Rhino Resource Partners 10-Q 12 May 17 2017 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2017	May 05, 2017
Entity Registrant Name	Rhino Resource Partners LP
Entity Central Index Key	1,490,630
Document Type	10-Q
Document Period End Date	Mar. 31, 2017
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Filer Category	Smaller Reporting Company
Trading Symbol	RHNO
Document Fiscal Period Focus	Q1
Document Fiscal Year Focus	2,017
Common Units [Member]
Entity Common Stock, Shares Outstanding		12,905,799
Subordinated Units [Member]
Entity Common Stock, Shares Outstanding		1,235,534

Condensed Consolidated Statemen

Condensed Consolidated Statements of Financial Position (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
CURRENT ASSETS:
Cash and cash equivalents	$ 36	$ 47
Accounts receivable, net of allowance for doubtful accounts ($0 as of March 31, 2017 and December 31, 2016)	19,644	13,893
Inventories	8,928	8,050
Advance royalties, current portion	1,147	898
Prepaid expenses and other	8,656	8,665
Total current assets	38,411	31,553
PROPERTY, PLANT AND EQUIPMENT:
At cost, including coal properties, mine development and construction costs	455,543	449,181
Less accumulated depreciation, depletion and amortization	(272,560)	(266,874)
Net property, plant and equipment	182,983	182,307
Advance royalties, net of current portion	7,790	7,652
Investment in unconsolidated affiliates	5,117	5,121
Intangible purchase option	21,750	21,750
Note receivable-related party	2,040	2,040
Other non-current assets	27,559	27,018
TOTAL	285,650	277,441
CURRENT LIABILITIES:
Accounts payable	12,469	10,420
Accrued expenses and other	12,517	10,063
Current portion of long-term debt	14,840	10,040
Current portion of asset retirement obligations	917	917
Total current liabilities	40,743	31,440
NON-CURRENT LIABILITIES:
Asset retirement obligations, net of current portion	22,801	22,361
Other non-current liabilities	45,516	45,371
Total non-current liabilities	68,317	67,732
Total liabilities	109,060	99,172
COMMITMENTS AND CONTINGENCIES (NOTE 12)
PARTNERS’ CAPITAL:
Limited partners	151,563	154,696
Subscription receivable from limited partners	(2,000)	(2,000)
General partner	8,946	8,959
Preferred partners	16,117	15,000
Preferred partner distribution earned	(1,117)
Accumulated other comprehensive income	3,081	1,614
Total partners’ capital	176,590	178,269
TOTAL	$ 285,650	$ 277,441

Condensed Consolidated Stateme3

Condensed Consolidated Statements of Financial Position (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 0	$ 0

Condensed Consolidated Stateme4

Condensed Consolidated Statements of Operations and Comprehensive Income (Unaudited) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2017	Mar. 31, 2016
REVENUES:
Coal sales		$ 51,781	$ 36,679
Freight and handling revenues		130	629
Other revenues		1,639	2,022
Total revenues		53,550	39,330
COSTS AND EXPENSES:
Cost of operations (exclusive of depreciation, depletion and amortization shown separately below)		44,939	29,496
Freight and handling costs		769	550
Depreciation, depletion and amortization		5,698	6,041
Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above)		3,050	4,040
(Gain) on sale/disposal of assets—net		(36)	(270)
Total costs and expenses		54,420	39,857
INCOME/(LOSS) FROM OPERATIONS		(870)	(527)
INTEREST AND OTHER (EXPENSE)/INCOME:
Interest expense		(1,155)	(1,570)
Interest income and other			35
Equity in net (loss)/income of unconsolidated affiliates		(4)	(79)
Total interest and other (expense)		(1,159)	(1,614)
NET (LOSS) BEFORE INCOME TAXES FROM CONTINUING OPERATIONS		(2,029)	(2,141)
INCOME TAXES
NET (LOSS) FROM CONTINUING OPERATIONS		(2,029)	(2,141)
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations			919
NET (LOSS)		(2,029)	(1,222)
Other comprehensive income:
Fair market value adjustment for available-for-sale investment		1,466
Amortization of actuarial gain under ASC Topic 715			(4,796)
COMPREHENSIVE (LOSS)		$ (563)	$ (6,018)
Net (loss)/income per limited partner unit, diluted:
Distributions paid per limited partner unit	[1]
General Partner [Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS) FROM CONTINUING OPERATIONS		$ (13)	$ (42)
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations			18
NET (LOSS)		(13)	(24)
Common Unitholders [Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS) FROM CONTINUING OPERATIONS		(2,859)	(1,375)
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations			590
NET (LOSS)		$ (2,859)	$ (785)
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations		$ (0.22)	$ (0.58)
Net income per unit from discontinued operations			0.25
Net (loss)/income per common unit, basic		(0.22)	(0.33)
Net (loss)/income per limited partner unit, diluted:
Net (loss) per unit from continuing operations		(0.22)	(0.58)
Net income per unit from discontinued operations			0.25
Net (loss) per common unit, diluted		$ (0.22)	$ (0.33)
Weighted average number of limited partner units outstanding, basic		12,906	2,349
Weighted average number of limited partner units outstanding, diluted		12,906	2,349
Subordinated Unitholders [Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS) FROM CONTINUING OPERATIONS		$ (274)	$ (724)
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations			311
NET (LOSS)		$ (274)	$ (413)
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations		$ (0.22)	$ (0.58)
Net income per unit from discontinued operations			0.25
Net (loss)/income per common unit, basic		(0.22)	(0.33)
Net (loss)/income per limited partner unit, diluted:
Net (loss) per unit from continuing operations		(0.22)	(0.58)
Net income per unit from discontinued operations			0.25
Net (loss) per common unit, diluted		$ (0.22)	$ (0.33)
Weighted average number of limited partner units outstanding, basic		1,236	1,236
Weighted average number of limited partner units outstanding, diluted		1,236	1,236
Preferred Unit Holders [Member]
INTEREST AND OTHER (EXPENSE)/INCOME:
NET (LOSS) FROM CONTINUING OPERATIONS		$ 1,117
DISCONTINUED OPERATIONS (NOTE 3)
Income from discontinued operations
NET (LOSS)		$ 1,117
Net (loss)/income per limited partner unit, basic:
Net (loss) per unit from continuing operations		$ 0.74
Net income per unit from discontinued operations
Net (loss)/income per common unit, basic		0.74
Net (loss)/income per limited partner unit, diluted:
Net (loss) per unit from continuing operations		0.74
Net income per unit from discontinued operations
Net (loss) per common unit, diluted		$ 0.74
Weighted average number of limited partner units outstanding, basic		1,500
Weighted average number of limited partner units outstanding, diluted		1,500
[1]	No distributions were paid for the three months ended March 31, 2017 and 2016.

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Operations and Comprehensive Income (Unaudited) (Parenthetical) - $ / shares		3 Months Ended
		Mar. 31, 2017	Mar. 31, 2016
Income Statement [Abstract]
Distributions paid per limited partner unit	[1]
[1]	No distributions were paid for the three months ended March 31, 2017 and 2016.

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
CASH FLOWS FROM OPERATING ACTIVITIES:
Net (loss)	$ (2,029)	$ (1,222)
Adjustments to reconcile net (loss) to net cash provided by/(used in) operating activities:
Depreciation, depletion and amortization	5,698	6,247
Accretion on asset retirement obligations	474	381	$ 1,512
Amortization of deferred revenue		(163)
Amortization of advance royalties	251	219
Amortization of debt issuance costs	310	563
Amortization of actuarial gain		(4,796)
Equity in net loss/(income) of unconsolidated affiliates	4	79
Loss on retirement of advance royalties	136	113
(Gain) on sale/disposal of assets—net	(36)	(270)
Equity-based compensation		39
Changes in assets and liabilities:
Accounts receivable	(6,002)	(1,330)
Inventories	(878)	1,722
Advance royalties	(774)	(1,100)
Prepaid expenses and other assets	175	906
Accounts payable	2,058	1,225
Accrued expenses and other liabilities	1,969	(3,722)
Asset retirement obligations	(34)	(70)
Postretirement benefits		(45)
Net cash provided by/(used in) operating activities	1,322	(1,224)
CASH FLOWS FROM INVESTING ACTIVITIES:
Additions to property, plant, and equipment	(6,585)	(2,507)
Proceeds from sales of property, plant, and equipment	2	340
Proceeds from business disposal	450
Net cash used in investing activities	(6,133)	(2,167)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on line of credit	33,300	25,700
Repayments on line of credit	(28,500)	(23,300)
Repayments on long-term debt		(55)
Distributions to unitholders		(24)
Payments on debt issuance costs		(362)
Limited partner contributions		2,000
Net cash provided by financing activities	4,800	3,959
NET( DECREASE)/INCREASE IN CASH AND CASH EQUIVALENTS	(11)	568
CASH AND CASH EQUIVALENTS—Beginning of period	47	78	78
CASH AND CASH EQUIVALENTS—End of period	$ 36	$ 646	$ 47

Basis of Presentation and Organ

Basis of Presentation and Organization	3 Months Ended
	Mar. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Basis of Presentation and Organization	1. BASIS OF PRESENTATION AND ORGANIZATION Basis of Presentation and Principles of Consolidation Unaudited Interim Financial Information Reclassifications. Debt Classification Organization Reverse Unit Split On April 18, 2016, we completed a 1-for-10 reverse split on our common units and subordinated units. Pursuant to the reverse split, common unitholders received one common unit for every 10 common units owned on April 18, 2016 and subordinated unitholders received one subordinated unit for every 10 subordinated units owned on April 18, 2016. All common and subordinated unit, net income (loss) per unit and distribution per unit references included herein have been adjusted as if the change took place before the date of the earliest transaction reported. Any fractional units resulting from the reverse unit split were rounded to the nearest whole unit. Royal Energy Resources, Inc. Acquisition On January 21, 2016, a definitive agreement (“Definitive Agreement”) was completed between Royal Energy Resources, Inc. (“Royal”) and Wexford Capital LP (“Wexford Capital”) whereby Royal acquired 676,911 issued and outstanding common units of the Partnership from Wexford Capital 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 interests of Rhino GP LLC, the general partner of the Partnership (the “General Partner”), as well as 945,525 issued and outstanding subordinated units of the Partnership from Wexford Capital for $1.0 million. On March 17, 2016, Royal completed the acquisition of all of the issued and outstanding membership interests of the General Partner as well as the 945,525 issued and outstanding subordinated units from Wexford Capital. 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 6,000,000 common units in the Partnership to Royal in a private placement at $1.50 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 was 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 1,333,333 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 1,333,333 common units at $3.00 per common unit from Royal (each, a “Repurchase Option”). The Repurchase Options terminate on December 31, 2017. On May 13, 2016 and September 30, 2016, Royal paid the Partnership $3.0 million and $2.0 million, respectively, for the promissory note installments that were due July 31, 2016 and September 30, 2016, respectively. The payments were made in relation to the Fifth Amendment of the amended and restated credit agreement completed on May 13, 2016. See Note 8 for more information on the Fifth Amendment to the amended and restated credit agreement. On December 30, 2016, the Partnership modified the Securities Purchase Agreement with Royal for the final $2.0 million payment due on or before December 31, 2016 to extend the due date to December 31, 2018 (see “Letter Agreement” discussion below). Option Agreement-Armstrong Energy On December 30, 2016, the Partnership entered into an option agreement (the “Option Agreement”) with Royal, Rhino Resources Partners Holdings, LLC (“Rhino Holdings”), an entity wholly owned by certain investment partnerships managed by Yorktown Partners LLC (“Yorktown”), and the General Partner. Upon execution of the Option Agreement, the Partnership received an option (the “Call Option”) from Rhino Holdings to acquire substantially all of the outstanding common stock of Armstrong Energy, Inc. (“Armstrong Energy”) that is currently owned by investment partnerships managed by Yorktown, representing approximately 97% of the outstanding common stock of Armstrong Energy. The Option Agreement stipulates that the Partnership can exercise the Call Option no earlier than January 1, 2018 and no later than December 31, 2019. In exchange for Rhino Holdings granting the Partnership the Call Option, the Partnership issued 5.0 million common units, representing limited partner interests in the Partnership (the “Call Option Premium Units”) to Rhino Holdings upon the execution of the Option Agreement. The Option Agreement stipulates the Partnership can exercise the Call Option and purchase the common stock of Armstrong Energy in exchange for a number of common units to be issued to Rhino Holdings, which when added with the Call Option Premium Units, will result in Rhino Holdings owning 51% of the fully diluted common units of the Partnership. The purchase of Armstrong Energy through the exercise of the Call Option would also require Royal to transfer a 51% ownership interest in the General Partner to Rhino Holdings. The Partnership’s ability to exercise the Call Option is conditioned upon (i) sixty (60) days having passed since the entry by Armstrong Energy into an agreement with its bondholders to restructure its bonds and (ii) the amendment of the Partnership’s revolving credit facility to permit the acquisition of Armstrong Energy. The Option Agreement also contains an option (the “Put Option”) granted by the Partnership to Rhino Holdings whereby Rhino Holdings has the right, but not the obligation, to cause the Partnership to purchase substantially all of the outstanding common stock of Armstrong Energy from Rhino Holdings under the same terms and conditions discussed above for the Call Option. The exercise of the Put Option is dependent upon (i) the entry by Armstrong Energy into an agreement with its bondholders to restructure its bonds and (ii) the termination and repayment of any outstanding balance under the Partnership’s revolving credit facility. The Option Agreement contains customary covenants, representations and warranties and indemnification obligations for losses arising from the inaccuracy of representations or warranties or breaches of covenants contained in the Option Agreement, the Seventh Amendment and the GP Amendment. Upon the request by Rhino Holdings, we will also enter into a registration rights agreement that provides Rhino Holdings with the right to demand two shelf registration statements and registration statements on Form S-1, as well as piggyback registration rights for as long as Rhino Holdings owns at least 10% of the outstanding common units. Series A Preferred Unit Purchase Agreement On December 30, 2016, the Partnership entered into a Series A Preferred Unit Purchase Agreement (the “Preferred Unit Agreement”) with Weston Energy LLC (“Weston”), an entity wholly owned by certain investment partnerships managed by Yorktown, and Royal. Under the Preferred Unit Agreement, Weston and Royal purchased 1,300,000 and 200,000, respectively, of Series A preferred units representing limited partner interests in the Partnership at a price of $10.00 per Series A preferred unit. The Series A preferred units have the preferences, rights and obligations set forth in the Fourth Amended and Restated Agreement of Limited Partnership of the Partnership. Weston and Royal paid cash of $11.0 million and $2.0 million, respectively, to the Partnership and Weston assigned to the Partnership a $2.0 million note receivable from Royal originally dated September 30, 2016 (the “Weston Promissory Note”). The Preferred Unit Agreement contains customary representations, warrants and covenants, which include among other things, that, for as long as the Series A preferred units are outstanding, the Partnership will cause CAM Mining, LLC (“CAM Mining”), which comprises the Partnership’s Central Appalachia segment, to conduct its business in the ordinary course consistent with past practice and use reasonable best efforts to maintain and preserve intact its current organization, business and franchise and to preserve the rights, franchises, goodwill and relationships of its employees, customers, lenders, suppliers, regulators and others having business relationships with CAM Mining. The Preferred Unit Agreement stipulates that upon the request of the holder of the majority of the Partnership’s common units following their conversion from Series A preferred units, as outlined in the Amended and Restated Partnership Agreement (defined below), the Partnership will enter into a registration rights agreement with such holder. Such majority holder has the right to demand two shelf registration statements and registration statements on Form S-1, as well as piggyback registration rights. Letter Agreement Regarding Rhino Promissory Note and Weston Promissory Note On December 30, 2016, the Partnership and Royal entered into a letter agreement whereby they extended the maturity dates of the Weston Promissory Note and the final installment payment of the Rhino Promissory Note to December 31, 2018. The letter agreement further provides that the aggregate $4.0 million balance of the Weston Promissory Note and Rhino Promissory Note may be converted at Royal’s option into a number of shares of Royal’s common stock equal to the outstanding balance multiplied by seventy-five percent (75%) of the volume-weighted average closing price of Royal’s common stock for the 90 days preceding the date of conversion (“Royal VWAP”), subject to a minimum Royal VWAP of $3.50 and a maximum Royal VWAP of $7.50. Fourth Amended and Restated Agreement of Limited Partnership of Rhino Resource Partners LP On December 30, 2016, the general partner entered into the Fourth Amended and Restated Agreement of Limited Partnership of the Partnership (“Amended and Restated Partnership Agreement”) to create, authorize and issue the Series A preferred units. The Series A preferred units are a new class of equity security that rank senior to all classes or series of equity securities of the Partnership with respect to distribution rights and rights upon liquidation. The holders of the Series A preferred units shall be entitled to receive annual distributions equal to the greater of (i) 50% of the CAM Mining free cash flow (as defined below) and (ii) an amount equal to the number of outstanding Series A preferred units multiplied by $0.80. “CAM Mining free cash flow” is defined in the Amended and Restated Partnership Agreement as (i) the total revenue of the Partnership’s Central Appalachia business segment, minus (ii) the cost of operations (exclusive of depreciation, depletion and amortization) for the Partnership’s Central Appalachia business segment, minus (iii) an amount equal to $6.50, multiplied by the aggregate number of coal tons sold by the Partnership from its Central Appalachia business segment. If the Partnership fails to pay any or all of the distributions in respect of the Series A preferred units, such deficiency will accrue until paid in full and the Partnership will not be permitted to pay any distributions on its partnership interests that rank junior to the Series A preferred units, including its common units. The Series A preferred units will be liquidated in accordance with their capital accounts and upon liquidation will be entitled to distributions of property and cash in accordance with the balances of their capital accounts prior to such distributions to equity securities that rank junior to the Series A preferred units. The Series A preferred units will vote on an as-converted basis with the common units, and the Partnership will be restricted from taking certain actions without the consent of the holders of a majority of the Series A preferred units, including: (i) the issuance of additional Series A preferred units, or securities that rank senior or equal to the Series A preferred units; (ii) the sale or transfer of CAM Mining or a material portion of its assets; (iii) the repurchase of common units, or the issuance of rights or warrants to holders of common units entitling them to purchase common units at less than fair market value; (iv) consummation of a spin off; (v) the incurrence, assumption or guaranty of indebtedness for borrowed money in excess of $50.0 million except indebtedness relating to entities or assets that are acquired by the Partnership or its affiliates that is in existence at the time of such acquisition or (vi) the modification of CAM Mining’s accounting principles or the financial or operational reporting principles of the Partnership’s Central Appalachia business segment, subject to certain exceptions. The Partnership will have the option to convert the outstanding Series A preferred units at any time on or after the time at which the amount of aggregate distributions paid in respect of each Series A preferred unit exceeds $10.00 per unit. Each Series A preferred unit will convert into a number of common units equal to the quotient (the “Series A Conversion Ratio”) of (i) the sum of $10.00 and any unpaid distributions in respect of such Series A Preferred Unit divided by (ii) 75% of the volume-weighted average closing price of the common units for the preceding 90 trading days (the “VWAP”); provided however, that the VWAP will be capped at a minimum of $2.00 and a maximum of $10.00. On December 31, 2021, all outstanding Series A preferred units will convert into common units at the then applicable Series A Conversion Ratio. Delisting of Common Units from NYSE On December 17, 2015, the New York Stock Exchange (“NYSE”) notified the Partnership that the NYSE had determined to commence proceedings to delist its common units from the NYSE as a result of our failure to comply with the continued listing standard set forth in Section 802.01B of the NYSE Listed Company Manual to maintain an average global market capitalization over a consecutive 30 trading-day period of at least $15 million for our common units. The NYSE also suspended the trading of our common units at the close of trading on December 17, 2015. On January 4, 2016, the Partnership filed an appeal with the NYSE to review the suspension and delisting determination of the Partnership’s common units. The NYSE held a hearing regarding our appeal on April 20, 2016 and affirmed its prior decision to delist our common units. On April 27, 2016, the NYSE filed with the SEC a notification of removal from listing and registration on Form 25 to delist the Partnership’s common units and terminate the registration of its common units under Section 12(b) of the Securities Exchange Act of 1934. The delisting became effective on May 9, 2016. The Partnership’s common units trade on the OTCQB Marketplace under the ticker symbol “RHNO.” The Partnership is exploring the possibility of listing its common units on the NASDAQ Stock Market (“NASDAQ”), pending its capability to meet the NASDAQ initial listing standards.

Summary of Significant Accounti

Summary of Significant Accounting Policies and General	3 Months Ended
	Mar. 31, 2017
Accounting Policies [Abstract]
Summary of Significant Accounting Policies and General	2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND GENERAL Investments in Unconsolidated Affiliates. In December 2012, the Partnership made an initial investment in a new joint venture, Muskie Proppant LLC (“Muskie”), with affiliates of Wexford Capital. In November 2014, the Partnership contributed its investment interest in Muskie to Mammoth Energy Partners LP (“Mammoth”) in return for a limited partner interest in Mammoth. In October 2016, the Partnership contributed its limited partner interests in Mammoth to Mammoth Energy Services, Inc. (NASDAQ: TUSK) (“Mammoth Inc.”) in exchange for 234,300 shares of common stock of Mammoth Inc. For the three months ended March 31, 2017 and December 31, 2016, the Partnership recorded a fair market value adjustment of $1.5 million and $1.6 million, respectively, for the available-for-sale investment based on the market value of the shares at March 31, 2017 and December 31, 2016, respectively, which was recorded in Other Comprehensive Income. As of March 31, 2017 and December 31, 2016, the Partnership has recorded its investment in Mammoth Inc. as a short-term asset, which the Partnership has classified as available-for-sale. The Partnership has included its investment in Mammoth Inc. and its prior investment in Muskie in its Other category for segment reporting purposes. In September 2014, the Partnership made an initial investment of $5.0 million in a new joint venture, Sturgeon Acquisitions LLC (“Sturgeon”), with affiliates of Wexford Capital and Gulfport Energy Corporation (NASDAQ: GPOR) (“Gulfport”). 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 share of the operating loss for this investment for the three months ended March 31, 2017 and 2016 of approximately ($4,000) and ($79,000), 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. On March 20, 2017, the Partnership executed a contribution agreement to contribute its limited partner interests in Sturgeon to Mammoth Inc. The Partnership expects to receive 336,447 shares of common stock of Mammoth Inc. once the transaction closes, which is expected to occur in late May 2017. Recently Issued Accounting Standards. Revenue Recognition Revenue Recognition—Construction-Type and Production-Type Contracts Property, Plant, and Equipment Intangibles—Goodwill and Other In August 2014, the FASB issued ASU 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230) Classification of Certain Cash Receipts and Cash Payments In October 2016, the FASB issued ASU 2016-17, Consolidation (Topic 810): Interests Held through Related Parties that are Under Common Control In January 2017, the FASB issued ASU 2017-01, Business Combinations (Topic 805)

Discontinued Operations

Discontinued Operations	3 Months Ended
	Mar. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Discontinued Operations	3. DISCONTINUED OPERATIONS Elk Horn Coal Leasing In August 2016, the Partnership entered into an agreement to sell its Elk Horn coal leasing company (“Elk Horn”) to a third party for total cash consideration of $12.0 million. The Partnership received $10.5 million in cash consideration upon the closing of the Elk Horn transaction and the remaining $1.5 million of consideration will be paid in ten equal monthly installments of $150,000 on the 20 th Three Months Ended March 31, 2017 2016 Major line items constituting (loss)/income from discontinued operations for the Elk Horn disposal: Other revenues $ - $ 1,098 Total revenues - 1,098 Cost of operations (exclusive of depreciation, depletion and amortization shown separately below) - (45 ) Depreciation, depletion and amortization - 205 Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above) - 15 Interest expense and other - 4 Total costs and expenses - 179 Income from discontinued operations before income taxes for the Elk Horn disposal - 919 Income taxes - - Net income from discontinued operations $ - $ 919 Cash Flows.

Prepaid Expenses and Other Curr

Prepaid Expenses and Other Current Assets	3 Months Ended
	Mar. 31, 2017
Prepaid Expense and Other Assets, Current [Abstract]
Prepaid Expenses and Other Current Assets	4. PREPAID EXPENSES AND OTHER CURRENT ASSETS Prepaid expenses and other current assets as of March 31, 2017 and December 31, 2016 consisted of the following: March 31, 2017 December 31, 2016 (in thousands) Other prepaid expenses $ 779 $ 707 Debt issuance costs—net 929 1,239 Prepaid insurance 822 1,432 Prepaid leases 113 77 Supply inventory 565 614 Deposits - 164 Available-for-sale investment 4,998 3,532 Note receivable-current portion 450 900 Total Prepaid expenses and other $ 8,656 $ 8,665 Debt issuance costs were included in Prepaid expenses and other current assets as of March 31, 2017 and December 31, 2016 since the Partnership classified its credit facility balance as a current liability. See Note 8 for further information on the amendments to the amended and restated senior secured credit facility. As of March 31, 2017 and December 31, 2016, the note receivable balance of $0.5 million and $0.9 million, respectively, relates to the $1.5 million of consideration to be paid in ten equal monthly installments of $150,000 for the Elk Horn sale discussed earlier.

Property, Plant and Equipment

Property, Plant and Equipment	3 Months Ended
	Mar. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment	5. PROPERTY, PLANT AND EQUIPMENT Property, plant and equipment, including coal properties and mine development and construction costs, as of March 31, 2017 and December 31, 2016 are summarized by major classification as follows: Useful Lives March 31, 2017 December 31, 2016 (in thousands) Land and land improvements $ 16,175 $ 16,377 Mining and other equipment and related facilities 2 - 20 Years 309,339 305,626 Mine development costs 1 - 15 Years 57,459 57,392 Coal properties and oil and natural gas properties 1 - 15 Years 67,989 67,989 Construction work in process 4,581 1,797 Total 455,543 449,181 Less accumulated depreciation, depletion and amortization (272,560 ) (266,874 ) Net $ 182,983 $ 182,307 Depreciation expense for mining and other equipment and related facilities, depletion expense for coal properties and oil and natural gas properties, amortization expense for mine development costs, amortization expense for intangible assets and amortization expense for asset retirement costs for the three months ended March 31, 2017 and 2016 were as follows: Three Months Ended March 31, 2017 2016 (in thousands) Depreciation expense-mining and other equipment and related facilities $ 4,436 $ 5,287 Depletion expense for coal properties and oil and natural gas properties 355 393 Amortization expense for mine development costs 757 403 Amortization expense for asset retirement costs 150 (42 ) Total depreciation, depletion and amortization $ 5,698 $ 6,041 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

Intangible and Other Non-curren

Intangible and Other Non-current Assets	3 Months Ended
	Mar. 31, 2017
Intangible And Other Non-current Assets
Intangible and Other Non-current Assets	6. INTANGIBLE AND OTHER NON-CURRENT ASSETS Other non-current assets as of March 31, 2017 and December 31, 2016 consisted of the following: March 31, 2017 December 31, 2016 (in thousands) Deposits and other $ 220 $ 218 Due (to)/from Rhino GP (26 ) (573 ) Non-current receivable 27,157 27,157 Deferred expenses 208 216 Total $ 27,559 $ 27,018 Non-current receivable Balance Sheet Note receivable-related party Call Option-Armstrong Energy The Partnership has determined the value of the common units issued at December 30, 2016 of $21.8 million constituted an amount that would be applied to the potential acquisition of Armstrong Energy, as discussed in Note 1. Because facts and circumstances, including the likelihood of consummation of the contemplated transaction, have not changed substantially since the agreement was executed, the Partnership has concluded that there has been no substantial change in the value of the Call Option.

Accrued Expenses and Other Curr

Accrued Expenses and Other Current Liabilities	3 Months Ended
	Mar. 31, 2017
Payables and Accruals [Abstract]
Accrued Expenses and Other Current Liabilities	7. ACCRUED EXPENSES AND OTHER CURRENT LIABILITIES Accrued expenses and other current liabilities as of March 31, 2017 and December 31, 2016 consisted of the following: March 31, 2017 December 31, 2016 (in thousands) Payroll, bonus and vacation expense $ 1,918 $ 1,496 Non income taxes 3,121 2,252 Royalty expenses 1,909 1,617 Accrued interest 603 601 Health claims 656 630 Workers’ compensation & pneumoconiosis 2,450 2,450 Deferred revenues - - Accrued insured litigation claims 26 277 Preferred unit distribution 1,117 - Other 717 740 Total $ 12,517 $ 10,063 The $26,000 and $277,000 accrued for insured litigation claims as of March 31, 2017 and December 31, 2016, respectively, consists of probable and estimable litigation claims that are the primary obligation of the Partnership. The amount accrued for litigation claims is also due from the Partnership’s insurance providers and is included in Accounts receivable, net of allowance for doubtful accounts on the Partnership’s unaudited condensed consolidated statements of financial position. The Partnership presents this amount on a gross asset and liability basis, as a right of setoff does not exist per the accounting guidance in ASC Topic 210, Balance Sheet

Debt

Debt	3 Months Ended
	Mar. 31, 2017
Debt Disclosure [Abstract]
Debt	8. DEBT Debt as of March 31, 2017 and December 31, 2016 consisted of the following: March 31, 2017 December 31, 2016 (in thousands) Senior secured credit facility with PNC Bank, N.A. $ 14,840 $ 10,040 Total 14,840 10,040 Less current portion (14,840 ) (10,040 ) Long-term debt $ - $ - Senior Secured Credit Facility with PNC Bank, N.A. On March 17, 2016, the Partnership entered into a fourth amendment (the “Fourth Amendment”) of the amended and restated credit agreement. The Fourth Amendment amended 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. The Fourth Amendment also eliminated 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%. On May 13, 2016, the Partnership entered into the Fifth Amendment of the amended and restated credit agreement, which extended the term to July 31, 2017. In July 2016, the Partnership entered into a sixth amendment (the “Sixth Amendment”) of our amended and restated senior secured credit agreement that permitted the sale of Elk Horn that was discussed earlier. The Sixth Amendment further reduced the maximum commitment amount allowed under the credit facility for the additional $1.5 million that is to be received from the Elk Horn sale by $375,000 each quarterly period beginning September 30, 2016 through June 30, 2017. In December 2016, the Partnership entered into a seventh amendment of its amended and restated credit agreement (the “Seventh Amendment”). The Seventh Amendment allows for the Series A preferred units as outlined in the Amended and Restated Partnership Agreement. The Seventh Amendment immediately reduces the revolving credit commitments by $11.0 million and provides for additional revolving credit commitment reductions of $2.0 million each on June 30, 2017 and September 30, 2017. The Seventh Amendment further reduces the revolving credit commitments over time on a dollar-for-dollar basis for the net cash proceeds received from any asset sales after the Seventh Amendment date once the aggregate net cash proceeds received exceeds $2.0 million. The Seventh Amendment alters the maximum leverage ratio to 4.0 to 1.0 effective December 31, 2016 through May 31, 2017 and 3.5 to 1.0 from June 30, 2017 through December 31, 2017. The maximum leverage ratio shall be reduced by 0.50 to 1.0 for every $10.0 million of net cash proceeds, in the aggregate, received after the Seventh Amendment date from (i) the issuance of any equity by the Partnership and/or (ii) the disposition of any assets in excess of $2.0 million in the aggregate, provided, however, that in no event will the maximum leverage ratio be reduced below 3.0 to 1.0. The Seventh Amendment alters the minimum consolidated EBITDA figure, as calculated on a rolling twelve months basis, to $12.5 million from December 31, 2016 through May 31, 2017 and $15.0 million from June 30, 2017 through December 31, 2017. The Seventh Amendment alters the maximum capital expenditures allowed, as calculated on a rolling twelve months basis, to $20.0 million through the expiration of the credit facility. A condition precedent to the effectiveness of the Seventh Amendment is the receipt of the $13.0 million of cash proceeds received by the Partnership from the issuance of the Series A preferred units pursuant to the Preferred Unit Agreement, which was used to repay outstanding borrowings under the revolving credit facility. Per the Seventh Amendment, the receipt of $13.0 million cash proceeds fulfills the required Royal equity contribution, which was a requirement of prior amendments to the credit agreement. On March 23, 2017, the Partnership entered into an eighth amendment (the “Eighth Amendment”) of its amended and restated credit agreement that allows the annual auditor’s report for the years ended December 31, 2016 and 2015 to contain a qualification with respect to the short-term classification of the Partnership’s credit facility balance without creating a default under the credit agreement. As of March 31, 2017 and December 31, 2016, the Partnership was in compliance with respect to all covenants contained in its credit agreement. At March 31, 2017, the Operating Company had borrowed $14.8 million at a variable interest rate of PRIME plus 3.50% (7.50% at March 31, 2017). In addition, the Operating Company had outstanding letters of credit of $26.1 million at a fixed interest rate of 5.00% at March 31, 2017. Based upon a maximum borrowing capacity of 4.00 times a trailing twelve-month EBITDA calculation (as defined in the credit agreement), the Operating Company had not used $7.7 million of the borrowing availability at March 31, 2017.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	9. ASSET RETIREMENT OBLIGATIONS The changes in asset retirement obligations for the three months ended March 31, 2017 and the year ended December 31, 2016 are as follows: Three months ended Year ended March 31, 2017 December 31, 2016 (in thousands) Balance at beginning of period (including current portion) $ 23,278 $ 23,077 Accretion expense 474 1,486 Adjustments to the liability from annual recosting and other - (1,085 ) Liabilities settled (34 ) (200 ) Balance at end of period 23,718 23,278 Less current portion of asset retirement obligation (917 ) (917 ) Long-term portion of asset retirement obligation $ 22,801 $ 22,361

Employee Benefits

Employee Benefits	3 Months Ended
	Mar. 31, 2017
Retirement Benefits [Abstract]
Employee Benefits	10. EMPLOYEE BENEFITS In conjunction with the acquisition of the coal operations of American Electric Power on April 16, 2004, the Operating Company acquired a postretirement benefit plan that provided 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 amortized the prior service cost benefit over the remaining term of the benefits provided through January 31, 2016. For the three months ended March 31, 2016, the Partnership recognized a benefit of approximately $3.9 million from the plan amendment in the Cost of operations line of the unaudited condensed consolidated statements of operations and comprehensive income. 401(k) Plans Three months ended March 31, 2017 2016 (in thousands) 401(k) plan expense $ 370 $ 308

Equity-Based Compensation

Equity-Based Compensation	3 Months Ended
	Mar. 31, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity-Based Compensation	11. EQUITY-BASED COMPENSATION In October 2010, the General Partner established the Rhino Long-Term Incentive Plan (the “Plan” or “LTIP”). The Plan is intended to promote the interests of the Partnership by providing to employees, consultants and directors of the General Partner, the Partnership or affiliates of either, incentive compensation awards to encourage superior performance. The LTIP provides for grants of restricted units, unit options, unit appreciation rights, phantom units, unit awards, and other unit-based awards. As discussed in Note 1, on March 17, 2016, Royal completed the acquisition of all of the issued and outstanding membership interests of Rhino GP LLC as well as 945,525 issued and outstanding subordinated units from Wexford Capital. Royal obtained control of, and a majority limited partner interest, in the Partnership with the completion of this transaction, which constituted a change in control of the Partnership. The language in the Partnership’s phantom unit and restricted unit grant agreements states that all outstanding, unvested units would become immediately vested upon a change in control. For the three months ended March 31, 2016, the Partnership recognized approximately $10,000 of expense from the vesting of these units as a result of the change in control.

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	12. COMMITMENTS AND CONTINGENCIES Coal Sales Contracts and Contingencies Year Tons (in thousands) Number of customers 2017 Q2-Q4 2,900 16 2018 701 4 Some of the contracts have sales price adjustment provisions, subject to certain limitations and adjustments, based on a variety of factors and indices. Purchase Commitments Purchased Coal Expenses Leases Three months ended March 31, 2017 2016 (in thousands) Lease expense $ 1,513 $ 1,029 Royalty expense $ 3,377 $ 2,342 Joint Ventures The Partnership may contribute additional capital to the Sturgeon joint venture that was formed in the third quarter of 2014. The Partnership made an initial capital contribution of $5.0 million during the third quarter ended September 30, 2014 based upon its proportionate ownership interest. The Partnership did not make any capital contributions to the Sturgeon joint venture during the three months ended March 31, 2017 or 2016. See Note 2 for discussion on the potential contribution of Sturgeon to Mammoth. Series A preferred unit distributions-

Earnings Per Unit ('EPU')

Earnings Per Unit ('EPU')	3 Months Ended
	Mar. 31, 2017
Earnings Per Unit [Abstract]
Earnings Per Unit ("EPU")	13. EARNINGS PER UNIT (“EPU”) On April 18, 2016, the Partnership completed a 1-for-10 reverse split on its common units and subordinated units. The following tables present a reconciliation of the numerators and denominators of the basic and diluted EPU calculations for the three months ended March 31, 2017 and 2016, which include the retrospective application of the 1-for-10 reverse unit split: Three months ended March 31, 2017 General Partner Common Unitholders Subordinated Unitholders Preferred Unitholders Numerator: (in thousands, except per unit data) Interest in net (loss)/income: Net (loss)/income from continuing operations $ (13 ) $ (2,859 ) $ (274 ) $ 1,117 Net income/(loss) from discontinued operations - - - - Total interest in net (loss)/income $ (13 ) $ (2,859 ) $ (274 ) $ 1,117 Denominator: Weighted average units used to compute basic EPU n/a 12,906 1,236 1,500 Weighted average units used to compute diluted EPU n/a 12,906 1,236 1,500 Net (loss)/income per limited partner unit, basic Net (loss)/income per unit from continuing operations n/a $ (0.22 ) $ (0.22 ) $ 0.74 Net income/(loss) per unit from discontinued operations n/a - - - Net (loss)/income per common unit, basic n/a $ (0.22 ) $ (0.22 ) $ 0.74 Net (loss)/income per limited partner unit, diluted Net (loss) per unit from continuing operations n/a $ (0.22 ) $ (0.22 ) 0.74 Net income/(loss) per unit from discontinued operations n/a - - - Net (loss) per common unit, diluted n/a $ (0.22 ) $ (0.22 ) 0.74 Three months ended March 31, 2016 General Partner Common Unitholders Subordinated Unitholders Preferred Unitholders Numerator: (in thousands, except per unit data) Interest in net (loss)/income: Net (loss) from continuing operations $ (42 ) $ (1,375 ) $ (724 ) n/a Net income from discontinued operations 18 590 311 n/a Total interest in net (loss) $ (24 ) $ (785 ) $ (413 ) n/a Denominator: Weighted average units used to compute basic EPU n/a 2,349 1,236 n/a Weighted average units used to compute diluted EPU n/a 2,349 1,236 n/a Net (loss)/income per limited partner unit, basic Net (loss) per unit from continuing operations n/a $ (0.58 ) $ (0.58 ) n/a Net income per unit from discontinued operations n/a 0.25 0.25 n/a Net income per common unit, basic n/a $ (0.33 ) $ (0.33 ) n/a Net (loss)/income per limited partner unit, diluted Net (loss) per unit from continuing operations n/a $ (0.58 ) $ (0.58 ) n/a Net income per unit from discontinued operations n/a 0.25 0.25 n/a Net income per common unit, diluted n/a $ (0.33 ) $ (0.33 ) n/a 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 total net losses for the three months ended March 31, 2017 and 2016, all potential dilutive units were excluded from the diluted EPU calculation for these periods.

Major Customers

Major Customers	3 Months Ended
	Mar. 31, 2017
Risks and Uncertainties [Abstract]
Major Customers	14. MAJOR CUSTOMERS The Partnership had revenues or receivables from the following major customers that in each period equaled or exceeded 10% of revenues: Three months Three months March 31 2017 December 31 2016 ended ended Receivable Receivable March 31 2017 March 31 2016 Balance Balance Sales Sales (in thousands) LGE/KU $ 1,397 $ 1,496 $ 10,521 $ 9,483 Big Rivers Electric Corporation 2,805 - 6,244 5,309

Fair Value of Financial Instrum

Fair Value of Financial Instruments	3 Months Ended
	Mar. 31, 2017
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	15. FAIR VALUE OF FINANCIAL INSTRUMENTS The Partnership determines the fair value of assets and liabilities based on the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants. The fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. The fair value hierarchy is based on whether the inputs to valuation techniques are observable or unobservable. Observable inputs reflect market data obtained from independent sources, while unobservable inputs reflect the Partnership’s assumptions of what market participants would use. The fair value hierarchy includes three levels of inputs that may be used to measure fair value as described below: Level One - Quoted prices for identical instruments in active markets. Level Two - The fair value of the assets and liabilities included in Level 2 are based on standard industry income approach models that use significant observable inputs. Level Three - Unobservable inputs significant to the fair value measurement supported by little or no market activity. In those cases when the inputs used to measure fair value meet the definition of more than one level of the fair value hierarchy, the lowest level input that is significant to the fair value measurement in its totality determines the applicable level in the fair value hierarchy. 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 amended and restated senior secured credit facility was based upon a Level 2 measurement utilizing a market approach, which incorporated market-based interest rate information with credit risks similar to the Partnership. The fair value of the Partnership’s amended and restated senior secured credit facility approximates the carrying value at March 31, 2017. As of March 31, 2017 and December 31, 2016, the Partnership had a recurring fair value measurement relating to its investment in Mammoth, Inc. As discussed in Note 2, in October 2016, the Partnership contributed its limited partner interests in Mammoth to Mammoth, Inc. in exchange for 234,300 shares of common stock of Mammoth, Inc. The common stock of Mammoth, Inc. began trading on the NASDAQ Global Select Market in October 2016 under the ticker symbol TUSK and the Partnership sold 1,953 shares during the initial public offering of Mammoth, Inc. and received proceeds of approximately $27,000. The Partnership’s remaining shares of Mammoth, Inc. are classified as a held-for-sale investment on the Partnership’s unaudited condensed consolidated statements of financial position. Based on the availability of a quoted price, the recurring fair value measurement of the Mammoth, Inc. shares is a Level 2 measurement.

Supplemental Disclosures of Cas

Supplemental Disclosures of Cash Flow Information	3 Months Ended
	Mar. 31, 2017
Supplemental Cash Flow Information [Abstract]
Supplemental Disclosures of Cash Flow Information	16. SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION The unaudited condensed consolidated statements of cash flows for the three months ended March 31, 2017 and 2016 excludes approximately $0.6 million and $0.3 million, respectively, of property additions, which are recorded in accounts payable.

Segment Information

Segment Information	3 Months Ended
	Mar. 31, 2017
Segment Reporting [Abstract]
Segment Information	17. SEGMENT INFORMATION The Partnership produces and markets coal from surface and underground mines in Kentucky, West Virginia, Ohio and Utah. The Partnership sells primarily to electric utilities in the United States. For the three months ended March 31, 2017, the Partnership had four reportable segments: Central Appalachia (comprised of both surface and underground mines located in Eastern Kentucky and Southern West Virginia), Northern Appalachia (comprised of both surface and underground mines located in Ohio), Rhino Western (comprised of an underground mine in Utah) and Illinois Basin (comprised of an underground mine in western Kentucky). The Partnership’s Other category is comprised of the Partnership’s ancillary businesses and its remaining oil and natural gas activities. The Partnership has not provided disclosure of total expenditures by segment for long-lived assets, as the Partnership does not maintain discrete financial information concerning segment expenditures for long lived-assets, and accordingly such information is not provided to the Partnership’s chief operating decision maker. The information provided in the following tables represents the primary measures used to assess segment performance by the Partnership’s chief operating decision maker. Reportable segment results of operations for the three months ended March 31, 2017 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization): Central Northern Rhino Illinois Total Appalachia Appalachia Western Basin Other Consolidated (in thousands) Total revenues $ 23,314 $ 6,127 $ 7,298 $ 16,807 $ 4 $ 53,550 DD&A 1,973 498 1,116 2,004 107 5,698 Interest expense - - - - 1,155 1,155 Net income (loss) from continuing operations $ 2,294 $ (780 ) $ (586 ) $ 654 $ (3,611 ) $ (2,029 ) Reportable segment results of operations for the three months ended March 31, 2016 are as follows: Central Northern Rhino Illinois Total Appalachia Appalachia Western Basin Other Consolidated (in thousands) Total revenues $ 5,612 $ 9,151 $ 9,597 $ 14,880 $ 90 $ 39,330 DD&A 1,723 952 1,411 1,814 141 6,041 Interest expense 183 82 36 69 1,200 1,570 Net income (loss) from continuing operations $ (3,001 ) $ 4,694 $ (39 ) $ 318 $ (4,113 ) $ (2,141 )

Accumulated Distribution Arrear

Accumulated Distribution Arrearages	3 Months Ended
	Mar. 31, 2017
Accumulated Distribution Arrearages
Accumulated distribution arrearages	18. ACCUMULATED DISTRIBUTION ARREARAGES Beginning with the quarter ended June 30, 2015 and continuing through the quarter ended March 31, 2017, we have suspended the cash distribution on our common units. For each of the quarters ended September 30, 2014, December 31, 2014 and March 31, 2015, we announced cash distributions per common unit at levels lower than the minimum quarterly distribution. We have not paid any distribution on our subordinated units for any quarter after the quarter ended March 31, 2012. The distribution suspension and prior reductions were the result of prolonged weakness in the coal markets, which has continued to adversely affect our cash flow. The current amount of accumulated arrearages as of March 31, 2017 related to the common unit distribution was approximately $265.1 million.

Summary of Significant Accoun25

Summary of Significant Accounting Policies and General (Policies)	3 Months Ended
	Mar. 31, 2017
Accounting Policies [Abstract]
Investments in Unconsolidated Affiliates	Investments in Unconsolidated Affiliates. In December 2012, the Partnership made an initial investment in a new joint venture, Muskie Proppant LLC (“Muskie”), with affiliates of Wexford Capital. In November 2014, the Partnership contributed its investment interest in Muskie to Mammoth Energy Partners LP (“Mammoth”) in return for a limited partner interest in Mammoth. In October 2016, the Partnership contributed its limited partner interests in Mammoth to Mammoth Energy Services, Inc. (NASDAQ: TUSK) (“Mammoth Inc.”) in exchange for 234,300 shares of common stock of Mammoth Inc. For the three months ended March 31, 2017 and December 31, 2016, the Partnership recorded a fair market value adjustment of $1.5 million and $1.6 million, respectively, for the available-for-sale investment based on the market value of the shares at March 31, 2017 and December 31, 2016, respectively, which was recorded in Other Comprehensive Income. As of March 31, 2017 and December 31, 2016, the Partnership has recorded its investment in Mammoth Inc. as a short-term asset, which the Partnership has classified as available-for-sale. The Partnership has included its investment in Mammoth Inc. and its prior investment in Muskie in its Other category for segment reporting purposes. In September 2014, the Partnership made an initial investment of $5.0 million in a new joint venture, Sturgeon Acquisitions LLC (“Sturgeon”), with affiliates of Wexford Capital and Gulfport Energy Corporation (NASDAQ: GPOR) (“Gulfport”). 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 share of the operating loss for this investment for the three months ended March 31, 2017 and 2016 of approximately ($4,000) and ($79,000), 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. On March 20, 2017, the Partnership executed a contribution agreement to contribute its limited partner interests in Sturgeon to Mammoth Inc. The Partnership expects to receive 336,447 shares of common stock of Mammoth Inc. once the transaction closes, which is expected to occur in late May 2017.
Recently Issued Accounting Standards	Recently Issued Accounting Standards. Revenue Recognition Revenue Recognition—Construction-Type and Production-Type Contracts Property, Plant, and Equipment Intangibles—Goodwill and Other In August 2014, the FASB issued ASU 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230) Classification of Certain Cash Receipts and Cash Payments In October 2016, the FASB issued ASU 2016-17, Consolidation (Topic 810): Interests Held through Related Parties that are Under Common Control In January 2017, the FASB issued ASU 2017-01, Business Combinations (Topic 805)

Discontinued Operations (Tables

Discontinued Operations (Tables)	3 Months Ended
	Mar. 31, 2017
Discontinued Operations and Disposal Groups [Abstract]
Schedule of Major Components of Net (Loss) Income from Discontinued Operations	The previous operating results of Elk Horn have been reclassified and reported on the (Gain)/loss from discontinued operations line on the Partnership’s unaudited condensed consolidated statement of operations and comprehensive income for the three months ended March 31, 2016. Three Months Ended March 31, 2017 2016 Major line items constituting (loss)/income from discontinued operations for the Elk Horn disposal: Other revenues $ - $ 1,098 Total revenues - 1,098 Cost of operations (exclusive of depreciation, depletion and amortization shown separately below) - (45 ) Depreciation, depletion and amortization - 205 Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above) - 15 Interest expense and other - 4 Total costs and expenses - 179 Income from discontinued operations before income taxes for the Elk Horn disposal - 919 Income taxes - - Net income from discontinued operations $ - $ 919

Prepaid Expenses And Other Cu27

Prepaid Expenses And Other Current Assets (Tables)	3 Months Ended
	Mar. 31, 2017
Prepaid Expense and Other Assets, Current [Abstract]
Schedule of Prepaid Expenses and Other Current Assets	Prepaid expenses and other current assets as of March 31, 2017 and December 31, 2016 consisted of the following: March 31, 2017 December 31, 2016 (in thousands) Other prepaid expenses $ 779 $ 707 Debt issuance costs—net 929 1,239 Prepaid insurance 822 1,432 Prepaid leases 113 77 Supply inventory 565 614 Deposits - 164 Available-for-sale investment 4,998 3,532 Note receivable-current portion 450 900 Total Prepaid expenses and other $ 8,656 $ 8,665

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	3 Months Ended
	Mar. 31, 2017
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment by Major Classification	Property, plant and equipment, including coal properties and mine development and construction costs, as of March 31, 2017 and December 31, 2016 are summarized by major classification as follows: Useful Lives March 31, 2017 December 31, 2016 (in thousands) Land and land improvements $ 16,175 $ 16,377 Mining and other equipment and related facilities 2 - 20 Years 309,339 305,626 Mine development costs 1 - 15 Years 57,459 57,392 Coal properties and oil and natural gas properties 1 - 15 Years 67,989 67,989 Construction work in process 4,581 1,797 Total 455,543 449,181 Less accumulated depreciation, depletion and amortization (272,560 ) (266,874 ) Net $ 182,983 $ 182,307
Schedule of Depreciation, Depletion, and Amortization	Depreciation expense for mining and other equipment and related facilities, depletion expense for coal properties and oil and natural gas properties, amortization expense for mine development costs, amortization expense for intangible assets and amortization expense for asset retirement costs for the three months ended March 31, 2017 and 2016 were as follows: Three Months Ended March 31, 2017 2016 (in thousands) Depreciation expense-mining and other equipment and related facilities $ 4,436 $ 5,287 Depletion expense for coal properties and oil and natural gas properties 355 393 Amortization expense for mine development costs 757 403 Amortization expense for asset retirement costs 150 (42 ) Total depreciation, depletion and amortization $ 5,698 $ 6,041

Intangible and Other Non-curr29

Intangible and Other Non-current Assets (Tables)	3 Months Ended
	Mar. 31, 2017
Intangible And Other Non-current Assets
Schedule of Other Non-current Assets	Other non-current assets as of March 31, 2017 and December 31, 2016 consisted of the following: March 31, 2017 December 31, 2016 (in thousands) Deposits and other $ 220 $ 218 Due (to)/from Rhino GP (26 ) (573 ) Non-current receivable 27,157 27,157 Deferred expenses 208 216 Total $ 27,559 $ 27,018

Accrued Expenses and Other Cu30

Accrued Expenses and Other Current Liabilities (Tables)	3 Months Ended
	Mar. 31, 2017
Payables and Accruals [Abstract]
Schedule of Accrued Expenses and Other Current Liabilities	Accrued expenses and other current liabilities as of March 31, 2017 and December 31, 2016 consisted of the following: March 31, 2017 December 31, 2016 (in thousands) Payroll, bonus and vacation expense $ 1,918 $ 1,496 Non income taxes 3,121 2,252 Royalty expenses 1,909 1,617 Accrued interest 603 601 Health claims 656 630 Workers’ compensation & pneumoconiosis 2,450 2,450 Deferred revenues - - Accrued insured litigation claims 26 277 Preferred unit distribution 1,117 - Other 717 740 Total $ 12,517 $ 10,063

Debt (Tables)

Debt (Tables)	3 Months Ended
	Mar. 31, 2017
Debt Disclosure [Abstract]
Schedule of Debt	Debt as of March 31, 2017 and December 31, 2016 consisted of the following: March 31, 2017 December 31, 2016 (in thousands) Senior secured credit facility with PNC Bank, N.A. $ 14,840 $ 10,040 Total 14,840 10,040 Less current portion (14,840 ) (10,040 ) Long-term debt $ - $ -

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations	The changes in asset retirement obligations for the three months ended March 31, 2017 and the year ended December 31, 2016 are as follows: Three months ended Year ended March 31, 2017 December 31, 2016 (in thousands) Balance at beginning of period (including current portion) $ 23,278 $ 23,077 Accretion expense 474 1,486 Adjustments to the liability from annual recosting and other - (1,085 ) Liabilities settled (34 ) (200 ) Balance at end of period 23,718 23,278 Less current portion of asset retirement obligation (917 ) (917 ) Long-term portion of asset retirement obligation $ 22,801 $ 22,361

Employee Benefits (Tables)

Employee Benefits (Tables)	3 Months Ended
	Mar. 31, 2017
Retirement Benefits [Abstract]
Schedule of Expense Under Defined Contribution Savings Plans	The expense under these plans for the three months ended March 31, 2017 and 2016 is included in Cost of operations and Selling, general and administrative expense in the Partnership’s unaudited condensed consolidated statements of operations and comprehensive income and was as follows: Three months ended March 31, 2017 2016 (in thousands) 401(k) plan expense $ 370 $ 308

Commitments and Contingencies (

Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2017
Commitments and Contingencies Disclosure [Abstract]
Schedule of Delivery Commitments	As of March 31, 2017, the Partnership had commitments under sales contracts to deliver annually scheduled base quantities of coal as follows: Year Tons (in thousands) Number of customers 2017 Q2-Q4 2,900 16 2018 701 4
Schedule of Lease and Royalty Expense	Three months ended March 31, 2017 2016 (in thousands) Lease expense $ 1,513 $ 1,029 Royalty expense $ 3,377 $ 2,342

Earnings Per Unit ('EPU') (Tabl

Earnings Per Unit ('EPU') (Tables)	3 Months Ended
	Mar. 31, 2017
Earnings Per Unit [Abstract]
Schedule of Calculation of Numerator and Denominator in Earnings Per Unit	The following tables present a reconciliation of the numerators and denominators of the basic and diluted EPU calculations for the three months ended March 31, 2017 and 2016, which include the retrospective application of the 1-for-10 reverse unit split: Three months ended March 31, 2017 General Partner Common Unitholders Subordinated Unitholders Preferred Unitholders Numerator: (in thousands, except per unit data) Interest in net (loss)/income: Net (loss)/income from continuing operations $ (13 ) $ (2,859 ) $ (274 ) $ 1,117 Net income/(loss) from discontinued operations - - - - Total interest in net (loss)/income $ (13 ) $ (2,859 ) $ (274 ) $ 1,117 Denominator: Weighted average units used to compute basic EPU n/a 12,906 1,236 1,500 Weighted average units used to compute diluted EPU n/a 12,906 1,236 1,500 Net (loss)/income per limited partner unit, basic Net (loss)/income per unit from continuing operations n/a $ (0.22 ) $ (0.22 ) $ 0.74 Net income/(loss) per unit from discontinued operations n/a - - - Net (loss)/income per common unit, basic n/a $ (0.22 ) $ (0.22 ) $ 0.74 Net (loss)/income per limited partner unit, diluted Net (loss) per unit from continuing operations n/a $ (0.22 ) $ (0.22 ) 0.74 Net income/(loss) per unit from discontinued operations n/a - - - Net (loss) per common unit, diluted n/a $ (0.22 ) $ (0.22 ) 0.74 Three months ended March 31, 2016 General Partner Common Unitholders Subordinated Unitholders Preferred Unitholders Numerator: (in thousands, except per unit data) Interest in net (loss)/income: Net (loss) from continuing operations $ (42 ) $ (1,375 ) $ (724 ) n/a Net income from discontinued operations 18 590 311 n/a Total interest in net (loss) $ (24 ) $ (785 ) $ (413 ) n/a Denominator: Weighted average units used to compute basic EPU n/a 2,349 1,236 n/a Weighted average units used to compute diluted EPU n/a 2,349 1,236 n/a Net (loss)/income per limited partner unit, basic Net (loss) per unit from continuing operations n/a $ (0.58 ) $ (0.58 ) n/a Net income per unit from discontinued operations n/a 0.25 0.25 n/a Net income per common unit, basic n/a $ (0.33 ) $ (0.33 ) n/a Net (loss)/income per limited partner unit, diluted Net (loss) per unit from continuing operations n/a $ (0.58 ) $ (0.58 ) n/a Net income per unit from discontinued operations n/a 0.25 0.25 n/a Net income per common unit, diluted n/a $ (0.33 ) $ (0.33 ) n/a

Major Customers (Tables)

Major Customers (Tables)	3 Months Ended
	Mar. 31, 2017
Risks and Uncertainties [Abstract]
Summary of Major Customers	The Partnership had revenues or receivables from the following major customers that in each period equaled or exceeded 10% of revenues: Three months Three months March 31 2017 December 31 2016 ended ended Receivable Receivable March 31 2017 March 31 2016 Balance Balance Sales Sales (in thousands) LGE/KU $ 1,397 $ 1,496 $ 10,521 $ 9,483 Big Rivers Electric Corporation 2,805 - 6,244 5,309

Segment Information (Tables)

Segment Information (Tables)	3 Months Ended
	Mar. 31, 2017
Segment Reporting [Abstract]
Schedule of Reportable Segment Results of Operations	Reportable segment results of operations for the three months ended March 31, 2017 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization): Central Northern Rhino Illinois Total Appalachia Appalachia Western Basin Other Consolidated (in thousands) Total revenues $ 23,314 $ 6,127 $ 7,298 $ 16,807 $ 4 $ 53,550 DD&A 1,973 498 1,116 2,004 107 5,698 Interest expense - - - - 1,155 1,155 Net income (loss) from continuing operations $ 2,294 $ (780 ) $ (586 ) $ 654 $ (3,611 ) $ (2,029 ) Reportable segment results of operations for the three months ended March 31, 2016 are as follows: Central Northern Rhino Illinois Total Appalachia Appalachia Western Basin Other Consolidated (in thousands) Total revenues $ 5,612 $ 9,151 $ 9,597 $ 14,880 $ 90 $ 39,330 DD&A 1,723 952 1,411 1,814 141 6,041 Interest expense 183 82 36 69 1,200 1,570 Net income (loss) from continuing operations $ (3,001 ) $ 4,694 $ (39 ) $ 318 $ (4,113 ) $ (2,141 )

Basis of Presentation and Org38

Basis of Presentation and Organization (Details Narrative) $ / shares in Units, $ in Thousands

Dec. 30, 2016USD ($)$ / sharesshares

Jul. 31, 2016USD ($)

May 13, 2016USD ($)

Apr. 18, 2016

Mar. 21, 2016USD ($)$ / sharesshares

Mar. 17, 2016shares

Jan. 21, 2016USD ($)shares

Mar. 31, 2017USD ($)

Sep. 30, 2016USD ($)

Dec. 31, 2016USD ($)

Dec. 30, 2016USD ($)$ / shares

May 31, 2016USD ($)

Mar. 31, 2016USD ($)

Dec. 17, 2015USD ($)

Revolving credit commitments

$ 75,000

$ 80,000

Line of credit current

$ 14,800

$ 1,000

Reverse split description

1-for-10 reverse split on its common units and subordinated units

Reverse stock split conversion ratio

10

Number of common unit issued during the period, value

$ 21,800

Royal Energy Resources, Inc [Member]

Common stock price per unit | $ / shares

$ 3

Number of common units rescind of purchase during the period | shares

1,333,333

Number of common units repurchase during the period | shares

1,333,333

Repurchase options termination date

Dec. 31, 2017

Repayment of debt

$ 3,000

$ 2,000

Debt due date

Jul. 31, 2016

Sep. 30, 2016

Debt conversion price per share | $ / shares

$ 1.50

Royal Energy Resources Inc. [Member] | Weston Promissory Note [Member]

Promissory note face value

$ 2,000

Wexford Capital L P [Member] | Royal Energy Resources, Inc [Member] | Subordinated Units [Member]

Number of common unit shares acquired during the period | shares

945,525

Royal VWAP [Member] | Minimum [Member]

Debt conversion price per share | $ / shares

$ 3.50

$ 3.50

Royal VWAP [Member] | Maximum [Member]

Debt conversion price per share | $ / shares

$ 7.50

$ 7.50

FFifth Amendment [Member]

Revolving credit commitments

$ 55,000

Line of credit maturity date

Dec. 31, 2017

Definitive Agreement [Member] | Royal Energy Resources, Inc [Member] | Wexford Capital L P [Member]

Number of common unit shares acquired during the period | shares

676,911

Number of common unit acquired during the period

$ 3,500

Definitive Agreement [Member] | Wexford Capital L P [Member] | Subordinated Units [Member]

Number of common unit shares acquired during the period | shares

945,525

Number of common unit acquired during the period

$ 1,000

Securities Purchase Agreement [Member] | Royal Energy Resources, Inc [Member]

Proceeds from shares issued

$ 2,000

Number of common unit shares issued during the period | shares

6,000,000

Number of common unit issued during the period, value

$ 9,000

Common stock price per unit | $ / shares

$ 1.50

Promissory note face value

$ 7,000

Promissory note payable periodic amount

$ 3,000

$ 2,000

$ 2,000

Repayment of debt

$ 2,000

Option Agreement [Member]

Ownership percentage

51.00%

Option Agreement [Member] | Royal Energy Resources, Inc [Member]

Number of common unit shares issued during the period | shares

5,000,000

Option Agreement [Member] | Armstrong Energy [Member] | Royal Energy Resources, Inc [Member]

Ownership percentage

97.00%

Equity Exchange Agreement [Member] | Armstrong Energy [Member]

Ownership percentage

51.00%

Series A Preferred Unit Purchase Agreement [Member] | Weston [Member]

Number of common unit shares issued during the period | shares

1,300,000

Number of common unit issued during the period, value

$ 11,000

Series A Preferred Unit Purchase Agreement [Member] | Royal Energy Resources Inc. [Member]

Number of common unit shares issued during the period | shares

200,000

Number of common unit issued during the period, value

$ 2,000

Letter Agreement [Member] | Rhino Note Weston Promissory Note [Member]

Promissory note face value

$ 4,000

$ 4,000

Weighted average closing price

75.00%

75.00%

Fourth Amended And Restated Agreement [Member]

Units of Partnership Interest, Description

(i) 50% of the CAM Mining free cash flow (as defined below) and (ii) an amount equal to the number of outstanding Series A preferred units multiplied by $0.80. “CAM Mining free cash flow” is defined in the Amended and Restated Partnership Agreement as (i) the total revenue of the Partnership’s Central Appalachia business segment, minus (ii) the cost of operations (exclusive of depreciation, depletion and amortization) for the Partnership’s Central Appalachia business segment, minus (iii) an amount equal to $6.50, multiplied by the aggregate number of met coal and steam coal tons sold by the Partnership from its Central Appalachia business segment.

Indebtedness

$ 50,000

$ 50,000

Common Units [Member]

Reverse stock split conversion ratio

10

Average global market capitalization value

$ 15,000

Subordinated Units [Member]

Reverse stock split conversion ratio

10

Subordinated Units [Member] | Wexford Capital L P [Member] | Royal Energy Resources Inc. [Member]

Number of common unit shares acquired during the period | shares

945,525

Series A Preferred Units [Member] | Minimum [Member]

Debt conversion price per share | $ / shares

$ 2

$ 2

Series A Preferred Units [Member] | Maximum [Member]

Debt conversion price per share | $ / shares

$ 10

$ 10

Series A Preferred Units [Member] | Fourth Amended And Restated Agreement [Member]

Weighted average closing price

75.00%

75.00%

Unpaid distribution | $ / shares

$ 10

Summary of Significant Accoun39

Summary of Significant Accounting Policies and General (Details Narrative) - USD ($) $ in Thousands	Mar. 20, 2017	Oct. 31, 2016	Sep. 30, 2014	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Available for sale of investment				$ 4,998		$ 3,532
Operating loss				(870)	$ (527)
Mammoth Energy Services, Inc. [Member]
Number of limited partner interest exchange for shares of common stock		234,300
Available for sale of investment				1,500		$ 1,600
Sturgeon Acquisitions LLC [Member]
Operating loss				$ (4)	$ (79)
Contribution Agreement [Member] | Mammoth Inc [Member]
Number of shares of common stock expects to receive	336,447
Sturgeon Acquisitions LLC [Member]
Payments to acquire interest in joint venture			$ 5,000

Discontinued Operations (Detail

Discontinued Operations (Details Narrative) - Elk Horn [Member] - USD ($) $ in Thousands	Sep. 20, 2016	Aug. 31, 2016	Dec. 31, 2016	Mar. 31, 2017	Mar. 31, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash consideration payable			$ 150
Cash Consideration paid monthly installment			1,500
Loss on business disposal			$ 119,900
Deferred revenue				$ 0	$ 200
Third Party [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash consideration		$ 12,000
Cash consideration upon the closing transaction paid		10,500
Cash consideration payable		$ 1,500
Cash Consideration paid monthly installment	$ 150

Discontinued Operations - Sched

Discontinued Operations - Schedule of Major Components of Net (Loss) Income from Discontinued Operations (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
Other revenues		$ 1,098
Total revenues		1,098
Cost of operations (exclusive of depreciation, depletion and amortization shown separately below)		(45)
Depreciation, depletion and amortization		205
Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above)		15
Interest expense and other		4
Total costs and expenses		179
Income from discontinued operations before income taxes for the Elk Horn disposal		919
Income taxes
Net income from discontinued operations		$ 919

Prepaid Expenses and Other Cu42

Prepaid Expenses and Other Current Assets (Details Narrative) - Elk Horn [Member] - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Mar. 31, 2017
Note receivable	$ 900	$ 500
Cash Consideration paid monthly installment	1,500
Cash consideration payable	$ 150

Prepaid Expenses and Other Cu43

Prepaid Expenses and Other Current Assets - Schedule of Prepaid Expenses and Other Current Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Prepaid Expense and Other Assets, Current [Abstract]
Other prepaid expenses	$ 779	$ 707
Debt issuance costs-net	929	1,239
Prepaid insurance	822	1,432
Prepaid leases	113	77
Supply inventory	565	614
Deposits		164
Available-for-sale investment	4,998	3,532
Note receivable- current portion	450	900
Total Prepaid expenses and other	$ 8,656	$ 8,665

Property, Plant and Equipment44

Property, Plant and Equipment (Details Narrative) $ in Thousands	12 Months Ended
	Dec. 30, 2015USD ($)
Property, Plant and Equipment [Abstract]
Proceeds from the sale of property	$ 7,200

Property, Plant and Equipment -

Property, Plant and Equipment - Property, Plant and Equipment by Major Classification (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
Property, Plant and Equipment [Line Items]
Total	$ 455,543	$ 449,181
Less accumulated depreciation, depletion and amortization	(272,560)	(266,874)
Net property, plant and equipment	182,983	182,307
Land and Land Improvements [Member]
Property, Plant and Equipment [Line Items]
Total	16,175	16,377
Mining and Other Equipment and Related Facilities [Member]
Property, Plant and Equipment [Line Items]
Total	$ 309,339	305,626
Mining and Other Equipment and Related Facilities [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	2 years
Mining and Other Equipment and Related Facilities [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	20 years
Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Total	$ 57,459	57,392
Mine Development Costs [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	1 year
Mine Development Costs [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	15 years
Coal Properties and Oil and Natural Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Total	$ 67,989	67,989
Coal Properties and Oil and Natural Gas Properties [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	1 year
Coal Properties and Oil and Natural Gas Properties [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Useful Lives	15 years
Construction Work In Process [Member]
Property, Plant and Equipment [Line Items]
Total	$ 4,581	$ 1,797

Property, Plant and Equipment46

Property, Plant and Equipment - Schedule of Depreciation, Depletion, and Amortization (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Property, Plant and Equipment [Line Items]
Total depreciation, depletion and amortization	$ 5,698	$ 6,041
Mining and Other Equipment and Related Facilities [Member]
Property, Plant and Equipment [Line Items]
Total depreciation, depletion and amortization	4,436	5,287
Coal Properties and Oil and Natural Gas Properties [Member]
Property, Plant and Equipment [Line Items]
Total depreciation, depletion and amortization	355	393
Mine Development Costs [Member]
Property, Plant and Equipment [Line Items]
Total depreciation, depletion and amortization	757	403
Asset Retirement Costs [Member]
Property, Plant and Equipment [Line Items]
Total depreciation, depletion and amortization	$ 150	$ (42)

Intangible and Other Non-curr47

Intangible and Other Non-current Assets (Details Narrative) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 30, 2016	Mar. 31, 2017
Prepaid Expenses And Other Current Assets Disclosure [Line Items]
Non-current receivable	$ 27,157		$ 27,157
Number of common unit issued during the period		$ 21,800
Option Agreement [Member] | Call Option [Member]
Prepaid Expenses And Other Current Assets Disclosure [Line Items]
Number of common unit shares issued during the period	5,000
Number of common unit issued during the period	$ 21,800
Partnership’s workers [Member]
Prepaid Expenses And Other Current Assets Disclosure [Line Items]
Non-current receivable	27,200		27,200
Workers' compensation liability, noncurrent	27,200		$ 27,200
Series A Preferred Units [Member] | Weston [Member]
Prepaid Expenses And Other Current Assets Disclosure [Line Items]
Note receivable	$ 2,000

Intangible and Other Non-curr48

Intangible and Other Non-current Assets - Schedule of Other Non-current Assets (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Intangible And Other Non-current Assets
Deposits and other	$ 220	$ 218
Due (to)/from Rhino GP	(26)	(573)
Non-current receivable	27,157	27,157
Deferred expenses	208	216
Total	$ 27,559	$ 27,018

Accrued Expenses and Other Cu49

Accrued Expenses and Other Current Liabilities (Details Narrative) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Payables and Accruals [Abstract]
Accrued insured litigation claims	$ 26	$ 277

Accrued Expenses and Other Cu50

Accrued Expenses and Other Current Liabilities - Schedule of Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Payables and Accruals [Abstract]
Payroll, bonus and vacation expense	$ 1,918	$ 1,496
Non income taxes	3,121	2,252
Royalty expenses	1,909	1,617
Accrued interest	603	601
Health claims	656	630
Workers’ compensation & pneumoconiosis	2,450	2,450
Deferred revenues
Accrued insured litigation claims	26	277
Preferred unit distribution	1,117
Other	717	740
Total	$ 12,517	$ 10,063

Debt (Details Narrative)

Debt (Details Narrative) - USD ($) $ in Thousands	May 13, 2016	Mar. 17, 2016	Jul. 29, 2011	Jul. 31, 2016	Mar. 31, 2017	Sep. 30, 2016	Dec. 31, 2016	May 31, 2016	Mar. 31, 2016	Apr. 30, 2015
Line of Credit Facility [Line Items]
Credit facility, maximum available								$ 75,000	$ 80,000
Proceeds from borrowing					$ 14,800
Debt instrument interest rate					7.50%
Borrowing availability, amount					$ 7,700
Series A Preferred Units [Member]
Line of Credit Facility [Line Items]
Amount of proceeds from equity issuance that will be used to satisfy schedule capital contributions					$ 13,000
Prime Rate [Member]
Line of Credit Facility [Line Items]
Debt instrument interest rate					3.50%
Sixth Amendment [Member] | Elk Horn [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maxmium commitment amount for additional				$ 1,500	$ 375	$ 375	$ 375
Sixth Amendment [Member] | Elk Horn [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maxmium commitment amount for additional					48,700
Sixth Amendment [Member] | Elk Horn [Member] | June 30, 2017 [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maxmium commitment amount for additional							375
Fourth Amendment [Member] | Prime Rate [Member]
Line of Credit Facility [Line Items]
Incremental interest rate above variable rate		3.50%
Fifth Amendment [Member]
Line of Credit Facility [Line Items]
Line of credit facility,extended expiration date	Jul. 31, 2017
Seventh Amendment [Member]
Line of Credit Facility [Line Items]
Threshold for revolving credit commitments							11,000
Line of credit facility, amount by which commitments must be reduced if proceeds from sale of assets are below threshold					2,000
Line of credit facility, threshold for reduction of maximum leverage ratio					10,000
Line of credit any dispositions of assets in excess can reduce the commitment							2,000
Maximum borrowing capacity of EBITDA					$ 2,000
Seventh Amendment [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of credit facility maximum leverage ratio reduction when threshold met					1
Line of credit facility, maximum leverage ratio required for distributions in excess of maximum stated amount					1
Seventh Amendment [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Line of credit facility maximum leverage ratio reduction when threshold met					0.50
Line of credit facility, maximum leverage ratio required for distributions in excess of maximum stated amount					3
Seventh Amendment [Member] | June 30, 2017 [Member]
Line of Credit Facility [Line Items]
Threshold for revolving credit commitments							2,000
Seventh Amendment [Member] | Sep 30, 2017 [Member]
Line of Credit Facility [Line Items]
Threshold for revolving credit commitments							$ 2,000
Seventh Amendment [Member] | December 31, 2017 Through May 31, 2017 [Member]
Line of Credit Facility [Line Items]
Minimum borrowing capacity of EBITDA					$ 12,500
Seventh Amendment [Member] | December 31, 2017 Through May 31, 2017 [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio					1
Seventh Amendment [Member] | December 31, 2017 Through May 31, 2017 [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio					4
Seventh Amendment [Member] | June 30, 2017 Through December 31, 2017 [Member]
Line of Credit Facility [Line Items]
Minimum borrowing capacity of EBITDA					$ 15,000
Seventh Amendment [Member] | June 30, 2017 Through December 31, 2017 [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio					1
Seventh Amendment [Member] | June 30, 2017 Through December 31, 2017 [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Line of credit facility, maximum leverage ratio					3.5
Letter Of Credit [Member]
Line of Credit Facility [Line Items]
Incremental interest rate above variable rate					5.00%
Outstanding letter of credit					$ 26,100
Maximum borrowing capacity description					Based upon a maximum borrowing capacity of 4.00 times a trailing twelve-month EBITDA calculation
Letter Of Credit [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available								$ 30,000	$ 30,000
Amended And Restated Credit Agreement [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available			$ 300,000							$ 100,000
Line of credit facility option to increase maximum borrowing capacity			50,000
Amended And Restated Credit Agreement [Member] | Letter Of Credit One [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available			300,000
Amended And Restated Credit Agreement [Member] | Letter Of Credit [Member]
Line of Credit Facility [Line Items]
Credit facility, maximum available			$ 75,000							$ 50,000
Credit Agreement [Member] | Series A Preferred Units [Member]
Line of Credit Facility [Line Items]
Amount of proceeds from equity issuance that will be used to satisfy schedule capital contributions					$ 13,000

Debt - Schedule Of Debt (Detail

Debt - Schedule Of Debt (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Debt Disclosure [Abstract]
Senior secured credit facility with PNC Bank, N.A.	$ 14,840	$ 10,040
Total	14,840	10,040
Less current portion	(14,840)	(10,040)
Long-term debt

Asset Retirement Obligations -

Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Balance at beginning of period (including current portion)	$ 23,278	$ 23,077	$ 23,077
Accretion expense	474	$ 381	1,512
Adjustments to the liability from annual recosting and other			(1,085)
Liabilities settled	(34)		(200)
Balance at end of period	23,718		23,278
Less current portion of asset retirement obligation	(917)		(917)
Long-term portion of asset retirement obligation	$ 22,801		$ 22,361

Employee Benefits (Details Narr

Employee Benefits (Details Narrative) - USD ($) $ in Thousands	Dec. 10, 2015	Mar. 31, 2016
Retirement Benefits [Abstract]
Prior service cost benefit	$ 6,500
Benefit recognized		$ 3,900

Employee Benefits - Schedule of

Employee Benefits - Schedule of Expense Under Defined Contribution Savings Plans (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Retirement Benefits [Abstract]
401(k) plan expense	$ 370	$ 308

Equity-Based Compensation (Deta

Equity-Based Compensation (Details Narrative) - USD ($) $ in Thousands	Mar. 17, 2016	Mar. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Accelerated vesting expense		$ 10
Royal Energy Resources Inc. [Member] | Wexford Capital L P [Member] | Subordinated Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of common unit shares acquired during the period	945,525

Commitments and Contingencies57

Commitments and Contingencies (Details Narrative) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Sep. 30, 2014
Sturgeon Acquisitions [Member]
Commitments And Contingencies [Line Items]
Payments to acquire interest in joint venture		$ 5,000
Purchase Commitment [Member]
Commitments And Contingencies [Line Items]
Commitment to purchase	the Partnership had a commitment to purchase approximately 1.0 million gallons of diesel fuel at fixed prices from January 2017 through December 2017

Commitments and Contingencies -

Commitments and Contingencies - Schedule of Delivery Commitments (Details)	3 Months Ended
	Mar. 31, 2017NumberT
Commitments and Contingencies Disclosure [Abstract]
Tons, 2017 Q2-Q4 | T	2,900,000
Tons, 2018 | T	701,000
Number of customers, 2017 Q2-Q4 | Number	16
Number of customers, 2018 | Number	4

Commitments and Contingencies59

Commitments and Contingencies - Schedule of Lease And Royalty Expense (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Commitments and Contingencies Disclosure [Abstract]
Lease expense	$ 1,513	$ 1,029
Royalty expense	$ 3,377	$ 2,342

Earnings Per Unit ('EPU') - Sch

Earnings Per Unit ('EPU') - Schedule of Calculation of Numerator and Denominator in Earnings Per Unit (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations	$ (2,029)	$ (2,141)
Interest in net (loss)/income: Net income from discontinued operations		919
Interest in net (loss)/income: Total interest in net income (loss)	(2,029)	(1,222)
General Partner [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations	(13)	(42)
Interest in net (loss)/income: Net income from discontinued operations		18
Interest in net (loss)/income: Total interest in net income (loss)	(13)	(24)
Common Unitholders [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations	(2,859)	(1,375)
Interest in net (loss)/income: Net income from discontinued operations		590
Interest in net (loss)/income: Total interest in net income (loss)	$ (2,859)	$ (785)
Weighted average units used to compute basic EPU	12,906	2,349
Weighted average units used to compute diluted EPU	12,906	2,349
Net (loss) per unit from continuing operations	$ (0.22)	$ (0.58)
Net income per unit from discontinued operations		0.25
Net (loss)/income per common unit, basic	(0.22)	(0.33)
Net (loss)/income per unit from continuing operations	(0.22)	(0.58)
Net income per unit from discontinued operations		0.25
Net income per common unit, diluted	$ (0.22)	$ (0.33)
Subordinated Unitholders [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations	$ (274)	$ (724)
Interest in net (loss)/income: Net income from discontinued operations		311
Interest in net (loss)/income: Total interest in net income (loss)	$ (274)	$ (413)
Weighted average units used to compute basic EPU	1,236	1,236
Weighted average units used to compute diluted EPU	1,236	1,236
Net (loss) per unit from continuing operations	$ (0.22)	$ (0.58)
Net income per unit from discontinued operations		0.25
Net (loss)/income per common unit, basic	(0.22)	(0.33)
Net (loss)/income per unit from continuing operations	(0.22)	(0.58)
Net income per unit from discontinued operations		0.25
Net income per common unit, diluted	$ (0.22)	$ (0.33)
Preferred Unit Holders [Member]
Earnings Per Unit [Line Items]
Interest in net (loss)/income: Net (loss) from continuing operations	$ 1,117
Interest in net (loss)/income: Net income from discontinued operations
Interest in net (loss)/income: Total interest in net income (loss)	$ 1,117
Weighted average units used to compute basic EPU	1,500
Weighted average units used to compute diluted EPU	1,500
Net (loss) per unit from continuing operations	$ 0.74
Net income per unit from discontinued operations
Net (loss)/income per common unit, basic	0.74
Net (loss)/income per unit from continuing operations	0.74
Net income per unit from discontinued operations
Net income per common unit, diluted	$ 0.74

Major Customers - Summary of Ma

Major Customers - Summary of Major Customers (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Revenue, Major Customer [Line Items]
Receivable balance	$ 19,644		$ 13,893
Revenue	53,550	$ 39,330
LGE/KU [Member]
Revenue, Major Customer [Line Items]
Receivable balance	1,397		1,496
Revenue	10,521	9,483
Big Rivers Electric Corporation [Member]
Revenue, Major Customer [Line Items]
Receivable balance	2,805
Revenue	$ 6,244	$ 5,309

Major Customers - Summary of 62

Major Customers - Summary of Major Customers (Details) (Parenthetical)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016
LGE/KU [Member]
Percentage of concentration risk	10.00%	10.00%
Big Rivers Electric Corporation [Member]
Percentage of concentration risk	10.00%	10.00%

Fair Value of Financial Instr63

Fair Value of Financial Instruments (Details Narrative) $ in Thousands	1 Months Ended
	Oct. 31, 2016USD ($)shares
Initial Public Offering [Member]
Number of shares sold	1,953
Proceeds from sale of stock | $	$ 27
Mammoth Energy Services, Inc. [Member]
Exchange shares of common stock	234,300

Supplemental Disclosures of C64

Supplemental Disclosures of Cash Flow Information (Details Narrative) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Accounts Payable [Member]
Other Significant Noncash Transactions [Line Items]
Property additions	$ 600	$ 300

Segment Information (Details Na

Segment Information (Details Narrative)	3 Months Ended
	Mar. 31, 2017Segments
Segment Reporting [Abstract]
Number of reportable business segments	4

Segment Information - Schedule

Segment Information - Schedule of Reportable Segment Results of Operations (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Segment Reporting Information [Line Items]
Total revenues	$ 53,550	$ 39,330
DD&A	5,698	6,041
Interest expense	1,155	1,570
Net Income (loss) from continuing operations	(2,029)	(2,141)
Central Appalachia [Member]
Segment Reporting Information [Line Items]
Total revenues	23,314	5,612
DD&A	1,973	1,723
Interest expense		183
Net Income (loss) from continuing operations	2,294	(3,001)
Northern Appalachia [Member]
Segment Reporting Information [Line Items]
Total revenues	6,127	9,151
DD&A	498	952
Interest expense		82
Net Income (loss) from continuing operations	(780)	4,694
Rhino Western [Member]
Segment Reporting Information [Line Items]
Total revenues	7,298	9,597
DD&A	1,116	1,411
Interest expense		36
Net Income (loss) from continuing operations	(586)	(39)
Illinois Basin [Member]
Segment Reporting Information [Line Items]
Total revenues	16,807	14,880
DD&A	2,004	1,814
Interest expense		69
Net Income (loss) from continuing operations	654	318
Segment Other [Member]
Segment Reporting Information [Line Items]
Total revenues	4	90
DD&A	107	141
Interest expense	1,155	1,200
Net Income (loss) from continuing operations	$ (3,611)	$ (4,113)

Accumulated Distribution Arre67

Accumulated Distribution Arrearages (Details Narrative) $ in Thousands	Mar. 31, 2017USD ($)
Accumulated Distribution Arrearages
Accumulated arrearages, current	$ 265,100