	$ (346)	$ (99)	$ (1,717)	$ 841	$ (876)	$ (931)	$ (4,966)

Summary_Of_Significant_Account2

Summary Of Significant Accounting Policies And General (Details) (USD $)	3 Months Ended		1 Months Ended		12 Months Ended	1 Months Ended	12 Months Ended	1 Months Ended	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Jan. 31, 2015	31-May-08	Dec. 31, 2014	Dec. 31, 2012	Dec. 31, 2013	Sep. 30, 2014	Sep. 30, 2014
	Mar. 31, 2015	Mar. 31, 2014	T	31-May-08	Dec. 31, 2014	Dec. 31, 2012	Dec. 31, 2013	Sep. 30, 2014	Sep. 30, 2014
Summary Of Significant Accounting Policies [Line Items]
Loss from operations	$3,748,000	$868,000
Equity in net income (loss) of unconsolidated affiliate	141,000	-917,000
Rhino Eastern LLC [Member]
Summary Of Significant Accounting Policies [Line Items]
Asset Impairment Charges, Total					5,900,000
Payments to acquire interest in joint venture				16,100,000
Ownership interest equity method investment				51.00%
Interest acquired			49.00%
Coal Reserves			34,000,000
Muskie Proppant [Member]
Summary Of Significant Accounting Policies [Line Items]
Payments to acquire interest in joint venture		200,000				2,000,000
Loss from operations		42,000
Loans to joint venture							200,000
Sturgeon Acquisitions [Member]
Summary Of Significant Accounting Policies [Line Items]
Payments to acquire interest in joint venture								5,000,000	5,000,000
Equity in net income (loss) of unconsolidated affiliate	100,000
Frac Sand And Natural Gas Drilling Limited Liability Companies [Member] \| Sturgeon Acquisitions [Member]
Summary Of Significant Accounting Policies [Line Items]
Ownership interest								100.00%	100.00%
Mammoth [Member]
Summary Of Significant Accounting Policies [Line Items]
Equity method investment	$1,900,000

Discontinued_Operations_Detail

Discontinued Operations (Details) (USD $)	3 Months Ended		1 Months Ended			12 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Feb. 28, 2015	Jan. 31, 2014	Mar. 31, 2014	Dec. 31, 2014	Dec. 31, 2013
	Mar. 31, 2015	Mar. 31, 2014	Feb. 28, 2015	item	Mar. 31, 2014	Dec. 31, 2014	acre
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	$56,184,000	$59,942,000
Income from discontinued operations	721,000	130,511,000
Blackhawk Midstream, LLC [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from the sale of interest			700,000	8,400,000
Number of equity interests sold				2
Percentage of payout interest				5.00%
Utica Shale Region Of Ohio [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage							5.00%
Gross acreage							152,300
Net acreage							7,615
Cumulative investment in pro rata interest in oil and gas leases							31,100,000
Drilling costs							23,300,000
Purchase price		184,000,000			184,000,000
Proceeds from the sale of property					179,000,000
Purchase price receivable		5,000,000			5,000,000
Gain on sale of acreage		121,700,000
Sale transaction costs						$46,000

Prepaid_Expenses_And_Other_Cur2

Prepaid Expenses And Other Current Assets (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Prepaid Expenses And Other Current Assets [Abstract]
Other prepaid expenses	$636	$827
Prepaid insurance	923	2,063
Prepaid leases	70	87
Supply inventory	794	827
Deposits	169	170
Total prepaid expenses and other	$2,592	$3,974

Property_Plant_And_Equipment_N

Property, Plant And Equipment (Narrative) (Details) (Bevins Branch, Eastern Kentucky [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014
Bevins Branch, Eastern Kentucky [Member]
Property, Plant and Equipment [Line Items]
Asset impairment loss	$8.30

Property_Plant_And_Equipment_P

Property, Plant And Equipment (Property, Plant And Equipment By Major Classification) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Total	670,977	$663,662
Less accumulated depreciation, depletion and amortization	-280,439	-280,225
Net property, plant and equipment	390,538	383,437
Land And Land Improvements [Member]
Property, Plant and Equipment [Line Items]
Total	18,800	18,845
Mining And Other Equipment And Related Facilities [Member]
Property, Plant and Equipment [Line Items]
Total	339,125	336,951
Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Total	76,571	79,536
Coal Properties [Member]
Property, Plant and Equipment [Line Items]
Total	222,265	215,325
Oil And Natural Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Total	8,093	8,093
Construction Work In Process [Member]
Property, Plant and Equipment [Line Items]
Total	6,123	$4,912
Minimum [Member] \| Mining And Other Equipment And Related Facilities [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	2 years
Minimum [Member] \| Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	1 year
Minimum [Member] \| Coal Properties [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	1 year
Maximum [Member] \| Mining And Other Equipment And Related Facilities [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	20 years
Maximum [Member] \| Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	15 years
Maximum [Member] \| Coal Properties [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	15 years

Property_Plant_And_Equipment_D

Property, Plant And Equipment (Depreciation, Depletion And Amortization) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	$8,852	$9,232
Mining And Other Equipment And Related Facilities [Member]
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	7,577	7,532
Coal Properties And Oil And Natural Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	808	1,194
Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	522	424
Intangible Assets [Member]
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	20	21
Asset Retirement Costs [Member]
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	($75)	$61

Goodwill_And_Intangible_Assets2

Goodwill And Intangible Assets (Narrative) (Details)	3 Months Ended
Goodwill And Intangible Assets (Narrative) (Details)	Mar. 31, 2015
Patent And Developed Technology [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible assets, useful life	17 years
Trade Name And Customer List [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible assets, useful life	20 years

Goodwill_And_Intangible_Assets3

Goodwill And Intangible Assets (Schedule Of Intangible Assets By Major Class) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$1,460	$1,460
Accumulated Amortization	413	393
Net Carrying Amount	1,047	1,067
Patent [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	728	728
Accumulated Amortization	261	250
Net Carrying Amount	467	478
Developed Technology [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	78	78
Accumulated Amortization	28	27
Net Carrying Amount	50	51
Trade Name [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	184	184
Accumulated Amortization	35	33
Net Carrying Amount	149	151
Customer List [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	470	470
Accumulated Amortization	89	83
Net Carrying Amount	$381	$387

Goodwill_And_Intangible_Assets4

Goodwill And Intangible Assets (Future Amortization Expense) (Details) (USD $)	Mar. 31, 2015
In Thousands, unless otherwise specified	Mar. 31, 2015
Acquired Finite-Lived Intangible Assets [Line Items]
2015 (from Apr 1 to Dec 31)	$60
2016	80
2017	80
2018	80
2019	80
Patent [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
2015 (from Apr 1 to Dec 31)	32
2016	43
2017	43
2018	43
2019	43
Developed Technology [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
2015 (from Apr 1 to Dec 31)	3
2016	5
2017	5
2018	5
2019	5
Trade Name [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
2015 (from Apr 1 to Dec 31)	7
2016	9
2017	9
2018	9
2019	9
Customer List [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
2015 (from Apr 1 to Dec 31)	18
2016	23
2017	23
2018	23
2019	$23

Other_NonCurrent_Assets_Narrat

Other Non-Current Assets (Narrative) (Details) (USD $)	1 Months Ended
Other Non-Current Assets (Narrative) (Details) (USD $)	Mar. 31, 2014	Mar. 31, 2015	Dec. 31, 2014
Other Non-Current Assets [Line Items]
Debt issuance costs, gross		$9,100,000	$9,100,000
Accumulated amortization of debt issuance costs		7,800,000	7,600,000
Workers' compensation insurance receivable		14,237,000	14,237,000
PNC Bank, N.A. [Member] \| Second Amendment [Member]
Other Non-Current Assets [Line Items]
Credit facility, maximum available	200,000,000
Amendment fee	100,000
Unamortized debt issuance costs written off	$1,100,000

Other_NonCurrent_Assets_Schedu

Other Non-Current Assets (Schedule Of Other Non-Current Assets) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Other Non-Current Assets [Abstract]
Deposits and other	$203	$347
Debt issuance costs-net	1,274	1,513
Non-current receivable	14,237	14,237
Deferred expenses	300	313
Total	$16,014	$16,410

Accrued_Expenses_And_Other_Cur2

Accrued Expenses And Other Current Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Accrued Expenses And Other Current Liabilities [Abstract]
Payroll, bonus and vacation expense	$2,940	$2,876
Non income taxes	3,571	4,323
Royalty expenses	2,195	1,772
Accrued interest	418	385
Health claims	1,141	1,270
Workers' compensation & pneumoconiosis	1,500	1,500
Deferred revenues	4,155	4,050
Accrued insured litigation claims	1,013	489
Other	2,595	669
Total	$19,528	$17,334

Debt_Senior_Secured_Credit_Fac

Debt (Senior Secured Credit Facility With PNC Bank, N.A.) (Narrative) (Details) (USD $)	3 Months Ended		1 Months Ended		3 Months Ended	12 Months Ended	21 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Mar. 31, 2014	Jul. 31, 2011	Dec. 31, 2015	Dec. 31, 2016	Sep. 30, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Line of credit facility, amount outstanding	$55,130,000							$54,450,000
Borrowings on line of credit	33,050,000	50,900,000
PNC Bank, N.A. 2014 Amendment [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available		200,000,000	200,000,000
Amendment fee		100,000	100,000
Line of credit facility, maximum investment in hydrocarbons	50,000,000
Unamortized debt issuance costs written off			1,100,000
PNC Bank, N.A. [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity measured as a multiple of EBITDA	350.00%
EBITDA measurement period for determining maximum borrowing capacity	12 months
Line of credit facility, remaining borrowing capacity	4,400,000
Credit Facility LIBOR Plus Applicable Spread [Member] \| PNC Bank, N.A. [Member]
Line of Credit Facility [Line Items]
Incremental interest rate above variable rate	2.50%
Effective interest rate	2.68%
Borrowings on line of credit	54,400,000
Credit Facility PRIME Plus Applicable Spread [Member] \| PNC Bank, N.A. [Member]
Line of Credit Facility [Line Items]
Incremental interest rate above variable rate	1.50%
Effective interest rate	4.75%
Borrowings on line of credit	700,000
Amended And Restated [Member] \| PNC Bank, N.A. [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available				300,000,000
Line of credit facility option to increase maximum borrowing capacity				50,000,000
Line of credit facility, expiration date	1-Jul-16
Line of credit facility, extended date	1-Jul-17
Second Amendment [Member] \| PNC Bank, N.A. [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available		200,000,000	200,000,000
Amendment fee		100,000	100,000
Unamortized debt issuance costs written off			1,100,000
Letters of Credit [Member] \| PNC Bank, N.A. [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available				75,000,000
Outstanding letters of credit	$16,000,000
Fixed interest rate	2.50%
Scenario, Forecast [Member] \| PNC Bank, N.A. 2014 Amendment [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio					325.00%	300.00%	350.00%

Debt_Schedule_Of_Debt_Details

Debt (Schedule Of Debt) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Debt [Abstract]
Senior secured credit facility with PNC Bank, N.A.	$55,130	$54,450
Other notes payable	3,033	2,982
Total	58,163	57,432
Less current portion	-214	-210
Long-term debt	$57,949	$57,222

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	3 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Asset Retirement Obligations [Abstract]
Balance at beginning of period (including current portion)	$29,883	$34,451	$34,451
Accretion expense	534	589	2,281
Adjustment resulting from addition of property	1,235
Adjustment resulting from disposal of property			-2,310	[1]
Adjustments to liability from annual recosting and other			-1,324
Reclassification To Held For Sale			-2,250
Liabilities settled	-116		-965
Balance at end of period	31,536		29,883
Less current portion of asset retirement obligation	-1,555		-1,431
Long-term portion of asset retirement obligation	$29,981		$28,452

[1]	The ($2.3) million adjustment for the year ended December 31, 2014 primarily relates to the transfer of certain mining permits to a third party that relieved the Partnership of the asset retirement obligations related to these permits.

Employee_Benefits_Components_O

Employee Benefits (Components Of Net Periodic Benefit Cost) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Employee Benefits [Abstract]
Service costs	$67	$74
Interest cost	51	59
Amortization of (gain)	-44	-92
Total	$74	$41

Employee_Benefits_Schedule_Of_

Employee Benefits (Schedule Of Expense Under Defined Contribution Savings Plans) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Employee Benefits [Abstract]
401(k) plan expense	$558	$568

EquityBased_Compensation_Detai

Equity-Based Compensation (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015
Equity-Based Compensation [Abstract]
Phantom units granted	33,948
Vesting period	3 years
Total fair value of awards granted	$0.10

Commitments_And_Contingencies_1

Commitments And Contingencies (Narrative) (Details) (USD $)	3 Months Ended	12 Months Ended	1 Months Ended	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2012	Sep. 30, 2014	Sep. 30, 2014
	gal	Dec. 31, 2012	Sep. 30, 2014	Sep. 30, 2014
Diesel Fuel [Member]
Commitments And Contingencies [Line Items]
Fuel purchase commitments, gallons	800,000
Purchase commitments	$1.80
Timber Wolf [Member]
Commitments And Contingencies [Line Items]
Payments to acquire interest in joint venture		0.1
Sturgeon Acquisitions [Member]
Commitments And Contingencies [Line Items]
Payments to acquire interest in joint venture			$5	$5

Commitments_And_Contingencies_2

Commitments And Contingencies (Schedule Of Delivery Commitments) (Details)	3 Months Ended
	Mar. 31, 2015
	customer
	T
Commitments And Contingencies [Abstract]
Tons, 2015 Q2-Q4	2,677,000
Tons, 2016	2,611,000
Tons, 2017	1,650,000
Number of customers, 2015 Q2-Q4	18
Number of customers, 2016	7
Number of customers, 2017	3

Commitments_And_Contingencies_3

Commitments And Contingencies (Schedule Of Purchased Coal Expenses) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Commitments And Contingencies [Abstract]
Purchased coal expense	($26)	$1,850

Commitments_And_Contingencies_4

Commitments And Contingencies (Schedule Of Lease And Royalty Expense) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Commitments And Contingencies [Abstract]
Lease expense	$1,121	$799
Royalty expense	$2,834	$2,760

Earnings_Per_Unit_EPU_Narrativ

Earnings Per Unit ("EPU") (Narrative) (Details)	3 Months Ended
Earnings Per Unit ("EPU") (Narrative) (Details)	Mar. 31, 2014
Earnings Per Unit ("EPU") [Abstract]
Anti-dilutive LTIP phantom units	6,000

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
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings Per Unit [Line Items]
Net (loss) from continuing operations	($4,562)	($4,966)
Net income from discontinued operations	721	130,511
Total interest in net income (loss)	-3,841	125,545
General Partner [Member]
Earnings Per Unit [Line Items]
Net (loss) from continuing operations	-91	-99
Net income from discontinued operations	14	2,610
Total interest in net income (loss)	-77	2,511
Common Unitholders [Member]
Earnings Per Unit [Line Items]
Net (loss) from continuing operations	-2,569	-2,795
Net income from discontinued operations	402	73,343
Total interest in net income (loss)	-2,167	70,548
Weighted average units used to compute basic EPU	16,692	16,667
Dilutive securities for net income from discontinued operations		6
Total dilutive securities		6
Weighted average units used to compute diluted EPU	16,692	16,673
Net (loss) per unit from continuing operations	($0.15)	($0.17)
Net income per unit from discontinued operations	$0.02	$4.40
Net (loss)/income per common unit, basic	($0.13)	$4.23
Net (loss)/income per unit from continuing operations	($0.15)	($0.17)
Net income per unit from discontinued operations	$0.02	$4.40
Net income per common unit, diluted	($0.13)	$4.23
Subordinated Unitholders[Member]
Earnings Per Unit [Line Items]
Net (loss) from continuing operations	-1,902	-2,072
Net income from discontinued operations	305	54,558
Total interest in net income (loss)	($1,597)	$52,486
Weighted average units used to compute basic EPU	12,397	12,397
Weighted average units used to compute diluted EPU	12,397	12,397
Net (loss) per unit from continuing operations	($0.15)	($0.17)
Net income per unit from discontinued operations	$0.02	$4.40
Net (loss)/income per common unit, basic	($0.13)	$4.23
Net (loss)/income per unit from continuing operations	($0.15)	($0.17)
Net income per unit from discontinued operations	$0.02	$4.40
Net income per common unit, diluted	($0.13)	$4.23

Major_Customers_Details

Major Customers (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Revenue, Major Customer [Line Items]
Receivable balance	$23,867		$22,467
Revenue	56,184	59,942
NRG Energy, Inc. (fka GenOn Energy, Inc.) [Member]
Revenue, Major Customer [Line Items]
Receivable balance	2,569
Revenue	8,563	6,820
PPL Corporation [Member]
Revenue, Major Customer [Line Items]
Receivable balance	1,511
Revenue	$7,206

Fair_Value_Of_Financial_Instru1

Fair Value Of Financial Instruments (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of property	$670,977,000	$663,662,000
Red Cliff Project [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Carrying amount of property		6,900,000
Bevins Branch, Eastern Kentucky [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Assets held for sale		2,400,000
Liabilities held for sale		$2,200,000

Supplemental_Disclosures_Of_Ca2

Supplemental Disclosures Of Cash Flow Information (Narrative) (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Units Issued [Member]
Other Significant Noncash Transactions [Line Items]
Value of units issued		$0.20
Recorded In Accounts Payable [Member]
Other Significant Noncash Transactions [Line Items]
Property additions	$0.80	$3

Supplemental_Disclosures_Of_Ca3

Supplemental Disclosures Of Cash Flow Information (Schedule Of Cash Flow, Supplemental Disclosures) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Other Significant Noncash Transactions [Line Items]
Coal properties (incl asset retirement costs)	$670,977	$663,662
Advance royalties, net of current portion	912	1,032
Other non-current assets - acquired	16,014	16,410
Accrued expenses and other	-19,528	-17,334
Asset retirement obligations	-29,981	-28,452
Investment in unconsolidated affiliates-Rhino Eastern - written off	7,412	20,653
Rhino Eastern [Member]
Other Significant Noncash Transactions [Line Items]
Coal properties (incl asset retirement costs)	12,104
Advance royalties, net of current portion	4,706
Other non-current assets - acquired	229
Other non-current assets - written off	-642
Accrued expenses and other	-2,012
Asset retirement obligations	-1,235
Net assets acquired	13,150
Investment in unconsolidated affiliates-Rhino Eastern - written off	($13,150)

Segment_Information_Narrative_

Segment Information (Narrative) (Details)	3 Months Ended
	Mar. 31, 2015
	segment
Segment Information [Abstract]
Number of reportable business segments	4

Segment_Information_Reportable

Segment Information (Reportable Segment Results Of Operations) (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Segment Reporting Information [Line Items]
Total revenues	$56,184	$59,942
DD&A	8,852	9,232
Interest expense	957	3,184
Net Income (loss) from continuing operations	-4,562	-4,966
Central Appalachia [Member]
Segment Reporting Information [Line Items]
Total revenues	22,250	30,561
DD&A	3,948	5,402
Interest expense	392	1,053
Net Income (loss) from continuing operations	-231	-3,818
Northern Appalachia [Member]
Segment Reporting Information [Line Items]
Total revenues	17,330	18,764
DD&A	1,846	1,878
Interest expense	114	177
Net Income (loss) from continuing operations	1,180	1,104
Rhino Western [Member]
Segment Reporting Information [Line Items]
Total revenues	8,460	9,586
DD&A	1,610	1,418
Interest expense	63	150
Net Income (loss) from continuing operations	-1,296	-346
Eastern Met [Member] \| Complete Basis [Member]
Segment Reporting Information [Line Items]
Total revenues		7,529
DD&A		500
Interest expense		15
Net Income (loss) from continuing operations		-1,717
Eastern Met [Member] \| Equity Method Eliminations [Member]
Segment Reporting Information [Line Items]
Total revenues		-7,529
DD&A		-500
Interest expense		-15
Net Income (loss) from continuing operations		841
Eastern Met [Member] \| Equity Method Presentation [Member]
Segment Reporting Information [Line Items]
Net Income (loss) from continuing operations		-876
Other [Member]
Segment Reporting Information [Line Items]
Total revenues	965	1,031
DD&A	234	327
Interest expense	270	1,686
Net Income (loss) from continuing operations	326	-931
Illinois Basin [Member]
Segment Reporting Information [Line Items]
Total revenues	7,179
DD&A	1,214	207
Interest expense	118	118
Net Income (loss) from continuing operations	($4,541)	($99)

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	3 Months Ended				0 Months Ended	3 Months Ended			9 Months Ended		1 Months Ended
Subsequent Events (Details) (USD $)	Mar. 31, 2015		Mar. 31, 2014		Apr. 20, 2015	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Dec. 31, 2016	Sep. 30, 2015	Apr. 30, 2015
Subsequent Event [Line Items]
Cash distribution	$0.05	[1]	$0.45	[1]
Distribution arrearages outstanding	$21,000,000
Common Units [Member]
Subsequent Event [Line Items]
Cash distribution, date declared	20-Apr-15
Cash distribution, date of distribution	15-May-15
Cash distribution, date of record	30-Apr-15
Minimum required distributions per unit	$0.45
Subordinated Units [Member]
Subsequent Event [Line Items]
Cash distribution	$0		$0
Subsequent Event [Member] \| Common Units [Member]
Subsequent Event [Line Items]
Cash distribution					$0.02
Cash distribution, annualized					0.08
Subsequent Event [Member] \| Subordinated Units [Member]
Subsequent Event [Line Items]
Cash distribution					$0
PNC Bank N.A. 2015 Amendment [Member] \| Scenario, Forecast [Member]
Subsequent Event [Line Items]
Line of credit facility, maximum leverage ratio						325.00%	350.00%		300.00%	375.00%
Line of credit facility, minimum fixed charge coverage ratio								110.00%
PNC Bank N.A. 2015 Amendment [Member] \| Subsequent Event [Member]
Subsequent Event [Line Items]
Line Of Credit Facility Extended Date											1-Jul-17
Line of credit facility, maximum leverage ratio required for extension											275.00%
Line of credit facility, miniumum liquidity											15,000,000
Line of credit facility, expiration date if requirements not met											1-Jul-16
Credit facility, maximum available											100,000,000
Line of credit facility, threshold for proceeds from disposition of assets that determines amount used to reduce commitments											35,000,000
Line of credit facility, amount by which commitments must be reduced if proceeds from sale of assets are below threshold											10,000,000
Line of credit facility, leverage ratio reduction related to sale of assets											25.00%
Line of credit facility, amount of sales proceeds that cause a decrease in leverage ratio											10,000,000
Line of credit facility, maximum quarterly distributions per unit											$0.04
Line of credit facility, maximum leverage ratio required for distributions in excess of maximum stated amount											300.00%
Line of credit facility, minimum borrowing availability required for distributions in excess of maximum stated amount											20,000,000
Line of credit facility, maximum investments											10,000,000
Line of credit facility, maximum leverage ratio related to limited investments											300.00%
Line of credit facility, minimum available liquidity for limited investments											20,000,000
Line of credit facility, maximum capital expenditures for remainder of fiscal year											20,000,000
Line of credit facility maximum capital expenditures after current fiscal year											27,500,000
Line of credit facility, maximum carryover of unused capital expenditures											5,000,000
PNC Bank N.A. 2015 Amendment [Member] \| Subsequent Event [Member] \| Letters of Credit [Member]
Subsequent Event [Line Items]
Credit facility, maximum available											$50,000,000
PNC Bank N.A. 2015 Amendment [Member] \| Subsequent Event [Member] \| Minimum [Member]
Subsequent Event [Line Items]
Line of credit facility, maximum leverage ratio											300.00%

[1]	No distributions were paid on the subordinated units for the three months ended March 31, 2015 and 2014