Rhino Resource Partners 10-K 25 Mar 16 2015 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Mar. 21, 2016	Jun. 30, 2015
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Entity Registrant Name	Rhino Resource Partners LP
Entity Central Index Key	1,490,630
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Entity Well-known Seasoned Issuer	No
Entity Public Float			$ 12.8
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Common [Member]
Entity Common Stock Shares Outstanding		76,919,137
Subordinated Units [Member]
Entity Common Stock Shares Outstanding		12,355,299

Consolidated Statements Of Fina

Consolidated Statements Of Financial Position - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
CURRENT ASSETS:
Cash and cash equivalents	$ 78	$ 626
Accounts receivable, net of allowance for doubtful accounts ($166 as of December 31, 2015 and $724 as of December 31, 2014)	14,569	22,467
Inventories	8,570	13,030
Advance royalties, current portion	753	1,032
Prepaid expenses and other	5,474	3,974
Total current assets	29,444	41,129
PROPERTY, PLANT AND EQUIPMENT:
At cost, including coal properties, mine development and construction costs	604,514	663,662
Less accumulated depreciation, depletion and amortization	(271,007)	(280,225)
Net property, plant and equipment	333,507	383,437
Advance royalties, net of current portion	7,326	1,363
Investment in unconsolidated affiliates	7,578	20,653
Intangible assets, net	505	1,067
Other non-current assets	26,307	16,410
Non-current assets held for sale		9,279
TOTAL	404,667	473,338
CURRENT LIABILITIES:
Accounts payable	9,336	10,924
Accrued expenses and other	14,102	17,334
Current portion of long-term debt	41,479	210
Current portion of asset retirement obligations	767	1,431
Current portion of postretirement benefits	45	425
Total current liabilities	65,729	30,324
NON-CURRENT LIABILITIES:
Long-term debt, net of current portion	2,595	57,222
Asset retirement obligations, net of current portion	22,980	28,452
Other non-current liabilities	45,435	27,942
Postretirement benefits, net of current portion		6,223
Non-current liabilities held for sale		2,250
Total non-current liabilities	71,010	122,089
Total liabilities	$ 136,739	$ 152,413
COMMITMENTS AND CONTINGENCIES (NOTE 15)
PARTNERS' CAPITAL:
Limited partners	$ 253,312	$ 308,586
General partner	9,821	10,966
Accumulated other comprehensive income	4,795	1,373
Total partners' capital	267,928	320,925
TOTAL	$ 404,667	$ 473,338

Consolidated Statements Of Fin3

Consolidated Statements Of Financial Position (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Consolidated Statements Of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 166	$ 724

Consolidated Statements Of Oper

Consolidated Statements Of Operations And Comprehensive Income - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
REVENUES:
Coal sales		$ 171,074	$ 202,881
Freight and handling revenues		2,790	2,020
Other revenues		32,882	34,156
Total revenues		206,746	239,057
COSTS AND EXPENSES:
Cost of operations (exclusive of depreciation, depletion and amortization shown separately below)		175,499	200,141
Freight and handling costs		2,693	1,877
Depreciation, depletion and amortization		33,181	37,233
Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above)		15,446	19,226
Asset impairment and related charges		31,564	45,296
(Gain) on sale/disposal of assets, net		(292)	(569)
Total costs and expenses		258,091	303,204
(LOSS) FROM OPERATIONS		(51,345)	(64,147)
INTEREST AND OTHER (EXPENSE)/INCOME:
Interest expense and other		(5,001)	(5,708)
Interest income and other		38	274
Equity in net income/(loss) of unconsolidated affiliates		342	(11,712)
Total interest and other (expense)		(4,621)	(17,146)
(LOSS) BEFORE INCOME TAXES FROM CONTINUING OPERATIONS		$ (55,966)	$ (81,293)
INCOME TAXES
NET (LOSS)/INCOME FROM CONTINUING OPERATIONS		$ (55,966)	$ (81,293)
DISCONTINUED OPERATIONS
Income from discontinued operations		722	130,342
NET (LOSS)/INCOME		(55,244)	49,049
Other comprehensive income:
Amortization of net actuarial gain		(782)	(368)
Change in actuarial gain under ASC Topic 815		(3,422)	858
COMPREHENSIVE (LOSS)/INCOME		$ (51,822)	$ 48,191
Net (loss)/income per limited partner unit, diluted:
Distributions paid per limited partner unit	[1]	$ 0.070	$ 1.385
Common Units [Member]
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations		(1.87)	(2.32)
Net income per unit from discontinued operations		0.02	4.39
Net (loss)/income per common unit, basic		(1.85)	2.07
Net (loss)/income per limited partner unit, diluted:
Net (loss)/income per unit from continuing operations		(1.87)	(2.32)
Net income per unit from discontinued operations		0.02	4.39
Net (loss)/income per common unit, diluted		$ (1.85)	$ 2.07
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic		16,714,000	16,678,000
Weighted average number of limited partner units outstanding, diluted:
Weighted average number of limited partner units outstanding, diluted		16,714,000	16,685,000
Subordinated Units [Member]
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations		$ (1.89)	$ (3.31)
Net income per unit from discontinued operations		0.02	4.39
Net (loss)/income per common unit, basic		(1.87)	1.08
Net (loss)/income per limited partner unit, diluted:
Net (loss)/income per unit from continuing operations		(1.89)	(3.31)
Net income per unit from discontinued operations		0.02	4.39
Net (loss)/income per common unit, diluted		(1.87)	1.08
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		12,396,000	12,397,000
Weighted average number of limited partner units outstanding, diluted:
Weighted average number of limited partner units outstanding, diluted		12,396,000	12,397,000
General Partner [Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS)/INCOME FROM CONTINUING OPERATIONS		$ (1,119)	$ (1,626)
DISCONTINUED OPERATIONS
Income from discontinued operations		14	2,607
NET (LOSS)/INCOME		(1,105)	981
Common Unitholders [Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS)/INCOME FROM CONTINUING OPERATIONS		(31,491)	(45,705)
DISCONTINUED OPERATIONS
Income from discontinued operations		406	73,271
NET (LOSS)/INCOME		$ (31,085)	$ 27,566
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations		$ (1.87)	$ (2.32)
Net income per unit from discontinued operations		0.02	4.39
Net (loss)/income per limited partner unit, diluted:
Net (loss)/income per unit from continuing operations		(1.87)	(2.32)
Net income per unit from discontinued operations		$ 0.02	$ 4.39
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic		16,714	16,678,000
Weighted average number of limited partner units outstanding, diluted:
Weighted average number of limited partner units outstanding, diluted		16,714	16,685,000
Subordinated Unitholders[Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS)/INCOME FROM CONTINUING OPERATIONS		$ (23,356)	$ (33,962)
DISCONTINUED OPERATIONS
Income from discontinued operations		302	54,464
NET (LOSS)/INCOME		$ (23,054)	$ 20,502
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations		$ (1.89)	$ (3.31)
Net income per unit from discontinued operations		0.02	4.39
Net (loss)/income per limited partner unit, diluted:
Net (loss)/income per unit from continuing operations		(1.89)	(3.31)
Net income per unit from discontinued operations		$ 0.02	$ 4.39
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic		12,396	12,397,000
Weighted average number of limited partner units outstanding, diluted:
Weighted average number of limited partner units outstanding, diluted		12,396	12,397,000
[1]	No distributions were paid on the subordinated units during 2015 and 2014.

Consolidated Statements Of Ope5

Consolidated Statements Of Operations And Comprehensive Income (Parenthetical) - $ / shares		3 Months Ended	12 Months Ended
		Dec. 31, 2015	Dec. 31, 2015	Dec. 31, 2014
Distributions paid per limited partner unit	[1]		$ 0.070	$ 1.385
Subordinated Units [Member]
Distributions paid per limited partner unit		$ 0	$ 0	$ 0
[1]	No distributions were paid on the subordinated units during 2015 and 2014.

Consolidated Statements Of Part

Consolidated Statements Of Partners' Capital - USD ($) shares in Thousands, $ in Thousands	Limited Partner [Member]Common [Member]	Limited Partner [Member]Subordinated [Member]	General Partner [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Total
Balance at Dec. 31, 2013	$ 180,702	$ 102,637	$ 10,801	$ 2,231	$ 296,371
Balance, shares at Dec. 31, 2013	16,660	12,397
Net income	$ 27,566	$ 20,502	981		49,049
Distributions to unitholders and general partner	(23,140)		(822)		(23,962)
General partners' contributions			6		6
Issuance of units under LTIP	$ 321				321
Issuance of units under LTIP, shares	25
Amortization of net actuarial gain					(368)
Change in actuarial gain under ASC Topic 815				858	858
Balance at Dec. 31, 2014	$ 185,447	$ 123,139	10,966	1,373	320,925
Balance, shares at Dec. 31, 2014	16,685	12,397
Offering costs	$ (2)				(2)
Net income	(31,085)	$ (23,054)	(1,105)		(55,244)
Distributions to unitholders and general partner	(1,225)		(42)		(1,267)
General partners' contributions			2		2
Issuance of units under LTIP	$ 90				90
Issuance of units under LTIP, shares	74
Amortization of net actuarial gain					(782)
Change in actuarial gain under ASC Topic 815				(3,422)	(3,422)
Balance at Dec. 31, 2015	$ 153,227	$ 100,085	$ 9,821	$ 4,795	$ 267,928
Balance, shares at Dec. 31, 2015	16,759	12,355
Offering costs		$ (42)

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Net (loss)/income	$ (55,244)	$ 49,049
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	33,181	37,233
Accretion on asset retirement obligations	2,082	2,281
Accretion on interest-free debt	48
Amortization of deferred revenue	(3,766)	(1,731)
Amortization of advance royalties	764	440
Amortization of debt issuance costs	1,419	2,127
Amortization of actuarial gain	(782)	(368)
Provision for doubtful accounts	528	724
Equity in net (income)/loss of unconsolidated affiliates	(342)	11,712
Distributions from unconsolidated affiliate	232
Loss on retirement of advance royalties	151	244
(Gain) on sale/disposal of assets-net	(1,014)	(130,621)
Loss on impairment of assets	31,564	45,296
Equity-based compensation	15	255
Changes in assets and liabilities:
Accounts receivable	7,148	634
Inventories	4,460	5,550
Advance royalties	(1,518)	(1,453)
Prepaid expenses and other assets	656	485
Accounts payable	(2,274)	(1,731)
Accrued expenses and other liabilities	(1,026)	2,841
Asset retirement obligations	321	(1,824)
Postretirement benefits	(2,398)	38
Net cash provided by operating activities	14,205	21,181
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant, and equipment	(13,168)	(62,986)
Proceeds from sales of property, plant, and equipment	15,114	189,618
Return of capital from unconsolidated affiliates	35
Principal payments received on notes receivable		205
Investment in unconsolidated affiliates		(10,096)
Net cash provided by investing activities	1,981	116,741
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on line of credit	94,400	170,040
Repayments on line of credit	(107,650)	(282,630)
Repayments on long-term debt	(157)	(1,024)
Payments on debt issuance costs	(2,062)	(103)
Payment of offering costs		(2)
Net settlement of employee withholding taxes on unit awards vested		(44)
General partner's contributions	2	6
Distributions to unitholders	(1,267)	(23,962)
Net cash (used) in financing activities	(16,734)	(137,719)
NET (DECREASE) INCREASE IN CASH AND CASH EQUIVALENTS	(548)	203
CASH AND CASH EQUIVALENTS-Beginning of period	626	423
CASH AND CASH EQUIVALENTS-End of period	$ 78	$ 626

Organization And Basis Of Prese

Organization And Basis Of Presentation	12 Months Ended
	Dec. 31, 2015
Organization And Basis Of Presentation [Abstract]
Organization And Basis Of Presentation	1. ORGANIZATION AND BASIS OF PRESENTATION Organization —Rhino Resource Partners LP and subsidiaries (the “Partnership”) is a Delaware limited partnership formed on April 19, 2010 to acquire Rhino Energy LLC (the “Predecessor” or the “Operating Company”). The Partnership had no operations during the period from April 19, 2010 (date of inception) to October 5, 2010 (the consummation of the initial public offering (“IPO”) date of the Partnership). The Operating Company and its wholly owned subsidiaries produce and market coal from surface and underground mines in Kentucky, Ohio, West Virginia and Utah. The majority of the Partnership’s sales are made to electric utilities and other coal-related organizations in the United States. In addition to operating coal properties, the Partnership manages and leases coal properties and collects royalties from such management and leasing activities. In addition to the Partnership’s coal operations, the Partnership has invested in oil and natural gas mineral rights and operations that have provided revenues to the Partnership . Initial Public Offering On October 5, 2010, Rhino Resource Partners LP completed its IPO of 3,244,000 common units, representing limited partner interests in the Partnership, at a price of $ 20.50 per common unit. Net proceeds from the offering were approximately $ 58.3 million, after deducting underwriting discounts and offering expenses of $ 8.2 million. The Partnership used the net proceeds from this offering, and a related capital contribution by Rhino GP LLC, the Partnership’s general partner (the “General Partner”) of approximately $ 10.4 million, to repay approximately $ 69.4 million of outstanding indebtedness under the Operating Company’s credit facility. These net proceeds do not include $ 9.3 million that was used to reimburse affiliates of the Partnership’s sponsor, Wexford Capital LP (“Wexford Capital”), for capital expenditures incurred with respect to the assets contributed to the Partnership in connection with the offering. In connection with the closing of the IPO, the owners of the Operating Company contributed their membership interests in the Operating Company to the Partnership, and the Partnership issued 12,397,000 subordinated units representing limited partner interests in the Partnership and 9,153,000 common units to Rhino Energy Holdings LLC, an affiliate of Wexford Capital, and issued incentive distribution rights to the General Partner. Upon the closing of the IPO, and as required by the Operating Company’s credit agreement by and among the Operating Company, as borrower, and its subsidiaries as guarantors, and PNC Bank, National Association, as agent, and the other lenders thereto (as amended from time to time, the “Credit Agreement”), the Partnership pledged 100 % of the membership interests in the Operating Company to the agent on behalf of itself and the other lenders to secure the Operating Company’s obligations under the Credit Agreement. Follow-on Offering s On July 18, 2011, the Partnership completed a public offering of 2,875,000 common units, representing limited partner interests in the Partnership, at a price of $ 24.50 per common unit. Of the common units issued, 375,000 units were issued in connection with the exercise of the underwriters’ option to purchase additional units. Net proceeds from the offering were approximately $ 66.4 million, after deducting underwriting discounts and offering expenses of approximately $ 4.1 million. The Partnership used the net proceeds from this offering, and a related capital contribution by the General Partner of approximately $ 1.4 million, to repay approximately $ 67.8 million of outstanding indebtedness under the Partnership’s credit facility. On September 13, 2013, the Partnership completed a public offering of 1,265,000 common units, representing limited partner interests in the Partnership, at a price of $12.30 per common unit. Of the common units issued, 165,000 units were issued in connection with the exercise of the underwriter’s option to purchase additional units. Net proceeds from the offering were approximately $14.6 million, after deducting underwriting discounts and offering expenses of approximately $1.0 million. The Partnership used the net proceeds from this offering, and a related capital contribution by the General Partner of approximately $0.3 million, to repay approximately $14.9 million of outstanding indebtedness under the Partnership’s credit facility. Basis of Presentation and Principles of Consolidation —The accompanying consolidated financial statements include the accounts of Rhino Resource Partners LP and its subsidiaries. Intercompany transactions and balances have been eliminated in consolidation. Debt Classification —The Partnership evaluated its amended and restated senior secured credit facility at December 31, 2015 to determine whether this debt liability should be classified as a long-term or current liability on the Partnership’s consolidated statements of financial position. In April 2015, the Partnership entered into a third amendment to its amended and restated senior secured credit facility (see Note 10 for further details of the third amendment). The third amendment extended the expiration date of the amended and restated credit agreement to July 2017. The extension was contingent upon (i) the Partnership’s leverage ratio being less than or equal to 2.75 to 1.0 and (ii) the Partnership having liquidity greater than or equal to $15 million, in each case for either the quarter ending December 31, 2015 or March 31, 2016. If both of these conditions were not satisfied for one of such quarters, the expiration date of the amended and restated credit agreement w ould revert to July 2016. As of December 31, 2015, the conditions for the extension of the credit facility were not met as the Partnership’s leverage ratio was 3.2 to 1.0 and liquidity was approximately $1.1 million . In March 2016, the Partnership amended its amended and restated senior secured credit facility where the expiration date was set to July 2016. The Partnership is working with its lenders to extend the amended and restated credit agreement to December 2017. Since the credit facility has an expiration date of July 2016, the Partnership determined that its credit facility debt liability of $41.2 million at December 31, 2015 should be classifi ed as a current liability on its consolidated s tatements of financial position, which results in a working capital deficiency of $36.3 million. The classification of the Partnership’s credit facility balance as a current liability raises substantial doubt of the Partnership’s ability to continue as a going concern for the next twelve months. The Partnership is also considering alternative financing options that could result in a new long-term credit facility. Since the credit facility has an expiration date of July 2016, the Partnership will have to secure alternative financing to replace its credit facility by the expiration date of July 2016 in order to continue its normal business operations and meet its obligations as they come due. The financial statements do not include any adjustments relating to the recoverability and classification of assets carrying amounts or the amount of and classification of liabilities that may result should the Partnership be unable to continue as a going concern.

Summary Of Significant Accounti

Summary Of Significant Accounting Policies And General	12 Months Ended
	Dec. 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 Company Environment and Risk Factors. The Partnership, in the course of its business activities, is exposed to a number of risks including: fluctuating market conditions of coal, truck and rail transportation, fuel costs, changing government regulations, unexpected maintenance and equipment failure, employee benefits cost control, changes in estimates of proven and probable coal reserves, as well as the ability of the Partnership to maintain adequate financing, necessary mining permits and control of sufficient recoverable coal properties. In addition, adverse weather and geological conditions may increase mining costs, sometimes substantially. Trade Receivables and Concentrations of Credit Risk. See Note 17 for discussion of major customers. The Partnership does not require collateral or other security on accounts receivable. The credit risk is controlled through credit approvals and monitoring procedures. During 2015 and 2014, the Partnership recorded accounts receivable allowances of approximately $0. 5 million and $0.7 million, respectively, in relation to customers that had entered bankruptcy proceedings. The Partnership recorded these allowances based upon its best estimates of the ultimate collectability of the accounts receivable balances through the bankruptcy proceedings of these customers. As of December 31, 2015, the Partnership had accounts receivable allowances of approximately $0.2 million outstanding for remaining accounts that were estimated to be uncollectable. Cash and Cash Equivalents. The Partnership considers all highly liquid investments purchased with original maturities of three months or less to be cash equivalents. Inventories. Inventories are stated at the lower of cost, based on a three month rolling average, or market. Inventories primarily consist of coal contained in stockpiles. Advance Royalties. The Partnership is required, under certain royalty lease agreements, to make minimum royalty payments whether or not mining activity is being performed on the leased property. These minimum payments may be recoupable once mining begins on the leased property. The Partnership capitalizes the recoupable minimum royalty payments and amortizes the deferred costs once mining activities begin on the units-of-production method or expenses the deferred costs when the Partnership has ceased mining or has made a decision not to mine on such property. Notes Receivable. In December 2015, the Partnership completed the sale of the Deane mining complex located in Central Appalachia (see Note 6 for further details on the Deane mining complex sale). The Partnership received $2.0 million for the Deane mining complex sale in the form of a note receivable from the third-party purchaser. The note receivable bears interest at an annual rate of 6% and has a maturity date of December 31, 2017. The note receivable was recorded in the Other non-current assets line of the Partnership’s consolidated statements of financial positon. In August 2011, the Partnership closed on an agreement to sell and assign certain non-core mining assets and related liabilities located in the Phelps, KY area to a third party. The mining assets included leasehold interests and permits to surface and mineral interests that included steam coal reserves and non-reserve coal deposits. Additionally, the sales agreement included the potential for additional payments of approximately $8.75 million dependent upon certain future contingencies. Rhino recorded the sale of the assets and transfer of liabilities in the third quarter of 2011, but did not record any of the potential $8.75 million consideration since this amount relied on future contingent conditions to be met before it could be recognized. In 2014, the third party entered negotiations with the Partnership regarding the payment of the $8.75 million consideration as the third party anticipated the contingencies would be met in the near future. The third party negotiated with the Partnership to accept a note receivable in lieu of immediate payment since the third party did not have the available funds to pay the $8.75 million consideration. The Partnership believes the collection of the $8.75 million is in doubt due to the necessity of the third party to request a note receivable and the belief that the third party will not be able to economically mine this property for an extended period due to the lack of certain mining permits. Based on the uncertainty of collection of the note receivable, the Partnership recorded a note receivable balance along with a corresponding allowance against the entire $8.75 mi llion note receivable balance. During 2015 and 2014, the Partnership received approximately $0.6 million and $0.3 million, respectively, in payments related to this note receivable and the balance at December 31, 2015 was $7.9 million, which remained fully reserved based on the factors discussed above. Property, Plant and Equipment. Property, pla nt, and equipment, including coal properties, oil and natural gas properties, mine development costs and construction costs, are recorded at cost, which includes construction overhead and interest, where applicable. Expenditures for major renewals and betterments are capitalized, while expenditures for maintenance and repairs are expensed as incurred. Mining and other equipment and related facilities are depreciated using the straight-line method based upon the shorter of estimated useful lives of the assets or the estimated life of each mine. Coal properties are depleted using the units-of-production method, based on estimated proven and probable reserves. Mine development costs are amortized using the units-of-production method, based on estimated proven and probable reserves. The Partnership assumes zero salvage values for its property, plant and equipment when depreciation and amortization are calculated. Gains or losses arising from sales or retirements are included in current operations. Stripping costs incurred in the production phase of a mine for the removal of overburden or waste materials for the purpose of obtaining access to coal that will be extracted are variable production costs that are included in the cost of inventory produced and extracted during the period the stripping costs are incurred. The Partnership defines a surface mine as a location where the Partnership utilizes operating assets necessary to extract coal, with the geographic boundary determined by property control, permit boundaries, and/or economic threshold limits. Multiple pits that share common infrastructure and processing equipment may be located within a single surface mine boundary, which can cover separate coal seams that typically are recovered incrementally as the overburden depth increases. In accordance with the accounting guidance for extractive mining activities, the Partnership defines a mine in production as one from which saleable minerals have begun to be extracted (produced) from an ore body, regardless of the level of production; however, the production phase does not commence with the removal of de minimis saleable mineral material that occurs in conjunction with the removal of overburden or waste material for the purpose of obtaining access to an ore body. The Partnership capitalizes only the development cost of the first pit at a mine site that may include multiple pits. Asset Impairments for Coal Properties, Mine Development Costs and Other Coal Mining Equipment and Related Facilities. The Partnership follows the accounting guidance in Accounting Standards Codification (“ASC”) 360 , Property, Plant and Equipment, on the impairment or disposal of property, plant and equipment for its coal mining assets, which requires that projected future cash flows from use and disposition of assets be compared with the carrying amounts of those assets when potential impairment is indicated. When the sum of projected undiscounted cash flows is less than the carrying amount, impairment losses are recognized. In determining such impairment losses, the Partnership must determine the fair value for the coal mining assets in question in accordance with the applicable fair value accounting guidance. Once the fair value is determined, the appropriate impairment loss must be recorded as the difference between the carrying amount of the coal mining assets and their respective fair values. Also, in certain situations, expected mine lives are shortened because of changes to planned operations or changes in coal reserve estimates. When that occurs and it is determined that the mine’s underlying costs are not recoverable in the future, reclamation and mine closing obligations are accelerated and the mine closing accrual is increased accordingly. To the extent it is determined that coal asset carrying values will not be recoverable during a shorter mine life, a provision for such impairment is recognized. During 2015 and 2014, the Partnership recorded $ 31.1 million and $45.3 million, respectively, of asset impairment losses and related charges associated with multiple coal properties that are further described in Note 6 . The Partnership also recorded an impairment charge of $0.5 million during 2015 related to intangible assets that are discussed further in Note 7. The asset impairment losses and related charges are recorded on the Asset impairment and related charges line of the Partnership’s consolidated statements of operations and comprehensive income. The Partnership also recorded an impairment charge of $5.9 million during 2014 related to the Partnership’s equity investment in the Rhino Eastern joint venture that is discussed further in Note 3. The impairment charge for the Rhino Eastern joint venture is recorded on the Equity in net (loss)/income of unconsolidated affiliates line of the Partnership’s consolidated statements of operations and comprehensive income. Debt Issuance Costs. Debt issuance costs reflect fees incurred to obtain financing and are amortized (included in interest expense) using the effective interest method over the life of the related debt. Debt issuance costs are included in Prepaid expenses and other current assets as of December 31, 2015 since the Partnership classified its credit facility balance as a current liability (see Note 1). As of December 31, 2014, debt issuance costs were included in other non-current assets. 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. In April 2015, the Partnership entered into a third amendment of its amended and restated senior secured credit facility that further reduced the borrowing commitment to $100 million. As part of executing the third amendment to the amended and restated senior secured credit facility, the Operating Company paid a fee of approximately $2.1 million to the lenders in April 2015, which was recorded as an addition to Debt issuance costs. The Partnership wrote-off approximately $0.2 million of its remaining unamortized debt issuance costs since the third amendment further reduced the borrowing commitment under the amended and restated senior secured credit facility . See Note 10 for further information on the amendment to the amended and restated senior secured credit facility. Asset Retirement Obligations. The accounting guidance for asset retirement obligations addresses asset retirement obligations that result from the acquisition, construction or normal operation of long-lived assets. This guidance requires companies to recognize asset retirement obligations at fair value when the liability is incurred or acquired. Upon initial recognition of a liability, an amount equal to the liability is capitalized as part of the related long-lived asset and allocated to expense over the useful life of the asset. The Partnership has recorded the asset retirement costs for its mining operations in coal properties. The Partnership estimates its future cost requirements for reclamation of land where it has conducted surface and underground mining operations, based on its interpretation of the technical standards of regulations enacted by the U.S. Office of Surface Mining, as well as state regulations. These costs relate to reclaiming the pit and support acreage at surface mines and sealing portals at underground mines. Other reclamation costs are related to refuse and slurry ponds, as well as holding and related termination/exit costs. The Partnership expenses contemporaneous reclamation which is performed prior to final mine closure. The establishment of the end of mine reclamation and closure liability is based upon permit requirements and requires significant estimates and assumptions, principally associated with regulatory requirements, costs and recoverable coal reserves. Annually, the Partnership reviews its end of mine reclamation and closure liability and makes necessary adjustments, including mine plan and permit changes and revisions to cost and production levels to optimize mining and reclamation efficiency. When a mine life is shortened due to a change in the mine plan, mine closing obligations are accelerated, the related accrual is increased and the related asset is reviewed for impairment, accordingly. The adjustments to the liability from annual recosting reflect changes in expected timing, cash flow and the discount rate used in the present value calculation of the liability. Each respective year includes a range of discount rates that are dependent upon the timing of the cash flows of the specific obligations. Changes in the asset retirement obligations for the year ended December 31, 201 5 were calculated with discount rates that ranged from 2.9% to 5.9% . Changes in the asset retirement obligations for the year ended December 31, 2014 were calculated with discount rates that ranged from 1.6% to 5.3% . The discount rates changed in each respective year due to changes in applicable market indicators that are used to arrive at an appropriate discount rate. Other recosting adjustments to the liability are made annually based on inflationary cost increases or decreases and changes in the expected operating periods of the mines. The related inflation rate utilized in the recosting adjustments was 2.3 % for 201 5 and 201 4 . Workers’ Compensation Benefits. Certain of the Partnership’s subsidiaries are liable under federal and state laws to pay workers’ compensation and coal workers’ pneumoconiosis (“black lung”) benefits to eligible employees, former employees and their dependents. The Partnership currently utilizes an insurance program and state workers’ compensation fund participation to secure its on-going obligations depending on the location of the operation. Premium expense for workers’ compensation benefits is recognized in the period in which the related insurance coverage is provided. The Partnership’s black lung benefit liability is calculated using the service cost method that considers the calculation of the actuarial present value of the estimated black lung obligation. The actuarial calculations using the service cost method for the Partnership’s black lung benefit liability are based on numerous assumptions including disability incidence, medical costs, mortality, death benefits, dependents and interest rates. In addition, the Partnership’s liability for traumatic workers’ compensation injury claims is the estimated present value of current workers' compensation benefits, based on actuarial estimates. The actuarial estimates for the Partnership’s workers’ compensation liability are based on numerous assumptions including claim development patterns, mortality, medical costs and interest rates. See Note 12 for more information on the Partnership’s workers’ compensation and black lung liabilities and expense. Revenue Recognition. Most of the Partnership’s revenues are generated under long-term coal sales contracts with electric utilities, industrial companies or other coal-related organizations, primarily in the eastern United States. Revenue is recognized and recorded when shipment or delivery to the customer has occurred, prices are fixed or determinable and the title or risk of loss has passed in accordance with the terms of the sales agreement. Under the typical terms of these agreements, risk of loss transfers to the customers at the mine or port, when the coal is loaded on the rail, barge, truck or other transportation source that delivers coal to its destination. Advance payments received are deferred and recognized in revenue as coal is shipped and title has passed. Coal sales revenues also result from the sale of brokered coal produced by others. The revenues related to brokered coal sales are included in coal sales revenues on a gross basis and the corresponding cost of the coal from the supplier is recorded in cost of coal sales in accordance with the revenue recognition accounting guidance on principal agent considerations. Freight and handling costs paid directly to third ‑party carriers and invoiced to coal customers are recorded as freight and handling costs and freight and handling revenues, respectively. Other revenues generally consist of coal royalty revenues, limestone sales, coal handling and processing, oil and natural gas royalty revenues, rebates and rental income. Coal royalty revenues are recognized on the basis of tons of coal sold by the Partnership’s lessees and the corresponding gross revenues from those sales. The leases are based on (1) minimum monthly or annual payments, (2) a minimum dollar royalty per ton and/or a percentage of the gross sales price, or (3) a combination of both. Coal royalty revenues are recorded from royalty reports submitted by the lessee, which are reconciled and subject to audit by the Partnership. Most of the Partnership’s lessees are required to make minimum monthly or annual royalty payments that are recoupable over certain time periods, generally two years. If tonnage royalty revenues do not meet the required minimum amount, the difference is paid as a deficiency. These deficiency payments received are recognized as an unearned revenue liability because they are generally recoupable over certain time periods. When a lessee recoups a deficiency payment through production, the recouped amount is deducted from the unearned revenue liability and added to revenue attributable to the coal royalty revenue in the current period. If a lessee does not recoup a deficiency paid during the allocated time period, the recoupment right lost becomes revenue in the current period and is deducted from the liability. With respect to other revenues recognized in situations unrelated to the shipment of coal or coal royalties, the Partnership carefully reviews the facts and circumstances of each transaction and does not recognize revenue until the following criteria are met: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the seller’s price to the buyer is fixed or determinable and collectibility is reasonably assured. Advance payments received are deferred and recognized in revenue when earned. Equity ‑Based Compensation. The Partnership applies the provisions of ASC Topic 718 to account for any unit awards granted to employees or directors. This guidance requires that all share ‑based payments to employees or directors, including grants of stock options, be recognized in the financial statements based on their fair value. The General Partner has currently granted restricted units and phantom units to directors and certain employees of the General Partner and Partnership that contain only a service condition. The fair value of each restricted unit and phantom unit award was calculated using the closing price of the Partnership’s common units on the date of grant. T he Compensation Committee of the board of directors of the General Partner has historically elected to pay some of the awards in cash or a combination of cash and common units. This policy has resulted in all employee awards being classified as liabilit ies and , t hus, the employee awards are required to be marked-to-market each reporting period until they are vested. Restricted unit awards granted to directors of the General Partner are considered nonemployee equity ‑based awards since the directors are not elected by unitholders. Thus, these director awards are also required to be marked-to-market each reporting period until they are vested. Expense related to unit awards is recorded in the selling, general and administrative line of the Partnership’s consolidated statements of operations and comprehensive income. Derivative Financial Instruments. On occasion, the Partnership has use d diesel fuel contracts to manage the risk of fluctuations in the cost of diesel fuel. The Partnership’s diesel fuel c ontracts have met the requirements for the normal purchase normal sale (“NPNS”) exception prescribed by the accounting guidance on derivatives and hedging, based on management’s intent and ability to take physical delivery of the diesel fuel. The Partnership did not have any diesel fuel contracts as of December 31, 2015. Investments in Joint Ventures. Investments in joint ventures are accounted for using the equity method or cost basis depending upon the level of ownership, the Partnership’s ability to exercise significant influence over the operating and financial policies of the investee and whether the Partnership is determined to be the primary beneficiary of a variable interest entity. Equity investments are recorded at original cost and adjusted periodically to recognize the Partnership’s proportionate share of the investees’ net income or losses after the date of investment. Any losses from the Partnership’s equity method investment are absorbed by the Partnership based upon its proportionate ownership percentage. If losses are incurred that exceed the Partnership’s investment in the equity method entity, then the Partnership must continue to record its proportionate share of losses in excess of its investment. Investments are written down only when there is clear evidence that a decline in value that is other than temporary has occurred. In May 2008, the Operating Company entered into a joint venture, Rhino Eastern, with an affiliate of Patriot to acquire the Eagle mining complex. To initially capitalize the Rhino Eastern joint venture, the Operating Company contributed approximately $ 16.1 million for a 51 % ownership interest in the joint venture and accounted for the investment in Rhino Eastern 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 21, “Segment Information.” On December 31, 2014, the Partnership entered into an agreement with a wholly owned subsidiary of Patriot that effectively terminated the Rhino Eastern joint venture. This agreement officially closed in January 2015 and is described further in Note 3. T he Partnership determined it was not the primary beneficiary of the variable interest entity for the year ended December 31, 2014 by performing a qualitative and quantitative analysis based on the controlling economic interests of the Rhino Eastern joint venture. This included an analysis of the expected economic contributions of the joint venture. The Partnership concluded that it was not the primary beneficiary of Rhino Eastern primarily because of certain contractual arrangements by the joint venture with Patriot and the fact that the Rhino Eastern joint venture was managed by a committee of an equal number of representatives from Patriot and us. As of December 31, 2014, the Partnership recorded its equity method investment of $ 13.2 million in the Rhino Eastern joint venture as a long-term asset. See Note 3 for a discussion of the impairment charge incurred on the Partnership’s equity method investment as of December 31, 2014. During 2014, the Partnership contributed additional capital based upon its ownership share to the Rhino Eastern joint venture in the amount of $4.8 million . 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. Muskie was formed to provide sand for fracking operations to drillers in the Utica Shale region and other oil and natural gas basins in the U nited S tates . During 2014, the Partnership contributed additional capital based upon its ownership share to the Muskie joint venture in the amount of $0.2 million. As disclosed in Note 19 “Related Party and Affiliate Transactions”, during 2013 the Partnership provided a loan to Muskie totaling approximately $0.2 million which 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. Prior to the Partnership’s contribution of Muskie to Mammoth, the Partnership recorded its proportionate portion of Muskie’s operating loss for 2014 of approximately $ 0.1 million. As of December 31, 2015 and 2014, 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. See Note 21 for information on the Partnership’s reportable segments. 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. 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 this joint venture and results of operations under the equity method based upon its ownership percentage. The Partnership recorded its proportionate portion of the operating income for this investment during 2015 and 2014 of approximately $0.3 million and $0.4 million , respectively . The Partnership has recorded its investment in Sturgeon on the Investment in unconsolidated affiliates line of the Partnership’s consolidated statements of financial position. The Partnership has included its investment in Sturgeon in its Other category for segment reporting purposes . Income Taxes. The Partnership is considered a partnership for income tax purposes. Accordingly, the partners report the Partnership’s taxable income or loss on their individual tax returns. Loss Contingencies. In accordance with the guidance on accounting for contingencies, the Partnership records loss contingencies at such time that an unfavorable outcome becomes probable and the amount can be reasonably estimated. When the reasonable estimate is a range, the recorded loss is the best estimate within the range. If no amount in the range is a better estimate than any other amount, the minimum amount of the range is recorded. The Partnership discloses information concerning loss contingencies for which an unfavorable outcome is probable. See Note 15, “Commitments and Contingencies,” for a discussion of such matters. Management’s Use of Estimates. The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements as well as the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Recently Issued Accounting Standards. In 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. In July 2015, the FASB approved to defer the effective date of ASU 2014-09 by one year. Accordingly, ASU 2014-09 will be effective for public entities for annual reporting periods beginning after December 15, 2017 and interim periods therein. 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”. ASC 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

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	3. SUBSEQUENT EVENTS For the quarter ended December 31, 2015, the Partnership continued the suspension of the cash distribution for its common units, which was initially suspended for the quarter ended June 30, 2015. No distribution will be paid for common or subordinated units for the quarter ended Dec ember 3 1 , 2015. Pursuant to the Partnership’s partnership agreement, t he Partnership’s common units accrue arrearages every quarter when the distribution level is below the minimum level of $0.445 per unit. The Partnership initially lowered its quarterly common unit distribution below the minimum level of $0.445 per unit with the quarter ended September 30, 2014. Thus, the Partnership’s distributions for each of the quarters ended September 30, 2014 through the current quarter ended Dec ember 3 1 , 2015 were below the minimum level and the current amount of accumulated arrearages as of Dec ember 3 1 , 2015 related to the common unit distribution is approximately $44.3 million. On January 21, 2016, a definitive agreement (“Definitive Agreement”) was completed between Royal Energy Resources, Inc. (“Royal”) and Wexford where Royal acquired 6,769,112 issued and outstanding common units of the Partnership previously owned by Wexford for $3.5 million . The Definitive Agreement also included the committed acquisition by Royal within sixty days from the date of the Definitive Agreement of all of the issued and outstanding membership intere sts of Rhino GP LLC, the general partner of the Partnership , as well as 9,455,252 issued and outstanding subordinated units of the Partnership currently owned by Wexford for $1.0 million . On March 17, 2016, Royal completed the acquisition of all of the issued and outstanding membership interests of Rhino GP LLC as well as the 9,455,252 issued and outstanding subordinated units from Wexford. Royal obtained control of, and a majority limited partner interest, in the Partnership with the completion of this transaction. On March 21 , 2016, the Partnership and Royal entered into a securities purchase agreement (the “Securities Purchase Agreement”) pursuant to which the Partnership issued 60,000,000 common units in the Partnership to Royal in a private placement at $0.15 per common unit for an aggregate purchase price of $9.0 million. Royal paid the Partnership $2.0 million in cash and delivered a promissory note payable to the Partnership in the amount of $7.0 million. The promissory note is payable in three installments: (i) $3.0 million on July 31, 2016; (ii) $2.0 million on or before September 30, 2016 and (iii) $2.0 million on or before December 31, 2016. In the event the disinterested members of the board of directors of the General Partner determine that the Partnership does not need the capital that would be provided by either or both installments set forth in (ii) and (iii) above, in each case, the Partnership has the option to rescind Royal’s purchase of 13,333,333 common units and the applicable installment will not be payable (each, a “Rescission Right”). If the Partnership fails to exercise a Rescission Right, in each case, the Partnership has the option to repurchase 13,333,333 common units at $0.30 per common unit from Royal (each, a “Repurchase Option”). The Repurchase Options terminate on December 31, 2017. Royal’s obligation to pay any installment of the promissory note is subject to certain conditions, including that the Operating Company has entered into an agreement to extend the Amended and Restated Credit Agreement, as amended, to a date no sooner than December 31, 2017. In the event such conditions are not satisfied as of the date each installment is due, Royal has the right to cancel the remaining unpaid balance of the promissory note in exchange for the surrender of such number of common units equal to the principal balance of the promissory note divided by $0.15. On March 17, 2016, the Operating Company, as borrower, and the Partnership and certain of its subsidiaries, as guarantors, entered into an amendment (the “Fourth Amendment”) of its amended and restated credit agreement, dated July 29, 2011, as amended by the first, second and third amendments thereto, with PNC Bank, National Association, as Administrative Agent, PNC Capital Markets and Union Bank, N.A., as Joint Lead Arrangers and Joint Bookrunners, Union Bank, N.A., as Syndication Agent, Raymond James Bank, FSB, Wells Fargo Bank, National Association and the Huntington National Bank, as Co-Documentation Agents and the lenders party thereto. The Fourth Amendment amends the definition of change of control in the amended and restated credit agreement to permit Royal to purchase the membership interests of the General Partner and sets the expiration date of the facility at July 2016. The Fourth Amendment reduces the borrowing capacity under the credit facility to a maximum of $80 million and reduces the amount available for letters of credit to $30 million. The Fourth Amendment eliminates the option to borrow funds utilizing the LIBOR rate plus an applicable margin and establishes the borrowing rate for all borrowings under the facility to be based upon the current PRIME rate plus an applicable margin of 3.50% . The Fourth Amendment eliminates the capability to make Swing Loans under the facility and eliminates the ability of the Partnership to pay distributions to its common or subordinated unitholders. The Fourth Amendment alters the maximum leverage ratio, calculated as of the end of the most recent month, on a trailing twelve month basis, to 6.75 to 1.00. The leverage ratio shall be reduced by 0.50 to 1.00 for every $10 million of net cash proceeds, in the aggregate, received by the Partnership after the date of the Fourth Amendment from a liquidity event; provided, however, that in no event shall the maximum permitted leverage ratio be reduced below 3.00 to 1.00. A liquidity event is defined in the Fourth Amendment as the issuance of any equity by the Partnership on or after the Fourth Amendment effective date (other than the Royal equity contribution discussed above), or the disposition of any assets by the Partnership. The Fourth Amendment requires the Partnership to maintain minimum liquidity of $5 million and minimum EBITDA, calculated as of the end of the most recent month, on a trailing twelve month basis, of $8 million. The Fourth Amendment limits the amount of the Partnership’s capital expenditures to $15 million , calculated as of end of the most recent month, on a trailing twelve month basis. The Fourth Amendment requires the Partnership to provide monthly financial statements and a weekly rolling thirteen week cash flow forecast to the administrative agent.

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2015
Discontinued Operations [Abstract]
Discontinued Operations	4. DISCONTINUED OPERATIONS Divestiture of Utica Shale Oil and Natural Gas Assets Beginning in 2011, t he 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 natural 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 year ended December 31, 2014 related to this sale, which is recorded in Income from discontinued operations in the 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 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 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 years ended December 31, 2015 and 2014, t he Partnership recorded th e $0.7 million and $8.4 million , respectively, in Income from discontinued operations in the consolidated statements of operations and comprehensive income. The gain from the Blackhawk transaction is included in the (Gain) on sale/disposal of assets—net line in the operating activities section of the Partnership’s 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 consolidated statements of cash flows.

Prepaid Expenses And Other Curr

Prepaid Expenses And Other Current Assets	12 Months Ended
	Dec. 31, 2015
Prepaid Expenses And Other Current Assets [Abstract]
Prepaid Expenses And Other Current Assets	5. PREPAID EXPENSES AND OTHER CURRENT ASSETS Prepaid expenses and other current assets as of December 31, 201 5 and 201 4 consisted of the following: December 31, 2015 2014 (in thousands) Other prepaid expenses $ 682 $ 827 Debt issuance costs—net 2,155 - Prepaid insurance 1,492 2,063 Prepaid leases 80 87 Supply inventory 901 827 Deposits 164 170 Total $ 5,474 $ 3,974 Debt issuance costs are included in Prepaid expenses and other current assets as of December 31, 2015 since the Partnership classified its credit facility balance as a current liability (see Note 1). As of December 31, 2014, debt issuance costs were included in other non-current assets (see Note8). Debt issuance costs were $11.6 million and $9.1 million as of December 31, 2015 and 2014, respectively. Accumulated amortization of debt issuance costs were $9.4 million and $7.6 million as of December 31, 2015 and 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. In April 2015, the Partnership entered into a third amendment of its amended and restated senior secured credit facility that further reduced the borrowing commitment to $100 million. As part of executing the third amendment to the amended and restated senior secured credit facility, the Operating Company paid a fee of approximately $2.1 million to the lenders in April 2015, which was recorded as an addition to Debt issuance costs. The Partnership wrote-off approximately $0.2 million of its remaining unamortized debt issuance costs since the third amendment further reduced the borrowing commitment under the amended and restated senior secured credit facility. See Note 10 for further information on the amendments to the amended and restated senior secured credit facility.

Property, Plant And Equipment

Property, Plant And Equipment	12 Months Ended
	Dec. 31, 2015
Property, Plant And Equipment [Abstract]
Property, Plant And Equipment	6. PROPERTY, PLANT AND EQUIPMENT Property, plant and equipment, including coal properties and mine development and construction costs, as of December 31, 201 5 and 201 4 are summarized by major classification as follows: December 31, Useful Lives 2015 2014 (in thousands) Land and land improvements $ 24,157 $ 18,845 Mining and other equipment and related facilities 2 - 20 Years 306,609 336,951 Mine development costs 1 - 15 Years 67,277 79,536 Coal properties 1 - 15 Years 203,791 215,325 Oil and natural gas properties - 8,093 Construction work in process 2,680 4,912 Total 604,514 663,662 Less accumulated depreciation, depletion and amortization (271,007) (280,225) Net $ 333,507 $ 383,437 Depreciation expense for mining and other equipment and related facilities, depletion expense for coal and oil and natural gas properties, amortization expense for mine development costs, amortization expense for intangible assets and amortization expense for asset retirement costs for the years ended December 31, 2015 and 2014 was as follows: Year Ended December 31, 2015 2014 (in thousands) Depreciation expense-mining and other equipment and related facilities $ 28,740 $ 30,529 Depletion expense for coal properties 2,871 4,633 Depletion expense for oil and natural gas properties 9 60 Amortization expense for mine development costs 1,935 1,737 Amortization expense for intangible assets 76 80 Amortization expense for asset retirement costs (450) 194 Total $ 33,181 $ 37,233 Taylorville Land Sale On December 30, 2015, the Partnership completed the sale of its land surface rights for the Taylorville property in central Illinois for approximately $7.2 million in net proceeds. The sale agreement allows the Partnership to retain the mining permit and control of the proven and probable coal reserves at the Taylorville property as the Partnership has the option to repurchase the rights to the land within seven years from the date of the sale agreement. In accordance with ASC 360-20-40-38 , Real Estate Sales - Derecognition , since the Partnership has the option to repurchase the rights to the land , the transaction has been accounted for as a financing arrangement rather than a sale. The Taylorville property is recorded in the consolidated statement s of financial position within the net property , plant and equipment caption and the related liability is recorded in the consolidated statement s of financial position within the other noncurrent liability caption . Asset Impairments-2015 As the prolonged weakness in the United States coal markets continued during 2015, the Partnership performed a comprehensive review of its current coal mining operations as well as potential future development projects to ascertain any potential impairment losses. The Partnership identified various properties, projects and operations that were potentially impaired based upon changes in its strategic plans, market conditions or other factors, specifically in Northern Appalachia where market conditions related to the Partnership’s operations deteriorated in the fourth quarter of 2015. The Partnership believes that an oversupply of coal being produced in Northern Appalachia has contributed to depressed coal prices from this region. The Partnership believes the oversupply of coal has been created due to historically low natural gas prices in this region, which competes with coal as a source of electricity generation. Utilities have chosen cheap natural gas for electricity generation over coal and, additionally, the Partnership believes the amount that the utilities’ power plants have been dispatched for electricity generation has fallen due to low electricity demand. The production of natural gas from the Utica Shale and Marcellus Shale regions that are located within the Northern Appalachian region have kept natural gas prices low and larger coal producers have low-cost long-wall mines in Northern Appalachia that can compete to sell lower priced coal to utilities that still require coal supplies in this region. The Partnership believes this combination of factors have decreased coal prices in Northern Appalachia to levels where certain current operations as well as future plans for the development of the Leesville Field will be unprofitable in the near term. In addition to impairment charges related to certain Northern Appalachia operations, the Partnership also recorded asset impairment and related charges for the sale of the Deane mining complex and the Cana Woodford oil and natural gas investment that are discussed further below. The Partnership recorded approximately $31.1 million of total asset impairment and related charges related to property, plant and equipment for the year ended December 31, 2015, which is recorded on the Asset impairment and related charges line of the consolidated statements of operations and comprehensive income. Hopedale Mining Complex The Partnership owns the Hopedale mining complex located in Northern Appalachia that includes an underground mine, preparation plant and full-service rail loadout facility. Hopedale had long-term coal sales contracts with two utility customers that officially expired at the end of 2015, but had carry-over provisions for contracted coal shipments that were not delivered in 2015 that are to be shipped in 2016. These carry-over tons under these sales contracts have prices well above current market levels for coal being sold in this region, but do not constitute annual coal sales volumes that Hopedale has historically been able to sell. The Partnership has been unsuccessful in securing any contracted sales business at profitable prices for Hopedale coal to replace these expiring sales contracts due to the depressed Northern Appalachia coal market conditions discussed above. Based upon these factors, the Partnership performed a detailed analysis of potential impairment for the Hopedale mining complex as of December 31, 2015. The Partnership’s projection of future undiscounted net cash flows to be generated from the Hopedale mining complex indicated that a potential impairment existed since the carrying amount of the long-lived asset group at the Hopedale mining complex exceeded the sum of the projected undiscounted net cash flows. Thus, the Partnership performed a further analysis to determine what, if any, impairment existed for the Hopedale mining complex asset group. The Partnership utilized a discounted cash flow method (i.e. income approach) to estimate the fair value of the Hopedale mining complex. Based on this analysis, the Partnership recorded total asset impairment and related charges of $19.0 million for the Hopedale mining complex for the year ended December 31, 2015. Sands Hill Mining Complex The Partnership owns the Sands Hill mining complex in Northern Appalachia that includes two surface coal mines located near Hamden, Ohio. The infrastructure at Sands Hill includes a coal preparation plant along with a river front barge and dock facility on the Ohio River. Coal produced at Sands Hill is primarily trucked to local industrial customers in the southeastern region of Ohio. In addition to coal production, limestone aggregate is also produced at Sands Hill as the process of removing overburden to access the coal seams includes the removal of high quality limestone. The Sands Hill complex includes limestone processing facilities that crush and size the limestone for sale to local customers. Sands Hill has contracted coal sales through the end of 2016 from its surface coal mine operations, but no contracted coal sales beyond this date. Limestone is sold on a non-contracted basis from Sands Hill’s operation. During 2015, the Partnership contracted with a third party engineering firm to perform an audit of the Partnership’s coal mineral. As part of the third party expert’s audit, they performed an independent pro forma economic analysis using industry-accepted guidelines and these were used, in part, to classify coal mineral as either proven and probable coal reserves or non-reserve coal deposits, based on current market conditions. In the depressed Northern Appalachia coal market environment described above, a majority of the Sands Hill coal mineral that had previously been classified as proven and probable coal reserves was re-classified as non-reserve coal deposits as of December 31, 2015 due to unfavorable projected economic performance. The Partnership’s long-term plan had previously included the eventual development of underground coal reserves at Sands Hill, which were reclassified to non-reserve coal deposits as of December 31, 2015 per the discussion above. However, due to the lack of contracted sales beyond year-end 2016 and the depressed Northern Appalachia coal market discussed above, the Partnership decided as of December 31, 2015 to no longer pursue the development of the underground coal deposits at Sands Hill. Thus, the Partnership will cease surface coal mining at the end of 2016 when its Sands Hill contracted coal sales are fulfilled. The Partnership currently plans to continue limestone sales into 2017 since adequate limestone inventory will remain once coal mining has ceased. Based upon the factors that led to the Partnership’s decision to discontinue coal mining at Sands Hill as of year-end 2016, the Partnership performed a detailed analysis of potential impairment for the Sands Hill mining complex. The Partnership’s projection of future undiscounted net cash flows to be generated from the San d s Hill mining complex indicated that a potential impairment existed since the carrying amount of the long-lived asset group at the Sands Hill mining complex exceeded the sum of the projected undiscounted net cash flows. Thus, the Partnership performed a further analysis to determine what, if any, impairment existed for the Sands Hill mining complex asset group. The Partnership utilized a discounted cash flow method (i.e. income approach) to estimate the fair value of the Sands Hill mining complex. Based on this analysis, the Partnership recorded total asset impairment and related charges of $5.7 million for the Sands Hill mining complex for the year ended December 31, 2015. Leesville Field The Partnership owns the Leesville field that is located in the Northern Appalachia coal region in eastern Ohio and is approximately 20 miles north of the Partnership’s Hopedale mining complex. The Leesville field is an undeveloped property that contains approximately 27.9 million tons of coal mineral that was classified as non-reserve coal deposits as of December 31, 2015. Prior to 2015, the Leesville field coal mineral had been classified as proven and probable coal reserves. The Leesville field coal mineral that had previously been classified as proven and probable coal reserves was re-classified as non-reserve coal deposits due to unfavorable projected economic performance based upon the third party engineering firm’s audit of the Partnership’s coal mineral that was discussed above. The Partnership’s long-term plan had included the eventual development of Leesville field to supplement the production from the Partnership’s nearby Hopedale mining complex because the coal qualities at Leesville closely matched the coal qualities at Hopedale. However, due to the recent downturn in the coal markets in Northern Appalachia discussed above, the reclassification of the Leesville field coal mineral to non-reserve coal deposits and the difficult economic conditions being experienced at Hopedale discussed above, the Partnership decided to reevaluate its plans for the Leesville field and examine this undeveloped property for potential impairment. The Partnership believes that the Leesville field mineral would be uneconomic to produce in current market conditions, which are not expected to improve in the near future, and would not produce positive undiscounted net cash flows. Thus, this fact pattern indicated that a potential impairment existed since the carrying amount of the long-lived asset group at Leesville exc eeded the sum of any projected undiscounted net cash flows. The Partnership analyzed the Leesville asset group and determined the fair value of the Leesville asset group should be based on any compensation that could be received by the Partnership by selling the assets to a third party in the current marketplace since it would be uneconomic to develop this project in the current market environment. Based on the current depressed state of the Northern Appalachia coal markets, the Partnership determined the Leesville field asset group had zero value as of December 31, 2015. The Partnership recorded total asset impairment and related charges of $3.5 million for the Leesville field for the year ended December 31, 2015. Deane Mining Complex On October 30, 2015, the Partnership executed a binding letter of intent with a third party for the purchase of the Partnership’s Deane mining complex. The sale of the Deane mining complex was completed on December 30, 2015. The Deane mining complex is located in eastern Kentucky and includes one underground mine that was idle during 2015. The infrastructure at the Deane mining complex consists of a preparation plant and a unit train loadout facility. The sale of the Deane complex transferred the underground mine, related equipment, the preparation plant and loadout facility in exchange for $2.0 million in the form of a promissory note receivable from the third party, while the Partnership also retained the mineral rights for the proven and probable steam coal reserves at this complex. The Deane mining complex sale also included a royalty agreement with the third party pursuant to which the Partnership will collect future royalties for coal mined and sold from the Deane complex. The sale of the Deane mining complex also relieved the Partnership of significant reclamation liabilities and bonding requirements. For third quarter 2015 financial reporting purposes, the Partnership evaluated the appropriate held for sale accounting criteria to determine if the Deane mining complex should be classified as held for sale as of September 30, 2015. Based on this evaluation, the Partnership determined the Deane mining complex met the held for sale criteria at September 30, 2015 and, accordingly, the Deane mining complex asset group was written down to its estimated fair value of $2.0 million. Due to the determination that the Deane mining complex met the held for sale criteria, the Partnership recorded an impairment charge of approximately $2.3 million for the third quarter ended September 30, 2015 and the Partnership ceased depreciation of this asset group at this time. Upon the completion of the sales agreement for the Deane mining complex, the Partnership removed the assets and liabilities related to this mining complex, which resulted in a gain of $0.4 million that was record in the A sset impairment and related charges line of the consolidated statements of operations and comprehensive income . The net $1.9 million asset impairment charge/loss for the Deane mining complex is recorded on the Asset impairment and related charges line of the consolidated statements of operations and comprehensive income. Cana Woodford Oil and Natural Gas Investment In August 2015, the Partnership completed the sale of its oil and natural gas investment of approximately 1,900 net mineral acres in the Cana Woodford region of western Oklahoma. The Partnership received a total of approximately $5.7 million in proceeds from the sale of the Cana Woodford oil and natural gas mineral rights. In the second quarter of 2015, the Partnership evaluated the appropriate held for sale accounting criteria to determine if the Cana Woodford mineral rights should be classified as held for sale. Based on this evaluation, the Partnership determined these mineral rights met the held for sale criteria at June 30, 2015 and, accordingly, these mineral rights were written down to their estimated fair value of $5.8 million. Due to the determination that the mineral rights met the held for sale criteria, the Partnership recorded an impairment charge of approximately $2.2 million for the Cana Woodford mineral rights during the second quarter of 2015. The impairment charge for the Cana Woodford mineral rights is recorded on the Asset impairment and related charges line of the consolidated statements of operations and comprehensive income. Bevins Branch Operation As discussed further below, the Partnership had 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. In May 2015, the Partnership finalized a contractual agreement with a third party to assume the Bevins Branch operation. As of December 31, 2015, the Partnership removed the assets and liabilities related to this mining complex, which resulted in a gain of $1.2 million that was record in the asset impair ment and related charges line of the consolidated statements of operations and comprehensive income . In addition, as of December 31, 2015, the Partnership removed the approximately $2.3 million of remaining assets and any related liabilities that had been previously classified as held for sale on its consolidated statements of financial position. Asset Impairments -2014 Due to the prolonged weakness in the U.S. coal markets and the dim prospects for an upturn in the coal markets in the near term, in the fourth quarter of 2014, the Partnership performed a comprehensive review of its current coal mining operations as well as potential future development projects to ascertain any potential impairment losses. The Partnership’s appointment of new executive management in the fourth quarter of 2014 and the Partnership’s annual budgeting process in the fourth quarter of 2014 led to some changes in the Partnership’s strategic views. The Partnership identified various properties, projects and operations that were potentially impaired based upon changes in its strategic plans, market conditions or other factors. The Partnership recorded approximately $ 45.3 million of asset impairment and related charges for the year ended December 31, 2014, which is recorded on the Asset impairme nt and related charges line of the consolidated statements of operations and comprehensive income. A s discussed in Note 3 , the Partnership also recorded an impairment charge of $5.9 mil lion related to the Rhino Eastern joint venture that is recorded on the Equity in net (loss)/income of unconsolidated affiliates line of the consolidated statements of operations and comprehensive income. The major components that comprise this total asset impairment and related charges are described below. Red Cliff Project The Partnership control s certain mineral rights and related surface land located eleven miles north of Loma , Colorado (referred to as the “Red Cliff” property). The Partnership had been working with the U.S. Bureau of Land Management (“BLM”) agency since 2005 on an environmental impact statement report (“EIS report”) that was required to be completed before the Partnership could move forward with the development and permitting of a mining project on the Red Cliff property. The Partnership capitalized the cost associated with the ongoing EIS report process as mine development costs, which had accumulated to approximately $11.2 million at December 31, 2014. In addition, the Partnership invested approximately $11.0 million to acquire land for the purpose of building a rail spur to the property and also purchased certain land tracts at a cost of approximately $5.0 million for the purpose of constructing a rail load-out facility. At December 31, 2014, the Partnership had a carrying amount of approximately $16.2 million for the purchased land and approximately $2.0 million for mineral rights associated with a lease of coal reserves with the BLM. These amounts are in addition to the $11.2 million of mine development cost discussed above. Additionally, the Partnership had $0.3 million of accrued liabilities in BLM refunds related to the Red Cliff EIS report. In summary, the Partnership had total carrying costs of approximately $29.1 million for the Red Cliff property at December 31, 2014 that was included in the Partnership’s Rhino Western segment . In early 2010, the Partnership had a detailed mine development study performed for the Red Cliff property by an independent third party, which estimated the total cost to build out the project would be approximately $420 million once the EIS report was finalized. The EIS report outlines the environmental effects a potential project would have on the affected area. An initial EIS report was issued for public comment and review in 2009, which received over 20,000 comments in the 90-day comment period. Based on the volume of comments received on the initial report, the BLM decided that the EIS report pr ocess needed to be restarted. The Partnership agreed to restart the EIS report and the first two chapters of the EIS report were completed and work on chapters three and four was ready to begin in November 2014. Chapters three and four of the EIS report involve the costlier portion of report project since this includes detailed studies of the impacts to air quality, wildlife, etc. Up t o the fourth quarter of 2014, the Partnership had decided to continue with the EIS report despite the prolonged weakness in the coal markets. However, the decision was made by the Partnership’s executive m anagement to limit capital spending on all projects due to the weak coal market conditions that had adversely affected the Partnership’s financial results during 2014. Thus, due to the lack of progress in getting the EIS report finalized, the amount of money spent on the project to date, the impending higher costs to be incurred on the next phase of the EIS report and the desire to limit capital spending on certain projects due to the ongoing weakness in the coal markets, the Partnership decided to suspend the EIS report process in November 2014. Based on the fact pattern described above, the Partnership determined at December 31, 2014 that it would not pursue the development of the Red Cliff property and the related assets would be abandoned or sold for current market value. Since the Partnership reached a decision to abandon the potential development of the Red Cliff asset group at December 31, 2014, the Partnership evaluated the assets for impairment in accordance with appl icable accounting guidelines. The Partnership determined that the mine development costs and mineral rights could not be sold to a third party, so the Partnership recorded an asset impairment loss of $13.2 million for the year ended December 31, 2014 for these assets, which represented the write down of the previous carrying value of these assets to zero . The land related to the Red Cliff project was recorded at fair value (based on a third party appraisal) less costs to sell for a total net fair value of approximately $ 6.9 million since the Partnership had committed to a plan to sell these assets, which resulted in an additional asset impairment charge of $ 9.3 million. In total, after netting the $0.3 million of BLM refunds that will not be repaid due to abandoning the EI S report process, the Partnership recorded asset impairment and related charges of $ 22.2 million related to its Red Cliff assets at December 31, 2014. The $6.9 million of land is recorded on the Non-current assets held for sale line of the Partnership’s consolidated statements of financial position. Rich Mountain Property In June 2011, the Partnership acquired coal mineral rights in Randolph and Upshur Counties, West Virginia for approximately $ 7.5 million (referred to as the “Rich Mountain” property). These development stage properties were unpermitted an d contained no infrastructure. The Partnership conducted a core drilling program on the Rich Mountain property after it was purchased and determined the property contained an estimated 8.2 million tons of proven and probable underground metallurgical coal reserves. The Partnership capitalized the cost associated with its core drilling as mine development costs and the total value in property, plant and equipment for the Rich Mountain property was $ 8.3 million at December 31, 2014. The Partnership included this property in its Other category for segment reporting purposes since it was undeveloped. T he ongoing deterioration in the metallurgical coal markets has resulted in weak demand and historically low prices for this quality of coal. In the fourth quarter of 2014, the Partnership reassessed its strategy for these mineral rights and determined that it was not economical to develop this small coal reserve given the cost of building the req uired infrastructure. Although the Partnership did not have an active marketing strategy for the Rich Mountain property, the Partnership contacted a third party coal company with current operations in the general area of the Rich Mountain property to determine if there would be any interest in acquiring these mineral rights. Repeated attempts to obtain a non-binding price quote for the Rich Mountain mineral rights from this or other third parties resulted in no indicative bids being offered. Based on the factors discussed above, the Partnership determ ined at December 31, 2014 that it would not pursue the development of the Rich Mountain property and the related assets would be abandoned. In accordance with app licable accounting guidelines, the Partnership r eviewed its Rich Mountain assets as of December 31, 2014 for any impairment indicators that may have been present for this long-lived asset group. Since the Partnership reached a decision to abandon the potential development of this asset group , the Partnership recorded an asset impairment loss of $ 8.3 million for the year ended December 31, 2014, which represented the write down of the previous carrying value of this asset group to zero . The Partnership determined the Rich Mountain assets had zero value since the Partnership could not solicit any financial bid for the Rich Mountain assets and the Partnership does see any alternative uses of the mineral right assets in their current state to generate value. Bevins Branch Operation The Partnership ha d 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 actively attempted to market the coal from this operation to potential new customers and had maintained the mine so that production could resume in a relatively short time period whenever ne w customers could be secured. The Partnership had unsuccessfully been able to market the coal from this operation as the coal markets ha d been especially weak for coal from Central Appalachia and the lower quality of coal from the Bevins Branch operation proved especially difficult to market. As the Partnership found it difficult to market the quality of coal found at this mine in the current market place, the Partnership initiated negotiations in October 2014 with a third party for the potential sale of the Bevins Branch operation. A t December 31, 2014, the Partnership received a letter of intent from the third party interested in the Bevins Branch operation to accept ownership of this operation, including its related reclamation obligations. In May 2015, the Partnership finalize d a contractual agreement with the third party to assume the Bevins Branch operation. The contractual agreement had the third party assume the Bevins Branch operation where the only financial compensation the Partnership received is a future override royalty and the assumption of the reclamation obligations by the buyer. The closing of the transaction also allowed 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. Since t he Partnership received a letter of intent at December 31, 2014 to transfer this operation to a third party, t he Partnership determined this asset group should be written down to an estimated fair value of approximately $ 2.4 million, which equates to the estimated fair value of the future royalty of approximately $ 0.2 million and the benefit to be recognized of transferring the reclamation obligations of approximately $ 2.2 million. Based on this analysis, t he Partnership recorded total asset impairment and related charges of $8.3 million for the Bevins Branch operation for the year ended December 31, 2014. The total asset impairment and related charges include approximately $ 1.7 million for the write-off of advanced royalty balances related to the Bevins Branch operation that t he Partnership do es not expect to recover in the future. The Partnership also recorded an $ 6.6 million write-down of mineral value and mine development costs to the estimated fair value of $ 2.4 million of the royalty asset and benefit from transferring the reclamation obligations. Other Asset Impairments As of December 31, 2014, the Partnership also performed a comprehensive review of its other mining operations, primarily in Central Appalachia since this region ha d experienced the most extensive downturn in the coal markets, to determine if any other assets might be potentially imp aired. The Partnership’s review resulted in an additional $ 6.5 million of asset impairment and related charges, with $ 3.2 million related to mineral rights, $ 1.8 million of mine development costs and $ 1.5 mill ion of advanced royalties that the Partnership d id not expect to recover. The majority of these additional charges, approximately $4.9 million, related to low quality steam coal operati ons in Central Appalachia that the Partnership determined were uneconomical to mine due to the ongoing downturn in the markets for this quality of coal. The remaining $ 1. 5 million primarily related to advanced royalties that the Partnership d id not expect to recover at its Central Appalachia operations, which were determined as part of the Partnership’s strategic reviews that were conducted in the fourth quarter of 2014 .

Goodwill And Intangible Assets

Goodwill And Intangible Assets	12 Months Ended
	Dec. 31, 2015
Goodwill And Intangible Assets [Abstract]
Goodwill And Intangible Assets	7. GOODWILL AND INTANGIBLE ASSETS ASC Topic 350 addresses financial accounting and reporting for goodwill and other intangible assets subsequent to their acquisition. Under the provisions of ASC Topic 350, goodwill and other intangible assets with indefinite useful lives are not amortized but instead tested for impairment at least annually. The Partnership reviews finite-lived intangible assets for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable . Intangible assets of the Partnership as of December 31, 201 5 consisted of the following: Gross Net Carrying Accumulated Carrying Intangible Asset Amount Amortization Amount (in thousands) Patent $ - $ - $ - Developed Technology - - - Trade Name 184 42 142 Customer List 470 107 363 Total $ 654 $ 149 $ 505 Intangible assets of the Partnership as of December 31, 201 4 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 had a licensing agreement with a third party that was attempting to develop a commercially viable roof bolt product that utilized the intellectual property of the Partnership’s patent and developed technology assets. In the fourth quarter of 2015, the third party notified the Partnership that they would not renew the licensing agreement and pursue the development of the produc t that would utili ze the Partnership’s patent and developed technology. Based on the third party’s decision to discontinue the license agreement, the Partnership performed an impairment analysis of its patent and developed technology intangible assets. This analysis determined these intangible assets had no realizable value since the Partnership could not market these asset to another third party for development and the Partnership could not internally develop a product utilizing the technology of these intangible assets. As of December 31, 2015, the Partnership recorded an impairment charge of approximately $0.5 million to reduce the carrying amount of its patent and developed technology intangible assets to zero. The impairment charge for the intangible assets is recorded on the Asset impairment and related charges line of the consolidated statements of operations and comprehensive income. The Partnership considers the trade name and customer list intangible assets to have a useful life of twenty years. These intangible assets are amortized over their useful life on a straight line basis. Amortization expense for the years ended December 31, 201 5 and 201 4 is included in the depreciation, depletion and amortization table included in Note 6. The future total amortization expense for each of the five succeeding years related to intangible assets that are currently recorded in the consolidated statement of financial position is estimated to be as follows at December 31, 201 5 : Customer Trade Name List Total (in thousands) 2016 $ 9 $ 23 $ 32 2017 9 23 32 2018 9 23 32 2019 9 23 32 2020 9 23 32

Other Non-Current Assets

Other Non-Current Assets	12 Months Ended
	Dec. 31, 2015
Other Non-Current Assets [Abstract]
Other Non-Current Assets	8. OTHER NON-CURRENT ASSETS Other non-current assets as of December 31, 201 5 and 201 4 consisted of the following: December 31, 2015 2014 (in thousands) Deposits and other $ 138 $ 347 Debt issuance costs—net - 1,513 Non-current receivable 23,908 14,237 Note receivable 2,000 - Deferred expenses 261 313 Total $ 26,307 $ 16,410 As of December 31, 201 5 and 201 4 , the non-current receivable balance of $ 2 3.9 million and $ 1 4. 2 million, respectively, consisted of the amount due from the Partnership’s workers’ compensation and black lung insurance providers for potential claims that are the primary responsibility of the Partnership, but are covered under the Partnership’s insurance policies. See Note 12 for a discussion of the $ 23.9 million and $ 1 4. 2 million that is also recorded in the Partnership’s other non-current workers’ compensation liabilities.

Accrued Expenses And Other Curr

Accrued Expenses And Other Current Liabilities	12 Months Ended
	Dec. 31, 2015
Accrued Expenses And Other Current Liabilities [Abstract]
Accrued Expenses And Other Current Liabilities	9. ACCRUED EXPENSES AND OTHER CURRENT LIABILITIES Accrued expenses and other current liabilities as of December 31, 201 5 and 201 4 consisted of the following: December 31, 2015 2014 (in thousands) Payroll, bonus and vacation expense $ 1,447 $ 2,876 Non-income taxes 3,774 4,323 Royalty expenses 1,566 1,772 Accrued interest 575 385 Health claims 817 1,270 Workers’ compensation & pneumoconiosis 1,150 1,500 Deferred revenues 2,260 4,050 Accrued insured litigation claims 266 489 Other 2,247 669 Total $ 14,102 $ 17,334 The $2.3 million deferred revenue balance as of December 31, 2015 decreased compared to the $4.1 million balance as of December 31, 2014 due to adverse coal market conditions in Central Appalachia during 2015 that affected lessees at the Partnership’s Elk Horn coal leasing operation. The $0. 3 million and $0.5 million accrued for insured litigation claims as of December 31, 2015 and 201 4, respectively, consist s of probable and estimable litigation claims that are the primary ob ligation of the Partnership. The amount accrued for litigation claims decreased due to the settlement of various litigation claims during the year ended Dec ember 3 1 , 201 5. T his amount is also due from the Partnership’s insurance providers and is included in Accounts receivable, net of allowance for doubtful accounts on the Partnership’s consolidated statements of financial position . The Partnership presents this amount on a gross asset and liability basis as a right of setoff does not exist per the accounting guidance in ASC Topic 210. This presentation has no impact on the Partnership’s results of operations or cash flows.

Debt

Debt	12 Months Ended
	Dec. 31, 2015
Debt [Abstract]
Debt	10. DEBT Debt as of December 31, 201 5 and 201 4 consisted of the following: December 31, 2015 2014 (in thousands) Senior secured credit facility with PNC Bank, N.A. $ 41,200 $ 54,450 Other notes payable 2,874 2,982 Total 44,074 57,432 Less current portion (41,479) (210) Long-term debt $ 2,595 $ 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 amende d and restated credit facility wa s $ 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 wa s available for letters of credit. As described below, in March 2016, December 2015, April 2015 and March 2014 , the amended and restated credit facility was amended and the borrowing capacity under the facility was reduced to $80.0 million, with the amount available for letters of credit reduced to $30 million . Borrowings under the facility bear interest based upon the current PRIME rate plus an applicable margin of 3.50% . As part of the agreement, the Operating Company is required to pay a commitment fee on the unused portion of the borrowing availability equal to 1.0% . Borrowings on the amended and restated senior secured credit facility are collateralized by all the unsecured assets of the Partnership. The amended and restated senior secured credit facility requires the Partnership to maintain certain minimum financial ratios and contains certain restrictive provisions, including among others, restrictions on making loans, investments and advances, incurring additional indebtedness, guaranteeing indebtedness, creating liens, and selling or assigning stock. The Partnership was in compliance with all covenants contained in the amended and restated senior secured credit facility as of and for the twelve-month period ended December 31, 201 5 . The amended and restated senior secured credit facility is set to expire in July 2016. 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 4 , which previously constituted a portion of the collateral under the amended and restated senior secured credit facility. This second amendment also reduce d the borrowing capacity under the amended and restated senior secured credit facility to a maximum of $200 million and altered the maximum leverage ratio . In addition, the second amendment adjust ed 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 consolidated statements of financial position and in Cash flows (used in) financing activities in the Partnership’s consolidated statements of cash flows . 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 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. The third amendment extended the expiration date of the amended and restated credit agreement to July 2017. The extension is contingent upon (i) the Partnership’s leverage ratio being less than or equal to 2.75 to 1.0 and (ii) the Partnership having liquidity greater than or equal to $15 million, in each case for either the quarter ending December 31, 2015 or March 31, 2016. If both of these conditions are not satisfied for one of the periods, the expiration date of the amended and restated credit agreement will revert to July 2016. See Note 1 for further discussion regarding the extension of the expiration date of the credit agreement. The third amendment also reduced the borrowing commitment under the credit facility to a maximum of $100 million and reduced 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 commitment 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 the commitment under the facility on a dollar-for-dollar basis. The third amendment changed 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 3.0 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 removed the interest coverage ratio covenant and replaced 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 ended 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 limited 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. As part of executing the third amendment to the amended and restated senior secured credit facility, the Operating Company paid a fee of approximately $2.1 million to the lenders in April 2015, which was recorded in Debt issuance costs in Other non-current assets on the P artnership’s consolidated statements of financial position. In addition, the Partnership recorded a non-cash charge of approximately $0.2 million to write-off a portion of its unamortized debt issuance costs since the third amendment reduced the borrowing commitment under the amended and restated senior secured credit facility, which was recorded in Interest expense on the Partnership’s consolidated statements of operations and comprehensive income. From the date of the third amendment in April 2015 of the amended and restated senior secured credit facility through December 31, 2015, the Partnership received gross proceeds from asset sales of approximately $14.3 million. Per the terms of the third amendment of the amended and restated senior secured credit facility described above for gross proceeds from asset sales in excess of $10 million but less than $35 million, the borrowing commitment under the credit facility was reduced to a maximum of $90 million and the maximum permitted leverage ratio decrease d to 3.25 to 1.0 as of December 31, 2015. On March 17, 2016, the Operating Company entered into an amendment ( the “Fourth Amendment”) of its a mended and r estated senior secured c redit facility . The Fourth Amendment amends the definiti on of change of control in the a mended and r estated c redit a greement to permit Royal to purchase the membership interests of the General Partner and sets the expiration date of the facility at July 2016. The Fourth Amendment reduces the borrowing capacity under the credit facility to a maximum of $80 million and reduces the amount available for letters of credit to $30 million. The Fourth Amendment eliminates the option to borrow funds utilizing the LIBOR rate plus an applicable margin and establishes the borrowing rate for all borrowings under the facility to be based upon the current PRIME rate plus an applicable margin of 3.50% . The Fourth Amendment eliminates the capability to make Swing Loans under the facility and eliminates the ability of the Partnership to pay distributions to its common or subordinated unitholders. The Fourth Amendment alters the maximum leverage ratio, calculated as of the end of the most recent month, on a trailing twelve month basis, to 6.75 to 1.00. The leverage ratio shall be reduced by 0.50 to 1.00 for every $10 million of net cash proceeds, in the aggregate, received by the Partnership after the date of the Fourth Amendment from a liquidity event; provided, however, that in no event shall the maximum permitted leverage ratio be reduced below 3.00 to 1.00. A liquidity event is defined in the Fourth Amendment as the issuance of any equity by the Partnership on or after the Fourth Amendment effective date (other than the Royal equity contribution discussed above), or the disposition of any assets by the Partnership. The Fourth Amendment requires the Partnership to maintain minimum liquidity of $5 million and minimum EBITDA, calculated as of the end of the most recent month, on a trailing twelve month basis, of $8 million. The Fourth Amendment limits the amount of the Partnership’s capital expenditures to $15 million, calculated as of end of the most recent month, on a trailing twelve month basis. The Fourth Amendment requires the Partnership to provide monthly financial statements and a weekly rolling thirteen week cash flow forecast to the a dministrative agent. At December 31, 201 5 , the Operating Company had borrowed $ 36.0 million at a variable interest rate of LIBOR plus 4.50 % ( 4.70 % at December 31, 201 5 ) and an additional $ 5.2 million at a variable interest rate of PRIME plus 3 .50% ( 7 . 00 % at December 31, 2015). In addition, the Operating Company had outstanding letters of credit of $ 27.4 million at a fixed interest rate of 4.50 % at December 31, 201 5 . Based upon a maximum borrowing capacity of 3.25 times a trailing twelve -month EBITDA calculation (as defined in the credit agreement), the Operating Company had not used $ 1.1 million of the borrowing availability at December 31, 2015. For the year ended December 31, 2014, the Partnership capitalized interest costs of approximately $0.1 million, which was related to the construction of its Pennyrile mine in western Kentucky. The Partnership did no t capitalize any interest costs during the year ended December 31, 2015 . Principal payments on long-term debt due subsequent to December 31, 201 5 are as follows: in thousands 2016 $ 41,479 2017 240 2018 257 2019 275 2020 295 Thereafter 1,528 Total principal payments $ 44,074

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	11. ASSET RETIREMENT OBLIGATIONS The changes in asset retirement obligations for the years ended December 31, 201 5 and 201 4 are as follows: Year Ended December 31, 2015 2014 (in thousands) Balance at beginning of period (including current portion) $ 29,883 $ 34,451 Accretion expense 2,082 2,281 Adjustment resulting from addition of property 1,235 - Adjustment resulting from disposal of property (1) (6,861) (2,310) Adjustments to the liability from annual recosting and other (2,078) (1,324) Reclassification to held for sale - (2,250) Liabilities settled (514) (965) Balance at end of period 23,747 29,883 Less current portion of asset retirement obligation (767) (1,431) Long-term portion of asset retirement obligation $ 22,980 $ 28,452 (1) The ($6.9) million adjustment for the year ended December 31, 2015 relates to the sale of the Partnership’s Deane mining complex discussed in Note 6. 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.

Workers' Compensation And Black

Workers' Compensation And Black Lung	12 Months Ended
	Dec. 31, 2015
Workers' Compensation And Black Lung [Abstract]
Workers' Compensation And Black Lung	12. WORKERS’ COMPENSATION AND B LACK LUNG Certain of the Partnership’s subsidiaries are liable under federal and state laws to pay workers’ compensation and coal workers’ black lung benefits to eligible employees, former employees and their dependents. The Partnership currently utilizes an insurance program and state workers’ compensation fund participation to secure its on-going obligations depending on the location of the operation. Premium expense for workers’ compensation benefits is recognized in the period in which the related insurance coverage is provided. The Partnership’s black lung benefit liability is calculated using the service cost method that considers the calculation of the actuarial present value of the estimated black lung obligation. The Partnership’s actuarial calculations using the service cost method for its black lung benefit liability are based on numerous assumptions including disability incidence, medical costs, mortality, death benefits, dependents and interest rates. The Partnership’s liability for traumatic workers’ compensation injury claims is the estimated present value of current workers' compensation benefits, based on actuarial estimates. The Partnership’s actuarial estimates for its workers’ compensation liability are based on numerous assumptions including claim development patterns, mortality, medical costs and interest rates. The discount rate used to calculate the estimated present value of future obligations for black lung was 4.0% for December 31, 201 5 and 201 4 and for workers' compensation was 2.0% at December 31, 201 5 and 201 4 . The black lung and workers' compensation expense s for the year s ended December 31, 201 5 and 201 4 are as follows: Year Ended December 31, 2015 2014 Black lung benefits: (in thousands) Service cost $ (991) $ 1,040 Interest cost 397 357 Actuarial loss/(gain) - 1,625 Total black lung (594) 3,022 Workers' compensation expense 4,334 1,197 Total expense $ 3,740 $ 4,219 The changes in the black lung benefit liability for the years ended December 31, 2015 and 2014 are as follows: Year Ended December 31, 2015 2014 (in thousands) Benefit obligations at beginning of year $ 10,033 $ 7,251 Service cost (991) 1,040 Interest cost 397 357 Actuarial loss/(gain) - 1,625 Benefits and expenses paid (214) (240) Benefit obligations at end of year $ 9,225 $ 10,033 The classification of the amounts recognized for the Partnership’s w orkers’ compensation and black lung benefits liability as of December 31, 201 5 and 201 4 are as follows: December 31, 2015 2014 (in thousands) Black lung claims $ 9,225 $ 10,033 Insured black lung and workers' compensation claims 23,907 14,237 Workers' compensation claims 6,210 5,172 Total obligations $ 39,342 $ 29,442 Less current portion (1,150) (1,500) Non-current obligations $ 38,192 $ 27,942 The balance for insured black lung and workers’ compensation claims as of December 31, 2015 and 2014 consisted of $23.9 million and $14.2 million, respectively, that is the primary obligation of the Partnership, but this amount is also due from the Partnership’s insurance providers, which is included in Note 8 as non-current receivables, based on the Partnership’s workers’ compensation insurance coverage. The increase in the 2015 balance compared to 2014 is primarily due to an expected increase in the frequency and success of entitlement claims for black lung exposure, which the Partnership believes is due to the Patient Protection and Affordable Care Act. The Partnership presents this amount on a gross asset and liability basis since a right of setoff does not exist per the accounting guidance in ASC Topic 210. This presentation has no impact on the Partnership’s results of operations or cash flows .

Employee Benefits

Employee Benefits	12 Months Ended
	Dec. 31, 2015
Employee Benefits [Abstract]
Employee Benefits	1 3 . EMPLOYEE BENEFITS Postretirement Plan —In conjunction with the acquisition of the coal operations of American Electric Power on April 16, 2004, the Operating Company acquired a postretirement benefit plan providing healthcare to eligible employees at its Hopedale operations . The Partnership has no other postretirement plans. On December 10, 2015, the Partnership notified the employees at its Hopedale operations that healthcare benefits from the postretirement benefit plan would cease on January 31, 2016. The negative plan amendment that arose on December 10, 2015 resulted in an approximate $6.5 million prior service cost benefit. The Partnership is amortizing the prior service cost benefit over the remaining term of the benefits to be provided until January 31, 2016. For the year ended December 31, 2015, the Partnership recognized a benefit of approximately $2.6 million from the plan amendment in the Cost of operations line of the consolidated statements of operations and comprehensive income. The remaining $3.9 million benefit from the plan amendment will be recognized in the first quarter of 2016. Summaries of the changes in benefit obligations and funded status of the plan as of the measurement dates of December 31, 201 5 and 201 4 are as follows: Year Ended December 31, 2015 2014 (in thousands) Benefit obligation at beginning of period $ 6,648 $ 6,120 Changes in benefit obligations: Service costs 254 297 Interest cost 191 236 Benefits paid (217) (495) Plan amendment (6,503) - Actuarial loss/(gain) (328) 490 Benefit obligation at end of period $ 45 $ 6,648 Fair value of plan assets at end of period $ - $ - Funded status $ (45) $ (6,648) The classification of net amounts recognized for postretirement benefits as of December 31, 201 5 and 201 4 are as follows: December 31, 2015 2014 (in thousands) Current liability—postretirement benefits $ (45) $ (425) Non-current liability—postretirement benefits - (6,223) Net amount recognized $ (45) $ (6,648) The amounts recognized in accumulated other comprehensive income for the years ended December 31, 201 5 and 201 4 are as follows: Year Ended December 31, 2015 2014 (in thousands) Balance at beginning of year $ 1,373 $ 2,231 Actuarial (loss)/gain 328 (490) Prior service (cost)/gain to be amortized 3,876 - Amortization of net actuarial gain (782) (368) Net actuarial gain $ 4,795 $ 1,373 The amounts reclassified from accumulated other comprehensive income to Cost of operations in the Partnership’s consolidated statements of operations for the years ended December 31, 201 5 and 2014 was $3.4 million (inclusive of the $2.6 million benefit from the negative plan amendment described above) and $0.4 million, respectively. December 31, 2015 2014 Weighted Average assumptions used to determine benefit obligations: Discount rate n/a 3.15% Expected return on plan assets n/a n/a Year Ended December 31, 2015 2014 Weighted Average assumptions used to determine periodic benefit cost: Discount rate (1) 3.15% 3.96% Expected return on plan assets n/a n/a Rate of compensation increase n/a n/a The components of net periodic benefit cost for the years ended December 31, 201 5 and 201 4 are as follows: Year Ended December 31, 2015 2014 (in thousands) Service costs $ 254 $ 297 Interest cost 191 236 Amortization of prior service cost (2,626) - Amortization of (gain) (782) (368) Benefit cost $ (2,963) $ 165 Amounts expected to be amortized from accumulated other comprehensive income into net periodic benefit cost during the year ending December 31, 201 6 , are as follows: (in thousands) Net actuarial gain $ 4,795 401(k) Plans —The Partnership and certain subsidiaries sponsor defined contribution savings plans for all employees. Under one defined contribution savings plan, the Partnership matches voluntary contributions of participants up to a maximum contribution based upon a percentage of a participant’s salary with an additional matching contribution possible at the Partnership’s discretion. The expense under these plans for the years ended December 31, 201 5 and 201 4 was as follows: Year Ended December 31, 2015 2014 (in thousands) 401(k) plan expense $ 2,027 $ 2,227

Equity-Based Compensation

Equity-Based Compensation	12 Months Ended
	Dec. 31, 2015
Equity-Based Compensation [Abstract]
Equity-Based Compensation	1 4 . EQUITY ‑BASED COMPENSATION In October 2010, the General Partner established the Rhino Long-Term Incentive Plan (the “Plan” or “LTIP”). The Plan is intended to promote the interests of the Partnership by providing to employees, consultants and directors of the General Partner, the Partnership or affiliates of either incentive compensation awards to encourage superior performance. The LTIP provides for grants of restricted units, unit options, unit appreciation rights, phantom units, unit awards, and other unit-based awards. The aggregate number of units initially reserved for issuance under the LTIP is 2,479,400 . As of December 31, 201 5, the General Partner had g ranted 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 quarter of each year since 2012 to certain employees in connection with the prior fiscal 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. The phantom units granted to certain employees vest in equal annual installments over a three year period from the date of grant. A summary of non-vested LTIP awards as of and for the years ended December 31, 201 5 and 201 4 is as follows: Common Units Weighted Average Grant Date Fair Value (per unit) (in thousands) Non-vested awards at December 31, 2013 55 $ 14.63 Granted 46 $ 12.32 Vested (34) $ 13.95 Forfeited (16) $ 13.01 Non-vested awards at December 31, 2014 51 $ 13.50 Granted 247 $ 1.06 Vested (86) $ 5.68 Forfeited (8) $ 6.43 Non-vested awards at December 31, 2015 204 $ 2.00 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. For the years ended December 31, 2015 and 201 4 , the Partnership recorded expense of approximatel y $ 0.1 million and approximately $ 0.3 million, respectively, for the LTIP awards. For the year ended December 31, 201 5 , the total fair value of the awards that vested wa s $0.1 million. As of December 31, 201 5 , the total unrecognized compensation expense related to the non-vested LTIP awards that are expected to vest was $ 0.3 million. The expense is expected to be recognized over a weighted ‑average period of 1.1 years. As of December 31, 2015, the intrinsic value of the non-vested LTIP awards was $ 0.1 million.

Commitments And Contingencies

Commitments And Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments And Contingencies [Abstract]
Commitments And Contingencies	1 5 . COMMITMENTS AND CONTINGENCIES Coal Sales Contracts and Contingencies —As of December 31, 201 5 , the Partnership had commitments under sales contracts to deliver annually scheduled base quantities of coal as follows: Year Tons (in thousands) Number of customers 2016 3,255 14 2017 1,914 8 2018 264 1 Some of the contracts have sales price adjustment provisions, subject to certain limitations and adjustments, based on a variety of factors and indices. Purchased Coal Expenses —The Partnership incurs purchased coal expense from time to time related to coal purchase contracts. In addition, the Partnership incurs expense from time to time related to coal purchased on the over-the-counter market (“OTC”). Purchase coal expense from coal purchase contracts and expense from OTC purchases for the years ended December 31, 2015 and 201 4 was as follows: Year Ended December 31, 2015 2014 (in thousands) Purchased coal expense $ (26) $ 6,168 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 years ended December 31, 2015 and 201 4 was as follows: Year Ended December 31, 2015 2014 (in thousands) Lease expense $ 6,204 $ 3,478 Royalty expense $ 10,754 $ 11,571 Approximate future minimum lease and royalty payments (not including advance royalties already paid and recorded as assets in the accompanying statements of financial position) are as follows: Years Ended December 31, Royalties Leases (in thousands) 2016 $ 2,824 3,664 2017 2,466 1,097 2018 2,436 148 2019 2,436 - 2020 2,556 - Thereafter 12,780 - Total minimum royalty and lease payments $ 25,498 $ 4,909 Environmental Matters —Based upon current knowledge, the Partnership believes that it is in compliance with environmental laws and regulations as currently promulgated. However, the exact nature of environmental control problems, if any, which the Partnership may encounter in the future cannot be predicted, primarily because of the increasing number, complexity and changing character of environmental requirements that may be enacted by federal and state authorities. Legal Matters —The Partnership is involved in various legal proceedings arising in the ordinary course of business due to claims from various third parties, as well as potential citations and fines from the Mine Safety and Health Administration, potential claims from land or lease owners and potential property damage claims from third parties. The Partnership is not party to any other pending litigation that is probable to have a material adverse effect on the financial condition, results of operations or cash flows of the Partnership. Management of the Partnership is also not aware of any significant legal, regulatory or governmental proceedings against or contemplated to be brought against the Partnership. Guarantees/Indemnifications and Financial Instruments with Off-Balance Sheet Risk —In the normal course of business, the Partnership is a party to certain guarantees and financial instruments with off-balance sheet risk, such as bank letters of credit and performance or surety bonds. No liabilities related to these arrangements are reflected in the consolidated statements of financial position. The amount of bank letters of credit outstanding with PNC Bank, N.A., as the letter of credit issuer under the Partnership’s credit facility, was $ 27.4 million as of December 31, 201 5 . The bank letters of credit outstanding reduce the borrowing capacity under the credit facility. In addition, the Partnership has outstanding surety bonds with third parties o f $ 59.1 mil li on as of December 31, 201 5 to secure reclamation and other performance commitments. The credit facility is fully and unconditionally, jointly and severally guaranteed by the Partnership and substantially all of its wholly owned subsidiaries. Borrowings under the credit facility are collateralized by the unsecured assets of the Partnership and substantially all of its wholly owned subsidiaries. See Note 10 for a more complete discussion of the Partnership’s debt obligations. Joint Venture s —The Partnership may contribute additional capital to the Timber Wolf joint venture that was formed in the first quarter of 2012. The Partnership did not make any capital contribution s to the Timber Wolf joint venture during the year ended December 31, 2015 . The Partnership was required to contribute additional capital to the Muskie Proppant joint venture that was formed in the fourth quarter of 2012. During the year ended December 31, 2014 , the Partnership made capital contributions to the Muskie Proppant joint venture of approximately $0.2 million based upon its proportionate ownership percentage. In addition, during the year ended Dec ember 3 1 , 2013, the Partnership provided a loan based upon its ownership share to Muskie in the amount of $0.2 million . The note was fully repaid in November 2014 in conjunction with the contribution of the Partnership’s interests in Muskie to Mammoth . With the contribution of the Partnership's interest in Muskie to Mammoth in the fourth quarter of 2014, the Partnership does not have any further fu nding commitments to Mammoth. 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 year ended Dec ember 3 1 , 2014 based upon its proportionate ownership interest.

Earnings Per Unit ("EPU")

Earnings Per Unit ("EPU")	12 Months Ended
	Dec. 31, 2015
Earnings Per Unit ("EPU") [Abstract]
Earnings Per Unit ("EPU")	1 6 . EARNINGS PER UNIT (“EPU”) The following table presents a reconciliation of the numerators and denominators of the basic and diluted EPU calculations for the years ended December 31, 201 5 and 201 4 : Year ended December 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 $ (1,119) $ (31,491) $ (23,356) Net income from discontinued operations 14 406 302 Interest in net income $ (1,105) $ (31,085) $ (23,054) Impact of subordinated distribution suspension: Net income/(loss) from continuing operations $ 5 $ 139 $ (144) Net income from discontinued operations - - - Interest in net income $ 5 $ 139 $ (144) Interest in net (loss)/income for EPU purposes: Net (loss) from continuing operations $ (1,114) $ (31,352) $ (23,500) Net income from discontinued operations 14 406 302 Interest in net income $ (1,100) $ (30,946) $ (23,198) Denominator: Weighted average units used to compute basic EPU n/a 16,714 12,396 Effect of dilutive securities — LTIP awards n/a - - Weighted average units used to compute diluted EPU n/a 16,714 12,396 Net (loss)/income per limited partner unit, basic: Net (loss) per unit from continuing operations n/a $ (1.87) $ (1.89) Net income per unit from discontinued operations n/a 0.02 0.02 Net income per limited partner unit, basic n/a $ (1.85) $ (1.87) Net (loss)/income per limited partner unit, diluted: Net (loss) per unit from continuing operations n/a $ (1.87) $ (1.89) Net income per unit from discontinued operations n/a 0.02 0.02 Net income per limited partner unit, diluted n/a $ (1.85) $ (1.87) Year ended December 31, 2014 General Partner Common Unitholders Subordinated Unitholders Numerator: (in thousands, except per unit data) Interest in net income (as previously reported): Net income from continuing operations $ (1,626) $ (45,705) $ (33,962) Net income from discontinued operations 2,607 73,271 54,464 Interest in net income $ 981 $ 27,566 $ 20,502 Impact of subordinated distribution suspension: Net income/(loss) from continuing operations $ 245 $ 6,908 $ (7,153) Net income from discontinued operations - - - Interest in net income/(loss) $ 245 $ 6,908 $ (7,153) Interest in net income/(loss) for EPU purposes (as restated): Net income/(loss) from continuing operations $ (1,381) $ (38,797) $ (41,115) Net income from discontinued operations 2,607 73,271 54,464 Interest in net income/(loss) $ 1,226 $ 34,474 $ 13,349 Denominator: Weighted average units used to compute basic EPU n/a 16,678 12,397 Effect of dilutive securities — LTIP awards n/a 7 - Weighted average units used to compute diluted EPU n/a 16,685 12,397 Net income per limited partner unit, basic: Net income per unit from continuing operations n/a $ (2.32) $ (3.31) Net income per unit from discontinued operations n/a 4.39 4.39 Net income per limited partner unit, basic n/a $ 2.07 $ 1.08 Net income per limited partner unit, diluted: Net income per unit from continuing operations n/a $ (2.32) $ (3.31) Net income per unit from discontinued operations n/a 4.39 4.39 Net income per limited partner unit, diluted n/a $ 2.07 $ 1.08 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 year ended Dec ember 3 1 , 2015, all potential dilutive units were excluded from the diluted EPU calculation for th i s 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. There were no anti-dilutive units for the year ended December 31, 201 4 .

Major Customers

Major Customers	12 Months Ended
	Dec. 31, 2015
Major Customers [Abstract]
Major Customers	1 7 . MAJOR CUSTOMERS The Partnership had revenues or receivables from the following major customers that in each period equaled or exceeded 10% of revenues or receivables (Note: customers with “n/a” had revenue or receivables below the 10% threshold in any period where this is indicated) : December 31, 2015 Receivable Balance Year Ended December 31, 2015 Sales December 31, 2014 Receivable Balance Year Ended December 31, 2014 Sales (in thousands) NRG Energy Inc. (fka GenOn Energy, Inc.) $ - $ 22,111 $ 2,932 $ 31,605 PPL Corporation 1,881 33,662 2,053 24,542 PacifiCorp Energy 1,969 21,519 n/a n/a

Fair Value Of Financial Instrum

Fair Value Of Financial Instruments	12 Months Ended
	Dec. 31, 2015
Fair Value Of Financial Instruments [Abstract]
Fair Value Of Financial Instruments	18. FAIR VALUE OF FINANCIAL INSTRUMENTS The book values of cash and cash equivalents, accounts receivable and accounts payable are considered to be representative of their respective fair values because of the immediate short-term maturity of these financial instruments. The fair value of the Partnership’s senior secured credit facility was determined based upon a market approach and approximates the carrying value at December 31, 201 5 . The fair value of the Partnership’s senior secured credit facility is a Level 2 measurement. As of December 31, 2015, the Partnership did not have any nonrecurring fair value measurements related to any assets held for sale. The Partnership previously had assets classified as held for sale that were related to the Partnership’s 2014 impairment actions related to its Red Cliff assets that are discussed in Note 6. As of December 31, 2015, the Partnership reclassified its previously held for sale assets to property, plant and equipment to be held and used since the Partnership no longer had an active plan to sell these assets in the next twelve months. For the year ended December 31, 2015, the Partnership had nonrecurring fair value measurements related to asset impairments as described in Note 6. The nonrecurring fair value measurements for the asset impairments described in Note 6 for the year ended December 31, 2015 were Level 3 measurements. 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 are a result of the Partnership’s impairment actions discussed in Note 6. 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. This land was valued using a market approach by a third party appraisal firm that determined the fair value of the asset based on sales of comparable property in the market along with other market factors such as competitive listings. The fair value of the Partnership’s land held for sale at December 31, 2014 was 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 6. The held for sale assets consisted of approximately $0.2 million of a future coal royalty income stream. The fair value of the future royalty income stream was determined by an income approach using a discounted cash flow analysis with an appropriate discount rate. The fair value of the remaining $2.2 million of assets and liabilities held for sale related to the Bevins Branch operation was also determined by an income approach using a discounted cash flow analysis. The $2.2 million of assets and liabilities held for sale related to the reclamation obligation being transferred in the Bevins Branch transaction and the income approach used to determine the fair value was based on the Partnership’s method to calculate its asset retirement obligations for reclamation, which is discussed in Note 2. The fair values of the Partnership’s assets and liabilities held for sale at December 31, 2014 for the Bevins Branch operation were Level 3 measurements. The Partnership completed the sale of its Bevins Branch assets and liabilities in May 2015.

Related Party And Affiliate Tra

Related Party And Affiliate Transactions	12 Months Ended
	Dec. 31, 2015
Related Party And Affiliate Transactions [Abstract]
Related Party And Affiliate Transactions	1 9 . RELATED PARTY AND AFFILIATE TRANSACTIONS Related Party Description 2015 2014 (in thousands) Wexford Capital LP Expenses for legal, consulting, and advisory services $ 143 $ 131 Wexford Capital LP Distributions paid 553 10,949 Wexford Capital LP Partner's contribution 2 6 Rhino Eastern LLC Equity in net (loss)/income of unconsolidated affiliate - (12,089) Rhino Eastern LLC Expenses for legal, health claims, workers' compensation and other expenses - 4,610 Rhino Eastern LLC Receivable for legal, health claims and workers’ compensation and other expenses - 223 Rhino Eastern LLC Investment in unconsolidated affiliate - 13,151 Timber Wolf Terminals LLC Investment in unconsolidated affiliate 130 130 Muskie Proppant LLC Investment in unconsolidated affiliate - - Mammoth Energy Partners LP Investment in unconsolidated affiliate 1,933 1,933 Sturgeon Acquisitions LLC Investment in unconsolidated affiliate 5,515 5,440 Sturgeon Acquisitions LLC Distributions from unconsolidated affiliate 232 - Sturgeon Acquisitions LLC Return of capital from unconsolidated affiliate 35 - Sturgeon Acquisitions LLC Equity in net income of unconsolidated affiliate 342 440 From time to time, employees from Wexford Capital perform legal, consulting, and advisory services to the Partnership. The Partnership incurred expenses of $0.1 million for the years ended December 31, 2015 and 2014 for legal, consulting, and advisory services performed by Wexford Capital. For the year ended December 31, 2014, the $12.1 million equity in net loss of unconsolidated affiliate for Rhino Eastern includes the $5.9 million impairment charge for the joint venture that was discussed earlier. From time to time, the Partnership has allocated and paid expenses on behalf of the Rhino Eastern joint venture. During the years ended December 31, 201 4 , the Partnership paid expenses for legal, health claims and workers’ compensation of $ 4.6 million on behalf of Rhino Eastern that were subsequently billed and paid by Rhino Eastern to the Partnership.

Supplemental Disclosures Of Cas

Supplemental Disclosures Of Cash Flow Information	12 Months Ended
	Dec. 31, 2015
Supplemental Disclosures Of Cash Flow Information [Abstract]
Supplemental Disclosures Of Cash Flow Information	20 . SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION Cash payments for interest were $ 3.4 million and $ 4.0 million for the years ended December 31, 201 5 and 201 4 , respectively. The consolidated statement of cash flows for the year ended December 31, 201 5 is exclusive of approximatel y $0.7 million of property, plant and equipment additions which are recorded in Accounts payable. The consolidated statements of cash flows for the year ended December 31, 201 5 also excludes approximately $0.1 million related to the value of LTIP units that were issued to certain employees and directors of the General Partne r. 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 consolidated statements of operations and comprehensive income for the year ended Dec ember 3 1 , 2015. The consolidated statement of cash flows for the year ended Dec ember 3 1 , 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 consolidated statement of cash flows for the year ended December 31, 201 4 is exclusive of approximately $0.2 million of property, plant and equipment additions which are recorded in Accounts payable. The consolidated statements of cash flows for the year ended December 31, 201 4 also excludes approximately $0.3 million related to the value of LTIP units that were issued to certain employees and directors of the General Partner.

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2015
Segment Information [Abstract]
Segment Information	2 1 . SEGMENT INFORMATION The Partnership primarily produces and markets coal from surface and underground mines in Kentucky, West Virginia, Ohio and Utah. The Partnership sells primarily to electric utilities in the United States. In addition, with the Elk Horn Acquisition mentioned earlier, the Partnership also leases coal reserves to third parties in exchange for royalty revenues. As of December 31, 201 5 , the Partnership has four reportable business segments: Central Appalachia, Northern Appalachia, Rhino Western and Illinois Basin . Additionally, the Partnership ha s an Other category that includes its ancillary businesses. The Central Appalachia segment consists of two mining complexes: Tug River and Rob Fork, which, as of December 31, 201 5 , together included one active underground mine, three active surface mines and three preparation plants and loadout facilities in eastern Kentucky and southern West Virginia. Additionally, the Central Appalachia segment includes the Partnership’s Elk Horn coal leasing operations. The Northern Appalachia segment consists of the Hopedale mining complex, the Sands Hill mining complex and the Leesville field. The Hopedale mining complex, located in northern Ohio, included one underground mine and one preparation plant and loadout facility as of December 31, 201 5 . The Sands Hill mining complex, located in southern Ohio, included two surface mines, a preparation plant and a river terminal as of December 31, 201 5 . The Eastern Met segment included the Partnership’s 51% equity interest in the results of operations of the Rhino Eastern joint venture, which owned the Rhino Eastern mining complex, located in West Virginia, and for which the Partnership served as manager. The Rhino Eastern joint venture was dissolved in January 2015 . T he 2014 financial results are shown since the joint venture owned, and the Partnership operated, this min ing complex during the year. The Rhino Western segment includes the Partnership ’s underground mine in th e Western Bituminous region at its Castle Valley mining complex in Utah. The Illinois Basin segment includes the Partnership’s underground mine, preparation plant and river loadout facility at its Pennyrile mining complex located in western Kentucky, as well as its Taylorville field reserves located in central Illinois. The Pennyrile mining complex began production and sales in mid-2014. The Partnership’s Other category as reclassified is comprised of the Partnership’s ancillary businesses and its remaining oil and natural gas activities. Held for sale assets are included in the applicable segment for reporting purposes. The Partnership has not provided disclosure of total expenditures by segment for long-lived assets, as the Partnership does not maintain discrete financial information concerning segment expenditures for long lived assets, and accordingly such information is not provided to the Partnership’s chief operating decision maker. The information provided in the following tables represents the primary measures used to assess segment performance by the Partnership’s chief operating decision maker. The Partnership ha s historically accounted for the Rhino Eastern joint venture (formed in the year ended December 31, 2008) under the equity method. Under the equity method of accounting, the Partnership has historically only presented limited information (net income). The Partnership consider ed this operation to comprise a separate operating segment prior to its dissolution in January 2015 and has presented additional operating detail (with corresponding eliminations and adjustments to reflect its percentage of ownership) below. Since this equity method investment met the significance test of ten percent of net income or loss in 2014 , the Partnership has presented additional summarized financial information for this equity method investment below. Reportable segment results of operations and financial position for the year ended December 31, 201 5 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization): Central Appalachia Northern Appalachia Rhino Western Illinois Basin Other Total Consolidated (in thousands) Total assets $ 227,880 $ 17,218 $ 37,198 $ 82,700 $ 39,671 $ 404,667 Total revenues 67,942 63,273 35,322 38,641 1,568 206,746 DD&A 12,641 7,562 6,314 5,928 736 33,181 Interest expense 2,040 522 315 597 1,527 5,001 Net Income (loss) from continuing operations $ (14,212) $ (20,487) $ (4,560) $ (13,807) $ (2,900) $ (55,966) Reportable segment results of operations and financial position for the year ended December 31, 201 4 are as follows: Eastern Met Central Appalachia Northern Appalachia Rhino Western Illinois Basin Complete Basis Equity Method Eliminations Equity Method Presentation * Other Total Consolidated (in thousands) Total assets $ 247,362 $ 52,822 $ 42,173 $ 80,126 $ 42,100 $ (42,100) $ - $ 50,855 $ 473,338 Total revenues 109,432 71,472 44,081 9,755 21,722 (21,722) - 4,317 239,057 DD&A 20,224 7,574 6,021 2,286 1,860 (1,860) - 1,128 37,233 Interest expense 2,055 473 329 343 81 (81) - 2,508 5,708 Net Income (loss) from continuing operations $ (33,019) $ 2,101 $ (22,822) $ (6,411) $ (12,208) $ 5,982 $ (12,089) $ (9,053) $ (81,293) * For the year ended December 31, 2014, the equity method net loss from continuing operations for Rhino Eastern includes the $5.9 million impairment charge for the joint venture that was discussed earlier. Additional summarized financial information for the equity method investment as of and for the periods ended December 31, 201 5 and 201 4 is as follows: 2015 2014 (Unaudited) (in thousands) Current assets $ - $ 3,641 Noncurrent assets - 38,459 Current liabilities - 3,629 Noncurrent liabilities - 3,202 Total costs and expenses - 33,850 (Loss)/income from operations - (12,128) Additional information on the Partnership’s revenue by product category for the periods ended December 31, 201 5 and 201 4 is as follows: 2015 2014 (in thousands) Met coal revenue $ 15,391 $ 26,058 Steam coal revenue 155,683 176,823 Other revenue 35,672 36,176 Total revenue $ 206,746 $ 239,057

Quarterly Financial Data

Quarterly Financial Data	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Data [Abstract]
Quarterly Financial Data	2 2 . QUARTERLY FINANCIAL DATA (UNAUDITED) (in thousands, except per unit data) First Quarter Second Quarter Third Quarter Fourth Quarter(1) 2015: Revenues $ 56,184 $ 56,765 $ 54,153 $ 39,644 (Loss) from operations (3,748) (6,959) (7,994) (32,644) Net (loss) from continuing operations (4,562) (8,112) (9,306) (33,986) Income from discontinued operations 722 - - - Net (loss) $ (3,840) $ (8,112) $ (9,306) $ (33,986) Basic and diluted net (loss)/income per limited partner unit: Common units: Net (loss) per unit from continuing operations $ (0.15) $ (0.27) $ (0.31) $ (1.14) Net income per unit from discontinued operations 0.02 - - - Net (loss) per common unit, basic and diluted $ (0.13) $ (0.27) $ (0.31) $ (1.14) Subordinated units: Net (loss) per unit from continuing operations $ (0.17) $ (0.27) $ (0.31) $ (1.14) Net income per unit from discontinued operations 0.02 - - - Net (loss) per subordinated unit, basic and diluted $ (0.15) $ (0.27) $ (0.31) $ (1.14) Weighted average number of limited partner units outstanding, basic: Common units 16,692 16,702 16,706 16,756 Subordinated units 12,397 12,397 12,397 12,393 Weighted average number of limited partner units outstanding, diluted: Common units 16,692 16,702 16,706 16,756 Subordinated units 12,397 12,397 12,397 12,393 (1) Fourth quarter 201 5 results include approximately $ 27 . 1 million of asset impairment and related charges. (in thousands, except per unit data) First Quarter Second Quarter Third Quarter Fourth Quarter(1) 2014: Revenues $ 59,942 $ 55,886 $ 61,359 $ 61,870 Income from operations (868) (4,445) (6,108) (52,726) Net (loss)/ income from continuing operations (4,966) (6,826) (8,864) (60,636) Income from discontinued operations 130,511 (52) (43) (74) Net (loss)/income $ 125,545 $ (6,878) $ (8,907) $ (60,710) Basic and diluted net (loss)/income per limited partner unit: Common units: Net income per unit from continuing operations $ 0.02 $ (0.05) $ (0.28) $ (2.03) Net income per unit from discontinued operations 4.40 (0.00) (0.00) (0.00) Net income per common unit, basic and diluted $ 4.42 $ (0.05) $ (0.28) $ (2.03) Subordinated units: Net income per unit from continuing operations $ (0.43) $ (0.49) $ (0.33) $ (2.08) Net income per unit from discontinued operations 4.40 (0.00) (0.00) (0.00) Net income per subordinated unit, basic and diluted $ 3.97 $ (0.49) $ (0.33) $ (2.08) Weighted average number of limited partner units outstanding, basic: Common units 16,667 16,677 16,681 16,685 Subordinated units 12,397 12,397 12,397 12,397 Weighted average number of limited partner units outstanding, diluted: Common units 16,673 16,677 16,681 16,685 Subordinated units 12,397 12,397 12,397 12,397 (1) Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership’s equity investment in the Rhino Eastern joint venture.

Summary Of Significant Accoun30

Summary Of Significant Accounting Policies And General (Policies)	12 Months Ended
	Dec. 31, 2015
Summary Of Significant Accounting Policies And General [Abstract]
Company Environment And Risk Factors	Company Environment and Risk Factors. The Partnership, in the course of its business activities, is exposed to a number of risks including: fluctuating market conditions of coal, truck and rail transportation, fuel costs, changing government regulations, unexpected maintenance and equipment failure, employee benefits cost control, changes in estimates of proven and probable coal reserves, as well as the ability of the Partnership to maintain adequate financing, necessary mining permits and control of sufficient recoverable coal properties. In addition, adverse weather and geological conditions may increase mining costs, sometimes substantially.
Trade Receivables And Concentrations Of Credit Risk	Trade Receivables and Concentrations of Credit Risk. See Note 17 for discussion of major customers. The Partnership does not require collateral or other security on accounts receivable. The credit risk is controlled through credit approvals and monitoring procedures. During 2015 and 2014, the Partnership recorded accounts receivable allowances of approximately $0. 5 million and $0.7 million, respectively, in relation to customers that had entered bankruptcy proceedings. The Partnership recorded these allowances based upon its best estimates of the ultimate collectability of the accounts receivable balances through the bankruptcy proceedings of these customers. As of December 31, 2015, the Partnership had accounts receivable allowances of approximately $0.2 million outstanding for remaining accounts that were estimated to be uncollectable.
Cash And Cash Equivalents	Cash and Cash Equivalents. The Partnership considers all highly liquid investments purchased with original maturities of three months or less to be cash equivalents.
Inventories	Inventories. Inventories are stated at the lower of cost, based on a three month rolling average, or market. Inventories primarily consist of coal contained in stockpiles.
Advance Royalties	Advance Royalties. The Partnership is required, under certain royalty lease agreements, to make minimum royalty payments whether or not mining activity is being performed on the leased property. These minimum payments may be recoupable once mining begins on the leased property. The Partnership capitalizes the recoupable minimum royalty payments and amortizes the deferred costs once mining activities begin on the units-of-production method or expenses the deferred costs when the Partnership has ceased mining or has made a decision not to mine on such property.
Note Receivable	Notes Receivable. In December 2015, the Partnership completed the sale of the Deane mining complex located in Central Appalachia (see Note 6 for further details on the Deane mining complex sale). The Partnership received $2.0 million for the Deane mining complex sale in the form of a note receivable from the third-party purchaser. The note receivable bears interest at an annual rate of 6% and has a maturity date of December 31, 2017. The note receivable was recorded in the Other non-current assets line of the Partnership’s consolidated statements of financial positon. In August 2011, the Partnership closed on an agreement to sell and assign certain non-core mining assets and related liabilities located in the Phelps, KY area to a third party. The mining assets included leasehold interests and permits to surface and mineral interests that included steam coal reserves and non-reserve coal deposits. Additionally, the sales agreement included the potential for additional payments of approximately $8.75 million dependent upon certain future contingencies. Rhino recorded the sale of the assets and transfer of liabilities in the third quarter of 2011, but did not record any of the potential $8.75 million consideration since this amount relied on future contingent conditions to be met before it could be recognized. In 2014, the third party entered negotiations with the Partnership regarding the payment of the $8.75 million consideration as the third party anticipated the contingencies would be met in the near future. The third party negotiated with the Partnership to accept a note receivable in lieu of immediate payment since the third party did not have the available funds to pay the $8.75 million consideration. The Partnership believes the collection of the $8.75 million is in doubt due to the necessity of the third party to request a note receivable and the belief that the third party will not be able to economically mine this property for an extended period due to the lack of certain mining permits. Based on the uncertainty of collection of the note receivable, the Partnership recorded a note receivable balance along with a corresponding allowance against the entire $8.75 mi llion note receivable balance. During 2015 and 2014, the Partnership received approximately $0.6 million and $0.3 million, respectively, in payments related to this note receivable and the balance at December 31, 2015 was $7.9 million, which remained fully reserved based on the factors discussed above.
Property, Plant And Equipment	Property, Plant and Equipment. Property, pla nt, and equipment, including coal properties, oil and natural gas properties, mine development costs and construction costs, are recorded at cost, which includes construction overhead and interest, where applicable. Expenditures for major renewals and betterments are capitalized, while expenditures for maintenance and repairs are expensed as incurred. Mining and other equipment and related facilities are depreciated using the straight-line method based upon the shorter of estimated useful lives of the assets or the estimated life of each mine. Coal properties are depleted using the units-of-production method, based on estimated proven and probable reserves. Mine development costs are amortized using the units-of-production method, based on estimated proven and probable reserves. The Partnership assumes zero salvage values for its property, plant and equipment when depreciation and amortization are calculated. Gains or losses arising from sales or retirements are included in current operations. Stripping costs incurred in the production phase of a mine for the removal of overburden or waste materials for the purpose of obtaining access to coal that will be extracted are variable production costs that are included in the cost of inventory produced and extracted during the period the stripping costs are incurred. The Partnership defines a surface mine as a location where the Partnership utilizes operating assets necessary to extract coal, with the geographic boundary determined by property control, permit boundaries, and/or economic threshold limits. Multiple pits that share common infrastructure and processing equipment may be located within a single surface mine boundary, which can cover separate coal seams that typically are recovered incrementally as the overburden depth increases. In accordance with the accounting guidance for extractive mining activities, the Partnership defines a mine in production as one from which saleable minerals have begun to be extracted (produced) from an ore body, regardless of the level of production; however, the production phase does not commence with the removal of de minimis saleable mineral material that occurs in conjunction with the removal of overburden or waste material for the purpose of obtaining access to an ore body. The Partnership capitalizes only the development cost of the first pit at a mine site that may include multiple pits.
Asset Impairments For Coal Properties, Mine Development Costs And Other Coal Mining Equipment And Related Facilities	Asset Impairments for Coal Properties, Mine Development Costs and Other Coal Mining Equipment and Related Facilities. The Partnership follows the accounting guidance in Accounting Standards Codification (“ASC”) 360 , Property, Plant and Equipment, on the impairment or disposal of property, plant and equipment for its coal mining assets, which requires that projected future cash flows from use and disposition of assets be compared with the carrying amounts of those assets when potential impairment is indicated. When the sum of projected undiscounted cash flows is less than the carrying amount, impairment losses are recognized. In determining such impairment losses, the Partnership must determine the fair value for the coal mining assets in question in accordance with the applicable fair value accounting guidance. Once the fair value is determined, the appropriate impairment loss must be recorded as the difference between the carrying amount of the coal mining assets and their respective fair values. Also, in certain situations, expected mine lives are shortened because of changes to planned operations or changes in coal reserve estimates. When that occurs and it is determined that the mine’s underlying costs are not recoverable in the future, reclamation and mine closing obligations are accelerated and the mine closing accrual is increased accordingly. To the extent it is determined that coal asset carrying values will not be recoverable during a shorter mine life, a provision for such impairment is recognized. During 2015 and 2014, the Partnership recorded $ 31.1 million and $45.3 million, respectively, of asset impairment losses and related charges associated with multiple coal properties that are further described in Note 6 . The Partnership also recorded an impairment charge of $0.5 million during 2015 related to intangible assets that are discussed further in Note 7. The asset impairment losses and related charges are recorded on the Asset impairment and related charges line of the Partnership’s consolidated statements of operations and comprehensive income. The Partnership also recorded an impairment charge of $5.9 million during 2014 related to the Partnership’s equity investment in the Rhino Eastern joint venture that is discussed further in Note 3. The impairment charge for the Rhino Eastern joint venture is recorded on the Equity in net (loss)/income of unconsolidated affiliates line of the Partnership’s consolidated statements of operations and comprehensive income.
Debt Issuance Costs	Debt Issuance Costs. Debt issuance costs reflect fees incurred to obtain financing and are amortized (included in interest expense) using the effective interest method over the life of the related debt. Debt issuance costs are included in Prepaid expenses and other current assets as of December 31, 2015 since the Partnership classified its credit facility balance as a current liability (see Note 1). As of December 31, 2014, debt issuance costs were included in other non-current assets. 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. In April 2015, the Partnership entered into a third amendment of its amended and restated senior secured credit facility that further reduced the borrowing commitment to $100 million. As part of executing the third amendment to the amended and restated senior secured credit facility, the Operating Company paid a fee of approximately $2.1 million to the lenders in April 2015, which was recorded as an addition to Debt issuance costs. The Partnership wrote-off approximately $0.2 million of its remaining unamortized debt issuance costs since the third amendment further reduced the borrowing commitment under the amended and restated senior secured credit facility . See Note 10 for further information on the amendment to the amended and restated senior secured credit facility.
Asset Retirement Obligations	Asset Retirement Obligations. The accounting guidance for asset retirement obligations addresses asset retirement obligations that result from the acquisition, construction or normal operation of long-lived assets. This guidance requires companies to recognize asset retirement obligations at fair value when the liability is incurred or acquired. Upon initial recognition of a liability, an amount equal to the liability is capitalized as part of the related long-lived asset and allocated to expense over the useful life of the asset. The Partnership has recorded the asset retirement costs for its mining operations in coal properties. The Partnership estimates its future cost requirements for reclamation of land where it has conducted surface and underground mining operations, based on its interpretation of the technical standards of regulations enacted by the U.S. Office of Surface Mining, as well as state regulations. These costs relate to reclaiming the pit and support acreage at surface mines and sealing portals at underground mines. Other reclamation costs are related to refuse and slurry ponds, as well as holding and related termination/exit costs. The Partnership expenses contemporaneous reclamation which is performed prior to final mine closure. The establishment of the end of mine reclamation and closure liability is based upon permit requirements and requires significant estimates and assumptions, principally associated with regulatory requirements, costs and recoverable coal reserves. Annually, the Partnership reviews its end of mine reclamation and closure liability and makes necessary adjustments, including mine plan and permit changes and revisions to cost and production levels to optimize mining and reclamation efficiency. When a mine life is shortened due to a change in the mine plan, mine closing obligations are accelerated, the related accrual is increased and the related asset is reviewed for impairment, accordingly. The adjustments to the liability from annual recosting reflect changes in expected timing, cash flow and the discount rate used in the present value calculation of the liability. Each respective year includes a range of discount rates that are dependent upon the timing of the cash flows of the specific obligations. Changes in the asset retirement obligations for the year ended December 31, 201 5 were calculated with discount rates that ranged from 2.9% to 5.9% . Changes in the asset retirement obligations for the year ended December 31, 2014 were calculated with discount rates that ranged from 1.6% to 5.3% . The discount rates changed in each respective year due to changes in applicable market indicators that are used to arrive at an appropriate discount rate. Other recosting adjustments to the liability are made annually based on inflationary cost increases or decreases and changes in the expected operating periods of the mines. The related inflation rate utilized in the recosting adjustments was 2.3 % for 201 5 and 201 4 .
Workers' Compensation Benefits	Workers’ Compensation Benefits. Certain of the Partnership’s subsidiaries are liable under federal and state laws to pay workers’ compensation and coal workers’ pneumoconiosis (“black lung”) benefits to eligible employees, former employees and their dependents. The Partnership currently utilizes an insurance program and state workers’ compensation fund participation to secure its on-going obligations depending on the location of the operation. Premium expense for workers’ compensation benefits is recognized in the period in which the related insurance coverage is provided. The Partnership’s black lung benefit liability is calculated using the service cost method that considers the calculation of the actuarial present value of the estimated black lung obligation. The actuarial calculations using the service cost method for the Partnership’s black lung benefit liability are based on numerous assumptions including disability incidence, medical costs, mortality, death benefits, dependents and interest rates. In addition, the Partnership’s liability for traumatic workers’ compensation injury claims is the estimated present value of current workers' compensation benefits, based on actuarial estimates. The actuarial estimates for the Partnership’s workers’ compensation liability are based on numerous assumptions including claim development patterns, mortality, medical costs and interest rates. See Note 12 for more information on the Partnership’s workers’ compensation and black lung liabilities and expense.
Revenue Recognition	Revenue Recognition. Most of the Partnership’s revenues are generated under long-term coal sales contracts with electric utilities, industrial companies or other coal-related organizations, primarily in the eastern United States. Revenue is recognized and recorded when shipment or delivery to the customer has occurred, prices are fixed or determinable and the title or risk of loss has passed in accordance with the terms of the sales agreement. Under the typical terms of these agreements, risk of loss transfers to the customers at the mine or port, when the coal is loaded on the rail, barge, truck or other transportation source that delivers coal to its destination. Advance payments received are deferred and recognized in revenue as coal is shipped and title has passed. Coal sales revenues also result from the sale of brokered coal produced by others. The revenues related to brokered coal sales are included in coal sales revenues on a gross basis and the corresponding cost of the coal from the supplier is recorded in cost of coal sales in accordance with the revenue recognition accounting guidance on principal agent considerations. Freight and handling costs paid directly to third ‑party carriers and invoiced to coal customers are recorded as freight and handling costs and freight and handling revenues, respectively. Other revenues generally consist of coal royalty revenues, limestone sales, coal handling and processing, oil and natural gas royalty revenues, rebates and rental income. Coal royalty revenues are recognized on the basis of tons of coal sold by the Partnership’s lessees and the corresponding gross revenues from those sales. The leases are based on (1) minimum monthly or annual payments, (2) a minimum dollar royalty per ton and/or a percentage of the gross sales price, or (3) a combination of both. Coal royalty revenues are recorded from royalty reports submitted by the lessee, which are reconciled and subject to audit by the Partnership. Most of the Partnership’s lessees are required to make minimum monthly or annual royalty payments that are recoupable over certain time periods, generally two years. If tonnage royalty revenues do not meet the required minimum amount, the difference is paid as a deficiency. These deficiency payments received are recognized as an unearned revenue liability because they are generally recoupable over certain time periods. When a lessee recoups a deficiency payment through production, the recouped amount is deducted from the unearned revenue liability and added to revenue attributable to the coal royalty revenue in the current period. If a lessee does not recoup a deficiency paid during the allocated time period, the recoupment right lost becomes revenue in the current period and is deducted from the liability. With respect to other revenues recognized in situations unrelated to the shipment of coal or coal royalties, the Partnership carefully reviews the facts and circumstances of each transaction and does not recognize revenue until the following criteria are met: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the seller’s price to the buyer is fixed or determinable and collectibility is reasonably assured. Advance payments received are deferred and recognized in revenue when earned.
Equity-Based Compensation	Equity ‑Based Compensation. The Partnership applies the provisions of ASC Topic 718 to account for any unit awards granted to employees or directors. This guidance requires that all share ‑based payments to employees or directors, including grants of stock options, be recognized in the financial statements based on their fair value. The General Partner has currently granted restricted units and phantom units to directors and certain employees of the General Partner and Partnership that contain only a service condition. The fair value of each restricted unit and phantom unit award was calculated using the closing price of the Partnership’s common units on the date of grant. T he Compensation Committee of the board of directors of the General Partner has historically elected to pay some of the awards in cash or a combination of cash and common units. This policy has resulted in all employee awards being classified as liabilit ies and , t hus, the employee awards are required to be marked-to-market each reporting period until they are vested. Restricted unit awards granted to directors of the General Partner are considered nonemployee equity ‑based awards since the directors are not elected by unitholders. Thus, these director awards are also required to be marked-to-market each reporting period until they are vested. Expense related to unit awards is recorded in the selling, general and administrative line of the Partnership’s consolidated statements of operations and comprehensive income.
Derivative Financial Instruments	Derivative Financial Instruments. On occasion, the Partnership has use d diesel fuel contracts to manage the risk of fluctuations in the cost of diesel fuel. The Partnership’s diesel fuel c ontracts have met the requirements for the normal purchase normal sale (“NPNS”) exception prescribed by the accounting guidance on derivatives and hedging, based on management’s intent and ability to take physical delivery of the diesel fuel. The Partnership did not have any diesel fuel contracts as of December 31, 2015.
Investments In Unconsolidated Affiliates	Investments in Joint Ventures. Investments in joint ventures are accounted for using the equity method or cost basis depending upon the level of ownership, the Partnership’s ability to exercise significant influence over the operating and financial policies of the investee and whether the Partnership is determined to be the primary beneficiary of a variable interest entity. Equity investments are recorded at original cost and adjusted periodically to recognize the Partnership’s proportionate share of the investees’ net income or losses after the date of investment. Any losses from the Partnership’s equity method investment are absorbed by the Partnership based upon its proportionate ownership percentage. If losses are incurred that exceed the Partnership’s investment in the equity method entity, then the Partnership must continue to record its proportionate share of losses in excess of its investment. Investments are written down only when there is clear evidence that a decline in value that is other than temporary has occurred. In May 2008, the Operating Company entered into a joint venture, Rhino Eastern, with an affiliate of Patriot to acquire the Eagle mining complex. To initially capitalize the Rhino Eastern joint venture, the Operating Company contributed approximately $ 16.1 million for a 51 % ownership interest in the joint venture and accounted for the investment in Rhino Eastern 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 21, “Segment Information.” On December 31, 2014, the Partnership entered into an agreement with a wholly owned subsidiary of Patriot that effectively terminated the Rhino Eastern joint venture. This agreement officially closed in January 2015 and is described further in Note 3. T he Partnership determined it was not the primary beneficiary of the variable interest entity for the year ended December 31, 2014 by performing a qualitative and quantitative analysis based on the controlling economic interests of the Rhino Eastern joint venture. This included an analysis of the expected economic contributions of the joint venture. The Partnership concluded that it was not the primary beneficiary of Rhino Eastern primarily because of certain contractual arrangements by the joint venture with Patriot and the fact that the Rhino Eastern joint venture was managed by a committee of an equal number of representatives from Patriot and us. As of December 31, 2014, the Partnership recorded its equity method investment of $ 13.2 million in the Rhino Eastern joint venture as a long-term asset. See Note 3 for a discussion of the impairment charge incurred on the Partnership’s equity method investment as of December 31, 2014. During 2014, the Partnership contributed additional capital based upon its ownership share to the Rhino Eastern joint venture in the amount of $4.8 million . 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. Muskie was formed to provide sand for fracking operations to drillers in the Utica Shale region and other oil and natural gas basins in the U nited S tates . During 2014, the Partnership contributed additional capital based upon its ownership share to the Muskie joint venture in the amount of $0.2 million. As disclosed in Note 19 “Related Party and Affiliate Transactions”, during 2013 the Partnership provided a loan to Muskie totaling approximately $0.2 million which 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. Prior to the Partnership’s contribution of Muskie to Mammoth, the Partnership recorded its proportionate portion of Muskie’s operating loss for 2014 of approximately $ 0.1 million. As of December 31, 2015 and 2014, 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. See Note 21 for information on the Partnership’s reportable segments. 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. 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 this joint venture and results of operations under the equity method based upon its ownership percentage. The Partnership recorded its proportionate portion of the operating income for this investment during 2015 and 2014 of approximately $0.3 million and $0.4 million , respectively . The Partnership has recorded its investment in Sturgeon on the Investment in unconsolidated affiliates line of the Partnership’s consolidated statements of financial position. The Partnership has included its investment in Sturgeon in its Other category for segment reporting purposes .
Income Taxes	Income Taxes. The Partnership is considered a partnership for income tax purposes. Accordingly, the partners report the Partnership’s taxable income or loss on their individual tax returns.
Loss Contingencies	Loss Contingencies. In accordance with the guidance on accounting for contingencies, the Partnership records loss contingencies at such time that an unfavorable outcome becomes probable and the amount can be reasonably estimated. When the reasonable estimate is a range, the recorded loss is the best estimate within the range. If no amount in the range is a better estimate than any other amount, the minimum amount of the range is recorded. The Partnership discloses information concerning loss contingencies for which an unfavorable outcome is probable. See Note 15, “Commitments and Contingencies,” for a discussion of such matters.
Management's Use Of Estimates	Management’s Use of Estimates. The preparation of consolidated financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements as well as the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Recently Issued Accounting Standards	Recently Issued Accounting Standards. In 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. In July 2015, the FASB approved to defer the effective date of ASU 2014-09 by one year. Accordingly, ASU 2014-09 will be effective for public entities for annual reporting periods beginning after December 15, 2017 and interim periods therein. 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”. ASC 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 adoption of ASU 2015-0 3 on January 1, 2016 is not expected to have a n impact on the Partnership’s financial statements.

Prepaid Expenses And Other Cu31

Prepaid Expenses And Other Current Assets (Tables)	12 Months Ended
	Dec. 31, 2015
Prepaid Expenses And Other Current Assets [Abstract]
Schedule Of Prepaid Expenses And Other Current Assets	December 31, 2015 2014 (in thousands) Other prepaid expenses $ 682 $ 827 Debt issuance costs—net 2,155 - Prepaid insurance 1,492 2,063 Prepaid leases 80 87 Supply inventory 901 827 Deposits 164 170 Total $ 5,474 $ 3,974

Property, Plant And Equipment (

Property, Plant And Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
Property, Plant And Equipment [Abstract]
Property, Plant And Equipment By Major Classification	December 31, Useful Lives 2015 2014 (in thousands) Land and land improvements $ 24,157 $ 18,845 Mining and other equipment and related facilities 2 - 20 Years 306,609 336,951 Mine development costs 1 - 15 Years 67,277 79,536 Coal properties 1 - 15 Years 203,791 215,325 Oil and natural gas properties - 8,093 Construction work in process 2,680 4,912 Total 604,514 663,662 Less accumulated depreciation, depletion and amortization (271,007) (280,225) Net $ 333,507 $ 383,437
Depreciation, Depletion, And Amortization	Year Ended December 31, 2015 2014 (in thousands) Depreciation expense-mining and other equipment and related facilities $ 28,740 $ 30,529 Depletion expense for coal properties 2,871 4,633 Depletion expense for oil and natural gas properties 9 60 Amortization expense for mine development costs 1,935 1,737 Amortization expense for intangible assets 76 80 Amortization expense for asset retirement costs (450) 194 Total $ 33,181 $ 37,233

Goodwill And Intangible Assets

Goodwill And Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2015
Goodwill And Intangible Assets [Abstract]
Schedule Of Intangible Assets By Major Class	Intangible assets of the Partnership as of December 31, 201 5 consisted of the following: Gross Net Carrying Accumulated Carrying Intangible Asset Amount Amortization Amount (in thousands) Patent $ - $ - $ - Developed Technology - - - Trade Name 184 42 142 Customer List 470 107 363 Total $ 654 $ 149 $ 505 Intangible assets of the Partnership as of December 31, 201 4 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	Customer Trade Name List Total (in thousands) 2016 $ 9 $ 23 $ 32 2017 9 23 32 2018 9 23 32 2019 9 23 32 2020 9 23 32

Other Non-Current Assets (Table

Other Non-Current Assets (Tables)	12 Months Ended
	Dec. 31, 2015
Other Non-Current Assets [Abstract]
Schedule Of Other Non-Current Assets	December 31, 2015 2014 (in thousands) Deposits and other $ 138 $ 347 Debt issuance costs—net - 1,513 Non-current receivable 23,908 14,237 Note receivable 2,000 - Deferred expenses 261 313 Total $ 26,307 $ 16,410

Accrued Expenses And Other Cu35

Accrued Expenses And Other Current Liabilities (Tables)	12 Months Ended
	Dec. 31, 2015
Accrued Expenses And Other Current Liabilities [Abstract]
Schedule Of Accrued Expenses And Other Current Liabilities	December 31, 2015 2014 (in thousands) Payroll, bonus and vacation expense $ 1,447 $ 2,876 Non-income taxes 3,774 4,323 Royalty expenses 1,566 1,772 Accrued interest 575 385 Health claims 817 1,270 Workers’ compensation & pneumoconiosis 1,150 1,500 Deferred revenues 2,260 4,050 Accrued insured litigation claims 266 489 Other 2,247 669 Total $ 14,102 $ 17,334

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt [Abstract]
Schedule Of Debt	December 31, 2015 2014 (in thousands) Senior secured credit facility with PNC Bank, N.A. $ 41,200 $ 54,450 Other notes payable 2,874 2,982 Total 44,074 57,432 Less current portion (41,479) (210) Long-term debt $ 2,595 $ 57,222
Schedule Of Principal Payments On Long-Term Debt	in thousands 2016 $ 41,479 2017 240 2018 257 2019 275 2020 295 Thereafter 1,528 Total principal payments $ 44,074

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligations [Abstract]
Schedule Of Asset Retirement Obligations	Year Ended December 31, 2015 2014 (in thousands) Balance at beginning of period (including current portion) $ 29,883 $ 34,451 Accretion expense 2,082 2,281 Adjustment resulting from addition of property 1,235 - Adjustment resulting from disposal of property (1) (6,861) (2,310) Adjustments to the liability from annual recosting and other (2,078) (1,324) Reclassification to held for sale - (2,250) Liabilities settled (514) (965) Balance at end of period 23,747 29,883 Less current portion of asset retirement obligation (767) (1,431) Long-term portion of asset retirement obligation $ 22,980 $ 28,452 (1) The ($6.9) million adjustment for the year ended December 31, 2015 relates to the sale of the Partnership’s Deane mining complex discussed in Note 6. 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.

Workers' Compensation And Bla38

Workers' Compensation And Black Lung (Tables)	12 Months Ended
	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Summary Of Black Lung And Workers' Compensation Expenses	Year Ended December 31, 2015 2014 (in thousands) Service costs $ 254 $ 297 Interest cost 191 236 Amortization of prior service cost (2,626) - Amortization of (gain) (782) (368) Benefit cost $ (2,963) $ 165
Classification Of Net Amounts Recognized For Workers' Compensation And Black Lung Benefits	December 31, 2015 2014 (in thousands) Current liability—postretirement benefits $ (45) $ (425) Non-current liability—postretirement benefits - (6,223) Net amount recognized $ (45) $ (6,648)
Workers' Compensation And Black Lung Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Summary Of Black Lung And Workers' Compensation Expenses	Year Ended December 31, 2015 2014 Black lung benefits: (in thousands) Service cost $ (991) $ 1,040 Interest cost 397 357 Actuarial loss/(gain) - 1,625 Total black lung (594) 3,022 Workers' compensation expense 4,334 1,197 Total expense $ 3,740 $ 4,219
Classification Of Net Amounts Recognized For Workers' Compensation And Black Lung Benefits	December 31, 2015 2014 (in thousands) Black lung claims $ 9,225 $ 10,033 Insured black lung and workers' compensation claims 23,907 14,237 Workers' compensation claims 6,210 5,172 Total obligations $ 39,342 $ 29,442 Less current portion (1,150) (1,500) Non-current obligations $ 38,192 $ 27,942
Black Lung Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Changes In Benefit Liability	Year Ended December 31, 2015 2014 (in thousands) Benefit obligations at beginning of year $ 10,033 $ 7,251 Service cost (991) 1,040 Interest cost 397 357 Actuarial loss/(gain) - 1,625 Benefits and expenses paid (214) (240) Benefit obligations at end of year $ 9,225 $ 10,033

Employee Benefits (Tables)

Employee Benefits (Tables)	12 Months Ended
	Dec. 31, 2015
Employee Benefits [Abstract]
Summary Of Changes In Benefit Obligations	Year Ended December 31, 2015 2014 (in thousands) Benefit obligation at beginning of period $ 6,648 $ 6,120 Changes in benefit obligations: Service costs 254 297 Interest cost 191 236 Benefits paid (217) (495) Plan amendment (6,503) - Actuarial loss/(gain) (328) 490 Benefit obligation at end of period $ 45 $ 6,648 Fair value of plan assets at end of period $ - $ - Funded status $ (45) $ (6,648)
Classification Of Net Amounts Recognized For Postretirement Benefits	December 31, 2015 2014 (in thousands) Current liability—postretirement benefits $ (45) $ (425) Non-current liability—postretirement benefits - (6,223) Net amount recognized $ (45) $ (6,648)
Amounts Recognized In Accumulated Other Comprehensive Income	Year Ended December 31, 2015 2014 (in thousands) Balance at beginning of year $ 1,373 $ 2,231 Actuarial (loss)/gain 328 (490) Prior service (cost)/gain to be amortized 3,876 - Amortization of net actuarial gain (782) (368) Net actuarial gain $ 4,795 $ 1,373
Weighted Average Assumptions Used To Determine Benefit Obligations	December 31, 2015 2014 Weighted Average assumptions used to determine benefit obligations: Discount rate n/a 3.15% Expected return on plan assets n/a n/a
Weighted Average Assumptions Used To Determine Net Periodic Benefit Cost	Year Ended December 31, 2015 2014 Weighted Average assumptions used to determine periodic benefit cost: Discount rate (1) 3.15% 3.96% Expected return on plan assets n/a n/a Rate of compensation increase n/a n/a
Components Of Net Periodic Benefit Cost	Year Ended December 31, 2015 2014 (in thousands) Service costs $ 254 $ 297 Interest cost 191 236 Amortization of prior service cost (2,626) - Amortization of (gain) (782) (368) Benefit cost $ (2,963) $ 165
Amounts Expected To Be Amortized From Accumulated Other Comprehensive Income Into Net Periodic Benefit Cost	(in thousands) Net actuarial gain $ 4,795
Schedule Of Expense Under Defined Contribution Savings Plans	Year Ended December 31, 2015 2014 (in thousands) 401(k) plan expense $ 2,027 $ 2,227

Equity-Based Compensation (Tabl

Equity-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
Equity-Based Compensation [Abstract]
Summary Of Non-Vested LTIP Awards	Common Units Weighted Average Grant Date Fair Value (per unit) (in thousands) Non-vested awards at December 31, 2013 55 $ 14.63 Granted 46 $ 12.32 Vested (34) $ 13.95 Forfeited (16) $ 13.01 Non-vested awards at December 31, 2014 51 $ 13.50 Granted 247 $ 1.06 Vested (86) $ 5.68 Forfeited (8) $ 6.43 Non-vested awards at December 31, 2015 204 $ 2.00

Commitments And Contingencies (

Commitments And Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments And Contingencies [Abstract]
Schedule Of Delivery Commitments	Year Tons (in thousands) Number of customers 2016 3,255 14 2017 1,914 8 2018 264 1
Schedule Of Purchased Coal Expenses	Year Ended December 31, 2015 2014 (in thousands) Purchased coal expense $ (26) $ 6,168 OTC expense $ - $ -
Schedule Of Lease And Royalty Expense	Year Ended December 31, 2015 2014 (in thousands) Lease expense $ 6,204 $ 3,478 Royalty expense $ 10,754 $ 11,571
Future Minimum Lease And Royalty Payments	Years Ended December 31, Royalties Leases (in thousands) 2016 $ 2,824 3,664 2017 2,466 1,097 2018 2,436 148 2019 2,436 - 2020 2,556 - Thereafter 12,780 - Total minimum royalty and lease payments $ 25,498 $ 4,909

Earnings Per Unit ("EPU") (Tabl

Earnings Per Unit ("EPU") (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Unit ("EPU") [Abstract]
Schedule Of Calculation Of Numerator And Denominator In Earnings Per Share	Year ended December 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 $ (1,119) $ (31,491) $ (23,356) Net income from discontinued operations 14 406 302 Interest in net income $ (1,105) $ (31,085) $ (23,054) Impact of subordinated distribution suspension: Net income/(loss) from continuing operations $ 5 $ 139 $ (144) Net income from discontinued operations - - - Interest in net income $ 5 $ 139 $ (144) Interest in net (loss)/income for EPU purposes: Net (loss) from continuing operations $ (1,114) $ (31,352) $ (23,500) Net income from discontinued operations 14 406 302 Interest in net income $ (1,100) $ (30,946) $ (23,198) Denominator: Weighted average units used to compute basic EPU n/a 16,714 12,396 Effect of dilutive securities — LTIP awards n/a - - Weighted average units used to compute diluted EPU n/a 16,714 12,396 Net (loss)/income per limited partner unit, basic: Net (loss) per unit from continuing operations n/a $ (1.87) $ (1.89) Net income per unit from discontinued operations n/a 0.02 0.02 Net income per limited partner unit, basic n/a $ (1.85) $ (1.87) Net (loss)/income per limited partner unit, diluted: Net (loss) per unit from continuing operations n/a $ (1.87) $ (1.89) Net income per unit from discontinued operations n/a 0.02 0.02 Net income per limited partner unit, diluted n/a $ (1.85) $ (1.87) Year ended December 31, 2014 General Partner Common Unitholders Subordinated Unitholders Numerator: (in thousands, except per unit data) Interest in net income (as previously reported): Net income from continuing operations $ (1,626) $ (45,705) $ (33,962) Net income from discontinued operations 2,607 73,271 54,464 Interest in net income $ 981 $ 27,566 $ 20,502 Impact of subordinated distribution suspension: Net income/(loss) from continuing operations $ 245 $ 6,908 $ (7,153) Net income from discontinued operations - - - Interest in net income/(loss) $ 245 $ 6,908 $ (7,153) Interest in net income/(loss) for EPU purposes (as restated): Net income/(loss) from continuing operations $ (1,381) $ (38,797) $ (41,115) Net income from discontinued operations 2,607 73,271 54,464 Interest in net income/(loss) $ 1,226 $ 34,474 $ 13,349 Denominator: Weighted average units used to compute basic EPU n/a 16,678 12,397 Effect of dilutive securities — LTIP awards n/a 7 - Weighted average units used to compute diluted EPU n/a 16,685 12,397 Net income per limited partner unit, basic: Net income per unit from continuing operations n/a $ (2.32) $ (3.31) Net income per unit from discontinued operations n/a 4.39 4.39 Net income per limited partner unit, basic n/a $ 2.07 $ 1.08 Net income per limited partner unit, diluted: Net income per unit from continuing operations n/a $ (2.32) $ (3.31) Net income per unit from discontinued operations n/a 4.39 4.39 Net income per limited partner unit, diluted n/a $ 2.07 $ 1.08

Major Customers (Tables)

Major Customers (Tables)	12 Months Ended
	Dec. 31, 2015
Major Customers [Abstract]
Major Customers	December 31, 2015 Receivable Balance Year Ended December 31, 2015 Sales December 31, 2014 Receivable Balance Year Ended December 31, 2014 Sales (in thousands) NRG Energy Inc. (fka GenOn Energy, Inc.) $ - $ 22,111 $ 2,932 $ 31,605 PPL Corporation 1,881 33,662 2,053 24,542 PacifiCorp Energy 1,969 21,519 n/a n/a

Related Party And Affiliate T44

Related Party And Affiliate Transactions (Tables)	12 Months Ended
	Dec. 31, 2015
Related Party And Affiliate Transactions [Abstract]
Schedule Of Related Party And Affiliate Transactions	Related Party Description 2015 2014 (in thousands) Wexford Capital LP Expenses for legal, consulting, and advisory services $ 143 $ 131 Wexford Capital LP Distributions paid 553 10,949 Wexford Capital LP Partner's contribution 2 6 Rhino Eastern LLC Equity in net (loss)/income of unconsolidated affiliate - (12,089) Rhino Eastern LLC Expenses for legal, health claims, workers' compensation and other expenses - 4,610 Rhino Eastern LLC Receivable for legal, health claims and workers’ compensation and other expenses - 223 Rhino Eastern LLC Investment in unconsolidated affiliate - 13,151 Timber Wolf Terminals LLC Investment in unconsolidated affiliate 130 130 Muskie Proppant LLC Investment in unconsolidated affiliate - - Mammoth Energy Partners LP Investment in unconsolidated affiliate 1,933 1,933 Sturgeon Acquisitions LLC Investment in unconsolidated affiliate 5,515 5,440 Sturgeon Acquisitions LLC Distributions from unconsolidated affiliate 232 - Sturgeon Acquisitions LLC Return of capital from unconsolidated affiliate 35 - Sturgeon Acquisitions LLC Equity in net income of unconsolidated affiliate 342 440

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Information [Abstract]
Reportable Segment Results Of Operations	Reportable segment results of operations and financial position for the year ended December 31, 201 5 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization): Central Appalachia Northern Appalachia Rhino Western Illinois Basin Other Total Consolidated (in thousands) Total assets $ 227,880 $ 17,218 $ 37,198 $ 82,700 $ 39,671 $ 404,667 Total revenues 67,942 63,273 35,322 38,641 1,568 206,746 DD&A 12,641 7,562 6,314 5,928 736 33,181 Interest expense 2,040 522 315 597 1,527 5,001 Net Income (loss) from continuing operations $ (14,212) $ (20,487) $ (4,560) $ (13,807) $ (2,900) $ (55,966) Reportable segment results of operations and financial position for the year ended December 31, 201 4 are as follows: Eastern Met Central Appalachia Northern Appalachia Rhino Western Illinois Basin Complete Basis Equity Method Eliminations Equity Method Presentation * Other Total Consolidated (in thousands) Total assets $ 247,362 $ 52,822 $ 42,173 $ 80,126 $ 42,100 $ (42,100) $ - $ 50,855 $ 473,338 Total revenues 109,432 71,472 44,081 9,755 21,722 (21,722) - 4,317 239,057 DD&A 20,224 7,574 6,021 2,286 1,860 (1,860) - 1,128 37,233 Interest expense 2,055 473 329 343 81 (81) - 2,508 5,708 Net Income (loss) from continuing operations $ (33,019) $ 2,101 $ (22,822) $ (6,411) $ (12,208) $ 5,982 $ (12,089) $ (9,053) $ (81,293) * For the year ended December 31, 2014, the equity method net loss from continuing operations for Rhino Eastern includes the $5.9 million impairment charge for the joint venture that was discussed earlier.
Equity Method Investments, Summarized Financial Information	2015 2014 (Unaudited) (in thousands) Current assets $ - $ 3,641 Noncurrent assets - 38,459 Current liabilities - 3,629 Noncurrent liabilities - 3,202 Total costs and expenses - 33,850 (Loss)/income from operations - (12,128)
Schedule Of Revenue By Product Category	2015 2014 (in thousands) Met coal revenue $ 15,391 $ 26,058 Steam coal revenue 155,683 176,823 Other revenue 35,672 36,176 Total revenue $ 206,746 $ 239,057

Quarterly Financial Data (Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Data [Abstract]
Schedule Of Quarterly Financial Data	(in thousands, except per unit data) First Quarter Second Quarter Third Quarter Fourth Quarter(1) 2015: Revenues $ 56,184 $ 56,765 $ 54,153 $ 39,644 (Loss) from operations (3,748) (6,959) (7,994) (32,644) Net (loss) from continuing operations (4,562) (8,112) (9,306) (33,986) Income from discontinued operations 722 - - - Net (loss) $ (3,840) $ (8,112) $ (9,306) $ (33,986) Basic and diluted net (loss)/income per limited partner unit: Common units: Net (loss) per unit from continuing operations $ (0.15) $ (0.27) $ (0.31) $ (1.14) Net income per unit from discontinued operations 0.02 - - - Net (loss) per common unit, basic and diluted $ (0.13) $ (0.27) $ (0.31) $ (1.14) Subordinated units: Net (loss) per unit from continuing operations $ (0.17) $ (0.27) $ (0.31) $ (1.14) Net income per unit from discontinued operations 0.02 - - - Net (loss) per subordinated unit, basic and diluted $ (0.15) $ (0.27) $ (0.31) $ (1.14) Weighted average number of limited partner units outstanding, basic: Common units 16,692 16,702 16,706 16,756 Subordinated units 12,397 12,397 12,397 12,393 Weighted average number of limited partner units outstanding, diluted: Common units 16,692 16,702 16,706 16,756 Subordinated units 12,397 12,397 12,397 12,393 (1) Fourth quarter 201 5 results include approximately $ 27 . 1 million of asset impairment and related charges. (in thousands, except per unit data) First Quarter Second Quarter Third Quarter Fourth Quarter(1) 2014: Revenues $ 59,942 $ 55,886 $ 61,359 $ 61,870 Income from operations (868) (4,445) (6,108) (52,726) Net (loss)/ income from continuing operations (4,966) (6,826) (8,864) (60,636) Income from discontinued operations 130,511 (52) (43) (74) Net (loss)/income $ 125,545 $ (6,878) $ (8,907) $ (60,710) Basic and diluted net (loss)/income per limited partner unit: Common units: Net income per unit from continuing operations $ 0.02 $ (0.05) $ (0.28) $ (2.03) Net income per unit from discontinued operations 4.40 (0.00) (0.00) (0.00) Net income per common unit, basic and diluted $ 4.42 $ (0.05) $ (0.28) $ (2.03) Subordinated units: Net income per unit from continuing operations $ (0.43) $ (0.49) $ (0.33) $ (2.08) Net income per unit from discontinued operations 4.40 (0.00) (0.00) (0.00) Net income per subordinated unit, basic and diluted $ 3.97 $ (0.49) $ (0.33) $ (2.08) Weighted average number of limited partner units outstanding, basic: Common units 16,667 16,677 16,681 16,685 Subordinated units 12,397 12,397 12,397 12,397 Weighted average number of limited partner units outstanding, diluted: Common units 16,673 16,677 16,681 16,685 Subordinated units 12,397 12,397 12,397 12,397 (1) Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership’s equity investment in the Rhino Eastern joint venture.

Organization And Basis Of Pre47

Organization And Basis Of Presentation (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Mar. 17, 2016	Sep. 13, 2013	Jul. 18, 2011	Oct. 05, 2010	Apr. 30, 2015	Dec. 31, 2015	Dec. 31, 2014
Basis Of Presentation And Organization Disclosure [Line Items]
Common units issued		1,265	2,875	3,244
Price per unit		$ 12.30	$ 24.50	$ 20.50
Underwriting discounts and offering expenses		$ 1,000	$ 4,100	$ 8,200			$ 2
Proceeds from issuance of common units		14,600	66,400	58,300
Partner contributions		300	1,400	10,400		$ 2	6
Payment of credit facility		$ 14,900	$ 67,800	69,400		$ 107,650	282,630
Payments to reimburse sponsor for capital expenditures				$ 9,300
Membership interest pledged as collateral				100.00%
Leverage ratio						320.00%
Liquidity						$ 1,100
Current portion of long-term debt						41,479	$ 210
Working capital (deficiency)						$ (36,300)
Third Amendment [Member]
Basis Of Presentation And Organization Disclosure [Line Items]
Line of credit facility, maximum leverage ratio required for extension						275.00%
Line of credit facility, miniumum liquidity					$ 15,000	$ 15,000
Fourth Amendment [Member]
Basis Of Presentation And Organization Disclosure [Line Items]
Line of credit facility, maximum leverage ratio required for extension	675.00%
Current portion of long-term debt						$ 41,200
Underwriters Option To Purchase Additional Units [Member]
Basis Of Presentation And Organization Disclosure [Line Items]
Common units issued		165	375
Rhino Energy Holdings LLC [Member] | Common Units [Member]
Basis Of Presentation And Organization Disclosure [Line Items]
Common units issued				9,153
Rhino Energy Holdings LLC [Member] | Subordinated Units [Member]
Basis Of Presentation And Organization Disclosure [Line Items]
Common units issued				12,397

Summary Of Significant Accoun48

Summary Of Significant Accounting Policies And General (Details) - USD ($) $ in Thousands	1 Months Ended						3 Months Ended										12 Months Ended
	Dec. 31, 2015	Apr. 30, 2015	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2012	May. 31, 2008	Dec. 31, 2015		Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Aug. 31, 2011
Summary Of Significant Accounting Policies [Line Items]
Allowance for doubtful accounts	$ 166						$ 166					$ 724					$ 166	$ 724
Provision for doubtful accounts																	528	724
Principal payments received on notes receivable																		205
Salvage value of property, plant and equipment	0						0										0
Asset impairment and related charges																	$ 31,564	$ 45,296
Recosting adjustment calculation, inflation rate																	2.30%	2.30%
Period for lessee to recoup royalty payments																	2 years
Loss from operations							32,644	[1]	$ 7,994	$ 6,959	$ 3,748	52,726	[2]	$ 6,108	$ 4,445	$ 868	$ 51,345	$ 64,147
Equity in net income (loss) of unconsolidated affiliate																	342	(11,712)
Patent And Developed Technology [Member]
Summary Of Significant Accounting Policies [Line Items]
Asset impairment and related charges																	500
Uncollectible Receivables [Member]
Summary Of Significant Accounting Policies [Line Items]
Allowance for doubtful accounts	200						200										200
Deane Mining Complex [Member]
Summary Of Significant Accounting Policies [Line Items]
Note receivable, gross	$ 2,000						2,000										2,000
Note receivable, interest rate	6.00%
Asset impairment and related charges							1,900		$ 2,300
Phelps Kentucky [Member]
Summary Of Significant Accounting Policies [Line Items]
Note receivable, gross	$ 7,900						7,900					8,750					7,900	8,750
Allowance for notes receivable	$ 8,750						$ 8,750										8,750
Potential additional payments																				$ 8,750
Principal payments received on notes receivable																	$ 600	300
Rhino Eastern LLC [Member]
Summary Of Significant Accounting Policies [Line Items]
Asset impairment and related charges																		5,900
Payments to acquire interest in joint venture						$ 16,100												4,800
Equity method investment												13,200						13,200
Ownership interest equity method investment	51.00%						51.00%										51.00%
Ownership interest						51.00%
Muskie Proppants [Member]
Summary Of Significant Accounting Policies [Line Items]
Payments to acquire interest in joint venture					$ 2,000													200
Loans to joint venture																			$ 200
Equity in net income (loss) of unconsolidated affiliate																		(100)
Sturgeon Acquisitions [Member]
Summary Of Significant Accounting Policies [Line Items]
Payments to acquire interest in joint venture			$ 5,000															5,000
Ownership interest	100.00%						100.00%										100.00%
Equity in net income (loss) of unconsolidated affiliate																	$ 300
Mammoth [Member]
Summary Of Significant Accounting Policies [Line Items]
Equity method investment	$ 1,900						$ 1,900					$ 1,900					$ 1,900	$ 1,900
Minimum [Member]
Summary Of Significant Accounting Policies [Line Items]
Discount rate, present value calculation																	2.90%	1.60%
Maximum [Member]
Summary Of Significant Accounting Policies [Line Items]
Discount rate, present value calculation																	5.90%	5.30%
Second Amendment [Member]
Summary Of Significant Accounting Policies [Line Items]
Credit facility, maximum available				$ 200,000												200,000
Amendment fee				100												$ 100
Unamortized debt issuance costs written off				$ 1,100
Third Amendment [Member]
Summary Of Significant Accounting Policies [Line Items]
Credit facility, maximum available	$ 90,000	$ 100,000					$ 90,000										$ 90,000
Amendment fee		2,100
Unamortized debt issuance costs written off		$ 200
[1]	Fourth quarter 2015 results include approximately $27.1 million of asset impairment and related charges.
[2]	Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership's equity investment in the Rhino Eastern joint venture.

Subsequent Events (Details)

Subsequent Events (Details) - USD ($)

Dec. 31, 2016

Sep. 30, 2016

Jul. 31, 2016

Mar. 21, 2016

Mar. 17, 2016

Jan. 21, 2016

Dec. 31, 2015

Sep. 30, 2016

Dec. 31, 2017

Dec. 31, 2015

Dec. 31, 2014

Dec. 31, 2017

Sep. 13, 2013

Jul. 31, 2011

Jul. 18, 2011

Oct. 05, 2010

Subsequent Event [Line Items]

Cash distribution

[1]

$ 0.070

$ 1.385

Minimum required distributions per unit

$ 0.445

Distribution arrearages outstanding

$ 44,300,000

$ 44,300,000

Payment to acquire interest

$ 10,096,000

Principal payments received on notes receivable

$ 205,000

Price per unit

$ 12.30

$ 24.50

$ 20.50

Liquidity

$ 1,100,000

$ 1,100,000

PRIME [Member]

Subsequent Event [Line Items]

Interest margin in addition to prime

3.50%

Letters of Credit [Member]

Subsequent Event [Line Items]

Credit facility, maximum available

$ 75,000,000

Royal Energy Resources, Inc. [Member] | Scenario, Forecast [Member]

Subsequent Event [Line Items]

Principal payments received on notes receivable

$ 2,000,000

$ 2,000,000

$ 3,000,000

Number of shares available to rescind

13,333,333

Number of shares available for repurchase

13,333,333

13,333,333

Price per unit

$ 0.30

$ 0.30

Fourth Amendment [Member]

Subsequent Event [Line Items]

Line of credit facility, maximum leverage ratio required for extension

675.00%

Fourth Amendment [Member] | Letters of Credit [Member]

Subsequent Event [Line Items]

Credit facility, maximum available

$ 30,000,000

Common Units [Member]

Subsequent Event [Line Items]

Cash distribution

$ 0

Subordinated Units [Member]

Subsequent Event [Line Items]

Cash distribution

$ 0

$ 0

$ 0

Subsequent Event [Member] | Royal Energy Resources, Inc. [Member]

Subsequent Event [Line Items]

Note receivable from issuance of units

$ 7,000,000

Subsequent Event [Member] | Royal Energy Resources, Inc. [Member] | Wexford Capital LP [Member]

Subsequent Event [Line Items]

Payment to acquire interest

$ 3,500,000

Subsequent Event [Member] | Royal Energy Resources, Inc. [Member] | Rhino GP LLC [Member]

Subsequent Event [Line Items]

Payment to acquire interest

1,000,000

Subsequent Event [Member] | Fourth Amendment [Member]

Subsequent Event [Line Items]

Credit facility, maximum available

$ 80,000,000

Interest margin in addition to prime

3.50%

Line of credit facility maximum leverage ratio reduction when threshold met

0.50%

Line of credit facility, threshold for reduction of maximum leverage ratio

$ 10,000,000

Line of credit facility, minimum EBITDA

8,000,000

Line of credit facility, maximum capital expenditures

$ 15,000,000

Subsequent Event [Member] | Fourth Amendment [Member] | PRIME [Member]

Subsequent Event [Line Items]

Interest margin in addition to prime

3.50%

Subsequent Event [Member] | Fourth Amendment [Member] | Letters of Credit [Member]

Subsequent Event [Line Items]

Credit facility, maximum available

$ 30,000,000

Subsequent Event [Member] | Minimum [Member]

Subsequent Event [Line Items]

Line of credit facility, maximum leverage ratio required for extension

300.00%

Subsequent Event [Member] | Minimum [Member] | Fourth Amendment [Member]

Subsequent Event [Line Items]

Liquidity

$ 5,000,000

Line of credit facility, minimum EBITDA

8,000,000

Subsequent Event [Member] | Common Units [Member] | Royal Energy Resources, Inc. [Member]

Subsequent Event [Line Items]

Shares sold

60,000,000

Proceeds from shares issued

2,000,000

Proceeds from and notes receivable related to issuance of common units

$ 9,000,000

Price per unit

$ 0.15

Subsequent Event [Member] | Common Units [Member] | Royal Energy Resources, Inc. [Member] | Wexford Capital LP [Member]

Subsequent Event [Line Items]

Shares sold

6,769,112

Subsequent Event [Member] | Subordinated Units [Member] | Royal Energy Resources, Inc. [Member] | Wexford Capital LP [Member]

Subsequent Event [Line Items]

Shares sold

$ 9,455,252

[1]

No distributions were paid on the subordinated units during 2015 and 2014.

Discontinued Operations (Detail

Discontinued Operations (Details)

1 Months Ended

3 Months Ended

12 Months Ended

Feb. 28, 2015USD ($)

Dec. 31, 2014USD ($)

Mar. 31, 2014USD ($)

Jan. 31, 2014USD ($)entity

Mar. 31, 2015USD ($)

Dec. 31, 2014USD ($)

[1]

Sep. 30, 2014USD ($)

Jun. 30, 2014USD ($)

Mar. 31, 2014USD ($)

Dec. 31, 2015USD ($)

Dec. 31, 2014USD ($)

Dec. 31, 2013USD ($)a

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Income from discontinued operations

$ 722,000

$ (74,000)

$ (43,000)

$ (52,000)

$ 130,511,000

$ 722,000

$ 130,342,000

Blackhawk Midstream, LLC [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Proceeds from the sale of property

$ 700,000

$ 8,400,000

Number of equity interests in entities sold | entity

2

Percentage of payout interest

5.00%

Income from discontinued operations

$ 700,000

8,400,000

Utica Shale Region Of Ohio [Member]

Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]

Cumulative investment in pro rata interest in oil and gas leases

$ 31,100,000

Ownership percentage

5.00%

Gross acreage | a

152,300

Net acreage | a

7,615

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

Sale transaction costs

$ 46,000

Gain (loss) on sale of property

$ 121,700,000

[1]

Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership's equity investment in the Rhino Eastern joint venture.

Prepaid Expenses and Other Cu51

Prepaid Expenses and Other Current Assets (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended
	Apr. 30, 2015	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Prepaid Expenses And Other Current Assets Disclosure [Line Items]
Debt issuance costs, current, gross			$ 11.6
Debt issuance costs, noncurrent, gross				$ 9.1
Accumulated amortization of debt issuance costs, current			9.4
Accumulated amortization of debt issuance costs, noncurrent				$ 7.6
Second Amendment [Member]
Prepaid Expenses And Other Current Assets Disclosure [Line Items]
Credit facility, maximum available		$ 200
Amendment fee		0.1
Unamortized debt issuance costs written off		$ 1.1
Third Amendment [Member]
Prepaid Expenses And Other Current Assets Disclosure [Line Items]
Credit facility, maximum available	$ 100		$ 90
Amendment fee	2.1
Unamortized debt issuance costs written off	$ 0.2

Prepaid Expenses And Other Cu52

Prepaid Expenses And Other Current Assets (Schedule Of Prepaid Expenses And Other Current Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Prepaid Expenses And Other Current Assets [Abstract]
Other prepaid expenses	$ 682	$ 827
Debt issuance costs-net	2,155
Prepaid insurance	1,492	2,063
Prepaid leases	80	87
Supply inventory	901	827
Deposits	164	170
Total Prepaid expenses and other	$ 5,474	$ 3,974

Property, Plant And Equipment53

Property, Plant And Equipment (Narrative) (Details) T in Millions	Dec. 31, 2015USD ($)itemcontract	Dec. 30, 2015USD ($)item	Aug. 31, 2015USD ($)a	Dec. 31, 2015USD ($)itemcontract	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Dec. 31, 2015USD ($)itemcontractT	Dec. 31, 2014USD ($)T	Dec. 31, 2011USD ($)	Dec. 30, 2014USD ($)
Property, Plant and Equipment [Line Items]
Asset impairment and related charges							$ 31,564,000	$ 45,296,000
Property, plant and equipment	$ 333,507,000			$ 333,507,000			333,507,000	383,437,000
Gain on sale of assets							$ 1,014,000	130,621,000
Non-current assets held for sale								9,279,000
Non-current liabilities held for sale								2,250,000
Central Appalachia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								6,500,000
Number of mines | item	2			2			2
Mine Development Costs [Member] | Central Appalachia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								1,800,000
Mineral Rights [Member] | Central Appalachia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								3,200,000
Steam Operations [Member] | Central Appalachia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								4,900,000
Royalties [Member] | Central Appalachia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								1,500,000
Rhino Eastern LLC [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								5,900,000
Red Cliff Project [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								22,200,000
Property, plant and equipment								29,100,000
Mineral rights								2,000,000
Accrued liabilities								300,000
Estimated project costs								420,000,000
Red Cliff Project [Member] | Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment								11,200,000
Red Cliff Project [Member] | Mine Development Costs And Mineral Rights [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								13,200,000
Property, plant and equipment								0
Red Cliff Project [Member] | Land Tracts [Member]
Property, Plant and Equipment [Line Items]
Payments to acquire land								5,000,000
Red Cliff Project [Member] | Land [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								9,300,000
Property, plant and equipment								6,900,000		$ 16,200,000
Payments to acquire land								11,000,000
Red Cliff Project [Member] | Bureau Of Land Management Refund [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								300,000
Taylorville Property, Central Illinois [Member]
Property, Plant and Equipment [Line Items]
Proceeds from the sale of property	$ 7,200,000
Repurchase agreement period							7 years
Deane Mining Complex And Cana Woodford Regions [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges							$ 31,100,000
Hopedale Mining Complex, Northern Appalachia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges							$ 19,000,000
Number of long term commitments | contract	2			2			2
Sands Hill Mining Complex, Northern Appalachia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges							$ 5,700,000
Number of mines | item	2			2			2
Leesville Field, Northern Appalachia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges							$ 3,500,000
Coal tonnage | T							27.9
Rich Mountain Property, West Virginia [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								$ 8,300,000
Coal reserves | T								8.2
Property, plant and equipment								$ 0		$ 8,300,000
Acquisition of mineral rights									$ 7,500,000
Bevins Branch, Eastern Kentucky [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								8,300,000
Asset impairment charges offset							$ 2,300,000
Property, plant and equipment								2,400,000
Gain on sale of assets	$ 1,200,000
Royalty receivable								200,000
Transfer of reclamation obligations								2,200,000
Bevins Branch, Eastern Kentucky [Member] | Mine Development Costs And Mineral Rights [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								6,600,000
Bevins Branch, Eastern Kentucky [Member] | Royalties [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges								1,700,000
Deane Branch, Eastern Kentucky [Member]
Property, Plant and Equipment [Line Items]
Number of mines | item		1
Note receivable, gross		$ 2,000,000
Cana Woodford, Western Oklahoma [Member]
Property, Plant and Equipment [Line Items]
Proceeds from the sale of property			$ 5,700,000
Asset impairment and related charges						$ 2,200,000
Mineral rights						$ 5,800,000
Net acreage | a			1,900
Deane Mining Complex [Member]
Property, Plant and Equipment [Line Items]
Asset impairment and related charges				$ 1,900,000	$ 2,300,000
Property, plant and equipment		2,000,000
Gain on sale of assets		$ 400,000
Note receivable, gross	2,000,000			2,000,000			2,000,000
Phelps Kentucky [Member]
Property, Plant and Equipment [Line Items]
Note receivable, gross	$ 7,900,000			$ 7,900,000			$ 7,900,000	$ 8,750,000

Property, Plant And Equipment54

Property, Plant And Equipment (Property, Plant And Equipment By Major Classification) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Total	$ 604,514	$ 663,662
Less accumulated depreciation, depletion and amortization	(271,007)	(280,225)
Net property, plant and equipment	333,507	383,437
Land And Land Improvements [Member]
Property, Plant and Equipment [Line Items]
Total	24,157	18,845
Mining And Other Equipment And Related Facilities [Member]
Property, Plant and Equipment [Line Items]
Total	306,609	336,951
Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Total	67,277	79,536
Coal Properties [Member]
Property, Plant and Equipment [Line Items]
Total	203,791	215,325
Oil And Natural Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Total		8,093
Construction Work In Process [Member]
Property, Plant and Equipment [Line Items]
Total	$ 2,680	$ 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 Equipment55

Property, Plant And Equipment (Depreciation, Depletion And Amortization) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Depreciation, depletion and amortization	$ 33,181	$ 37,233
Asset Retirement Costs [Member]
Property, Plant and Equipment [Line Items]
Amortization	(450)	194
Intangible Assets [Member]
Property, Plant and Equipment [Line Items]
Amortization	76	80
Mining And Other Equipment And Related Facilities [Member]
Property, Plant and Equipment [Line Items]
Depreciation	28,740	30,529
Coal Properties [Member]
Property, Plant and Equipment [Line Items]
Depletion	2,871	4,633
Oil And Natural Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Depletion	9	60
Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Amortization	$ 1,935	$ 1,737

Goodwill And Intangible Asset56

Goodwill And Intangible Assets (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Acquired Finite-Lived Intangible Assets [Line Items]
Asset impairment and related charges	$ 31,564,000	$ 45,296,000
Intangible assets	505,000	1,067,000
Patent And Developed Technology [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Asset impairment and related charges	500,000
Patent [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible assets	0	478,000
Developed Technology [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible assets	0	51,000
Trade Name [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible assets	142,000	151,000
Customer List [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible assets	$ 363,000	$ 387,000
Trade Name And Customer List [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible assets, useful life	20 years

Goodwill And Intangible Asset57

Goodwill And Intangible Assets (Schedule Of Intangible Assets By Major Class) (Details) - USD ($)	Dec. 31, 2015	Dec. 31, 2014
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 654,000	$ 1,460,000
Accumulated Amortization	149,000	393,000
Net Carrying Amount	505,000	1,067,000
Patent [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount		728,000
Accumulated Amortization		250,000
Net Carrying Amount	0	478,000
Developed Technology [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount		78,000
Accumulated Amortization		27,000
Net Carrying Amount	0	51,000
Trade Name [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	184,000	184,000
Accumulated Amortization	42,000	33,000
Net Carrying Amount	142,000	151,000
Customer List [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	470,000	470,000
Accumulated Amortization	107,000	83,000
Net Carrying Amount	$ 363,000	$ 387,000

Goodwill And Intangible Asset58

Goodwill And Intangible Assets (Future Amortization Expense) (Details) $ in Thousands	Dec. 31, 2015USD ($)
Patent [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
2,016	$ 9
2,017	9
2,018	9
2,019	9
2,020	9
Developed Technology [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
2,016	23
2,017	23
2,018	23
2,019	23
2,020	23
Trade Name [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
2,016	32
2,017	32
2,018	32
2,019	32
2,020	$ 32

Other Non-Current Assets (Narra

Other Non-Current Assets (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended
	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Other Non-Current Assets [Line Items]
Workers' compensation insurance receivable		$ 23,908	$ 14,237
Second Amendment [Member]
Other Non-Current Assets [Line Items]
Credit facility, maximum available	$ 200,000
Amendment fee	100
Unamortized debt issuance costs written off	$ 1,100

Other Non-Current Assets (Sched

Other Non-Current Assets (Schedule Of Other Non-Current Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Other Non-Current Assets [Abstract]
Deposits and other	$ 138	$ 347
Debt issuance costs-net		1,513
Non-current receivable	23,908	14,237
Note receivable	2,000
Deferred expenses	261	313
Total	$ 26,307	$ 16,410

Accrued Expenses And Other Cu61

Accrued Expenses And Other Current Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Accrued Expenses And Other Current Liabilities [Abstract]
Payroll, bonus and vacation expense	$ 1,447	$ 2,876
Non income taxes	3,774	4,323
Royalty expenses	1,566	1,772
Accrued interest	575	385
Health claims	817	1,270
Workers' compensation & pneumoconiosis	1,150	1,500
Deferred revenues	2,260	4,050
Accrued insured litigation claims	266	489
Other	2,247	669
Total	$ 14,102	$ 17,334

Debt (Senior Secured Credit Fac

Debt (Senior Secured Credit Facility With PNC Bank, N.A.) (Narrative) (Details) - USD ($)	Mar. 17, 2016	Dec. 31, 2015	Apr. 30, 2015	Mar. 31, 2014	Jul. 31, 2011	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2015	Dec. 31, 2014
Line of Credit Facility [Line Items]
Proceeds from sales of property, plant, and equipment										$ 14,300,000	$ 15,114,000	$ 189,618,000
Line of credit facility, amount outstanding		$ 41,200,000					$ 41,200,000			41,200,000	41,200,000	54,450,000
Borrowings on line of credit											$ 94,400,000	170,040,000
Maximum borrowing capacity measured as a multiple of EBITDA											325.00%
EBITDA measurement period for determining maximum borrowing capacity											12 months
Line of credit facility, remaining borrowing capacity		1,100,000					1,100,000			1,100,000	$ 1,100,000
Interest costs capitalized											0	$ 100,000
Letters of Credit [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available					$ 75,000,000
Line of credit facility, amount outstanding		27,400,000					27,400,000			27,400,000	27,400,000
Outstanding letters of credit		$ 27,400,000					$ 27,400,000			$ 27,400,000	$ 27,400,000
Long-term debt, percentage bearing fixed interest, percentage		4.50%					4.50%			4.50%	4.50%
Minimum [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio required for extension	300.00%
LIBOR [Member]
Line of Credit Facility [Line Items]
Incremental interest rate above variable rate											4.50%
Line of credit facility, amount outstanding		$ 36,000,000					$ 36,000,000			$ 36,000,000	$ 36,000,000
Effective interest rate		4.70%					4.70%			4.70%	4.70%
PRIME [Member]
Line of Credit Facility [Line Items]
Incremental interest rate above variable rate											3.50%
Line of credit facility, amount outstanding		$ 5,200,000					$ 5,200,000			$ 5,200,000	$ 5,200,000
Effective interest rate		7.00%					7.00%			7.00%	7.00%
First Amendment [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
Second Amendment [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available				$ 200,000,000
Line of credit facility, maximum investment in hydrocarbons				50,000,000
Amendment fee				100,000
Unamortized debt issuance costs written off				$ 1,100,000
Third Amendment [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available		$ 90,000,000	$ 100,000,000				$ 90,000,000			$ 90,000,000	$ 90,000,000
Line of credit facility, maximum investment in hydrocarbons			10,000,000
Amendment fee			2,100,000
Unamortized debt issuance costs written off			$ 200,000
Line of credit facility, maximum leverage ratio		325.00%	275.00%				350.00%	375.00%
Line of credit facility, miniumum liquidity			$ 15,000,000								$ 15,000,000
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, amount of sales proceeds that cause a decrease in leverage ratio			$ 10,000,000
Line of credit facility, maximum quarterly distributions per unit			$ 0.035
Line of credit facility, leverage ratio threshold for maximum distribution			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, minimum fixed charge coverage ratio			110.00%
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
Line of credit facility, leverage ratio reduction related to sale of assets			25.00%
Line of credit facility, maximum leverage ratio required for extension											275.00%
Third Amendment [Member] | Letters of Credit [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available			$ 50,000,000
Third Amendment [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio			300.00%
Fourth Amendment [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio required for extension	675.00%
Fourth Amendment [Member] | Letters of Credit [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available	$ 30,000,000
Fourth Amendment [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available	$ 80,000,000
Incremental interest rate above variable rate	3.50%
Commitment fee	1.00%
Line of credit facility, maximum leverage ratio	675.00%
Line of credit facility, miniumum liquidity	$ 5,000,000
Line of credit facility, amount of sales proceeds that cause a decrease in leverage ratio	10,000,000
Line of credit facility, maximum capital expenditures for remainder of fiscal year	$ 15,000,000
Line of credit facility, leverage ratio reduction related to sale of assets	50.00%
Line of credit facility, minimum EBITDA	$ 8,000,000
Fourth Amendment [Member] | Subsequent Event [Member] | Letters of Credit [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available	$ 30,000,000
Fourth Amendment [Member] | Minimum [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio	300.00%
Line of credit facility, minimum EBITDA	$ 8,000,000
Fourth Amendment [Member] | PRIME [Member] | Subsequent Event [Member]
Line of Credit Facility [Line Items]
Incremental interest rate above variable rate	3.50%
Scenario, Forecast [Member] | Third Amendment [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio						325.00%			300.00%

Debt (Schedule Of Debt) (Detail

Debt (Schedule Of Debt) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Debt [Abstract]
Senior secured credit facility with PNC Bank, N.A.	$ 41,200	$ 54,450
Other notes payable	2,874	2,982
Total	44,074	57,432
Less current portion	(41,479)	(210)
Long-term debt	$ 2,595	$ 57,222

Debt (Schedule Of Principal Pay

Debt (Schedule Of Principal Payments On Long-Term Debt) (Details) $ in Thousands	Dec. 31, 2015USD ($)
Debt [Abstract]
2,016	$ 41,479
2,017	240
2,018	257
2,019	275
2,020	295
Thereafter	1,528
Total principal payments	$ 44,074

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations [Abstract]
Balance at beginning of period (including current portion)		$ 29,883	$ 34,451
Accretion expense		2,082	2,281
Adjustment resulting from addition of property		1,235
Adjustment resulting from disposal of property	[1]	(6,861)	(2,310)
Adjustments to liability from annual recosting and other		(2,078)	(1,324)
Reclassification To Held For Sale			(2,250)
Liabilities settled		(514)	(965)
Balance at end of period		$ 29,883	$ 34,451	$ 23,747	$ 29,883
Less current portion of asset retirement obligation				(767)	(1,431)
Long-term portion of asset retirement obligation				$ 22,980	$ 28,452
[1]	The ($6.9) million adjustment for the year ended December 31, 2015 relates to the sale of the Partnership's Deane mining complex discussed in Note 6. 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.

Workers' Compensation And Bla66

Workers' Compensation And Black Lung (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended										12 Months Ended
	Dec. 31, 2015		Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Partners' capital	$ 267,928					$ 320,925					$ 267,928	$ 320,925	$ 296,371
Net income	(33,986)	[1]	$ (9,306)	$ (8,112)	$ (3,840)	(60,710)	[2]	$ (8,907)	$ (6,878)	$ 125,545	(55,244)	49,049
Workers' compensation insurance receivable	23,908					14,237					$ 23,908	14,237
Black Lung Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate											4.00%
Workers' compensation insurance receivable	$ 23,900					$ 14,200					$ 23,900	$ 14,200
Workers Compensation [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate											2.00%	2.00%
[1]	Fourth quarter 2015 results include approximately $27.1 million of asset impairment and related charges.
[2]	Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership's equity investment in the Rhino Eastern joint venture.

Workers' Compensation And Bla67

Workers' Compensation And Black Lung (Summary Of Black Lung And Workers' Compensation Expenses) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 254	$ 297
Interest cost	191	236
Actuarial (gain)/loss	(328)	490
Total	(2,963)	165
Black Lung Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	(991)	1,040
Interest cost	397	357
Actuarial (gain)/loss		1,625
Total	(594)	3,022
Workers Compensation [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	4,334	1,197
Workers' Compensation And Black Lung Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total	$ 3,740	$ 4,219

Workers' Compensation And Bla68

Workers' Compensation And Black Lung (Schedule Of Changes In Benefit Liability) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of period	$ 6,648	$ 6,120
Service cost	254	297
Interest cost	191	236
Actuarial (gain)/loss	(328)	490
Change in benefit obligations: Benefits paid	(217)	(495)
Benefit obligation at end of period	45	6,648
Black Lung Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation at beginning of period	10,033	7,251
Service cost	(991)	1,040
Interest cost	397	357
Actuarial (gain)/loss		1,625
Change in benefit obligations: Benefits paid	(214)	(240)
Benefit obligation at end of period	$ 9,225	$ 10,033

Workers' Compensation And Bla69

Workers' Compensation And Black Lung (Classification Of Net Amounts Recognized For Workers' Compensation And Black Lung Benefits) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Less current portion	$ (45)	$ (425)
Non-current obligations		6,223
Black Lung Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total obligations	9,225	10,033
Insured Black Lung And Workers Compensation Claims [Member]
Defined Benefit Plan Disclosure [Line Items]
Total obligations	23,907	14,237
Workers Compensation [Member]
Defined Benefit Plan Disclosure [Line Items]
Total obligations	6,210	5,172
Workers' Compensation And Black Lung Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Total obligations	39,342	29,442
Less current portion	(1,150)	(1,500)
Non-current obligations	$ 38,192	$ 27,942

Employee Benefits (Narrative) (

Employee Benefits (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended		15 Months Ended
	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Mar. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Prior service cost (credit)		$ 2.6
Amounts reclassified from AOCI		$ 3.4	$ 0.4
Scenario, Forecast [Member]
Defined Benefit Plan Disclosure [Line Items]
Prior service cost (credit)	$ 3.9			$ (6.5)

Employee Benefits (Summary Of C

Employee Benefits (Summary Of Changes In Benefit Obligations) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Employee Benefits [Abstract]
Benefit obligation at beginning of period	$ 6,648	$ 6,120
Change in benefit obligations: Service costs	254	297
Change in benefit obligations: Interest cost	191	236
Change in benefit obligations: Benefits paid	(217)	(495)
Change in benefit obligation: Plan amendment	(6,503)
Change in benefit obligations: Actuarial loss/(gain)	(328)	490
Benefit obligation at end of period	45	6,648
Funded status	$ (45)	$ (6,648)

Employee Benefits (Classificati

Employee Benefits (Classification Of Net Amounts Recognized For Postretirement Benefits) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Employee Benefits [Abstract]
Current liability - postretirement benefits	$ (45)	$ (425)
Non-current liability - postretirement benefits		(6,223)
Net amount recognized	$ (45)	$ (6,648)

Employee Benefits (Amounts Reco

Employee Benefits (Amounts Recognized In Accumulated Other Comprehensive Income) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Employee Benefits [Abstract]
Balance at beginning of year	$ 1,373	$ 2,231
Actuarial (loss)/gain	328	(490)
Prior service (cost)/gain to be amortized	3,876
Amortization of net actuarial gain	(782)	(368)
Net actuarial gain	$ 4,795	$ 1,373

Employee Benefits (Weighted Ave

Employee Benefits (Weighted Average Assumptions Used To Determine Benefit Obligations) (Details)	Dec. 31, 2014
Employee Benefits [Abstract]
Discount rate	3.15%

Employee Benefits (Weighted A75

Employee Benefits (Weighted Average Assumptions Used To Determine Periodic Benefit Cost) (Details)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Employee Benefits [Abstract]
Discount rate	3.15%	3.96%

Employee Benefits (Components O

Employee Benefits (Components Of Net Periodic Benefit Cost) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Employee Benefits [Abstract]
Service costs	$ 254	$ 297
Interest cost	191	236
Amortization of prior service cost	(2,626)
Amortization of (gain)	(782)	(368)
Total	$ (2,963)	$ 165

Employee Benefits (Amounts Expe

Employee Benefits (Amounts Expected To Be Amortized From Accumulated Other Comprehensive Income Into Net Periodic Benefit Cost) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Employee Benefits [Abstract]
Net actuarial gain	$ 4,795

Employee Benefits (Schedule Of

Employee Benefits (Schedule Of Expense Under Defined Contribution Savings Plans) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Employee Benefits [Abstract]
401(k) plan expense	$ 2,027	$ 2,227

Equity-Based Compensation (Narr

Equity-Based Compensation (Narrative) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2010	Dec. 31, 2015	Dec. 31, 2014
Equity-Based Compensation [Abstract]
Number of units reserved for future issuance	2,479,400
Vesting period		3 years
Share based compensation expense		$ 0.1	$ 0.3
Total fair value of awards that vested		0.1
Total unrecognized compensation expense		$ 0.3
Weighted average period of recognition		1 year 1 month 6 days
Intrinsic value of non-vested awards		$ 0.1

Equity-Based Compensation (Summ

Equity-Based Compensation (Summary Of Non-Vested LTIP Awards) (Details) - $ / shares shares in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Equity-Based Compensation [Abstract]
Common Units, Non-vested awards, Beginning balance	51	55
Common Units, Granted	247	46
Common Units, Vested	(86)	(34)
Common Units, Forfeited	(8)	(16)
Common Units, Non-vested awards, Ending balance	204	51
Weighted Average Grant Date Fair Value (per unit), Non-vested awards, Beginning balance	$ 13.50	$ 14.63
Weighted Average Grant Date Fair Value (per unit), Granted	1.06	12.32
Weighted Average Grant Date Fair Value (per unit), Vested	5.68	13.95
Weighted Average Grant Date Fair Value (per unit), Forfeited	6.43	13.01
Weighted Average Grant Date Fair Value (per unit), Non-vested awards, Ending balance	$ 2	$ 13.50

Commitments And Contingencies81

Commitments And Contingencies (Narrative) (Details) - USD ($)	1 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Commitments And Contingencies [Line Items]
Off balance sheet liabilities		$ 0
Line of credit facility, amount outstanding		41,200,000	$ 54,450,000
Long-term debt		44,074,000	57,432,000
Surety Bonds [Member]
Commitments And Contingencies [Line Items]
Long-term debt		59,100,000
Timber Wolf [Member]
Commitments And Contingencies [Line Items]
Payments to acquire interest in joint venture		$ 0
Muskie Proppants [Member]
Commitments And Contingencies [Line Items]
Payments to acquire interest in joint venture			200,000
Loans to joint venture				$ 200,000
Sturgeon Acquisitions [Member]
Commitments And Contingencies [Line Items]
Payments to acquire interest in joint venture	$ 5,000,000		$ 5,000,000

Commitments And Contingencies82

Commitments And Contingencies (Schedule Of Delivery Commitments) (Details) T in Thousands	12 Months Ended
	Dec. 31, 2015customerT
Commitments And Contingencies [Abstract]
Tons, 2016 | T	3,255
Tons, 2017 | T	1,914
Tons, 2018 | T	264
Number of customers, 2016 | customer	14
Number of customers, 2017 | customer	8
Number of customers, 2018 | customer	1

Commitments And Contingencies83

Commitments And Contingencies (Schedule Of Purchased Coal Expenses) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Commitments And Contingencies [Abstract]
Purchased coal expense	$ (26)	$ 6,168

Commitments And Contingencies84

Commitments And Contingencies (Schedule Of Lease And Royalty Expense) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Commitments And Contingencies [Abstract]
Lease expense	$ 6,204	$ 3,478
Royalty expense	$ 10,754	$ 11,571

Commitments And Contingencies85

Commitments And Contingencies (Future Minimum Lease And Royalty Payments) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Commitments And Contingencies [Abstract]
Royalties, 2016	$ 2,824
Royalties, 2017	2,466
Royalties, 2018	2,436
Royalties, 2019	2,436
Royalties, 2020	2,556
Royalties, Thereafter	12,780
Total minimum royalty payments	25,498
Leases, 2016	3,664
Leases, 2017	1,097
Leases, 2018	148
Total minimum lease payments	$ 4,909

Earnings Per Unit ("EPU") (Narr

Earnings Per Unit ("EPU") (Narrative) (Details)	12 Months Ended
	Dec. 31, 2014shares
Earnings Per Unit ("EPU") [Abstract]
Anti-dilutive LTIP phantom units	0

Earnings Per Unit ("EPU") (Sche

Earnings Per Unit ("EPU") (Schedule Of Calculation Of Numerator And Denominator In Earnings Per Share) (Details) - USD ($)	3 Months Ended										12 Months Ended
	Dec. 31, 2015	[1]	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	[2]	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations	$ (33,986,000)		$ (9,306,000)	$ (8,112,000)	$ (4,562,000)	$ (60,636,000)		$ (8,864,000)	$ (6,826,000)	$ (4,966,000)	$ (55,966,000)	$ (81,293,000)
Interest in net (loss)/income: Net income from discontinued operations					722,000	(74,000)		(43,000)	(52,000)	130,511,000	722,000	130,342,000
Interest in net (loss)/income: Total interest in net income (loss)	$ (33,986,000)		$ (9,306,000)	$ (8,112,000)	$ (3,840,000)	$ (60,710,000)		$ (8,907,000)	$ (6,878,000)	$ 125,545,000	(55,244,000)	49,049,000
General Partner [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations											(1,119,000)	(1,626,000)
Interest in net (loss)/income: Net income from discontinued operations											14,000	2,607,000
Interest in net (loss)/income: Total interest in net income (loss)											(1,105,000)	981,000
Impact of subordinated distribution suspension: Net income/(loss) from continuing operations											5,000
Impact of subordinated distribution suspension: Interest in net income/(loss)											5,000
Interest in net (loss)/income for EPU purposes: Net income/(loss) from continuing operations											(1,114,000)
Interest in net (loss)/income for EPU purposes: Net income from discontinued operations											14,000
Interest in net (loss)/income for EPU purposes: Interest in net (loss)/income											$ (1,100,000)
Effect of dilutive securities - LTIP awards
General Partner [Member] | As Previously Reported [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												(1,626,000)
Interest in net (loss)/income: Net income from discontinued operations												2,607,000
Interest in net (loss)/income: Total interest in net income (loss)												981,000
General Partner [Member] | Adjustment [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												245,000
Interest in net (loss)/income: Total interest in net income (loss)												245,000
General Partner [Member] | As Restated [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												(1,381,000)
Interest in net (loss)/income: Net income from discontinued operations												2,607,000
Interest in net (loss)/income: Total interest in net income (loss)												1,226,000
Common Unitholders [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations											$ (31,491,000)	(45,705,000)
Interest in net (loss)/income: Net income from discontinued operations											406,000	73,271,000
Interest in net (loss)/income: Total interest in net income (loss)											(31,085,000)	$ 27,566,000
Impact of subordinated distribution suspension: Net income/(loss) from continuing operations											139,000
Impact of subordinated distribution suspension: Interest in net income/(loss)											139,000
Interest in net (loss)/income for EPU purposes: Net income/(loss) from continuing operations											(31,352,000)
Interest in net (loss)/income for EPU purposes: Net income from discontinued operations											406,000
Interest in net (loss)/income for EPU purposes: Interest in net (loss)/income											$ (30,946,000)
Weighted average units used to compute basic EPU											16,714	16,678,000
Effect of dilutive securities - LTIP awards												7,000
Weighted average units used to compute diluted EPU											16,714	16,685,000
Net (loss) per unit from continuing operations											$ (1.87)	$ (2.32)
Net income per unit from discontinued operations											0.02	4.39
Net (loss)/income per common unit, basic											(1.85)	2.07
Net (loss)/income per unit from continuing operations											(1.87)	(2.32)
Net income per unit from discontinued operations											0.02	4.39
Net income per common unit, diluted											$ (1.85)	$ 2.07
Common Unitholders [Member] | As Previously Reported [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												$ (45,705,000)
Interest in net (loss)/income: Net income from discontinued operations												73,271,000
Interest in net (loss)/income: Total interest in net income (loss)												27,566,000
Common Unitholders [Member] | Adjustment [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												6,908,000
Interest in net (loss)/income: Total interest in net income (loss)												6,908,000
Common Unitholders [Member] | As Restated [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												(38,797,000)
Interest in net (loss)/income: Net income from discontinued operations												73,271,000
Interest in net (loss)/income: Total interest in net income (loss)												34,474,000
Subordinated Unitholders[Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations											$ (23,356,000)	(33,962,000)
Interest in net (loss)/income: Net income from discontinued operations											302,000	54,464,000
Interest in net (loss)/income: Total interest in net income (loss)											(23,054,000)	$ 20,502,000
Impact of subordinated distribution suspension: Net income/(loss) from continuing operations											(144,000)
Impact of subordinated distribution suspension: Interest in net income/(loss)											(144,000)
Interest in net (loss)/income for EPU purposes: Net income/(loss) from continuing operations											(23,500,000)
Interest in net (loss)/income for EPU purposes: Net income from discontinued operations											302,000
Interest in net (loss)/income for EPU purposes: Interest in net (loss)/income											$ (23,198,000)
Weighted average units used to compute basic EPU											12,396	12,397,000
Effect of dilutive securities - LTIP awards
Weighted average units used to compute diluted EPU											12,396	12,397,000
Net (loss) per unit from continuing operations											$ (1.89)	$ (3.31)
Net income per unit from discontinued operations											0.02	4.39
Net (loss)/income per common unit, basic											(1.87)	1.08
Net (loss)/income per unit from continuing operations											(1.89)	(3.31)
Net income per unit from discontinued operations											0.02	4.39
Net income per common unit, diluted											$ (1.87)	$ 1.08
Subordinated Unitholders[Member] | As Previously Reported [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												$ (33,962,000)
Interest in net (loss)/income: Net income from discontinued operations												54,464,000
Interest in net (loss)/income: Total interest in net income (loss)												20,502,000
Subordinated Unitholders[Member] | Adjustment [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												(7,153,000)
Interest in net (loss)/income: Total interest in net income (loss)												(7,153)
Subordinated Unitholders[Member] | As Restated [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations												(41,115,000)
Interest in net (loss)/income: Net income from discontinued operations												54,464,000
Interest in net (loss)/income: Total interest in net income (loss)												$ 13,349,000
[1]	Fourth quarter 2015 results include approximately $27.1 million of asset impairment and related charges.
[2]	Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership's equity investment in the Rhino Eastern joint venture.

Major Customers (Details)

Major Customers (Details) - USD ($) $ in Thousands	3 Months Ended										12 Months Ended
	Dec. 31, 2015		Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Revenue, Major Customer [Line Items]
Receivable balance	$ 14,569					$ 22,467					$ 14,569	$ 22,467
Revenue	39,644	[1]	$ 54,153	$ 56,765	$ 56,184	61,870	[2]	$ 61,359	$ 55,886	$ 59,942	206,746	239,057
NRG Energy, Inc. (fka GenOn Energy, Inc.) [Member]
Revenue, Major Customer [Line Items]
Receivable balance						2,932						2,932
Revenue											22,111	31,605
PPL Corporation [Member]
Revenue, Major Customer [Line Items]
Receivable balance	1,881					$ 2,053					1,881	2,053
Revenue											33,662	$ 24,542
PacificCorp Energy [Member]
Revenue, Major Customer [Line Items]
Receivable balance	$ 1,969										1,969
Revenue											$ 21,519
[1]	Fourth quarter 2015 results include approximately $27.1 million of asset impairment and related charges.
[2]	Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership's equity investment in the Rhino Eastern joint venture.

Fair Value Of Financial Instr89

Fair Value Of Financial Instruments (Details) $ in Thousands	Dec. 31, 2014USD ($)
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Non-current assets held for sale	$ 9,279
Non-current liabilities held for sale	2,250
Red Cliff Project [Member] | Land [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Non-current assets held for sale	6,900
Bevins Branch, Eastern Kentucky [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Royalty receivable	200
Bevins Branch, Eastern Kentucky [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Non-current assets held for sale	2,400
Non-current liabilities held for sale	$ 2,200

Related Party And Affiliate T90

Related Party And Affiliate Transactions (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Wexford Capital LP [Member]
Related Party Transaction [Line Items]
Expenses for legal, consulting, advisory services, health claims, workers' compensation and other expenses	$ 143	$ 131
Rhino Eastern LLC [Member]
Related Party Transaction [Line Items]
Expenses for legal, consulting, advisory services, health claims, workers' compensation and other expenses		$ 4,610

Related Party And Affiliate T91

Related Party And Affiliate Transactions (Schedule Of Related Party And Affiliate Transactions) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Related Party Transaction [Line Items]
Partner's contribution	$ 2	$ 6
Equity in net income (loss) of unconsolidated affiliate	342	(11,712)
Return of capital from unconsolidated affiliate	232
Investment in unconsolidated affiliates	7,578	20,653
Wexford Capital LP [Member]
Related Party Transaction [Line Items]
Expenses for legal, consulting, advisory services, health claims, workers' compensation and other expenses	143	131
Distributions paid	553	10,949
Partner's contribution	2	6
Rhino Eastern LLC [Member]
Related Party Transaction [Line Items]
Expenses for legal, consulting, advisory services, health claims, workers' compensation and other expenses		4,610
Equity in net income (loss) of unconsolidated affiliate		(12,089)
Receivable for legal, health claims and workers' compensation and other expenses		223
Investment in unconsolidated affiliates		13,151
Timber Wolf [Member]
Related Party Transaction [Line Items]
Investment in unconsolidated affiliates	130	130
Mammoth Energy Partners LP [Member]
Related Party Transaction [Line Items]
Investment in unconsolidated affiliates	1,933	1,933
Sturgeon Acquisitions [Member]
Related Party Transaction [Line Items]
Equity in net income (loss) of unconsolidated affiliate	342	440
Distribution from unconsolidated affiliate	232
Return of capital from unconsolidated affiliate	35
Investment in unconsolidated affiliates	$ 5,515	$ 5,440

Supplemental Disclosures Of C92

Supplemental Disclosures Of Cash Flow Information (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Other Significant Noncash Transactions [Line Items]
Interest paid	$ 3.4	$ 4
Recorded In Accounts Payable [Member]
Other Significant Noncash Transactions [Line Items]
Property additions	0.7	0.2
Value of units issued		$ 0.3
Units Issued [Member]
Other Significant Noncash Transactions [Line Items]
Property additions	$ 0.1

Supplemental Disclosures Of C93

Supplemental Disclosures Of Cash Flow Information (Schedule Of Cash Flow, Supplemental Disclosures) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Other Significant Noncash Transactions [Line Items]
Coal properties (incl asset retirement costs)	$ 604,514	$ 663,662
Advance royalties, net of current portion	753	1,032
Other non-current assets - acquired	26,307	16,410
Accrued expenses and other	(14,102)	(17,334)
Asset retirement obligations	(22,980)	$ (28,452)
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)	12 Months Ended
	Dec. 31, 2015segmentitem
Segment Reporting Information [Line Items]
Number of reportable business segments | segment	4
Central Appalachia [Member]
Segment Reporting Information [Line Items]
Number of mines	2
Underground Mine [Member] | Central Appalachia [Member]
Segment Reporting Information [Line Items]
Number of mines	1
Underground Mine [Member] | Northern Appalachia [Member]
Segment Reporting Information [Line Items]
Number of mines	1
Preparation Plants And Loadout Facilities [Member] | Central Appalachia [Member]
Segment Reporting Information [Line Items]
Number of mines	3
Preparation Plants And Loadout Facilities [Member] | Northern Appalachia [Member]
Segment Reporting Information [Line Items]
Number of mines	1
Surface Mine [Member] | Central Appalachia [Member]
Segment Reporting Information [Line Items]
Number of mines	3
Surface Mines [Member] | Northern Appalachia [Member]
Segment Reporting Information [Line Items]
Number of mines	2

Segment Information (Reportable

Segment Information (Reportable Segment Results Of Operations) (Details) - USD ($) $ in Thousands		3 Months Ended										12 Months Ended
		Dec. 31, 2015		Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Segment Reporting Information [Line Items]
Total assets		$ 404,667					$ 473,338					$ 404,667	$ 473,338
Total revenues		39,644	[1]	$ 54,153	$ 56,765	$ 56,184	61,870	[2]	$ 61,359	$ 55,886	$ 59,942	206,746	239,057
DD&A												33,181	37,233
Interest expense												5,001	5,708
Net Income (loss) from continuing operations												(55,966)	(81,293)
Central Appalachia [Member]
Segment Reporting Information [Line Items]
Total assets		227,880					247,362					227,880	247,362
Total revenues												67,942	109,432
DD&A												12,641	20,224
Interest expense												2,040	2,055
Net Income (loss) from continuing operations												(14,212)	(33,019)
Northern Appalachia [Member]
Segment Reporting Information [Line Items]
Total assets		17,218					52,822					17,218	52,822
Total revenues												63,273	71,472
DD&A												7,562	7,574
Interest expense												522	473
Net Income (loss) from continuing operations												(20,487)	2,101
Rhino Western [Member]
Segment Reporting Information [Line Items]
Total assets		37,198					42,173					37,198	42,173
Total revenues												35,322	44,081
DD&A												6,314	6,021
Interest expense												315	329
Net Income (loss) from continuing operations												(4,560)	(22,822)
Illinois Basin [Member]
Segment Reporting Information [Line Items]
Total assets		82,700					80,126					82,700	80,126
Total revenues												38,641	9,755
DD&A												5,928	2,286
Interest expense												597	343
Net Income (loss) from continuing operations												(13,807)	(6,411)
Eastern Met [Member] | Complete Basis [Member]
Segment Reporting Information [Line Items]
Total assets							42,100						42,100
Total revenues													21,722
DD&A													1,860
Interest expense													81
Net Income (loss) from continuing operations													(12,208)
Eastern Met [Member] | Equity Method Eliminations [Member]
Segment Reporting Information [Line Items]
Total assets							$ (42,100)						(42,100)
Total revenues													(21,722)
DD&A													(1,860)
Interest expense													(81)
Net Income (loss) from continuing operations													$ 5,982
Eastern Met [Member] | Equity Method Presentation [Member]
Segment Reporting Information [Line Items]
Total assets	[3]
Total revenues	[3]
DD&A	[3]
Interest expense	[3]
Net Income (loss) from continuing operations	[3]												$ (12,089)
Other [Member]
Segment Reporting Information [Line Items]
Total assets		$ 39,671					$ 50,855					39,671	50,855
Total revenues												1,568	4,317
DD&A												736	1,128
Interest expense												1,527	2,508
Net Income (loss) from continuing operations												$ (2,900)	$ (9,053)
[1]	Fourth quarter 2015 results include approximately $27.1 million of asset impairment and related charges.
[2]	Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership's equity investment in the Rhino Eastern joint venture.
[3]	For the year ended December 31, 2014, the equity method net loss from continuing operations for Rhino Eastern includes the $5.9 million impairment charge for the joint venture that was discussed earlier.

Segment Information (Equity Met

Segment Information (Equity Method Investments, Summarized Financial Information) (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2014USD ($)
Segment Information [Abstract]
Current assets	$ 3,641
Noncurrent assets	38,459
Current liabilities	3,629
Noncurrent liabilities	3,202
Total costs and expenses	33,850
(Loss) from operations	$ (12,128)

Segment Information (Schedule O

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

3 Months Ended

12 Months Ended

Dec. 31, 2015

[1]

Sep. 30, 2015

Jun. 30, 2015

Mar. 31, 2015

Dec. 31, 2014

[2]

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Dec. 31, 2015

Dec. 31, 2014

Segment Reporting Information [Line Items]

Revenue

$ 39,644

$ 54,153

$ 56,765

$ 56,184

$ 61,870

$ 61,359

$ 55,886

$ 59,942

$ 206,746

$ 239,057

Met Coal [Member]

Segment Reporting Information [Line Items]

Revenue

15,391

26,058

Steam Coal [Member]

Segment Reporting Information [Line Items]

Revenue

155,683

176,823

Other [Member]

Segment Reporting Information [Line Items]

Revenue

$ 35,672

$ 36,176

[1]

Fourth quarter 2015 results include approximately $27.1 million of asset impairment and related charges.

[2]

Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership's equity investment in the Rhino Eastern joint venture.

Quarterly Financial Data (Detai

Quarterly Financial Data (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended										12 Months Ended
	Dec. 31, 2015	[1]	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	[2]	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Quarterly Financial Data [Line Items]
Revenues	$ 39,644		$ 54,153	$ 56,765	$ 56,184	$ 61,870		$ 61,359	$ 55,886	$ 59,942	$ 206,746	$ 239,057
(Loss) from operations	(32,644)		(7,994)	(6,959)	(3,748)	(52,726)		(6,108)	(4,445)	(868)	(51,345)	(64,147)
NET (LOSS) FROM CONTINUING OPERATIONS	(33,986)		(9,306)	(8,112)	(4,562)	(60,636)		(8,864)	(6,826)	(4,966)	(55,966)	(81,293)
Income from discontinued operations					722	(74)		(43)	(52)	130,511	722	130,342
Net (loss)/income	$ (33,986)		$ (9,306)	$ (8,112)	$ (3,840)	$ (60,710)		$ (8,907)	$ (6,878)	$ 125,545	$ (55,244)	$ 49,049
Common Units [Member]
Basic and diluted net (loss)/income per limited partner unit:
Net (loss) per unit from continuing operations	$ (1.14)		$ (0.31)	$ (0.27)	$ (0.15)	$ (2.03)		$ (0.28)	$ (0.05)	$ 0.02
Net income from discontinued operations					0.02	0		0	0	4.40
Net (loss) per common unit, basic and diluted	$ (1.14)		$ (0.31)	$ (0.27)	$ (0.13)	$ (2.03)		$ (0.28)	$ (0.05)	$ 4.42
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic	16,756		16,706	16,702	16,692	16,685		16,681	16,677	16,667	16,714	16,678
Weighted average number of limited partner units outstanding, diluted	16,756		16,706	16,702	16,692	16,685		16,681	16,677	16,673	16,714	16,685
Subordinated Units [Member]
Basic and diluted net (loss)/income per limited partner unit:
Net (loss) per unit from continuing operations	$ (1.14)		$ (0.31)	$ (0.27)	$ (0.17)	$ (2.08)		$ (0.33)	$ (0.49)	$ (0.43)
Net income from discontinued operations					0.02	0		0	0	4.40
Net (loss) per common unit, basic and diluted	$ (1.14)		$ (0.31)	$ (0.27)	$ (0.15)	$ (2.08)		$ (0.33)	$ (0.49)	$ 3.97
Weighted average number of limited partner units outstanding, basic:
Weighted average number of limited partner units outstanding, basic	12,393		12,397	12,397	12,397	12,397		12,397	12,397	12,397	12,396	12,397
Weighted average number of limited partner units outstanding, diluted	12,393		12,397	12,397	12,397	12,397		12,397	12,397	12,397	12,396	12,397
[1]	Fourth quarter 2015 results include approximately $27.1 million of asset impairment and related charges.
[2]	Fourth quarter 2014 results include approximately $45.3 million of asset impairment and related charges as well as an approximate $5.9 million charge for the impairment of the Partnership's equity investment in the Rhino Eastern joint venture.