Document and Entity Information
Document and Entity Information - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Mar. 17, 2017 | Jun. 30, 2016 | |
Entity Registrant Name | Rhino Resource Partners LP | ||
Entity Central Index Key | 1,490,630 | ||
Document Type | 10-K | ||
Document Period End Date | Dec. 31, 2016 | ||
Amendment Flag | false | ||
Current Fiscal Year End Date | --12-31 | ||
Entity Well-known Seasoned Issuer | No | ||
Entity Voluntary Filer | No | ||
Entity Current Reporting Status | Yes | ||
Entity Filer Category | Smaller Reporting Company | ||
Entity Public Float | $ 2,500 | ||
Trading Symbol | RHNO | ||
Document Fiscal Period Focus | FY | ||
Document Fiscal Year Focus | 2,016 | ||
Common Units [Member] | |||
Entity Common Stock, Shares Outstanding | 12,905,799 | ||
Subordinated Units [Member] | |||
Entity Common Stock, Shares Outstanding | 1,235,534 |
Consolidated Statements of Fina
Consolidated Statements of Financial Position - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
CURRENT ASSETS: | ||
Cash and cash equivalents | $ 47 | $ 59 |
Accounts receivable, net of allowance for doubtful accounts ($0 as of December 31, 2016 and December 31, 2015) | 13,893 | 12,597 |
Inventories | 8,050 | 8,570 |
Advance royalties, current portion | 898 | 753 |
Prepaid expenses and other | 8,665 | 5,467 |
Current assets held for sale | 1,998 | |
Total current assets | 31,553 | 29,444 |
PROPERTY, PLANT AND EQUIPMENT: | ||
At cost, including coal properties, mine development and construction costs | 449,181 | 484,690 |
Less accumulated depreciation, depletion and amortization | (266,874) | (259,892) |
Net property, plant and equipment | 182,307 | 224,798 |
Advance royalties, net of current portion | 7,652 | 7,172 |
Investment in unconsolidated affiliates | 5,121 | 7,578 |
Intangible purchase option | 21,750 | |
Note receivable-related party | 2,040 | |
Other non-current assets | 27,018 | 26,306 |
Non-current assets held for sale | 109,368 | |
TOTAL | 277,441 | 404,666 |
CURRENT LIABILITIES: | ||
Accounts payable | 10,420 | 9,199 |
Accrued expenses and other | 10,063 | 11,049 |
Current portion of long-term debt | 10,040 | 41,479 |
Current portion of asset retirement obligations | 917 | 767 |
Current portion of postretirement benefits | 45 | |
Current liabilities held for sale | 930 | |
Total current liabilities | 31,440 | 63,469 |
NON-CURRENT LIABILITIES: | ||
Long-term debt, net of current portion | 2,595 | |
Asset retirement obligations, net of current portion | 22,361 | 22,310 |
Other non-current liabilities | 45,371 | 44,765 |
Non-current liabilities held for sale | 3,599 | |
Total non-current liabilities | 67,732 | 73,269 |
Total liabilities | 99,172 | 136,738 |
PARTNERS' CAPITAL: | ||
Limited partners | 154,696 | 253,312 |
Subscription receivable from limited partners | (2,000) | |
General partner | 8,959 | 9,821 |
Preferred partners | 15,000 | |
Accumulated other comprehensive income | 1,614 | 4,795 |
Total partners' capital | 178,269 | 267,928 |
TOTAL | $ 277,441 | $ 404,666 |
Consolidated Statements of Fin3
Consolidated Statements of Financial Position (Parenthetical) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Statement of Financial Position [Abstract] | ||
Accounts receivable, allowance for doubtful accounts | $ 0 | $ 0 |
Consolidated Statements of Oper
Consolidated Statements of Operations and Comprehensive Income - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | ||
REVENUES: | |||
Coal sales | $ 160,841 | $ 171,074 | |
Freight and handling revenues | 1,866 | 2,790 | |
Other revenues | 8,073 | 21,168 | |
Total revenues | 170,780 | 195,032 | |
COSTS AND EXPENSES: | |||
Cost of operations (exclusive of depreciation, depletion and amortization shown separately below) | 135,447 | 173,312 | |
Freight and handling costs | 1,731 | 2,693 | |
Depreciation, depletion and amortization | 23,786 | 31,572 | |
Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above) | 14,464 | 14,873 | |
Asset impairment and related charges | 2,639 | 31,564 | |
(Gain) on sale/disposal of assets, net | (465) | (263) | |
Total costs and expenses | 177,602 | 253,751 | |
(LOSS) FROM OPERATIONS | (6,822) | (58,719) | |
INTEREST AND OTHER (EXPENSE)/INCOME: | |||
Interest expense and other | (6,696) | (4,990) | |
Interest income and other | 28 | 38 | |
Gain on debt extinguishment | 1,663 | ||
Equity in net income/(loss) of unconsolidated affiliates | (223) | 342 | |
Total interest and other (expense) | (5,228) | (4,610) | |
(LOSS) BEFORE INCOME TAXES FROM CONTINUING OPERATIONS | (12,050) | (63,329) | |
INCOME TAXES | |||
NET (LOSS) FROM CONTINUING OPERATIONS | (12,050) | (63,329) | |
DISCONTINUED OPERATIONS | |||
Net (Loss)/Income from discontinued operations | (118,713) | 8,085 | |
NET LOSS | (130,763) | (55,244) | |
Other comprehensive income: | |||
Fair market value adjustment for available-for-sale investment | 1,614 | ||
Change in actuarial gain on post retirement plan | (4,795) | 3,422 | |
COMPREHENSIVE LOSS | $ (133,944) | $ (51,822) | |
Net (loss)/income per limited partner unit, diluted: | |||
Distributions paid per limited partner unit | [1] | $ 0.07 | |
General Partner [Member] | |||
INTEREST AND OTHER (EXPENSE)/INCOME: | |||
NET (LOSS) FROM CONTINUING OPERATIONS | $ (107) | $ (1,267) | |
DISCONTINUED OPERATIONS | |||
Net (Loss)/Income from discontinued operations | (755) | 162 | |
NET LOSS | (862) | (1,105) | |
Common Unitholders [Member] | |||
INTEREST AND OTHER (EXPENSE)/INCOME: | |||
NET (LOSS) FROM CONTINUING OPERATIONS | (10,040) | (35,634) | |
DISCONTINUED OPERATIONS | |||
Net (Loss)/Income from discontinued operations | (99,166) | 4,549 | |
NET LOSS | $ (109,206) | $ (31,085) | |
Net (loss)/income per limited partner unit, basic: | |||
Net (loss) per unit from continuing operations | $ (1.54) | $ (21.24) | |
Net (loss)/income per unit from discontinued operations | (15.21) | 2.72 | |
Net (loss) per common unit, basic | (16.75) | (18.52) | |
Net (loss)/income per limited partner unit, diluted: | |||
Net (loss) per unit from continuing operations | (1.54) | (21.24) | |
Net (loss)/income per unit from discontinued operations | (15.21) | 2.72 | |
Net (loss) per common unit, diluted | $ (16.75) | $ (18.52) | |
Weighted average number of limited partner units outstanding, basic | 6,520,000 | 1,671,000 | |
Weighted average number of limited partner units outstanding, diluted | 6,520,000 | 1,671,000 | |
Subordinated Unitholders [Member] | |||
INTEREST AND OTHER (EXPENSE)/INCOME: | |||
NET (LOSS) FROM CONTINUING OPERATIONS | $ (1,903) | $ (26,428) | |
DISCONTINUED OPERATIONS | |||
Net (Loss)/Income from discontinued operations | (18,792) | 3,374 | |
NET LOSS | $ (20,695) | $ (23,054) | |
Net (loss)/income per limited partner unit, basic: | |||
Net (loss) per unit from continuing operations | $ (1.54) | $ (21.44) | |
Net (loss)/income per unit from discontinued operations | (15.21) | 2.72 | |
Net (loss) per common unit, basic | (16.75) | (18.72) | |
Net (loss)/income per limited partner unit, diluted: | |||
Net (loss) per unit from continuing operations | (1.54) | (21.44) | |
Net (loss)/income per unit from discontinued operations | (15.21) | 2.72 | |
Net (loss) per common unit, diluted | (16.75) | (18.72) | |
Distributions paid per limited partner unit | |||
Weighted average number of limited partner units outstanding, basic | 1,236,000 | 1,240,000 | |
Weighted average number of limited partner units outstanding, diluted | 1,236,000 | 1,240,000 | |
[1] | No distributions were paid on the subordinated units during 2016 and 2015. |
Consolidated Statements of Ope5
Consolidated Statements of Operations and Comprehensive Income (Parenthetical) - $ / shares | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | ||
Distributions paid per limited partner unit | [1] | $ 0.07 | |
Subordinated Unitholders [Member] | |||
Distributions paid per limited partner unit | |||
[1] | No distributions were paid on the subordinated units during 2016 and 2015. |
Consolidated Statements of Part
Consolidated Statements of Partners' Capital - USD ($) $ in Thousands | Limited Partner Common Capital [Member] | Limited Partner Subordinated Capital [Member] | General Partner Capital [Member] | Preferred Partner Capital [Member] | Accumulated Other Comprehensive Income/(Loss) [Member] | Total |
Balance at Dec. 31, 2014 | $ 185,447 | $ 123,139 | $ 10,966 | $ 1,373 | $ 320,925 | |
Balance, shares at Dec. 31, 2014 | 1,669,000 | 1,240,000 | ||||
Net income | $ (31,085) | $ (23,054) | (1,105) | (55,244) | ||
Distributions to unitholders and general partner | (1,225) | (42) | (1,267) | |||
General partners' contributions | 2 | 2 | ||||
Offering costs at Dec. 31, 2014 | (4) | |||||
Issuance of units under LTIP | $ 90 | 90 | ||||
Issuance of units under LTIP, shares | 7,000 | |||||
Change in actuarial gain under ASC Topic 815 | 3,422 | 3,422 | ||||
Mark-to-market investment in Mammoth | ||||||
Balance at Dec. 31, 2015 | $ 153,227 | $ 100,085 | 9,821 | 4,795 | 267,928 | |
Balance, shares at Dec. 31, 2015 | 1,676,000 | 1,236,000 | ||||
Net income | $ (109,206) | $ (20,695) | (862) | (130,763) | ||
Distributions to unitholders and general partner | (24) | (24) | ||||
Issuance of units under LTIP | $ 559 | 559 | ||||
Issuance of units under LTIP, shares | 230,000 | |||||
Change in actuarial gain under ASC Topic 815 | (4,795) | (4,795) | ||||
Limited partner contribution | $ 9,000 | 9,000 | ||||
Limited partner contribution, shares | 6,000,000 | |||||
Preferred partner contributions | 15,000 | 15,000 | ||||
Subscription receivable from limited partners | (2,000) | (2,000) | ||||
Issuance of units for purchase option | $ 21,750 | 21,750 | ||||
Issuance of units for purchase option, shares | 5,000,000 | |||||
Mark-to-market investment in Mammoth | 1,614 | 1,614 | ||||
Balance at Dec. 31, 2016 | $ 73,306 | $ 79,390 | $ 8,959 | $ 15,000 | $ 1,614 | $ 178,269 |
Balance, shares at Dec. 31, 2016 | 12,906,000 | 1,236,000 |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
CASH FLOWS FROM OPERATING ACTIVITIES: | ||
Net (loss) | $ (130,763) | $ (55,244) |
Adjustments to reconcile net (loss) to net cash provided by operating activities: | ||
Depreciation, depletion and amortization | 24,198 | 33,181 |
Accretion on asset retirement obligations | 1,512 | 2,082 |
Accretion on interest-free debt | 48 | |
Amortization of deferred revenue | (1,337) | (3,766) |
Amortization of advance royalties | 1,037 | 764 |
Amortization of debt issuance costs | 2,872 | 1,419 |
Amortization of actuarial gain | (4,795) | (782) |
Provision for doubtful accounts | 528 | |
Equity in net (income)/loss of unconsolidated affiliates | 223 | (342) |
Distributions from unconsolidated affiliate | 300 | 232 |
Loss on retirement of advance royalties | 157 | 151 |
(Gain) on sale/disposal of assets-net | (465) | (1,014) |
Loss on impairment of assets | 2,639 | 31,564 |
Loss on business disposal | 119,932 | |
Equity-based compensation | 528 | 15 |
Changes in assets and liabilities: | ||
Accounts receivable | (1,019) | 7,148 |
Inventories | 520 | 4,460 |
Advance royalties | (1,821) | (1,518) |
Prepaid expenses and other assets | 1,079 | 656 |
Accounts payable | 1,446 | (2,274) |
Accrued expenses and other liabilities | (3,178) | (1,026) |
Asset retirement obligations | (892) | 321 |
Postretirement benefits | (45) | (2,398) |
Net cash provided by operating activities | 12,128 | 14,205 |
CASH FLOWS FROM INVESTING ACTIVITIES: | ||
Additions to property, plant, and equipment | (7,582) | (13,168) |
Proceeds from sales of property, plant, and equipment | 349 | 15,114 |
Proceeds from business disposal | 11,100 | |
Proceeds from sale of unconsolidated affiliate | 27 | |
Return of capital from unconsolidated affiliate | 35 | |
Net cash provided by investing activities | 3,894 | 1,981 |
CASH FLOWS FROM FINANCING ACTIVITIES: | ||
Borrowings on line of credit | 101,350 | 94,400 |
Repayments on line of credit | (132,509) | (107,650) |
Repayments on long-term debt | (1,211) | (157) |
Gain on debt extinguishment | (1,663) | |
Distributions to unitholders | (24) | (1,267) |
General partner's contributions | 2 | |
Payments of debt issuance costs | (1,956) | (2,062) |
Preferred partner's contributions | 12,960 | |
Limited partner contribution | 7,000 | |
Net cash (used in) financing activities | (16,053) | (16,734) |
NET (DECREASE) IN CASH AND CASH EQUIVALENTS | (31) | (548) |
CASH AND CASH EQUIVALENTS-Beginning of period | 78 | 626 |
CASH AND CASH EQUIVALENTS-End of period | $ 47 | $ 78 |
Organization and Basis of Prese
Organization and Basis of Presentation | 12 Months Ended |
Dec. 31, 2016 | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Organization and Basis of Presentation | 1. ORGANIZATION AND BASIS OF PRESENTATION 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 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. Initial Public Offering On October 5, 2010, Rhino Resource Partners LP completed its IPO of 324,400 common units, representing limited partner interests in the Partnership, at a price of $205.00 per common unit. Net proceeds from the offering were approximately $58.3 million, after deducting underwriting discounts and offering expenses of $8.2 million. The Partnership used the net proceeds from this offering, and a related capital contribution by Rhino GP LLC, the Partnership’s general partner (the “General Partner”) of approximately $10.4 million, to repay approximately $69.4 million of outstanding indebtedness under the Operating Company’s credit facility. These net proceeds do not include $9.3 million that was used to reimburse affiliates of the Partnership’s sponsor, Wexford Capital LP (“Wexford Capital”), for capital expenditures incurred with respect to the assets contributed to the Partnership in connection with the offering. In connection with the closing of the IPO, the owners of the Operating Company contributed their membership interests in the Operating Company to the Partnership, and the Partnership issued 1,239,700 subordinated units representing limited partner interests in the Partnership and 915,300 common units to Rhino Energy Holdings LLC, an affiliate of Wexford Capital, and issued incentive distribution rights to the General Partner. Upon the closing of the IPO, and as required by the Operating Company’s credit agreement by and among the Operating Company, as borrower, and its subsidiaries as guarantors, and PNC Bank, National Association, as agent, and the other lenders thereto (as amended from time to time, the “Credit Agreement”), the Partnership pledged 100% of the membership interests in the Operating Company to the agent on behalf of itself and the other lenders to secure the Operating Company’s obligations under the Credit Agreement. Follow-on Offerings On July 18, 2011, the Partnership completed a public offering of 287,500 common units, representing limited partner interests in the Partnership, at a price of $245.00 per common unit. Of the common units issued, 37,500 units were issued in connection with the exercise of the underwriters’ option to purchase additional units. Net proceeds from the offering were approximately $66.4 million, after deducting underwriting discounts and offering expenses of approximately $4.1 million. The Partnership used the net proceeds from this offering, and a related capital contribution by the General Partner of approximately $1.4 million, to repay approximately $67.8 million of outstanding indebtedness under the Partnership’s credit facility. On September 13, 2013, the Partnership completed a public offering of 126,500 common units, representing limited partner interests in the Partnership, at a price of $123.00 per common unit. Of the common units issued, 16,500 units were issued in connection with the exercise of the underwriter’s option to purchase additional units. Net proceeds from the offering were approximately $14.6 million, after deducting underwriting discounts and offering expenses of approximately $1.0 million. The Partnership used the net proceeds from this offering, and a related capital contribution by the General Partner of approximately $0.3 million, to repay approximately $14.9 million of outstanding indebtedness under the Partnership’s credit facility. Royal Energy Resources, Inc. Acquisition and Other Transactions On January 21, 2016, a definitive agreement (“Definitive Agreement”) was completed between Royal Energy Resources, Inc. (“Royal”) and 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 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 “Rhino Promissory Note”). 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. Royal’s obligation to pay any installment of the promissory note is subject to certain conditions, including that the Operating Company has entered into an agreement to extend the amended and restated credit agreement, as amended, to a date no sooner than December 31, 2017. In the event such conditions are not satisfied as of the date each installment is due, Royal has the right to cancel the remaining unpaid balance of the promissory note in exchange for the surrender of such number of common units equal to the principal balance of the promissory note divided by $1.50. 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 9 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 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. 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 agreed to purchase 1,300,000 and 200,000, respectively, of Series A preferred units representing limited partner interests in the Partnership (“Series A Preferred Units”) 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, 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 met coal and steam 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 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. Basis of Presentation and Principles of Consolidation Reclassifications. Debt Classification |
Summary of Significant Accounti
Summary of Significant Accounting Policies and General | 12 Months Ended |
Dec. 31, 2016 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies and General | 2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND GENERAL Trade Receivables and Concentrations of Credit Risk. Cash and Cash Equivalents. Inventories. Advance Royalties. Property, Plant and Equipment. Stripping costs incurred in the production phase of a mine for the removal of overburden or waste materials for the purpose of obtaining access to coal that will be extracted are variable production costs that are included in the cost of inventory produced and extracted during the period the stripping costs are incurred. The Partnership defines a surface mine as a location where the Partnership utilizes operating assets necessary to extract coal, with the geographic boundary determined by property control, permit boundaries, and/or economic threshold limits. Multiple pits that share common infrastructure and processing equipment may be located within a single surface mine boundary, which can cover separate coal seams that typically are recovered incrementally as the overburden depth increases. In accordance with the accounting guidance for extractive mining activities, the Partnership defines a mine in production as one from which saleable minerals have begun to be extracted (produced) from an ore body, regardless of the level of production; however, the production phase does not commence with the removal of de minimis saleable mineral material that occurs in conjunction with the removal of overburden or waste material for the purpose of obtaining access to an ore body. The Partnership capitalizes only the development cost of the first pit at a mine site that may include multiple pits. Asset Impairments for Coal Properties, Mine Development Costs and Other Coal Mining Equipment and Related Facilities. Debt Issuance Costs. Asset Retirement Obligations. The Partnership estimates its future cost requirements for reclamation of land where it has conducted surface and underground mining operations, based on its interpretation of the technical standards of regulations enacted by the U.S. Office of Surface Mining, as well as state regulations. These costs relate to reclaiming the pit and support acreage at surface mines and sealing portals at underground mines. Other reclamation costs are related to refuse and slurry ponds, as well as holding and related termination/exit costs. The Partnership expenses contemporaneous reclamation which is performed prior to final mine closure. The establishment of the end of mine reclamation and closure liability is based upon permit requirements and requires significant estimates and assumptions, principally associated with regulatory requirements, costs and recoverable coal reserves. Annually, the Partnership reviews its end of mine reclamation and closure liability and makes necessary adjustments, including mine plan and permit changes and revisions to cost and production levels to optimize mining and reclamation efficiency. When a mine life is shortened due to a change in the mine plan, mine closing obligations are accelerated, the related accrual is increased and the related asset is reviewed for impairment, accordingly. The adjustments to the liability from annual recosting reflect changes in expected timing, cash flow and the discount rate used in the present value calculation of the liability. Each respective year includes a range of discount rates that are dependent upon the timing of the cash flows of the specific obligations. Changes in the asset retirement obligations for the year ended December 31, 2016 were calculated with discount rates that ranged from 7.0% to 9.1%. Changes in the asset retirement obligations for the year ended December 31, 2015 were calculated with discount rates that ranged from 2.9% to 5.9%. The discount rates changed in each respective year due to changes in applicable market indicators that are used to arrive at an appropriate discount rate. Other recosting adjustments to the liability are made annually based on inflationary cost increases or decreases and changes in the expected operating periods of the mines. The related inflation rate utilized in the recosting adjustments was 2.3 % for 2016 and 2015. Revenue Recognition. Freight and handling costs paid directly to third-party carriers and invoiced to coal customers are recorded as freight and handling costs and freight and handling revenues, respectively. Other revenues generally consist of coal royalty revenues, limestone sales, coal handling and processing, oil and natural gas royalty revenues, rebates and rental income. With respect to other revenues recognized in situations unrelated to the shipment of coal, the Partnership carefully reviews the facts and circumstances of each transaction and does not recognize revenue until the following criteria are met: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the seller’s price to the buyer is fixed or determinable and collectibility is reasonably assured. Advance payments received are deferred and recognized in revenue when earned. Equity-Based Compensation. The Compensation Committee of the board of directors of the General Partner has historically elected to pay some of the awards in cash or a combination of cash and common units. This policy has resulted in all employee awards being classified as liabilities and, thus, the employee awards are required to be marked-to-market each reporting period until they are vested. Restricted unit awards granted to directors of the General Partner are considered nonemployee equity-based awards since the directors are not elected by unitholders. Thus, these director awards are also required to be marked-to-market each reporting period until they are vested. Expense related to unit awards is recorded in the selling, general and administrative line of the Partnership’s consolidated statements of operations and comprehensive income. Derivative Financial Instruments. Investments in Joint Ventures. In December 2012, the Partnership made an initial investment of approximately $2.0 million in a new joint venture, Muskie Proppant LLC (“Muskie”), with affiliates of Wexford Capital. During 2014, the Partnership contributed additional capital based upon its ownership share to the Muskie joint venture in the amount of $0.2 million. In November 2014, the Partnership contributed its investment interest in Muskie to Mammoth in return for a limited partner interest in Mammoth. The non-cash transaction was a contribution of the Partnership’s investment interest in the Muskie entity for an investment interest in Mammoth. Thus, the Partnership determined that the non-cash exchange of the Partnership’s ownership interest in Muskie did not result in any gain or loss. Prior to the Partnership’s contribution of Muskie to Mammoth, the Partnership recorded its proportionate portion of Muskie’s operating loss for 2014 of approximately $0.1 million. As of December 31, 2016 and 2015, the Partnership has recorded its investment in Mammoth of $1.9 million as a short-term asset, which the Partnership has classified as available-for-sale. In October 2016, the Partnership contributed its limited partner interests in Mammoth to Mammoth Energy Services, Inc. in exchange for 234,300 shares of common stock of Mammoth Energy Services, Inc. The Partnership recorded a fair market value adjustment of $1.6 million for the available-for-sale investment based on the market value of the shares at December 31, 2016, which was recorded in Other Comprehensive Income. The Partnership has included its investment in Mammoth and its prior investment in Muskie in its Other category for segment reporting purposes. In September 2014, the Partnership made an initial investment of $5.0 million in a new joint venture, Sturgeon Acquisitions LLC (“Sturgeon”), with affiliates of Wexford Capital and Gulfport. 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 year ended December 31, 2016 of approximately $0.2 million and its proportionate share of operating income of approximately $0.3 million for the year ended December 31 2015. The Partnership has recorded its investment in Sturgeon on the Investment in unconsolidated affiliates line of the Partnership’s consolidated statements of financial position. The Partnership has included its investment in Sturgeon in its Other category for segment reporting purposes. Income Taxes. Loss Contingencies. Management’s Use of Estimates. Recently Issued Accounting Standards. In August 2014, the FASB issued ASU 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern In January 2015, the FASB issued ASU 2015-01, “Income Statement-Extraordinary and Unusual Items”. ASC 225-20, Income Statement—Extraordinary and Unusual Items, required that an entity separately classify, present, and disclose extraordinary events and transactions. ASU 2015-01 eliminates the concept of extraordinary items. The amendments in ASU 2015-01 are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. A reporting entity may apply the amendments prospectively. A reporting entity also may apply the amendments retrospectively to all prior periods presented in the financial statements. Early adoption is permitted provided that the guidance is applied from the beginning of the fiscal year of adoption. The effective date is the same for both public business entities and all other entities. The adoption of ASU 2015-01 on January 1, 2016 has not had a material impact on the Partnership’s financial statements. In February 2015, the FASB issued ASU 2015-02, “Consolidation”. ASU 2015-02 affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. Specifically, the amendments of ASU 2015-02: a) modify the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, b) eliminate the presumption that a general partner should consolidate a limited partnership, c) affect the consolidation analysis of reporting entities that are involved with VIEs, particularly those that have fee arrangements and related party relationships and d) provide a scope exception from consolidation guidance for reporting entities with interests in legal entities that are required to comply with or operate in accordance with requirements that are similar to those in Rule 2a-7 of the Investment Company Act of 1940 for registered money market funds. ASU 2015-02 is effective for public business entities for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2015. A reporting entity may apply the amendments in this Update using a modified retrospective approach by recording a cumulative-effect adjustment to equity as of the beginning of the fiscal year of adoption. A reporting entity also may apply the amendments retrospectively. The adoption of ASU 2015-02 on January 1, 2016 did not have a material impact on the Partnership’s financial statements. In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842).” ASU 2016-02 requires that lessees recognize all leases (other than leases with a term of twelve months or less) on the balance sheet as lease liabilities, based upon the present value of the lease payments, with corresponding right of use assets. ASU 2016-02 also makes targeted changes to other aspects of current guidance, including identifying a lease and lease classification criteria as well as the lessor accounting model, including guidance on separating components of a contract and consideration in the contract. The amendments in ASU 2016-02 will be effective for the Partnership on January 1, 2019 and will require modified retrospective application as of the beginning of the earliest period presented in the financial statements. Early application is permitted. The Partnership is currently evaluating this guidance. In August 2016, the FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments.” ASU 2016-15 provides guidance on eight cash flow issues, including debt prepayment or debt extinguishment costs. ASU 2016-15 requires that cash payments related to debt prepayments or debt extinguishments, excluding accrued interest, be classified as a financing activity rather than an operating activity even when the effects enter into the determination of net income. The amendments in ASU 2016-15 will be effective on January 1, 2018 and must be applied retrospectively. Early application is permitted. The Partnership is currently evaluating this guidance. In October 2016, the FASB issued ASU 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties that are Under Common Control.” ASU 2016-17 amends the consolidation guidance on how a reporting entity that is the single decision maker of a variable interest entity (VIE) should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. ASU is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. The adoption of ASU 2016-17 is not expected to have a material impact on the Partnership’s financial statements. In January 2017, the FASB issued ASU 2017-01, “Business Combinations (Topic 805).” ASU 2017—01 clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. ASU is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. The Partnership is currently evaluating this guidance. |
Subsequent Events
Subsequent Events | 12 Months Ended |
Dec. 31, 2016 | |
Subsequent Events [Abstract] | |
Subsequent Events | 3. SUBSEQUENT EVENTS 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 May 2017. The common stock of Mammoth Inc. trades on the NASDAQ Global Select Market under the symbol TUSK. Beginning with the quarter ended June 30, 2015 and continuing through the quarter ended December 31, 2016, 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. |
Discontinued Operations
Discontinued Operations | 12 Months Ended |
Dec. 31, 2016 | |
Discontinued Operations and Disposal Groups [Abstract] | |
Discontinued Operations | 4. 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 Major assets and liabilities of discontinued operations, as of December 31, 2016 and 2015 are summarized as follows: Carrying amount of major classes of assets included as part of discontinued operations: Cash and cash equivalents $ - $ 19 Accounts receivable, net of allowance for doubtful accounts - 1,972 Prepaid expenses and other - 7 Total current assets of the disposal group classified as held for sale in the statement of financial position - 1,998 Property and equipment (net) - 108,709 Advance royalties, net of current portion - 154 Intangible assets (net) 505 Total non-current assets of the disposal group classified as held for sale in the statement of financial position $ - $ 109,368 Carrying amount of major classes of liabilities included as part of discontinued operations: Accounts payable $ - $ 137 Accrued expenses and other - 793 Total current liabilities of the disposal group classified as held for sale in the statement of financial position - 930 Asset retirement obligations, net of current portion - 670 Deferred revenue 2,259 Other non-current liabilities - 670 Total non-current liabilities of the disposal group classified as held for sale in the statement of financial position - 3,599 Major components of net (loss)/income from discontinued operations for the years ended December 31, 2016 and 2015 are summarized as follows: Year Ended December 31, 2016 2015 Major line items constituting (loss)/income from discontinued operations for the Elk Horn disposal: Royalty income $ 2,668 $ 11,714 Total revenues 2,668 11,714 Cost of operations (exclusive of depreciation, depletion and amortization shown separately below) 799 2,187 Depreciation, depletion and amortization 413 1,608 Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above) 174 573 (Gain) on sale/disposal of assets, net 119,982 (28 ) Interest expense and other 13 11 Total costs and expenses 121,381 4,351 (Loss/Income) from discontinued operations before income taxes for the Elk Horn disposal (118,713 ) 7,363 Income from discontinued operations relating to Blackhawk disposal - 722 (Loss/Income) from discontinued operations before income taxes (118,713 ) 8,085 Income taxes - - Net(Loss)/Income from discontinued operations (118,713 ) 8,085 Cash Flows. |
Prepaid Expenses and Other Curr
Prepaid Expenses and Other Current Assets | 12 Months Ended |
Dec. 31, 2016 | |
Prepaid Expense and Other Assets, Current [Abstract] | |
Prepaid Expenses and Other Current Assets | 5. PREPAID EXPENSES AND OTHER CURRENT ASSETS Prepaid expenses and other current assets as of December 31, 2016 and 2015 consisted of the following: December 31, 2016 2015 (in thousands) Other prepaid expenses $ 707 $ 675 Debt issuance costs—net 1,239 2,155 Prepaid insurance 1,432 1,492 Prepaid leases 77 80 Supply inventory 614 901 Deposits 164 164 Available-for-sale investment 3,532 - Note receivable-current portion 900 - Total $ 8,665 $ 5,467 Debt issuance costs were included in Prepaid expenses and other current assets for the years ended December 31, 2016 and 2015 since the Partnership classified its credit facility balance as a current liability. See Note 9 for further information on the amendments to the amended and restated senior secured credit facility. The $0.9 million note receivable 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 | 12 Months Ended |
Dec. 31, 2016 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment | 6. PROPERTY, PLANT AND EQUIPMENT Property, plant and equipment, including coal properties and mine development and construction costs, as of December 31, 2016 and 2015 are summarized by major classification as follows: December 31, Useful Lives 2016 2015 (in thousands) Land and land improvements $ 16,377 $ 17,513 Mining and other equipment and related facilities 2 - 20 Years 305,626 305,845 Mine development costs 1 - 15 Years 57,392 64,262 Coal, oil and natural gas properties 1 - 15 Years 67,989 94,390 Construction work in process 1,797 2,680 Total 449,181 484,690 Less accumulated depreciation, depletion and amortization (266,874 ) (259,892 ) Net $ 182,307 $ 224,798 Depreciation expense for mining and other equipment and related facilities, depletion expense for coal and oil and natural gas properties, amortization expense for mine development costs, amortization expense for intangible assets and amortization expense for asset retirement costs for the years ended December 31, 2016 and 2015 was as follows: Year Ended December 31, 2016 2015 (in thousands) Depreciation expense-mining and other equipment and related facilities $ 20,479 $ 28,698 Depletion expense for coal properties 1,542 1,346 Amortization expense for mine development costs 1,901 1,935 Amortization expense for intangible assets - 43 Amortization expense for asset retirement costs (136 ) (450 ) Total $ 23,786 $ 31,572 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 Asset Impairments-2016 The Partnership performed a comprehensive review of our current coal mining operations as well as potential future development projects for the year ended December 31, 2016 to ascertain any potential impairment losses. Based on the impairment analysis, the Partnership concluded that none of the coal properties, mine development costs or other coal mining equipment and related facilities were impaired at December 31, 2016. However, for the year ended December 31, 2016, the Partnership recorded $2.6 million of asset impairment losses and related charges associated with the 2015 sale of the Deane mining complex. Of the total $2.6 million non-cash impairment and other non-cash charges incurred, approximately $2.0 million related to impairment of the note receivable that was recorded in 2015 relating to the sale of the Deane mining complex. The additional $0.6 million impairment related to other non-recoverable items associated with the sale of the Deane mining complex. The $2.6 million asset impairment charge/loss for the Deane mining complex is recorded on the Asset impairment and related charges line of the consolidated statements of operations and comprehensive income. Asset Impairments-2015 During 2015, the Partnership performed a comprehensive review of its current coal mining operations as well as potential future development projects to ascertain any potential impairment losses. The Partnership identified various properties, projects and operations that were potentially impaired based upon changes in its strategic plans, market conditions or other factors, specifically in Northern Appalachia where market conditions related to the Partnership’s operations deteriorated in the fourth quarter of 2015. In addition to impairment charges related to certain Northern Appalachia operations, the Partnership also recorded asset impairment and related charges for the sale of the Deane mining complex and the Cana Woodford oil and natural gas investment that are discussed further below. The Partnership recorded approximately $31.1 million of total asset impairment and related charges related to property, plant and equipment for the year ended December 31, 2015, which is recorded on the Asset impairment and related charges line of the consolidated statements of operations and comprehensive income. |
Intangible and Other Non-curren
Intangible and Other Non-current Assets | 12 Months Ended |
Dec. 31, 2016 | |
Intangible And Other Non-current Assets | |
Intangible and Other Non-current Assets | 7. INTANGIBLE AND OTHER NON-CURRENT ASSETS Other non-current assets as of December 31, 2016 and 2015 consisted of the following: December 31, 2016 2015 (in thousands) Deposits and other $ 218 $ 218 Due (to) Rhino GP (573 ) (80 ) Non-current receivable 27,157 23,908 Note receivable - 2,000 Deferred expenses 216 260 Total $ 27,018 $ 26,306 Non-current receivable Note receivable-related party Intangible purchase option Note receivable |
Accrued Expenses and Other Curr
Accrued Expenses and Other Current Liabilities | 12 Months Ended |
Dec. 31, 2016 | |
Payables and Accruals [Abstract] | |
Accrued Expenses and Other Current Liabilities | 8. ACCRUED EXPENSES AND OTHER CURRENT LIABILITIES Accrued expenses and other current liabilities as of December 31, 2016 and 2015 consisted of the following: December 31, 2016 2015 (in thousands) Payroll, bonus and vacation expense $ 1,496 $ 1,439 Non-income taxes 2,252 2,993 Royalty expenses 1,617 1,566 Accrued interest 601 571 Health claims 630 817 Workers’ compensation & pneumoconiosis 2,450 1,150 Accrued insured litigation claims 277 266 Other 740 2,247 Total $ 10,063 $ 11,049 The $0.3 million and $0.3 million accrued for insured litigation claims as of December 31, 2016 and 2015, respectively, consists of probable and estimable litigation claims that are the primary obligation of the Partnership. This amount is also due from the Partnership’s insurance providers and is included in Accounts receivable, net of allowance for doubtful accounts on the Partnership’s consolidated statements of financial position. The Partnership presents this amount on a gross asset and liability basis as a right of setoff does not exist per the accounting guidance in ASC Topic 210. This presentation has no impact on the Partnership’s results of operations or cash flows. |
Debt
Debt | 12 Months Ended |
Dec. 31, 2016 | |
Debt Disclosure [Abstract] | |
Debt | 9. DEBT Debt as of December 31, 2016 and 2015 consisted of the following: December 31, 2016 2015 (in thousands) Senior secured credit facility with PNC Bank, N.A. $ 10,040 $ 41,200 Other notes payable - 2,874 Total 10,040 44,074 Less current portion (10,040 ) (41,479 ) Long-term debt $ - $ 2,595 Senior Secured Credit Facility with PNC Bank, N.A. On March 17, 2016, our Operating Company, as borrower, and we and certain of our subsidiaries, as guarantors, entered into a fourth amendment (the “Fourth Amendment”) of our 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 our 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, we entered into the Fifth Amendment of the Amended and Restated Credit Agreement, which extended the term to July 31, 2017. In July 2016, we entered into a sixth amendment (the “Sixth Amendment”) of our amended and restated senior secured credit facility 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 Fourth Amended and Restated Agreement of Limited Partnership of the Partnership. 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 will be 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. At December 31, 2016, the Operating Company had borrowed $10.0 million at a variable interest rate of PRIME plus 3.50% (7.25% at December 31, 2016). In addition, the Operating Company had outstanding letters of credit of $26.1 million at a fixed interest rate of 5.00% at December 31, 2016. 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 $12.9 million of the borrowing availability at December 31, 2016. Other Notes Payable The Partnership did not capitalize any interest costs during the year ended December 31, 2016. Principal payments on long-term debt due subsequent to December 31, 2016 are as follows: (in thousands) 2017 $ 10,040 2018 - 2019 - 2020 - Thereafter - Total principal payments $ 10,040 |
Asset Retirement Obligations
Asset Retirement Obligations | 12 Months Ended |
Dec. 31, 2016 | |
Asset Retirement Obligation Disclosure [Abstract] | |
Asset Retirement Obligations | 10. ASSET RETIREMENT OBLIGATIONS The changes in asset retirement obligations for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Balance at beginning of period (including current portion) $ 23,077 $ 29,883 Accretion expense 1,486 2,082 Adjustment resulting from addition of property - 1,235 Adjustment resulting from disposal of property (1) - (7,531 ) Adjustments to the liability from annual recosting and other (1,085 ) (2,078 ) Reclassification to held for sale - - Liabilities settled (200 ) (514 ) Balance at end of period 23,278 23,077 Less current portion of asset retirement obligation (917 ) (767 ) Long-term portion of asset retirement obligation $ 22,361 $ 22,310 (1) The ($7.5) million adjustment for the year ended December 31, 2015 relates to the sale of the Partnership’s Deane mining complex discussed in Note 6 and the sale of Elk Horn discussed in Note 4. |
Workers' Compensation and Black
Workers' Compensation and Black Lung | 12 Months Ended |
Dec. 31, 2016 | |
Workers Compensation And Black Lung | |
Workers' Compensation and Black Lung | 11. WORKERS’ COMPENSATION AND BLACK LUNG Certain of the Partnership’s subsidiaries are liable under federal and state laws to pay workers’ compensation and coal workers’ black lung benefits to eligible employees, former employees and their dependents. The Partnership currently utilizes an insurance program and state workers’ compensation fund participation to secure its on-going obligations depending on the location of the operation. Premium expense for workers’ compensation benefits is recognized in the period in which the related insurance coverage is provided. The Partnership’s black lung benefit liability is calculated using the service cost method that considers the calculation of the actuarial present value of the estimated black lung obligation. The Partnership’s actuarial calculations using the service cost method for its black lung benefit liability are based on numerous assumptions including disability incidence, medical costs, mortality, death benefits, dependents and interest rates. The Partnership’s liability for traumatic workers’ compensation injury claims is the estimated present value of current workers’ compensation benefits, based on actuarial estimates. The Partnership’s actuarial estimates for its workers’ compensation liability are based on numerous assumptions including claim development patterns, mortality, medical costs and interest rates. The discount rate used to calculate the estimated present value of future obligations for black lung was 4.0% for December 31, 2016 and 2015 and for workers’ compensation was 2.0% at December 31, 2016 and 2015. The uninsured black lung and workers’ compensation expenses for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Black lung benefits: Service cost $ (506 ) $ (991 ) Interest cost 363 397 Actuarial loss/(gain) - - Total black lung (143 ) (594 ) Workers’ compensation expense 4,013 4,334 Total expense $ 3,870 $ 3,740 The changes in the black lung benefit liability for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Benefit obligations at beginning of year $ 9,225 $ 10,033 Service cost (506 ) (991 ) Interest cost 363 397 Actuarial loss/(gain) - - Benefits and expenses paid (300 ) (214 ) Benefit obligations at end of year $ 8,782 $ 9,225 The classification of the amounts recognized for the Partnership’s workers’ compensation and black lung benefits liability as of December 31, 2016 and 2015 are as follows: December 31, 2016 2015 (in thousands) Black lung claims $ 8,782 $ 9,225 Insured black lung and workers’ compensation claims 27,157 23,907 Workers’ compensation claims 5,584 5,540 Total obligations $ 41,523 $ 38,672 Less current portion (2,450 ) (1,150 ) Non-current obligations $ 39,073 $ 37,522 The balance for insured black lung and workers’ compensation claims as of December 31, 2016 and 2015 consisted of $27.2 million and $23.9 million, respectively. This is a primary obligation of the Partnership, but is also due from the Partnership’s insurance providers and is included in Note 7 as non-current receivables. The Partnership presents this amount on a gross asset and liability basis since a right of setoff does not exist per the accounting guidance in ASC Topic 210. This presentation has no impact on the Partnership’s results of operations or cash flows. |
Employee Benefits
Employee Benefits | 12 Months Ended |
Dec. 31, 2016 | |
Compensation and Retirement Disclosure [Abstract] | |
Employee Benefits | 12. EMPLOYEE BENEFITS Postretirement Plan 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 to be provided until January 31, 2016. For the year ended December 31, 2015, the Partnership recognized a benefit of approximately $2.6 million from the plan amendment in the Cost of operations line of the consolidated statements of operations and comprehensive income. The remaining $3.9 million benefit from the plan amendment was recognized in the first quarter of 2016. Summaries of the changes in benefit obligations and funded status of the plan as of the measurement dates of December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Benefit obligation at beginning of period $ 45 $ 6,648 Changes in benefit obligations: Service cost - 254 Interest cost - 191 Benefits paid (45 ) (217 ) Plan amendment - (6,503 ) Actuarial loss/(gain) - (328 ) Benefit obligation at end of period $ - $ 45 Fair value of plan assets at end of period $ - $ - Funded status $ - $ (45 ) The classification of net amounts recognized for postretirement benefits as of December 31, 2016 and 2015 are as follows: December 31, 2016 2015 (in thousands) Current liability—postretirement benefits $ - $ (45 ) Non-current liability—postretirement benefits - - Net amount recognized $ - $ (45 ) The amounts recognized in accumulated other comprehensive income for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Balance at beginning of year $ 4,795 $ 1,373 Actuarial (loss)/gain - 328 Prior service (cost)/gain to be amortized (3,876 ) 3,876 Amortization of net actuarial gain (919 ) (782 ) Net actuarial gain $ - $ 4,795 The amounts reclassified from accumulated other comprehensive income to Cost of operations in the Partnership’s consolidated statements of operations for the years ended December 31, 2016 and 2015 was $4.8 million and $3.4 million (inclusive of the $2.6 million benefit from the negative plan amendment described above), respectively. December 31, 2016 2015 Weighted Average assumptions used to determine benefit obligations: Discount rate n/a n/a Expected return on plan assets n/a n/a Year Ended December 31, 2016 2015 Weighted Average assumptions used to determine periodic benefit cost: Discount rate (1) n/a 3.15 % Expected return on plan assets n/a n/a Rate of compensation increase n/a n/a The components of net periodic benefit cost for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Service cost $ - $ 254 Interest cost - 191 Amortization of prior service cost (3,876 ) (2,626 ) Amortization of (gain) (919 ) (782 ) Benefit cost $ (4,795 ) $ (2,963 ) 401(k) Plans Year Ended December 31, 2016 2015 (in thousands) 401(k) plan expense $ 1,463 $ 2,007 |
Equity-Based Compensation
Equity-Based Compensation | 12 Months Ended |
Dec. 31, 2016 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
Equity-Based Compensation | 13. EQUITY-BASED COMPENSATION In October 2010, the General Partner established the Rhino Long-Term Incentive Plan (the “Plan” or “LTIP”). The Plan is intended to promote the interests of the Partnership by providing to employees, consultants and directors of the General Partner, the Partnership or affiliates of either incentive compensation awards to encourage superior performance. The LTIP provides for grants of restricted units, unit options, unit appreciation rights, phantom units, unit awards, and other unit-based awards. The aggregate number of units initially reserved for issuance under the LTIP is 247,940. As of December 31, 2016, the General Partner had granted phantom units to certain employees and restricted units and unit awards to its directors. These grants consisted of annual restricted unit awards to directors and phantom unit awards with tandem distribution equivalent rights (“DERs”) granted in the first quarter of each year since 2012 to certain employees in connection with the prior fiscal year’s performance. The DERs consist of rights to accrue quarterly cash distributions in an amount equal to the cash distribution the Partnership makes to unitholders during the vesting period. These awards are subject to service based vesting conditions and any accrued distributions will be forfeited if the related awards fail to vest according to the relevant service based vesting conditions. The phantom units granted to certain employees vest in equal annual installments over a three year period from the date of grant. A summary of non-vested LTIP awards as of and for the years ended December 31, 2016 and 2015 is as follows: Common Units Weighted Average Grant Date Fair Value (per unit) (in thousands) Non-vested awards at December 31, 2014 51 $ 13.50 Granted 247 $ 1.06 Vested (86 ) $ 5.68 Forfeited (8 ) $ 6.43 Non-vested awards at December 31, 2015 204 $ 2.00 Granted 183 $ 2.19 Vested (381 ) $ 2.05 Forfeited (6 ) $ 6.25 Non-vested awards at December 31, 2016 - $ - The Partnership accounts for its unit-based awards as liabilities with applicable mark-to-market adjustments at each reporting period because the Compensation Committee of the board of directors of the General Partner has historically elected to pay some of the awards in cash in lieu of issuing common units. 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 will become immediately vested upon a change in control. The Partnership recognized approximately $10,000 of expense from the vesting of these units as a result of the change in control. For the years ended December 31, 2016 and 2015, the Partnership recorded expense of approximately $0.4 million and $0.1 million, respectively, for the LTIP awards. For the year ended December 31, 2016, the total fair value of the awards that vested was $0.5 million. As of December 31, 2016, the Partnership did not have any unrecognized compensation expense or intrinsic value of any non-vested LTIP awards. |
Commitments and Contingencies
Commitments and Contingencies | 12 Months Ended |
Dec. 31, 2016 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | 14. COMMITMENTS AND CONTINGENCIES Coal Sales Contracts and Contingencies Year Tons (in thousands) Number of customers 2017 3,669 14 2018 701 5 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 Year Ended December 31, 2016 2015 (in thousands) Purchased coal expense $ - $ (26 ) OTC expense $ - $ - Leases Year Ended December 31, 2016 2015 (in thousands) Lease expense $ 4,932 $ 6,204 Royalty expense $ 9,978 $ 10,678 Approximate future minimum lease and royalty payments (not including advance royalties already paid and recorded as assets in the accompanying statements of financial position) are as follows: Years Ending December 31, Royalties Leases (in thousands) 2017 $ 1,640 $ 2,533 2018 1,615 148 2019 1,665 - 2020 1,648 - 2021 1,767 - Thereafter 8,836 - Total minimum royalty and lease payments $ 17,171 $ 2,681 Environmental Matters Legal Matters Guarantees/Indemnifications and Financial Instruments with Off-Balance Sheet Risk The credit facility is fully and unconditionally, jointly and severally guaranteed by the Partnership and substantially all of its wholly owned subsidiaries. Borrowings under the credit facility are collateralized by the unsecured assets of the Partnership and substantially all of its wholly owned subsidiaries. See Note 9 for a more complete discussion of the Partnership’s debt obligations. 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 year ended December 31, 2014 based upon its proportionate ownership interest. |
Earnings Per Unit ('EPU')
Earnings Per Unit ('EPU') | 12 Months Ended |
Dec. 31, 2016 | |
Earnings Per Unit [Abstract] | |
Earnings Per Unit ("EPU") | 15. EARNINGS PER UNIT (“EPU”) The following table presents a reconciliation of the numerators and denominators of the basic and diluted EPU calculations for the years ended December 31, 2016 and 2015: Year ended December 31, 2016 General Partner Common Unitholders Subordinated Unitholders (in thousands, except per unit data) Numerator: Interest in net (loss)/ income: Net (loss) from continuing operations $ (107 ) $ (10,040 ) $ (1,903 ) Net (loss) from discontinued operations (755 ) (99,166 ) (18,792 ) Interest in net (loss) $ (862 ) $ (109,206 ) $ (20,695 ) Impact of subordinated distribution suspension: Net income/(loss) from continuing operations $ - $ - $ - Net income/(loss) from discontinued operations - - - Interest in net income/(loss) $ - $ - $ - Interest in net (loss)/income for EPU purposes: Net (loss) from continuing operations $ (107 ) $ (10,040 ) $ (1,903 ) Net (loss) from discontinued operations (755 ) (99,166 ) (18,792 ) Interest in net (loss) $ (862 ) $ (109,206 ) $ (20,695 ) Denominator: Weighted average units used to compute basic EPU n/a 6,520 1,236 Effect of dilutive securities — LTIP awards n/a - - Weighted average units used to compute diluted EPU n/a 6,520 1,236 Net (loss)/income per limited partner unit, basic: Net (loss) per unit from continuing operations n/a $ (1.54 ) $ (1.54 ) Net (loss) per unit from discontinued operations n/a (15.21 ) (15.21 ) Net (loss) per limited partner unit, basic n/a $ (16.75 ) $ (16.75 ) Net (loss)/income per limited partner unit, diluted: Net (loss) per unit from continuing operations n/a $ (1.54 ) $ (1.54 ) Net (loss) per unit from discontinued operations n/a (15.21 ) (15.21 ) Net (loss) per limited partner unit, diluted n/a $ (16.75 ) $ (16.75 ) Year ended December 31, 2015 General Partner Common Unitholders Subordinated Unitholders (in thousands, except per unit data) Numerator: Interest in net (loss)/income: Net (loss) from continuing operations $ (1,267 ) $ (35,634 ) $ (26,428 ) Net income from discontinued operations 162 4,549 3,374 Interest in net (loss) $ (1,105 ) $ (31,085 ) $ (23,054 ) Impact of subordinated distribution suspension: Net (loss)/income from continuing operations $ 5 $ 139 $ (144 ) Net (loss)/income from discontinued operations - - - Interest in net (loss)/income $ 5 $ 139 $ (144 ) Interest in net (loss)/income for EPU purposes Net (loss) from continuing operations $ (1,262 ) $ (35,495 ) $ (26,572 ) Net income from discontinued operations 162 4,549 3,374 Interest in net(loss) $ (1,100 ) $ (30,946 ) $ (23,198 ) Denominator: Weighted average units used to compute basic EPU n/a 1,671 1,240 Effect of dilutive securities — LTIP awards n/a - - Weighted average units used to compute diluted EPU n/a 1,671 1,240 Net (loss)/income per limited partner unit, basic: Net (loss) per unit from continuing operations n/a $ (21.24 ) $ (21.44 ) Net income per unit from discontinued operations n/a 2.72 2.72 Net(loss) per limited partner unit, basic n/a $ (18.52 ) $ (18.72 ) Net (loss)/income per limited partner unit, diluted: Net (loss) per unit from continuing operations n/a $ (21.24 ) $ (21.44 ) Net income per unit from discontinued operations n/a 2.72 2.72 Net (loss) per limited partner unit, diluted n/a $ (18.52 ) $ (18.72 ) Diluted EPU gives effect to all dilutive potential common units outstanding during the period using the treasury stock method. Diluted EPU excludes all dilutive potential units calculated under the treasury stock method if their effect is anti-dilutive. Since the Partnership incurred a total net loss for the year ended December 31, 2016 and 2015, all potential dilutive units were excluded from the diluted EPU calculation for this period because when an entity incurs a net loss in a period, potential dilutive units shall not be included in the computation of diluted EPU since their effect will always be anti-dilutive. There were no anti-dilutive units for the year ended December 31, 2016. |
Major Customers
Major Customers | 12 Months Ended |
Dec. 31, 2016 | |
Risks and Uncertainties [Abstract] | |
Major Customers | 16. MAJOR CUSTOMERS The Partnership had revenues or receivables from the following major customers that in each period equaled or exceeded 10% of revenues or receivables (Note: customers with “n/a” had revenue or receivables below the 10% threshold in any period where this is indicated): December 31, 2016 Receivable Balance Year Ended December 31, 2016 Sales December 31, 2015 Receivable Balance Year Ended December 31, 2015 Sales (in thousands) PPL Corporation $ 1,496 $ 42,175 $ 1,881 $ 33,662 PacifiCorp Energy 1,509 19,581 1,969 21,519 Big Rivers - 16,241 - 4,638 |
Fair Value Measurements
Fair Value Measurements | 12 Months Ended |
Dec. 31, 2016 | |
Fair Value Disclosures [Abstract] | |
Fair Value Measurements | 17. FAIR VALUE MEASUREMENTS 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 senior secured credit facility was determined based upon a market approach and approximates the carrying value at December 31, 2016. The fair value of the Partnership’s senior secured credit facility is a Level 2 measurement. As of December 31, 2016, the Partnership had a recurring fair value measurement relating to its investment in Mammoth Energy Services, Inc. (“Mammoth, Inc.”). In October 2016, the Partnership contributed its limited partner interests in Mammoth to Mammoth Energy Services, Inc. (“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 subject to a 180-day lock-up period from the date of Mammoth Inc.’s initial public offering and are classified as a held-for-sale investment on the Partnership’s 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. As of December 31, 2016, the Partnership did not have any nonrecurring fair value measurements related to any assets held for sale. As of December 31, 2015, the Partnership had assets classified as held for sale that were related to the Partnership’s 2016 sale of its Elk Horn coal leasing business as discussed in Note 4. The Partnership previously had assets classified as held for sale that were related to the Partnership’s 2014 impairment actions related to its Red Cliff assets. As of December 31, 2015, the Partnership reclassified its previously held for sale assets to property, plant and equipment to be held and used since the Partnership no longer had an active plan to sell these assets in the next twelve months. For the years ended December 31, 2016 and December 31, 2015, the Partnership had nonrecurring fair value measurements related to asset impairments as described in Note 6. The nonrecurring fair value measurements for the asset impairments described in Note 6 for the years ended December 31, 2016 and December 31, 2015 were Level 3 measurements. |
Related Party and Affiliate Tra
Related Party and Affiliate Transactions | 12 Months Ended |
Dec. 31, 2016 | |
Related Party Transactions [Abstract] | |
Related Party and Affiliate Transactions | 18. RELATED PARTY AND AFFILIATE TRANSACTIONS Related Party Description 2016 2015 (in thousands) Royal Energy Resources, Inc. Partner’s contribution $ 7,000 Royal Energy Resources, Inc. Purchase of preferred units 2,000 Weston Energy LLC Purchase of preferred units 11,000 Wexford Capital LP Expenses for legal, consulting, and advisory services 11 143 Wexford Capital LP Distributions paid - 553 Wexford Capital LP Partner’s contribution - 2 Timber Wolf Terminals LLC Investment in unconsolidated affiliate - 130 Mammoth Energy Partners LP Investment in unconsolidated affiliate - 1,933 Sturgeon Acquisitions LLC Investment in unconsolidated affiliate - 5,515 Sturgeon Acquisitions LLC Distributions from unconsolidated affiliate 300 232 Sturgeon Acquisitions LLC Return of capital from unconsolidated affiliate - 35 Sturgeon Acquisitions LLC Equity in net income of unconsolidated affiliate (223 ) 342 From time to time, employees from Wexford Capital perform legal, consulting, and advisory services to the Partnership. The Partnership incurred expenses of $0.1 million for the years ended December 31, 2016 and 2015 for legal, consulting, and advisory services performed by Wexford Capital. |
Supplemental Disclosures of Cas
Supplemental Disclosures of Cash Flow Information | 12 Months Ended |
Dec. 31, 2016 | |
Supplemental Cash Flow Information [Abstract] | |
Supplemental Disclosures of Cash Flow Information | 19. SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION Cash payments for interest were $3.8 million and $3.4 million for the years ended December 31, 2016 and 2015, respectively. The consolidated statement of cash flows for the year ended December 31, 2016 is exclusive of approximately $1.1 million of property, plant and equipment additions which are recorded in Accounts payable. The consolidated statements of cash flows for the year ended December 31, 2016 also excludes approximately $0.6 million related to the value of LTIP units that were issued to certain employees and directors of the General Partner. As discussed in Note 1, the Partnership and Rhino Holdings executed an Option Agreement in December 2016 where the Partnership received a Call Option from Rhino Holdings to acquire substantially all of the outstanding common stock of Armstrong Energy. In exchange for Rhino Holdings granting the Partnership the Call Option, the Partnership issued 5.0 million common units to Rhino Holdings upon the execution of the Option Agreement. The Partnership valued the Call Option at $21.8 million based upon the closing price of the Partnership’s publicly traded common units on the date the Option Agreement was executed. In January 2015, the Partnership dissolved the Rhino Eastern joint venture with Patriot. As part of the dissolution, the Partnership retained coal reserves, a prepaid advanced royalty balance and other assets and liabilities. In addition, the Partnership and Patriot agreed to a dissolution payment as part of the dissolution based upon a final working capital adjustment calculation, which is a liability of the Partnership. The Partnership recorded the dissolution of the joint venture by removing the investment in the Rhino Eastern unconsolidated subsidiary and recording the specific assets and liabilities retained in the dissolution. The dissolution of the Rhino Eastern joint venture completed in January 2015 had no impact on the Partnership’s consolidated statements of operations and comprehensive income for the year ended December 31, 2015. The consolidated statement of cash flows for the year ended December 31, 2015 excludes the removal of the investment in the unconsolidated subsidiary and the recognition of the retained assets and liabilities, which are detailed in the table below. (in thousands) Coal properties (incl asset retirement costs) $ 12,104 Advance royalties, net of current portion 4,706 Other non-current assets - acquired 229 Other non-current assets - written off (642 ) Accrued expenses and other (2,012 ) Asset retirement obligations (1,235 ) Net assets acquired 13,150 Investment in unconsolidated affiliates-Rhino Eastern - written off $ (13,150 ) The consolidated statement of cash flows for the year ended December 31, 2015 is exclusive of approximately $0.7 million of property, plant and equipment additions which are recorded in Accounts payable. The consolidated statements of cash flows for the year ended December 31, 2015 also excludes approximately $0.1 million related to the value of LTIP units that were issued to certain employees and directors of the General Partner. |
Segment Information
Segment Information | 12 Months Ended |
Dec. 31, 2016 | |
Segment Reporting [Abstract] | |
Segment Information | 20. SEGMENT INFORMATION The Partnership primarily produces and markets coal from surface and underground mines in Kentucky, West Virginia, Ohio and Utah. The Partnership sells primarily to electric utilities in the United States. As of December 31, 2016, the Partnership has four reportable business segments: Central Appalachia, Northern Appalachia, Rhino Western and Illinois Basin. Additionally, the Partnership has an Other category that includes its ancillary businesses. The Partnership’s Other category as reclassified is comprised of the Partnership’s ancillary businesses and its remaining oil and natural gas activities. Held for sale assets are included in the applicable segment for reporting purposes. The Partnership has not provided disclosure of total expenditures by segment for long-lived assets, as the Partnership does not maintain discrete financial information concerning segment expenditures for long lived assets, and accordingly such information is not provided to the Partnership’s chief operating decision maker. The information provided in the following tables represents the primary measures used to assess segment performance by the Partnership’s chief operating decision maker. Reportable segment results of operations and financial position for the year ended December 31, 2016 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization): Central Appalachia Northern Appalachia Rhino Western Illinois Basin Other Total Consolidated (in thousands) Total assets $ 89,918 $ 9,758 $ 33,205 $ 80,218 $ 64,342 $ 277,441 Total revenues 37,753 38,834 34,675 59,095 423 170,780 DD&A 6,553 3,142 5,211 8,326 554 23,786 Interest expense 2,051 314 383 982 2,966 6,696 Net Income (loss) from continuing operations $ (10,615 ) $ 8,791 $ (1,042 ) $ (5,524 ) $ (3,660 ) $ (12,050 ) Reportable segment results of operations and financial position for the year ended December 31, 2015 are as follows: Central Appalachia Northern Appalachia Rhino Western Illinois Basin Other Total Consolidated (in thousands) Total assets $ 227,880 $ 17,218 $ 37,198 $ 82,699 $ 39,671 $ 404,666 Total revenues 56,228 63,273 35,322 38,641 1,568 195,032 DD&A 11,032 7,562 6,314 5,928 736 31,572 Interest expense 2,029 522 315 597 1,527 4,990 Net Income (loss) from continuing operations $ (21,575 ) $ (20,487 ) $ (4,560 ) $ (13,807 ) $ (2,900 ) $ (63,329 ) Additional information on the Partnership’s revenue by product category for the periods ended December 31, 2016 and 2015 is as follows: 2016 2015 (in thousands) Met coal revenue $ 21,542 $ 15,391 Steam coal revenue 139,299 155,683 Other revenue 9,939 23,958 Total revenue $ 170,780 $ 195,032 |
Summary of Significant Accoun28
Summary of Significant Accounting Policies and General (Policies) | 12 Months Ended |
Dec. 31, 2016 | |
Accounting Policies [Abstract] | |
Trade Receivables and Concentrations of Credit Risk | Trade Receivables and Concentrations of Credit Risk. |
Cash and Cash Equivalents | Cash and Cash Equivalents. |
Inventories | Inventories. |
Advance Royalties | Advance Royalties. |
Property, Plant and Equipment | Property, Plant and Equipment. Stripping costs incurred in the production phase of a mine for the removal of overburden or waste materials for the purpose of obtaining access to coal that will be extracted are variable production costs that are included in the cost of inventory produced and extracted during the period the stripping costs are incurred. The Partnership defines a surface mine as a location where the Partnership utilizes operating assets necessary to extract coal, with the geographic boundary determined by property control, permit boundaries, and/or economic threshold limits. Multiple pits that share common infrastructure and processing equipment may be located within a single surface mine boundary, which can cover separate coal seams that typically are recovered incrementally as the overburden depth increases. In accordance with the accounting guidance for extractive mining activities, the Partnership defines a mine in production as one from which saleable minerals have begun to be extracted (produced) from an ore body, regardless of the level of production; however, the production phase does not commence with the removal of de minimis saleable mineral material that occurs in conjunction with the removal of overburden or waste material for the purpose of obtaining access to an ore body. The Partnership capitalizes only the development cost of the first pit at a mine site that may include multiple pits. |
Asset Impairments for Coal Properties, Mine Development Costs and Other Coal Mining Equipment and Related Facilities | Asset Impairments for Coal Properties, Mine Development Costs and Other Coal Mining Equipment and Related Facilities. |
Debt Issuance Costs | Debt Issuance Costs. |
Asset Retirement Obligations | Asset Retirement Obligations. The Partnership estimates its future cost requirements for reclamation of land where it has conducted surface and underground mining operations, based on its interpretation of the technical standards of regulations enacted by the U.S. Office of Surface Mining, as well as state regulations. These costs relate to reclaiming the pit and support acreage at surface mines and sealing portals at underground mines. Other reclamation costs are related to refuse and slurry ponds, as well as holding and related termination/exit costs. The Partnership expenses contemporaneous reclamation which is performed prior to final mine closure. The establishment of the end of mine reclamation and closure liability is based upon permit requirements and requires significant estimates and assumptions, principally associated with regulatory requirements, costs and recoverable coal reserves. Annually, the Partnership reviews its end of mine reclamation and closure liability and makes necessary adjustments, including mine plan and permit changes and revisions to cost and production levels to optimize mining and reclamation efficiency. When a mine life is shortened due to a change in the mine plan, mine closing obligations are accelerated, the related accrual is increased and the related asset is reviewed for impairment, accordingly. The adjustments to the liability from annual recosting reflect changes in expected timing, cash flow and the discount rate used in the present value calculation of the liability. Each respective year includes a range of discount rates that are dependent upon the timing of the cash flows of the specific obligations. Changes in the asset retirement obligations for the year ended December 31, 2016 were calculated with discount rates that ranged from 7.0% to 9.1%. Changes in the asset retirement obligations for the year ended December 31, 2015 were calculated with discount rates that ranged from 2.9% to 5.9%. The discount rates changed in each respective year due to changes in applicable market indicators that are used to arrive at an appropriate discount rate. Other recosting adjustments to the liability are made annually based on inflationary cost increases or decreases and changes in the expected operating periods of the mines. The related inflation rate utilized in the recosting adjustments was 2.3 % for 2016 and 2015. |
Revenue Recognition | Revenue Recognition. Freight and handling costs paid directly to third-party carriers and invoiced to coal customers are recorded as freight and handling costs and freight and handling revenues, respectively. Other revenues generally consist of coal royalty revenues, limestone sales, coal handling and processing, oil and natural gas royalty revenues, rebates and rental income. With respect to other revenues recognized in situations unrelated to the shipment of coal, the Partnership carefully reviews the facts and circumstances of each transaction and does not recognize revenue until the following criteria are met: persuasive evidence of an arrangement exists, delivery has occurred or services have been rendered, the seller’s price to the buyer is fixed or determinable and collectibility is reasonably assured. Advance payments received are deferred and recognized in revenue when earned. |
Equity-Based Compensation | Equity-Based Compensation. The Compensation Committee of the board of directors of the General Partner has historically elected to pay some of the awards in cash or a combination of cash and common units. This policy has resulted in all employee awards being classified as liabilities and, thus, the employee awards are required to be marked-to-market each reporting period until they are vested. Restricted unit awards granted to directors of the General Partner are considered nonemployee equity-based awards since the directors are not elected by unitholders. Thus, these director awards are also required to be marked-to-market each reporting period until they are vested. Expense related to unit awards is recorded in the selling, general and administrative line of the Partnership’s consolidated statements of operations and comprehensive income. |
Derivative Financial Instruments | Derivative Financial Instruments. |
Investments in Joint Ventures | Investments in Joint Ventures. In December 2012, the Partnership made an initial investment of approximately $2.0 million in a new joint venture, Muskie Proppant LLC (“Muskie”), with affiliates of Wexford Capital. During 2014, the Partnership contributed additional capital based upon its ownership share to the Muskie joint venture in the amount of $0.2 million. In November 2014, the Partnership contributed its investment interest in Muskie to Mammoth in return for a limited partner interest in Mammoth. The non-cash transaction was a contribution of the Partnership’s investment interest in the Muskie entity for an investment interest in Mammoth. Thus, the Partnership determined that the non-cash exchange of the Partnership’s ownership interest in Muskie did not result in any gain or loss. Prior to the Partnership’s contribution of Muskie to Mammoth, the Partnership recorded its proportionate portion of Muskie’s operating loss for 2014 of approximately $0.1 million. As of December 31, 2016 and 2015, the Partnership has recorded its investment in Mammoth of $1.9 million as a short-term asset, which the Partnership has classified as available-for-sale. In October 2016, the Partnership contributed its limited partner interests in Mammoth to Mammoth Energy Services, Inc. in exchange for 234,300 shares of common stock of Mammoth Energy Services, Inc. The Partnership recorded a fair market value adjustment of $1.6 million for the available-for-sale investment based on the market value of the shares at December 31, 2016, which was recorded in Other Comprehensive Income. The Partnership has included its investment in Mammoth and its prior investment in Muskie in its Other category for segment reporting purposes. In September 2014, the Partnership made an initial investment of $5.0 million in a new joint venture, Sturgeon Acquisitions LLC (“Sturgeon”), with affiliates of Wexford Capital and Gulfport. 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 year ended December 31, 2016 of approximately $0.2 million and its proportionate share of operating income of approximately $0.3 million for the year ended December 31 2015. The Partnership has recorded its investment in Sturgeon on the Investment in unconsolidated affiliates line of the Partnership’s consolidated statements of financial position. The Partnership has included its investment in Sturgeon in its Other category for segment reporting purposes. |
Income Taxes | Income Taxes. |
Loss Contingencies | Loss Contingencies. |
Management's Use of Estimates | Management’s Use of Estimates. |
Recently Issued Accounting Standards | Recently Issued Accounting Standards. In August 2014, the FASB issued ASU 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern In January 2015, the FASB issued ASU 2015-01, “Income Statement-Extraordinary and Unusual Items”. ASC 225-20, Income Statement—Extraordinary and Unusual Items, required that an entity separately classify, present, and disclose extraordinary events and transactions. ASU 2015-01 eliminates the concept of extraordinary items. The amendments in ASU 2015-01 are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2015. A reporting entity may apply the amendments prospectively. A reporting entity also may apply the amendments retrospectively to all prior periods presented in the financial statements. Early adoption is permitted provided that the guidance is applied from the beginning of the fiscal year of adoption. The effective date is the same for both public business entities and all other entities. The adoption of ASU 2015-01 on January 1, 2016 has not had a material impact on the Partnership’s financial statements. In February 2015, the FASB issued ASU 2015-02, “Consolidation”. ASU 2015-02 affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. All legal entities are subject to reevaluation under the revised consolidation model. Specifically, the amendments of ASU 2015-02: a) modify the evaluation of whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities, b) eliminate the presumption that a general partner should consolidate a limited partnership, c) affect the consolidation analysis of reporting entities that are involved with VIEs, particularly those that have fee arrangements and related party relationships and d) provide a scope exception from consolidation guidance for reporting entities with interests in legal entities that are required to comply with or operate in accordance with requirements that are similar to those in Rule 2a-7 of the Investment Company Act of 1940 for registered money market funds. ASU 2015-02 is effective for public business entities for fiscal years, and for interim periods within those fiscal years, beginning after December 15, 2015. A reporting entity may apply the amendments in this Update using a modified retrospective approach by recording a cumulative-effect adjustment to equity as of the beginning of the fiscal year of adoption. A reporting entity also may apply the amendments retrospectively. The adoption of ASU 2015-02 on January 1, 2016 did not have a material impact on the Partnership’s financial statements. In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842).” ASU 2016-02 requires that lessees recognize all leases (other than leases with a term of twelve months or less) on the balance sheet as lease liabilities, based upon the present value of the lease payments, with corresponding right of use assets. ASU 2016-02 also makes targeted changes to other aspects of current guidance, including identifying a lease and lease classification criteria as well as the lessor accounting model, including guidance on separating components of a contract and consideration in the contract. The amendments in ASU 2016-02 will be effective for the Partnership on January 1, 2019 and will require modified retrospective application as of the beginning of the earliest period presented in the financial statements. Early application is permitted. The Partnership is currently evaluating this guidance. In August 2016, the FASB issued ASU 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments.” ASU 2016-15 provides guidance on eight cash flow issues, including debt prepayment or debt extinguishment costs. ASU 2016-15 requires that cash payments related to debt prepayments or debt extinguishments, excluding accrued interest, be classified as a financing activity rather than an operating activity even when the effects enter into the determination of net income. The amendments in ASU 2016-15 will be effective on January 1, 2018 and must be applied retrospectively. Early application is permitted. The Partnership is currently evaluating this guidance. In October 2016, the FASB issued ASU 2016-17, “Consolidation (Topic 810): Interests Held through Related Parties that are Under Common Control.” ASU 2016-17 amends the consolidation guidance on how a reporting entity that is the single decision maker of a variable interest entity (VIE) should treat indirect interests in the entity held through related parties that are under common control with the reporting entity when determining whether it is the primary beneficiary of that VIE. ASU is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. The adoption of ASU 2016-17 is not expected to have a material impact on the Partnership’s financial statements. In January 2017, the FASB issued ASU 2017-01, “Business Combinations (Topic 805).” ASU 2017—01 clarifies the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. ASU is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years. The Partnership is currently evaluating this guidance. |
Discontinued Operations (Tables
Discontinued Operations (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Discontinued Operations and Disposal Groups [Abstract] | |
Schedule of Major Assets and Liabilities of Discontinued Operations | Major assets and liabilities of discontinued operations, as of December 31, 2016 and 2015 are summarized as follows: Carrying amount of major classes of assets included as part of discontinued operations: Cash and cash equivalents $ - $ 19 Accounts receivable, net of allowance for doubtful accounts - 1,972 Prepaid expenses and other - 7 Total current assets of the disposal group classified as held for sale in the statement of financial position - 1,998 Property and equipment (net) - 108,709 Advance royalties, net of current portion - 154 Intangible assets (net) 505 Total non-current assets of the disposal group classified as held for sale in the statement of financial position $ - $ 109,368 Carrying amount of major classes of liabilities included as part of discontinued operations: Accounts payable $ - $ 137 Accrued expenses and other - 793 Total current liabilities of the disposal group classified as held for sale in the statement of financial position - 930 Asset retirement obligations, net of current portion - 670 Deferred revenue 2,259 Other non-current liabilities - 670 Total non-current liabilities of the disposal group classified as held for sale in the statement of financial position - 3,599 |
Schedule of Major Components of Net (Loss) Income from Discontinued Operations | Major components of net (loss)/income from discontinued operations for the years ended December 31, 2016 and 2015 are summarized as follows: Year Ended December 31, 2016 2015 Major line items constituting (loss)/income from discontinued operations for the Elk Horn disposal: Royalty income $ 2,668 $ 11,714 Total revenues 2,668 11,714 Cost of operations (exclusive of depreciation, depletion and amortization shown separately below) 799 2,187 Depreciation, depletion and amortization 413 1,608 Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above) 174 573 (Gain) on sale/disposal of assets, net 119,982 (28 ) Interest expense and other 13 11 Total costs and expenses 121,381 4,351 (Loss/Income) from discontinued operations before income taxes for the Elk Horn disposal (118,713 ) 7,363 Income from discontinued operations relating to Blackhawk disposal - 722 (Loss/Income) from discontinued operations before income taxes (118,713 ) 8,085 Income taxes - - Net(Loss)/Income from discontinued operations (118,713 ) 8,085 |
Prepaid Expenses And Other Cu30
Prepaid Expenses And Other Current Assets (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Prepaid Expense and Other Assets, Current [Abstract] | |
Schedule of Prepaid Expenses and Other Current Assets | Prepaid expenses and other current assets as of December 31, 2016 and 2015 consisted of the following: December 31, 2016 2015 (in thousands) Other prepaid expenses $ 707 $ 675 Debt issuance costs—net 1,239 2,155 Prepaid insurance 1,432 1,492 Prepaid leases 77 80 Supply inventory 614 901 Deposits 164 164 Available-for-sale investment 3,532 - Note receivable-current portion 900 - Total $ 8,665 $ 5,467 |
Property, Plant and Equipment (
Property, Plant and Equipment (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
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 December 31, 2016 and 2015 are summarized by major classification as follows: December 31, Useful Lives 2016 2015 (in thousands) Land and land improvements $ 16,377 $ 17,513 Mining and other equipment and related facilities 2 - 20 Years 305,626 305,845 Mine development costs 1 - 15 Years 57,392 64,262 Coal, oil and natural gas properties 1 - 15 Years 67,989 94,390 Construction work in process 1,797 2,680 Total 449,181 484,690 Less accumulated depreciation, depletion and amortization (266,874 ) (259,892 ) Net $ 182,307 $ 224,798 |
Schedule of Depreciation, Depletion, and Amortization | Depreciation expense for mining and other equipment and related facilities, depletion expense for coal and oil and natural gas properties, amortization expense for mine development costs, amortization expense for intangible assets and amortization expense for asset retirement costs for the years ended December 31, 2016 and 2015 was as follows: Year Ended December 31, 2016 2015 (in thousands) Depreciation expense-mining and other equipment and related facilities $ 20,479 $ 28,698 Depletion expense for coal properties 1,542 1,346 Amortization expense for mine development costs 1,901 1,935 Amortization expense for intangible assets - 43 Amortization expense for asset retirement costs (136 ) (450 ) Total $ 23,786 $ 31,572 |
Intangible and Other Non-curr32
Intangible and Other Non-current Assets (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Intangible And Other Non-current Assets | |
Schedule of Other Non-current Assets | Other non-current assets as of December 31, 2016 and 2015 consisted of the following: December 31, 2016 2015 (in thousands) Deposits and other $ 218 $ 218 Due (to) Rhino GP (573 ) (80 ) Non-current receivable 27,157 23,908 Note receivable - 2,000 Deferred expenses 216 260 Total $ 27,018 $ 26,306 |
Accrued Expenses and Other Cu33
Accrued Expenses and Other Current Liabilities (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Payables and Accruals [Abstract] | |
Schedule of Accrued Expenses and Other Current Liabilities | Accrued expenses and other current liabilities as of December 31, 2016 and 2015 consisted of the following: December 31, 2016 2015 (in thousands) Payroll, bonus and vacation expense $ 1,496 $ 1,439 Non-income taxes 2,252 2,993 Royalty expenses 1,617 1,566 Accrued interest 601 571 Health claims 630 817 Workers’ compensation & pneumoconiosis 2,450 1,150 Accrued insured litigation claims 277 266 Other 740 2,247 Total $ 10,063 $ 11,049 |
Debt (Tables)
Debt (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Debt Disclosure [Abstract] | |
Schedule of Debt | Debt as of December 31, 2016 and 2015 consisted of the following: December 31, 2016 2015 (in thousands) Senior secured credit facility with PNC Bank, N.A. $ 10,040 $ 41,200 Other notes payable - 2,874 Total 10,040 44,074 Less current portion (10,040 ) (41,479 ) Long-term debt $ - $ 2,595 |
Schedule of Principal Payments on Long-term Debt | Principal payments on long-term debt due subsequent to December 31, 2016 are as follows: (in thousands) 2017 $ 10,040 2018 - 2019 - 2020 - Thereafter - Total principal payments $ 10,040 |
Asset Retirement Obligations (T
Asset Retirement Obligations (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Asset Retirement Obligation Disclosure [Abstract] | |
Schedule of Asset Retirement Obligations | The changes in asset retirement obligations for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Balance at beginning of period (including current portion) $ 23,077 $ 29,883 Accretion expense 1,486 2,082 Adjustment resulting from addition of property - 1,235 Adjustment resulting from disposal of property (1) - (7,531 ) Adjustments to the liability from annual recosting and other (1,085 ) (2,078 ) Reclassification to held for sale - - Liabilities settled (200 ) (514 ) Balance at end of period 23,278 23,077 Less current portion of asset retirement obligation (917 ) (767 ) Long-term portion of asset retirement obligation $ 22,361 $ 22,310 (1) The ($7.5) million adjustment for the year ended December 31, 2015 relates to the sale of the Partnership’s Deane mining complex discussed in Note 6 and the sale of Elk Horn discussed in Note 4. |
Workers' Compensation and Bla36
Workers' Compensation and Black Lung (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Workers Compensation And Black Lung Tables | |
Summary of Black Lung and Workers' Compensation Expenses | The uninsured black lung and workers’ compensation expenses for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Black lung benefits: Service cost $ (506 ) $ (991 ) Interest cost 363 397 Actuarial loss/(gain) - - Total black lung (143 ) (594 ) Workers’ compensation expense 4,013 4,334 Total expense $ 3,870 $ 3,740 |
Schedule of Changes in Benefit Liability | The changes in the black lung benefit liability for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Benefit obligations at beginning of year $ 9,225 $ 10,033 Service cost (506 ) (991 ) Interest cost 363 397 Actuarial loss/(gain) - - Benefits and expenses paid (300 ) (214 ) Benefit obligations at end of year $ 8,782 $ 9,225 |
Classification of Net Amounts Recognized for Workers' Compensation and Black Lung Benefits | The classification of the amounts recognized for the Partnership’s workers’ compensation and black lung benefits liability as of December 31, 2016 and 2015 are as follows: December 31, 2016 2015 (in thousands) Black lung claims $ 8,782 $ 9,225 Insured black lung and workers’ compensation claims 27,157 23,907 Workers’ compensation claims 5,584 5,540 Total obligations $ 41,523 $ 38,672 Less current portion (2,450 ) (1,150 ) Non-current obligations $ 39,073 $ 37,522 |
Employee Benefits (Tables)
Employee Benefits (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Compensation and Retirement Disclosure [Abstract] | |
Summary of Changes in Benefit Obligations | Summaries of the changes in benefit obligations and funded status of the plan as of the measurement dates of December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Benefit obligation at beginning of period $ 45 $ 6,648 Changes in benefit obligations: Service cost - 254 Interest cost - 191 Benefits paid (45 ) (217 ) Plan amendment - (6,503 ) Actuarial loss/(gain) - (328 ) Benefit obligation at end of period $ - $ 45 Fair value of plan assets at end of period $ - $ - Funded status $ - $ (45 ) |
Classification of Net Amounts Recognized for Postretirement Benefits | The classification of net amounts recognized for postretirement benefits as of December 31, 2016 and 2015 are as follows: December 31, 2016 2015 (in thousands) Current liability—postretirement benefits $ - $ (45 ) Non-current liability—postretirement benefits - - Net amount recognized $ - $ (45 ) |
Schedule of Recognized in Accumulated Other Comprehensive Income | The amounts recognized in accumulated other comprehensive income for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Balance at beginning of year $ 4,795 $ 1,373 Actuarial (loss)/gain - 328 Prior service (cost)/gain to be amortized (3,876 ) 3,876 Amortization of net actuarial gain (919 ) (782 ) Net actuarial gain $ - $ 4,795 |
Schedule of Weighted Average Assumptions Used to Determine Benefit Obligations | December 31, 2016 2015 Weighted Average assumptions used to determine benefit obligations: Discount rate n/a n/a Expected return on plan assets n/a n/a |
Schedule of Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost | Year Ended December 31, 2016 2015 Weighted Average assumptions used to determine periodic benefit cost: Discount rate (1) n/a 3.15 % Expected return on plan assets n/a n/a Rate of compensation increase n/a n/a |
Components of Net Periodic Benefit Cost | The components of net periodic benefit cost for the years ended December 31, 2016 and 2015 are as follows: Year Ended December 31, 2016 2015 (in thousands) Service cost $ - $ 254 Interest cost - 191 Amortization of prior service cost (3,876 ) (2,626 ) Amortization of (gain) (919 ) (782 ) Benefit cost $ (4,795 ) $ (2,963 ) |
Schedule of Expense Under Defined Contribution Savings Plans | The expense under these plans for the years ended December 31, 2016 and 2015 was as follows: Year Ended December 31, 2016 2015 (in thousands) 401(k) plan expense $ 1,463 $ 2,007 |
Equity Based Compensation (Tabl
Equity Based Compensation (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
Summary of Non-vested LTIP Awards | A summary of non-vested LTIP awards as of and for the years ended December 31, 2016 and 2015 is as follows: Common Units Weighted Average Grant Date Fair Value (per unit) (in thousands) Non-vested awards at December 31, 2014 51 $ 13.50 Granted 247 $ 1.06 Vested (86 ) $ 5.68 Forfeited (8 ) $ 6.43 Non-vested awards at December 31, 2015 204 $ 2.00 Granted 183 $ 2.19 Vested (381 ) $ 2.05 Forfeited (6 ) $ 6.25 Non-vested awards at December 31, 2016 - $ - |
Commitments and Contingencies (
Commitments and Contingencies (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Commitments and Contingencies Disclosure [Abstract] | |
Schedule of Delivery Commitments | As of December 31, 2016, 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 3,669 14 2018 701 5 |
Schedule of Purchased Coal Expenses | Purchase coal expense from coal purchase contracts and expense from OTC purchases for the years ended December 31, 2016 and 2015 was as follows: Year Ended December 31, 2016 2015 (in thousands) Purchased coal expense $ - $ (26 ) OTC expense $ - $ - |
Schedule of Lease and Royalty Expense | Lease and royalty expense for the years ended December 31, 2016 and 2015 was as follows: Year Ended December 31, 2016 2015 (in thousands) Lease expense $ 4,932 $ 6,204 Royalty expense $ 9,978 $ 10,678 |
Schedule of Future Minimum Lease and Royalty Payments | Approximate future minimum lease and royalty payments (not including advance royalties already paid and recorded as assets in the accompanying statements of financial position) are as follows: Years Ending December 31, Royalties Leases (in thousands) 2017 $ 1,640 $ 2,533 2018 1,615 148 2019 1,665 - 2020 1,648 - 2021 1,767 - Thereafter 8,836 - Total minimum royalty and lease payments $ 17,171 $ 2,681 |
Earnings Per Unit ('EPU') (Tabl
Earnings Per Unit ('EPU') (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Earnings Per Unit [Abstract] | |
Schedule of Calculation of Numerator and Denominator in Earnings Per Unit | The following table presents a reconciliation of the numerators and denominators of the basic and diluted EPU calculations for the years ended December 31, 2016 and 2015: Year ended December 31, 2016 General Partner Common Unitholders Subordinated Unitholders (in thousands, except per unit data) Numerator: Interest in net (loss)/ income: Net (loss) from continuing operations $ (107 ) $ (10,040 ) $ (1,903 ) Net (loss) from discontinued operations (755 ) (99,166 ) (18,792 ) Interest in net (loss) $ (862 ) $ (109,206 ) $ (20,695 ) Impact of subordinated distribution suspension: Net income/(loss) from continuing operations $ - $ - $ - Net income/(loss) from discontinued operations - - - Interest in net income/(loss) $ - $ - $ - Interest in net (loss)/income for EPU purposes: Net (loss) from continuing operations $ (107 ) $ (10,040 ) $ (1,903 ) Net (loss) from discontinued operations (755 ) (99,166 ) (18,792 ) Interest in net (loss) $ (862 ) $ (109,206 ) $ (20,695 ) Denominator: Weighted average units used to compute basic EPU n/a 6,520 1,236 Effect of dilutive securities — LTIP awards n/a - - Weighted average units used to compute diluted EPU n/a 6,520 1,236 Net (loss)/income per limited partner unit, basic: Net (loss) per unit from continuing operations n/a $ (1.54 ) $ (1.54 ) Net (loss) per unit from discontinued operations n/a (15.21 ) (15.21 ) Net (loss) per limited partner unit, basic n/a $ (16.75 ) $ (16.75 ) Net (loss)/income per limited partner unit, diluted: Net (loss) per unit from continuing operations n/a $ (1.54 ) $ (1.54 ) Net (loss) per unit from discontinued operations n/a (15.21 ) (15.21 ) Net (loss) per limited partner unit, diluted n/a $ (16.75 ) $ (16.75 ) Year ended December 31, 2015 General Partner Common Unitholders Subordinated Unitholders (in thousands, except per unit data) Numerator: Interest in net (loss)/income: Net (loss) from continuing operations $ (1,267 ) $ (35,634 ) $ (26,428 ) Net income from discontinued operations 162 4,549 3,374 Interest in net (loss) $ (1,105 ) $ (31,085 ) $ (23,054 ) Impact of subordinated distribution suspension: Net (loss)/income from continuing operations $ 5 $ 139 $ (144 ) Net (loss)/income from discontinued operations - - - Interest in net (loss)/income $ 5 $ 139 $ (144 ) Interest in net (loss)/income for EPU purposes Net (loss) from continuing operations $ (1,262 ) $ (35,495 ) $ (26,572 ) Net income from discontinued operations 162 4,549 3,374 Interest in net(loss) $ (1,100 ) $ (30,946 ) $ (23,198 ) Denominator: Weighted average units used to compute basic EPU n/a 1,671 1,240 Effect of dilutive securities — LTIP awards n/a - - Weighted average units used to compute diluted EPU n/a 1,671 1,240 Net (loss)/income per limited partner unit, basic: Net (loss) per unit from continuing operations n/a $ (21.24 ) $ (21.44 ) Net income per unit from discontinued operations n/a 2.72 2.72 Net(loss) per limited partner unit, basic n/a $ (18.52 ) $ (18.72 ) Net (loss)/income per limited partner unit, diluted: Net (loss) per unit from continuing operations n/a $ (21.24 ) $ (21.44 ) Net income per unit from discontinued operations n/a 2.72 2.72 Net (loss) per limited partner unit, diluted n/a $ (18.52 ) $ (18.72 ) |
Major Customers (Tables)
Major Customers (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
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 or receivables (Note: customers with “n/a” had revenue or receivables below the 10% threshold in any period where this is indicated): December 31, 2016 Receivable Balance Year Ended December 31, 2016 Sales December 31, 2015 Receivable Balance Year Ended December 31, 2015 Sales (in thousands) PPL Corporation $ 1,496 $ 42,175 $ 1,881 $ 33,662 PacifiCorp Energy 1,509 19,581 1,969 21,519 Big Rivers - 16,241 - 4,638 |
Related Party and Affiliate T42
Related Party and Affiliate Transactions (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Related Party Transactions [Abstract] | |
Schedule of Related Party and Affiliate Transactions | Related Party Description 2016 2015 (in thousands) Royal Energy Resources, Inc. Partner’s contribution $ 7,000 Royal Energy Resources, Inc. Purchase of preferred units 2,000 Weston Energy LLC Purchase of preferred units 11,000 Wexford Capital LP Expenses for legal, consulting, and advisory services 11 143 Wexford Capital LP Distributions paid - 553 Wexford Capital LP Partner’s contribution - 2 Timber Wolf Terminals LLC Investment in unconsolidated affiliate - 130 Mammoth Energy Partners LP Investment in unconsolidated affiliate - 1,933 Sturgeon Acquisitions LLC Investment in unconsolidated affiliate - 5,515 Sturgeon Acquisitions LLC Distributions from unconsolidated affiliate 300 232 Sturgeon Acquisitions LLC Return of capital from unconsolidated affiliate - 35 Sturgeon Acquisitions LLC Equity in net income of unconsolidated affiliate (223 ) 342 |
Supplemental Disclosures of C43
Supplemental Disclosures of Cash Flow Information (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Supplemental Cash Flow Elements [Abstract] | |
Schedule of Cash Flow Supplemental Disclosures | The consolidated statement of cash flows for the year ended December 31, 2015 excludes the removal of the investment in the unconsolidated subsidiary and the recognition of the retained assets and liabilities, which are detailed in the table below. (in thousands) Coal properties (incl asset retirement costs) $ 12,104 Advance royalties, net of current portion 4,706 Other non-current assets - acquired 229 Other non-current assets - written off (642 ) Accrued expenses and other (2,012 ) Asset retirement obligations (1,235 ) Net assets acquired 13,150 Investment in unconsolidated affiliates-Rhino Eastern - written off $ (13,150 ) |
Segment Information (Tables)
Segment Information (Tables) | 12 Months Ended |
Dec. 31, 2016 | |
Segment Reporting [Abstract] | |
Schedule of Reportable Segment Results of Operations | Reportable segment results of operations and financial position for the year ended December 31, 2016 are as follows (Note: “DD&A” refers to depreciation, depletion and amortization): Central Appalachia Northern Appalachia Rhino Western Illinois Basin Other Total Consolidated (in thousands) Total assets $ 89,918 $ 9,758 $ 33,205 $ 80,218 $ 64,342 $ 277,441 Total revenues 37,753 38,834 34,675 59,095 423 170,780 DD&A 6,553 3,142 5,211 8,326 554 23,786 Interest expense 2,051 314 383 982 2,966 6,696 Net Income (loss) from continuing operations $ (10,615 ) $ 8,791 $ (1,042 ) $ (5,524 ) $ (3,660 ) $ (12,050 ) Reportable segment results of operations and financial position for the year ended December 31, 2015 are as follows: Central Appalachia Northern Appalachia Rhino Western Illinois Basin Other Total Consolidated (in thousands) Total assets $ 227,880 $ 17,218 $ 37,198 $ 82,699 $ 39,671 $ 404,666 Total revenues 56,228 63,273 35,322 38,641 1,568 195,032 DD&A 11,032 7,562 6,314 5,928 736 31,572 Interest expense 2,029 522 315 597 1,527 4,990 Net Income (loss) from continuing operations $ (21,575 ) $ (20,487 ) $ (4,560 ) $ (13,807 ) $ (2,900 ) $ (63,329 ) |
Schedule of Revenue by Product Category | Additional information on the Partnership’s revenue by product category for the periods ended December 31, 2016 and 2015 is as follows: 2016 2015 (in thousands) Met coal revenue $ 21,542 $ 15,391 Steam coal revenue 139,299 155,683 Other revenue 9,939 23,958 Total revenue $ 170,780 $ 195,032 |
Organization and Basis of Pre45
Organization and Basis of Presentation (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 ($)shares | Sep. 13, 2013USD ($)$ / sharesshares | Jul. 18, 2011USD ($)$ / sharesshares | Oct. 05, 2010USD ($)$ / sharesshares | Oct. 31, 2016shares | Sep. 30, 2016USD ($) | Dec. 31, 2016USD ($) | Dec. 31, 2015USD ($) | Dec. 31, 2014USD ($) |
Reverse split description | 1-for-10 reverse split on its common units and subordinated units | ||||||||||||||
Reverse stock split conversion ratio | 10 | ||||||||||||||
Underwriting discounts and offering expenses | |||||||||||||||
Proceeds from partner's contribution | $ 2 | ||||||||||||||
Payment of credit facility | 132,509 | $ 107,650 | |||||||||||||
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 | ||||||||||||||
Debt conversion price per share | $ / shares | $ 1.50 | ||||||||||||||
Repayment of debt | $ 3,000 | $ 2,000 | |||||||||||||
Debt due date | Jul. 31, 2016 | Sep. 30, 2016 | |||||||||||||
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 | ||||||||||||||
Royal VWAP [Member] | Maximum [Member] | |||||||||||||||
Debt conversion price per share | $ / shares | $ 7.50 | ||||||||||||||
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 | ||||||||||||||
Debt maturity description | due on or before December 31, 2016 to extend the due date to December 31, 2018 | ||||||||||||||
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] | |||||||||||||||
Price per unit | $ / shares | $ 10 | ||||||||||||||
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] | |||||||||||||||
Price per unit | $ / shares | $ 10 | ||||||||||||||
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 | ||||||||||||||
Weighted average closing price | 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 Partnerships Central Appalachia business segment, minus (ii) the cost of operations (exclusive of depreciation, depletion and amortization) for the Partnerships 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 | ||||||||||||||
Fifth Amendment [Member] | |||||||||||||||
Credit facility Description | Partnership entered into a fifth amendment (the Fifth Amendment) of its amended and restated agreement that initially extended the term of the senior secured credit facility to July 31, 2017. Per the Fifth Amendment, the term of the credit facility automatically extended to December 31, 2017 | Partnership has met the requirements to extend the maturity date of the credit facility to December 31, 2017. Since the credit facility has an expiration date of December 2017, the Partnership determined that its credit facility debt liability of $10.0 million at December 31, 2016 should be classified as a current liability on its consolidated statements of financial position. | |||||||||||||
Threshold for revolving credit commitments | $ 55,000 | ||||||||||||||
Credit facility maturity date | Dec. 31, 2017 | ||||||||||||||
Initial Public Offering [Member] | |||||||||||||||
Common units issued | shares | 126,500 | 287,500 | 324,400 | 1,953 | |||||||||||
Price per unit | $ / shares | $ 123 | $ 245 | $ 205 | ||||||||||||
Proceeds from shares issued | $ 14,600 | $ 66,400 | $ 58,300 | ||||||||||||
Underwriting discounts and offering expenses | 1,000 | 4,100 | 8,200 | ||||||||||||
Proceeds from partner's contribution | 300 | 1,400 | 10,400 | ||||||||||||
Payment of credit facility | $ 14,900 | $ 67,800 | 69,400 | ||||||||||||
Payments to reimburse sponsor capital expenditures | $ 9,300 | ||||||||||||||
Initial Public Offering [Member] | Underwriter [Member] | |||||||||||||||
Common units issued | shares | 37,500 | ||||||||||||||
Initial Public Offering [Member] | Credit Agreement [Member] | |||||||||||||||
Membership interest pledged as collateral | 100.00% | ||||||||||||||
Public Offering [Member] | Underwriter [Member] | |||||||||||||||
Common units issued | shares | 16,500 | ||||||||||||||
Common Units [Member] | |||||||||||||||
Reverse stock split conversion ratio | 10 | ||||||||||||||
Common Units [Member] | Public Offering [Member] | |||||||||||||||
Common units issued | shares | 915,300 | ||||||||||||||
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 | ||||||||||||||
Subordinated Units [Member] | Public Offering [Member] | |||||||||||||||
Common units issued | shares | 1,239,700 | ||||||||||||||
Series A Preferred Units [Member] | Minimum [Member] | |||||||||||||||
Debt conversion price per share | $ / shares | $ 2 | ||||||||||||||
Series A Preferred Units [Member] | Maximum [Member] | |||||||||||||||
Debt conversion price per share | $ / shares | 10 | ||||||||||||||
Series A Preferred Units [Member] | Fourth Amended And Restated Agreement [Member] | |||||||||||||||
Price per unit | $ / shares | $ 10 | ||||||||||||||
Weighted average closing price | 75.00% | ||||||||||||||
Unpaid distribution | $ / shares | $ 10 |
Summary of Significant Accoun46
Summary of Significant Accounting Policies and General (Details Narrative) $ in Thousands | Dec. 31, 2014USD ($) | Oct. 31, 2016shares | Sep. 30, 2014USD ($) | Dec. 31, 2012USD ($) | Dec. 31, 2016USD ($)Number | Dec. 31, 2015USD ($) |
Property plant and equipment salvage value | $ 0 | |||||
Asset retirement obligations, description | Changes in the asset retirement obligations for the year ended December 31, 2016 were calculated with discount rates that ranged from 7.0% to 9.1%. Changes in the asset retirement obligations for the year ended December 31, 2015 were calculated with discount rates that ranged from 2.9% to 5.9%. The discount rates changed in each respective year due to changes in applicable market indicators that are used to arrive at an appropriate discount rate. Other recosting adjustments to the liability are made annually based on inflationary cost increases or decreases and changes in the expected operating periods of the mines. The related inflation rate utilized in the recosting adjustments was 2.3 % for 2016 and 2015. | |||||
Gallons of diesel purchased | Number | 1,000,000 | |||||
Partners' Contributed Capital | $ 8,959 | $ 9,821 | ||||
Operating loss | (6,822) | (58,719) | ||||
Available for sale of investment | 3,532 | |||||
Equity in net income (loss) of unconsolidated affiliate | (223) | 342 | ||||
Mammoth Energy Partners LP [Member] | ||||||
Equity method investment | 1,900 | 1,900 | ||||
Mammoth Energy Services, Inc. [Member] | ||||||
Number of limited partner interest exchange for shares of common stock | shares | 234,300 | |||||
Available for sale of investment | 1,600 | |||||
Muskie Proppant LLC [Member] | ||||||
Payments to acquire interest in joint venture | $ 2,000 | |||||
Partners' Contributed Capital | $ 200 | |||||
Operating loss | $ 100 | |||||
Sturgeon Acquisitions LLC [Member] | ||||||
Payments to acquire interest in joint venture | $ 5,000 | |||||
Equity in net income (loss) of unconsolidated affiliate | $ 200 | $ 300 |
Subsequent Events (Details Narr
Subsequent Events (Details Narrative) | Mar. 20, 2017shares |
Subsequent Event [Member] | |
Number of common stock shares received | 336,447 |
Discontinued Operations (Detail
Discontinued Operations (Details Narrative) - USD ($) $ in Thousands | Sep. 20, 2016 | Aug. 31, 2016 | Jun. 30, 2016 | Dec. 31, 2016 | Dec. 31, 2015 |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||
Asset impairment charges | $ 2,639 | $ 31,564 | |||
Loss on business disposal | (119,932) | ||||
Coal Properties [Member] | |||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||
Asset impairment charges | $ 118,700 | ||||
Elk Horn [Member] | |||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||
Cash consideration payable | 1,500 | ||||
Cash Consideration paid monthly installment | 150 | ||||
Disposal of assets and liabilities | $ 1,200 | ||||
Loss on business disposal | 119,900 | ||||
Deferred revenue | $ 1,300 | $ 3,800 | |||
Elk Horn [Member] | 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 Assets and Liabilities of Discontinued Operations (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Discontinued Operations and Disposal Groups [Abstract] | ||
Cash and cash equivalents | $ 19 | |
Accounts receivable, net of allowance for doubtful accounts | 1,972 | |
Prepaid expenses and other | 7 | |
Total current assets of the disposal group classified as held for sale in the statement of financial position | 1,998 | |
Property and equipment (net) | 108,709 | |
Advance royalties, net of current portion | 154 | |
Intangible assets (net) | 505 | |
Total non-current assets of the disposal group classified as held for sale in the statement of financial position | 109,368 | |
Accounts payable | 137 | |
Accrued expenses and other | 793 | |
Total current liabilities of the disposal group classified as held for sale in the statement of financial position | 930 | |
Asset retirement obligations, net of current portion | 670 | |
Deferred revenue | 2,259 | |
Other non-current liabilities | 670 | |
Total non-current liabilities of the disposal group classified as held for sale in the statement of financial position | $ 3,599 |
Discontinued Operations - Sch50
Discontinued Operations - Schedule of Major Components of Net (Loss) Income from Discontinued Operations (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Discontinued Operations and Disposal Groups [Abstract] | ||
Royalty income | $ 2,668 | $ 11,714 |
Total revenues | 2,668 | 11,714 |
Cost of operations (exclusive of depreciation, depletion and amortization shown separately below) | 799 | 2,187 |
Depreciation, depletion and amortization | 413 | 1,608 |
Selling, general and administrative (exclusive of depreciation, depletion and amortization shown separately above) | 174 | 573 |
(Gain) on sale/disposal of assets, net | 119,982 | (28) |
Interest expense and other | 13 | 11 |
Total costs and expenses | 121,381 | 4,351 |
(Loss/Income) from discontinued operations before income taxes for the Elk Horn disposal | (118,713) | 7,363 |
Income from discontinued operations relating to Blackhawk disposal | 722 | |
(Loss/Income) from discontinued operations before income taxes | (118,713) | 8,085 |
Income taxes | ||
Net(Loss)/Income from discontinued operations | $ (118,713) | $ 8,085 |
Prepaid Expenses and Other Cu51
Prepaid Expenses and Other Current Assets (Details Narrative) - Elk Horn [Member] $ in Thousands | 12 Months Ended |
Dec. 31, 2016USD ($) | |
Note receivable | $ 900 |
Cash consideration payable | 1,500 |
Cash Consideration paid monthly installment | $ 150 |
Prepaid Expenses and Other Cu52
Prepaid Expenses and Other Current Assets - Schedule of Prepaid Expenses and Other Current Assets (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Prepaid Expense and Other Assets, Current [Abstract] | ||
Other prepaid expenses | $ 707 | $ 675 |
Debt issuance costs-net | 1,239 | 2,155 |
Prepaid insurance | 1,432 | 1,492 |
Prepaid leases | 77 | 80 |
Supply inventory | 614 | 901 |
Deposits | 164 | 164 |
Available-for-sale investment | 3,532 | |
Note receivable- current portion | 900 | |
Total Prepaid expenses and other | $ 8,665 | $ 5,467 |
Property, Plant and Equipment53
Property, Plant and Equipment (Details Narrative) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Proceeds from the sale of property | $ 7,200 | |
Asset impairment charges | 2,639 | $ 31,564 |
Noncash impairment charges | 2,600 | |
Deane Mining Complex [Member] | ||
Asset impairment charges | 2,600 | |
Noncash impairment charges | 2,000 | |
Asset impairment other | $ 600 |
Property, Plant and Equipment -
Property, Plant and Equipment - Property, Plant and Equipment by Major Classification (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Property, Plant and Equipment [Line Items] | ||
Total | $ 449,181 | $ 484,690 |
Less accumulated depreciation, depletion and amortization | (266,874) | (259,892) |
Net property, plant and equipment | 182,307 | 224,798 |
Mining and Other Equipment and Related Facilities [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total | $ 305,626 | 305,845 |
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 | $ 57,392 | 64,262 |
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 Oil And Natural Gas Properties [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total | $ 67,989 | 94,390 |
Coal Oil And Natural Gas Properties [Member] | Minimum [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Useful Lives | 1 year | |
Coal Oil And Natural Gas Properties [Member] | Maximum [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Useful Lives | 15 years | |
Land and Land Improvements [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total | $ 16,377 | 17,513 |
Construction Work In Process [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total | $ 1,797 | $ 2,680 |
Property, Plant and Equipment55
Property, Plant and Equipment - Schedule of Depreciation, Depletion, and Amortization (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Property, Plant and Equipment [Line Items] | ||
Total depreciation, depletion and amortization | $ 23,786 | $ 31,572 |
Asset Retirement Costs [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total depreciation, depletion and amortization | (136) | (450) |
Intangible Assets [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total depreciation, depletion and amortization | 43 | |
Mining and Other Equipment and Related Facilities [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total depreciation, depletion and amortization | 20,479 | 28,698 |
Coal Properties [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total depreciation, depletion and amortization | 1,542 | 1,346 |
Mine Development Costs [Member] | ||
Property, Plant and Equipment [Line Items] | ||
Total depreciation, depletion and amortization | $ 1,901 | $ 1,935 |
Intangible and Other Non-curr56
Intangible and Other Non-current Assets (Details Narrative) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Prepaid Expenses And Other Current Assets Disclosure [Line Items] | ||
Non-current receivable | $ 27,157 | $ 23,908 |
Workers' compensation liability, noncurrent | 27,200 | 23,900 |
Note receivable | $ 2,000 | |
Impairment of note receivables | $ 2,000 | |
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 | |
Series A Preferred Units [Member] | Weston [Member] | ||
Prepaid Expenses And Other Current Assets Disclosure [Line Items] | ||
Note receivable | $ 2,000 |
Intangible and Other Non-curr57
Intangible and Other Non-current Assets - Schedule of Other Non-current Assets (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Intangible And Other Non-current Assets | ||
Deposits and other | $ 218 | $ 218 |
Due (to) Rhino GP | (573) | (80) |
Non-current receivable | 27,157 | 23,908 |
Note receivable | 2,000 | |
Deferred expenses | 216 | 260 |
Total | $ 27,018 | $ 26,306 |
Accrued Expenses and Other Cu58
Accrued Expenses and Other Current Liabilities (Details Narrative) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Payables and Accruals [Abstract] | ||
Accrued insured litigation claims | $ 277 | $ 266 |
Accrued Expenses and Other Cu59
Accrued Expenses and Other Current Liabilities - Schedule of Accrued Expenses and Other Current Liabilities (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Payables and Accruals [Abstract] | ||
Payroll, bonus and vacation expense | $ 1,496 | $ 1,439 |
Non income taxes | 2,252 | 2,993 |
Royalty expenses | 1,617 | 1,566 |
Accrued interest | 601 | 571 |
Health claims | 630 | 817 |
Workers’ compensation & pneumoconiosis | 2,450 | 1,150 |
Accrued insured litigation claims | 277 | 266 |
Other | 740 | 2,247 |
Total | $ 10,063 | $ 11,049 |
Debt (Details Narrative)
Debt (Details Narrative) - USD ($) $ in Thousands | Jul. 07, 2016 | May 13, 2016 | Mar. 17, 2016 | Jul. 29, 2011 | Jul. 31, 2016 | Sep. 30, 2016 | Dec. 31, 2016 | Dec. 31, 2015 | May 31, 2016 | Mar. 31, 2016 | Apr. 30, 2015 |
Line of Credit Facility [Line Items] | |||||||||||
Credit facility, maximum available | $ 10,000 | $ 75,000 | $ 80,000 | ||||||||
Incremental interest rate above variable rate | 7.25% | ||||||||||
Gain from extinguishment of debt | $ 1,663 | ||||||||||
Third Party [Member] | |||||||||||
Line of Credit Facility [Line Items] | |||||||||||
Other notes payable | $ 2,800 | ||||||||||
Settlement of debt on cash consideration | 1,100 | ||||||||||
Repayment of debt | $ 1,100 | ||||||||||
Gain from extinguishment of debt | $ 1,700 | ||||||||||
Prime Rate [Member] | |||||||||||
Line of Credit Facility [Line Items] | |||||||||||
Incremental interest rate above variable rate | 3.50% | ||||||||||
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 | ||||||||||
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 | ||||||||||
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 | ||||||||
Sixth Amendment [Member] | Elk Horn [Member] | March 31, 2017 [Member] | |||||||||||
Line of Credit Facility [Line Items] | |||||||||||
Line of credit facility, maxmium commitment amount for additional | 375 | ||||||||||
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 | ||||||||||
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 | $ 20,000 | ||||||||||
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] | 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] | 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] | Minimum [Member] | |||||||||||
Line of Credit Facility [Line Items] | |||||||||||
Line of credit facility, maximum leverage ratio | 4 | ||||||||||
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] | 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] | Minimum [Member] | |||||||||||
Line of Credit Facility [Line Items] | |||||||||||
Line of credit facility, maximum leverage ratio | 3.5 | ||||||||||
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 | ||||||||||
Letter Of Credit [Member] | |||||||||||
Line of Credit Facility [Line Items] | |||||||||||
Credit facility, maximum available | $ 12,900 | ||||||||||
Incremental interest rate above variable rate | 5.00% | ||||||||||
Outstanding letter of credit | $ 26,100 | ||||||||||
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 | Dec. 31, 2016 | Dec. 31, 2015 |
Debt Disclosure [Abstract] | ||
Senior secured credit facility with PNC Bank, N.A. | $ 10,040 | $ 41,200 |
Other notes payable | 2,874 | |
Total | 10,040 | 44,074 |
Less current portion | (10,040) | (41,479) |
Long-term debt | $ 2,595 |
Debt - Schedule of Principal Pa
Debt - Schedule of Principal Payments on Long-term Debt (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Debt Disclosure [Abstract] | ||
2,017 | $ 10,040 | |
2,018 | ||
2,019 | ||
2,020 | ||
Thereafter | ||
Total principal payments | $ 10,040 | $ 44,074 |
Asset Retirement Obligations -
Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Details) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | ||
Asset Retirement Obligation Disclosure [Abstract] | |||
Balance at beginning of period (including current portion) | $ 23,077 | $ 29,883 | |
Accretion expense | 1,512 | 2,082 | |
Adjustment resulting from addition of property | 1,235 | ||
Adjustment resulting from disposal of property | [1] | (7,531) | |
Adjustments to the liability from annual recosting and other | (1,085) | (2,078) | |
Reclassification to held for sale | |||
Liabilities settled | (200) | (514) | |
Balance at end of period | 23,278 | 23,077 | |
Less current portion of asset retirement obligation | (917) | (767) | |
Long-term portion of asset retirement obligation | $ 22,361 | $ 22,310 | |
[1] | The ($7.5) million adjustment for the year ended December 31, 2015 relates to the sale of the Partnership's Deane mining complex discussed in Note 6 and the sale of Elk Horn discussed in Note 4. |
Asset Retirement Obligations 64
Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Details) (Parenthetical) - USD ($) $ in Thousands | 12 Months Ended | ||
Dec. 31, 2016 | Dec. 31, 2015 | ||
Asset Retirement Obligation Disclosure [Abstract] | |||
Adjustment from sale of property | [1] | $ 7,531 | |
[1] | The ($7.5) million adjustment for the year ended December 31, 2015 relates to the sale of the Partnership's Deane mining complex discussed in Note 6 and the sale of Elk Horn discussed in Note 4. |
Workers' Compensation and Bla65
Workers' Compensation and Black Lung (Details Narrative) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Black Lung [Member] | ||
Discount rate | 4.00% | 4.00% |
Workers' compensation insurance | $ 27,200 | $ 23,900 |
Workers' Compensation [Member] | ||
Discount rate | 2.00% | 2.00% |
Workers' Compensation and Bla66
Workers' Compensation and Black Lung - Summary of Black Lung and Workers' Compensation Expenses (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Service cost | $ 254 | |
Interest cost | 191 | |
Actuarial loss/(gain) | (328) | |
Total | (4,795) | (2,963) |
Black Lung Benefits [Member] | ||
Service cost | (506) | (991) |
Interest cost | 363 | 397 |
Actuarial loss/(gain) | ||
Total | (143) | (594) |
Workers' Compensation [Member] | ||
Total | 4,013 | 4,334 |
Workers' Compensation And Black Lung Benefits [Member] | ||
Total | $ 3,870 | $ 3,740 |
Workers' Compensation and Bla67
Workers' Compensation and Black Lung - Schedule of Changes in Benefit Liability (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Benefit obligations at beginning of year | $ 45 | $ 6,648 |
Service cost | 254 | |
Interest cost | 191 | |
Actuarial loss/(gain) | (328) | |
Benefits and expenses paid | (45) | (217) |
Benefit obligations at end of year | 45 | |
Black Lung Benefits [Member] | ||
Benefit obligations at beginning of year | 9,225 | 10,033 |
Service cost | (506) | (991) |
Interest cost | 363 | 397 |
Actuarial loss/(gain) | ||
Benefits and expenses paid | (300) | (214) |
Benefit obligations at end of year | $ 8,782 | $ 9,225 |
Workers' Compensation and Bla68
Workers' Compensation and Black Lung - Classification of Net Amounts Recognized for Workers' Compensation and Black Lung Benefits (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Less current portion | $ 45 | |
Black Lung Claims [Member] | ||
Total obligations | 8,782 | 9,225 |
Insured Black Lung And Workers' Compensation Claims [Member] | ||
Total obligations | 27,157 | 23,907 |
Workers' Compensation Claims [Member] | ||
Total obligations | 5,584 | 5,540 |
Workers' Compensation And Black Lung Benefits [Member] | ||
Total obligations | 41,523 | 38,672 |
Less current portion | (2,450) | (1,150) |
Non-current obligations | $ 39,073 | $ 37,522 |
Employee Benefits (Details Narr
Employee Benefits (Details Narrative) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | ||
Mar. 31, 2016 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 10, 2015 | |
Compensation and Retirement Disclosure [Abstract] | ||||
Prior service cost benefit | $ 6,500 | |||
Benefit recognized | $ 3,900 | $ 3,876 | $ (3,876) | |
Accumulated other comprehensive income change in actuarial gain on post retirement plan | $ (4,795) | $ 3,422 |
Employee Benefits - Summary of
Employee Benefits - Summary of Changes in Benefit Obligations (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Compensation and Retirement Disclosure [Abstract] | ||
Benefit obligations at beginning of year | $ 45 | $ 6,648 |
Service cost | 254 | |
Interest cost | 191 | |
Benefits paid | (45) | (217) |
Plan amendment | (6,503) | |
Actuarial loss/(gain) | (328) | |
Benefit obligations at end of year | 45 | |
Fair value of plan assets at end of period | ||
Funded status | $ (45) |
Employee Benefits - Classificat
Employee Benefits - Classification of Net Amounts Recognized for Postretirement Benefits (Details) - USD ($) $ in Thousands | Dec. 31, 2016 | Dec. 31, 2015 |
Compensation and Retirement Disclosure [Abstract] | ||
Current liability-postretirement benefits | $ (45) | |
Non-current liability-postretirement benefits | ||
Net amount recognized | $ (45) |
Employee Benefits - Schedule of
Employee Benefits - Schedule of Recognized in Accumulated Other Comprehensive Income (Details) - USD ($) $ in Thousands | 3 Months Ended | 12 Months Ended | |
Mar. 31, 2016 | Dec. 31, 2016 | Dec. 31, 2015 | |
Compensation and Retirement Disclosure [Abstract] | |||
Balance at beginning of year | $ 4,795 | $ 4,795 | $ 1,373 |
Actuarial (loss)/gain | 328 | ||
Prior service (cost)/gain to be amortized | $ (3,900) | (3,876) | 3,876 |
Amortization of net actuarial gain | (919) | (782) | |
Net actuarial gain | $ 4,795 |
Employee Benefits - Schedule 73
Employee Benefits - Schedule of Weighted Average Assumptions Used to Determine Benefit Obligations (Details) - USD ($) | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Compensation and Retirement Disclosure [Abstract] | ||
Discount rate | ||
Expected return on plan assets |
Employee Benefits - Schedule 74
Employee Benefits - Schedule of Weighted Average Assumptions Used to Determine Net Periodic Benefit Cost (Details) | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Compensation and Retirement Disclosure [Abstract] | ||
Discount rate | 3.15% | |
Expected return on plan assets | ||
Rate of compensation increase |
Employee Benefits - Components
Employee Benefits - Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Compensation and Retirement Disclosure [Abstract] | ||
Service cost | $ 254 | |
Interest cost | 191 | |
Amortization of prior service cost | (3,876) | (2,626) |
Amortization of (gain) | (919) | (782) |
Benefit cost | $ (4,795) | $ (2,963) |
Employee Benefits - Schedule 76
Employee Benefits - Schedule of Expense Under Defined Contribution Savings Plans (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Compensation and Retirement Disclosure [Abstract] | ||
401(k) plan expense | $ 1,463 | $ 2,007 |
Equity-Based Compensation (Deta
Equity-Based Compensation (Details Narrative) - USD ($) $ in Thousands | Mar. 17, 2016 | Dec. 31, 2016 | Dec. 31, 2015 |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Accelerated vesting expense | $ 10 | ||
Total fair value of the awards that vested | $ 500 | ||
Long-Term Incentive Plan [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Number of units reserved for issuance | 247,940 | ||
LTIP Awards [Member] | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Equity-based compensation expense | $ 400 | $ 100 | |
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 |
Equity-Based Compensation - Sum
Equity-Based Compensation - Summary of Non-vested LTIP Awards (Details) - $ / shares | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | ||
Common Units, Non-vested awards, Beginning Balance | 204,000 | 51,000 |
Common Units, Granted | 183,000 | 247,000 |
Common Units, Vested | (381,000) | (86,000) |
Common Units, Forfeited | (6,000) | (8,000) |
Common Units, Non-vested awards, Ending Balance | 204,000 | |
Weighted Average Grant Date Fair Value (per unit), Non-vested awards, Beginning Balance | $ 2 | $ 13.50 |
Weighted Average Grant Date Fair Value (per unit), Granted | 2.19 | 1.06 |
Weighted Average Grant Date Fair Value (per unit), Vested | 2.05 | 5.68 |
Weighted Average Grant Date Fair Value (per unit), Forfeited | 6.25 | 6.43 |
Weighted Average Grant Date Fair Value (per unit), Non-vested awards, Ending Balance | $ 2 |
Commitments and Contingencies79
Commitments and Contingencies (Details Narrative) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2014 | |
Sturgeon Acquisitions [Member] | ||
Commitments And Contingencies [Line Items] | ||
Payments to acquire interest in joint venture | $ 5,000 | |
Surety Bonds With Third Parties [Member] | ||
Commitments And Contingencies [Line Items] | ||
Line of credit, outstanding | $ 48,900 | |
Letter Of Credit [Member] | ||
Commitments And Contingencies [Line Items] | ||
Line of credit, outstanding | $ 26,100 | |
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 | |
Commitment to purchase at fixed prices | $ 2,000 |
Commitments and Contingencies -
Commitments and Contingencies - Schedule of Delivery Commitments (Details) | 12 Months Ended |
Dec. 31, 2016CustomersT | |
Commitments and Contingencies Disclosure [Abstract] | |
Tons, 2017 | T | 3,669,000 |
Tons, 2018 | T | 701,000 |
Number of customers, 2017 | Customers | 14 |
Number of customers, 2018 | Customers | 5 |
Commitments and Contingencies81
Commitments and Contingencies - Schedule of Purchased Coal Expenses (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Commitments And Contingencies - Schedule Of Purchased Coal Expenses Details | ||
Purchased coal expense | $ (26) | |
OTC expense |
Commitments and Contingencies82
Commitments and Contingencies - Schedule of Lease And Royalty Expense (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Commitments and Contingencies Disclosure [Abstract] | ||
Lease expense | $ 4,932 | $ 6,204 |
Royalty expense | $ 9,978 | $ 10,678 |
Commitments and Contingencies83
Commitments and Contingencies - Future Minimum Lease and Royalty Payments (Details) $ in Thousands | 12 Months Ended |
Dec. 31, 2016USD ($) | |
Commitments And Contingencies - Future Minimum Lease And Royalty Payments Details | |
Royalties, 2017 | $ 1,640 |
Royalties, 2018 | 1,615 |
Royalties, 2019 | 1,665 |
Royalties, 2020 | 1,648 |
Royalties, 2021 | 1,767 |
Royalties, Thereafter | 8,836 |
Total minimum royalty payments | 17,171 |
Leases, 2017 | 2,533 |
Leases, 2018 | 148 |
Leases, 2019 | |
Leases, 2020 | |
Leases, 2021 | |
Leases, Thereafter | |
Total minimum lease payments | $ 2,681 |
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 | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Earnings Per Unit [Line Items] | ||
Interest in net (loss)/income: Net (loss) from continuing operations | $ (12,050) | $ (63,329) |
Interest in net (loss)/income: Net income from discontinued operations | (118,713) | 8,085 |
Interest in net (loss)/income: Total interest in net income (loss) | (130,763) | (55,244) |
General Partner [Member] | ||
Earnings Per Unit [Line Items] | ||
Interest in net (loss)/income: Net (loss) from continuing operations | (107) | (1,267) |
Interest in net (loss)/income: Net income from discontinued operations | (755) | 162 |
Interest in net (loss)/income: Total interest in net income (loss) | (862) | (1,105) |
Impact of subordinated distribution suspension: Net income/(loss) from continuing operations | 5 | |
Impact of subordinated distribution suspension: Net income/(loss) from discontinued continuing operations | ||
Impact of subordinated distribution suspension: Interest in net income/(loss) | 5 | |
Interest in net (loss)/income for EPU purposes: Net income/(loss) from continuing operations | (107) | (1,262) |
Interest in net (loss)/income for EPU purposes: Net income from discontinued operations | (755) | 162 |
Interest in net (loss)/income for EPU purposes: Interest in net (loss)/income | (862) | (1,100) |
Common Unitholders [Member] | ||
Earnings Per Unit [Line Items] | ||
Interest in net (loss)/income: Net (loss) from continuing operations | (10,040) | (35,634) |
Interest in net (loss)/income: Net income from discontinued operations | (99,166) | 4,549 |
Interest in net (loss)/income: Total interest in net income (loss) | (109,206) | (31,085) |
Impact of subordinated distribution suspension: Net income/(loss) from continuing operations | 139 | |
Impact of subordinated distribution suspension: Net income/(loss) from discontinued continuing operations | ||
Impact of subordinated distribution suspension: Interest in net income/(loss) | 139 | |
Interest in net (loss)/income for EPU purposes: Net income/(loss) from continuing operations | (10,040) | (35,495) |
Interest in net (loss)/income for EPU purposes: Net income from discontinued operations | (99,166) | 4,549 |
Interest in net (loss)/income for EPU purposes: Interest in net (loss)/income | $ (109,206) | $ (30,946) |
Weighted average units used to compute basic EPU | 6,520,000 | 1,671,000 |
Effect of dilutive securities - LTIP awards | ||
Weighted average units used to compute diluted EPU | 6,520,000 | 1,671,000 |
Net (loss) per unit from continuing operations | $ (1.54) | $ (21.24) |
Net income per unit from discontinued operations | (15.21) | 2.72 |
Net (loss)/income per common unit, basic | (16.75) | (18.52) |
Net (loss)/income per unit from continuing operations | (1.54) | (21.24) |
Net income per unit from discontinued operations | (15.21) | 2.72 |
Net income per common unit, diluted | $ (16.75) | $ (18.52) |
Subordinated Unitholders [Member] | ||
Earnings Per Unit [Line Items] | ||
Interest in net (loss)/income: Net (loss) from continuing operations | $ (1,903) | $ (26,428) |
Interest in net (loss)/income: Net income from discontinued operations | (18,792) | 3,374 |
Interest in net (loss)/income: Total interest in net income (loss) | (20,695) | (23,054) |
Impact of subordinated distribution suspension: Net income/(loss) from continuing operations | (144) | |
Impact of subordinated distribution suspension: Net income/(loss) from discontinued continuing operations | ||
Impact of subordinated distribution suspension: Interest in net income/(loss) | (144) | |
Interest in net (loss)/income for EPU purposes: Net income/(loss) from continuing operations | (1,903) | (26,572) |
Interest in net (loss)/income for EPU purposes: Net income from discontinued operations | (18,792) | 3,374 |
Interest in net (loss)/income for EPU purposes: Interest in net (loss)/income | $ (20,695) | $ (23,198) |
Weighted average units used to compute basic EPU | 1,236,000 | 1,240,000 |
Effect of dilutive securities - LTIP awards | ||
Weighted average units used to compute diluted EPU | 1,236,000 | 1,240,000 |
Net (loss) per unit from continuing operations | $ (1.54) | $ (21.44) |
Net income per unit from discontinued operations | (15.21) | 2.72 |
Net (loss)/income per common unit, basic | (16.75) | (18.72) |
Net (loss)/income per unit from continuing operations | (1.54) | (21.44) |
Net income per unit from discontinued operations | (15.21) | 2.72 |
Net income per common unit, diluted | $ (16.75) | $ (18.72) |
Major Customers - Summary of Ma
Major Customers - Summary of Major Customers (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Revenue, Major Customer [Line Items] | ||
Receivable balance | $ 13,893 | $ 12,597 |
Revenue | 170,780 | 195,032 |
PPL Corporation [Member] | ||
Revenue, Major Customer [Line Items] | ||
Receivable balance | 1,496 | 1,881 |
Revenue | 42,175 | 33,662 |
PacifiCorp Energy [Member] | ||
Revenue, Major Customer [Line Items] | ||
Receivable balance | 1,509 | 1,969 |
Revenue | 19,581 | 21,519 |
Big Rivers Electric Corporation [Member] | ||
Revenue, Major Customer [Line Items] | ||
Receivable balance | ||
Revenue | $ 16,241 | |
NRG Energy, Inc [Member] | ||
Revenue, Major Customer [Line Items] | ||
Revenue | $ 4,638 |
Major Customers - Summary of 86
Major Customers - Summary of Major Customers (Details) (Parenthetical) | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
PPL Corporation [Member] | ||
Percentage of concentration risk | 10.00% | 10.00% |
PacifiCorp Energy [Member] | ||
Percentage of concentration risk | 10.00% | 10.00% |
Big Rivers Electric Corporation [Member] | ||
Percentage of concentration risk | 10.00% | 10.00% |
Fair Value Measurements (Detail
Fair Value Measurements (Details Narrative) - USD ($) $ in Thousands | Sep. 13, 2013 | Jul. 18, 2011 | Oct. 05, 2010 | Oct. 31, 2016 |
Initial Public Offering [Member] | ||||
Number of shares sold | 126,500 | 287,500 | 324,400 | 1,953 |
Proceeds from sale of stock | $ 27 | |||
Mammoth Energy Services, Inc. [Member] | ||||
Exchange shares of common stock | 234,300 |
Related Party and Affiliate T88
Related Party and Affiliate Transactions (Details Narrative) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Related Party Transactions [Abstract] | ||
Expense related to legal services | $ 100 | $ 100 |
Related Party and Affiliate T89
Related Party and Affiliate Transactions - Schedule of Related Party and Affiliate Transactions (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Related Party One [Member] | ||
Related party description | Royal Energy Resources, Inc. | Royal Energy Resources, Inc. |
Related Party and Affiliate Transactions description | Partner's contribution | Partner's contribution |
Related party amount | $ 7,000 | |
Related Party Two [Member] | ||
Related party description | Royal Energy Resources, Inc. | Royal Energy Resources, Inc. |
Related Party and Affiliate Transactions description | Purchase of preferred units | Purchase of preferred units |
Related party amount | $ 2,000 | |
Related Party Three [Member] | ||
Related party description | Weston Energy LLC | Weston Energy LLC |
Related Party and Affiliate Transactions description | Purchase of preferred units | Purchase of preferred units |
Related party amount | $ 11,000 | |
Related Party Four [Member] | ||
Related party description | Wexford Capital LP | Wexford Capital LP |
Related Party and Affiliate Transactions description | Expenses for legal, consulting, and advisory services | Expenses for legal, consulting, and advisory services |
Related party amount | $ 11 | $ 143 |
Related Party Five [Member] | ||
Related party description | Wexford Capital LP | Wexford Capital LP |
Related Party and Affiliate Transactions description | Distributions paid | Distributions paid |
Related party amount | $ 553 | |
Related Party Six [Member] | ||
Related party description | Wexford Capital LP | Wexford Capital LP |
Related Party and Affiliate Transactions description | Partner's contribution | Partner's contribution |
Related party amount | $ 2 | |
Related Party One Seven [Member] | ||
Related party description | Timber Wolf Terminals LLC | Timber Wolf Terminals LLC |
Related Party and Affiliate Transactions description | Investment in unconsolidated affiliate | Investment in unconsolidated affiliate |
Related party amount | $ 130 | |
Related Party Eight [Member] | ||
Related party description | Mammoth Energy Partners LP | Mammoth Energy Partners LP |
Related Party and Affiliate Transactions description | Investment in unconsolidated affiliate | Investment in unconsolidated affiliate |
Related party amount | $ 1,933 | |
Related Party Nine [Member] | ||
Related party description | Sturgeon Acquisitions LLC | Sturgeon Acquisitions LLC |
Related Party and Affiliate Transactions description | Investment in unconsolidated affiliate | Investment in unconsolidated affiliate |
Related party amount | $ 5,515 | |
Related Party Ten [Member] | ||
Related party description | Sturgeon Acquisitions LLC | Sturgeon Acquisitions LLC |
Related Party and Affiliate Transactions description | Distributions from unconsolidated affiliate | Distributions from unconsolidated affiliate |
Related party amount | $ 300 | $ 232 |
Related Party Elven [Member] | ||
Related party description | Sturgeon Acquisitions LLC | Sturgeon Acquisitions LLC |
Related Party and Affiliate Transactions description | Return of capital from unconsolidated affiliate | Return of capital from unconsolidated affiliate |
Related party amount | $ 35 | |
Related Party Twelve [Member] | ||
Related party description | Sturgeon Acquisitions LLC | Sturgeon Acquisitions LLC |
Related Party and Affiliate Transactions description | Equity in net income of unconsolidated affiliate | Equity in net income of unconsolidated affiliate |
Related party amount | $ (223) | $ 342 |
Supplemental Disclosures of C90
Supplemental Disclosures of Cash Flow Information (Details Narrative) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Other Significant Noncash Transactions [Line Items] | ||
Interest paid | $ 3,800 | $ 3,400 |
Option Agreement [Member] | Call Option [Member] | ||
Other Significant Noncash Transactions [Line Items] | ||
Number of common unit shares issued during the period | 5,000 | |
Number of common unit issued during the period | $ 21,800 | |
Accounts Payable [Member] | ||
Other Significant Noncash Transactions [Line Items] | ||
Property additions | 1,100 | 700 |
LTIP Units [Member] | ||
Other Significant Noncash Transactions [Line Items] | ||
Property additions | $ 600 | $ 100 |
Supplemental Disclosures of C91
Supplemental Disclosures of Cash Flow Information - Schedule of Cash Flow Supplemental Disclosures (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2015 | Dec. 31, 2016 | |
Other Significant Noncash Transactions [Line Items] | ||
Coal properties (incl asset retirement costs) | $ 484,690 | $ 449,181 |
Advance royalties, net of current portion | 753 | 898 |
Other non-current assets - acquired | 26,306 | $ 27,018 |
Rhino Eastern [Member] | ||
Other Significant Noncash Transactions [Line Items] | ||
Coal properties (incl asset retirement costs) | 12,104 | |
Advance royalties, net of current portion | 4,706 | |
Other non-current assets - acquired | 229 | |
Other non-current assets - written off | (642) | |
Accrued expenses and other | (2,012) | |
Asset retirement obligations | (1,235) | |
Net assets acquired | 13,150 | |
Investment in unconsolidated affiliates-Rhino Eastern - written off | $ (13,150) |
Segment Information (Details Na
Segment Information (Details Narrative) | 12 Months Ended |
Dec. 31, 2016Segments | |
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 | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Segment Reporting Information [Line Items] | ||
Total assets | $ 277,441 | $ 404,666 |
Total revenues | 170,780 | 195,032 |
DD&A | 23,786 | 31,572 |
Interest expense | 6,696 | 4,990 |
Net Income (loss) from continuing operations | (12,050) | (63,329) |
Central Appalachia [Member] | ||
Segment Reporting Information [Line Items] | ||
Total assets | 89,918 | 227,880 |
Total revenues | 37,753 | 56,228 |
DD&A | 6,553 | 11,032 |
Interest expense | 2,051 | 2,029 |
Net Income (loss) from continuing operations | (10,615) | (21,575) |
Northern Appalachia [Member] | ||
Segment Reporting Information [Line Items] | ||
Total assets | 9,758 | 17,218 |
Total revenues | 38,834 | 63,273 |
DD&A | 3,142 | 7,562 |
Interest expense | 314 | 522 |
Net Income (loss) from continuing operations | 8,791 | (20,487) |
Rhino Western [Member] | ||
Segment Reporting Information [Line Items] | ||
Total assets | 33,205 | 37,198 |
Total revenues | 34,675 | 35,322 |
DD&A | 5,211 | 6,314 |
Interest expense | 383 | 315 |
Net Income (loss) from continuing operations | (1,042) | (4,560) |
Illinois Basin [Member] | ||
Segment Reporting Information [Line Items] | ||
Total assets | 80,218 | 82,699 |
Total revenues | 59,095 | 38,641 |
DD&A | 8,326 | 5,928 |
Interest expense | 982 | 597 |
Net Income (loss) from continuing operations | (5,524) | (13,807) |
Segment Other [Member] | ||
Segment Reporting Information [Line Items] | ||
Total assets | 64,342 | 39,671 |
Total revenues | 423 | 1,568 |
DD&A | 554 | 736 |
Interest expense | 2,966 | 1,527 |
Net Income (loss) from continuing operations | $ (3,660) | $ (2,900) |
Segment Information - Schedul94
Segment Information - Schedule of Revenue by Product Category (Details) - USD ($) $ in Thousands | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2015 | |
Total revenue | $ 170,780 | $ 195,032 |
Met Coal [Member] | ||
Total revenue | 21,542 | 15,391 |
Steam Coal [Member] | ||
Total revenue | 139,299 | 155,683 |
Other [Member] | ||
Total revenue | $ 9,939 | $ 23,958 |