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The fair value of the Partnership's contract receivable is determined based on the present value of future cash flow projections related to the underlying asset at a discount rate of 15% at June 30, 2023 and December 31, 2022. Other long-term assets, net includes long-term lease amendment fee receivables from contracts with customers. Revenues from Alpha Metallurgical Resources, Inc. and Foresight are included within the Partnership's Mineral Rights segment. The fair value of the Opco Senior Notes at June 30, 2023 and December 31, 2022 were estimated by management utilizing the present value replacement method incorporating the interest rate of the Opco Credit facility at June 30, 2023 and December 31, 2022, respectively. Relates to accrued distribution paid upon the redemption of 47,499 preferred units in February 2023. Amounts reclassified into income out of accumulated other comprehensive loss were $2.3 million and $(3.0) million for the three months ended June 30, 2023 and 2022, respectively, and $(18.3) million and $(4.7) million for the six months ended June 30, 2023 and 2022, respectively. Relates to accrued distribution paid upon the redemption of 45,000 preferred units in June 2023. Transportation and processing services revenues from contracts with customers as defined under ASC 606 was $2.7 million and $4.9 million for the three months ended June 30, 2023 and 2022, respectively and $5.6 million and $8.0 million for the six months ended June 30, 2023 and 2022, respectively. The remaining transportation and processing services revenues of $0.6 million and $0.7 million for the three months ended June 30, 2023 and 2022, respectively, and $1.3 million and $1.4 million for the six months ended June 30, 2023 and 2022, respectively, related to other NRP-owned infrastructure leased to and operated by third-party operators accounted for under other guidance. See Note 15. Financing Transaction for more information. Totals include the amount paid to NRP's general partner in accordance with the general partner's 2% general partner interest. Net income includes $5.0 million of income attributable to preferred unitholders that accumulated during the period, of which $4.9 million is allocated to the common unitholders and $0.1 million is allocated to the general partner. Relates to accrued distribution paid upon the redemption of 19,321 preferred units paid-in-kind in February 2022. Net income includes $7.5 million of income attributable to preferred unitholders that accumulated during the period, of which $7.4 million is allocated to the common unitholders and $0.2 million is allocated to the general partner. 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Table of Contents

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

FORM 10-Q

 

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the quarterly period ended June 30, 2023 or

 

TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

     
  

Commission file number:

 001-31465

 

 

nrp20220630_10qimg001.jpg

 

NATURAL RESOURCE PARTNERS LP

 

(Exact name of registrant as specified in its charter)

 

 

Delaware

35-2164875

(State or other jurisdiction of

incorporation or organization)

(I.R.S. Employer

Identification No.)

1415 Louisiana Street, Suite 3325

Houston, Texas 77002

(Address of principal executive offices)

(Zip Code)

(713) 751-7507

(Registrants telephone number, including area code) 

   

 

Securities registered pursuant to Section 12(b) of the Act:

 

Title of each class

 

Trading Symbol(s)

 

Name of each exchange on which registered

Common Units representing limited partner interests

 

NRP

 

New York Stock Exchange

 

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ☒    No  ☐

 

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).    Yes  ☒   No ☐

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See definition of "accelerated filer", "large accelerated filer", "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

 

Large Accelerated Filer

Accelerated Filer

 

Non-accelerated Filer

Smaller Reporting Company

 
  

Emerging Growth Company

 

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ☐

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    Yes      No  ☒

 

APPLICABLE ONLY TO ISSUERS INVOLVED IN BANKRUPTCY PROCEEDINGS DURING THE PRECEDING FIVE YEARS:

 

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Section 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court.  Yes ☐    No  ☐

 

APPLICABLE ONLY TO CORPORATE ISSUERS

 

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

 

 

 

 

NATURAL RESOURCE PARTNERS, L.P.

TABLE OF CONTENTS

 

   

Page

Part I. Financial Information

Item 1.

Consolidated Financial Statements

 
 

Consolidated Balance Sheets

1

 

Consolidated Statements of Comprehensive Income

2

 

Consolidated Statements of Partners Capital

3

 

Consolidated Statements of Cash Flows

4

 

Notes to Consolidated Financial Statements

5

Item 2.

Managements Discussion and Analysis of Financial Condition and Results of Operations

17

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

29

Item 4.

Controls and Procedures

29

Part II. Other Information

Item 1.

Legal Proceedings

30

Item 1A.

Risk Factors

30

Item 2.

Unregistered Sales of Equity Securities and Use of Proceeds

30

Item 3.

Defaults Upon Senior Securities

30

Item 4.

Mine Safety Disclosures

30

Item 5.

Other Information

30

Item 6.

Exhibits

30

 

Signatures

31

 

 

 

 

PART I. FINANCIAL INFORMATION

ITEM 1. CONSOLIDATED FINANCIAL STATEMENTS

 

NATURAL RESOURCE PARTNERS L.P.

CONSOLIDATED BALANCE SHEETS

 

  

June 30,

  

December 31,

 
  2023  2022 

(In thousands, except unit data)

 

(Unaudited)

    

ASSETS

        

Current assets

        

Cash and cash equivalents

 $10,730  $39,091 

Accounts receivable, net

  37,120   42,701 

Other current assets, net

  2,865   1,822 

Total current assets

 $50,715  $83,614 

Land

  24,008   24,008 

Mineral rights, net

  404,741   412,312 

Intangible assets, net

  14,432   14,713 

Equity in unconsolidated investment

  290,900   306,470 

Long-term contract receivable, net

  27,659   28,946 

Other long-term assets, net

  7,804   7,068 

Total assets

 $820,259  $877,131 

LIABILITIES AND CAPITAL

        

Current liabilities

        

Accounts payable

 $1,524  $1,992 

Accrued liabilities

  5,715   11,916 

Accrued interest

  625   989 

Current portion of deferred revenue

  6,823   6,256 

Current portion of long-term debt, net

  36,743   39,076 

Total current liabilities

 $51,430  $60,229 

Deferred revenue

  36,815   40,181 

Long-term debt, net

  145,693   129,205 

Other non-current liabilities

  6,462   5,472 

Total liabilities

 $240,400  $235,087 

Commitments and contingencies (see Note 13)

          

Class A Convertible Preferred Units (121,667 and 250,000 units issued and outstanding at June 30, 2023 and December 31, 2022, respectively, at $1,000 par value per unit; liquidation preference of $1,850 per unit at June 30, 2023 and December 31, 2022) (See Note 3)

 $80,099  $164,587 

Partners’ capital

        

Common unitholders’ interest (12,634,642 and 12,505,996 units issued and outstanding at June 30, 2023 and December 31, 2022, respectively)

 $444,838  $404,799 

General partner’s interest

  6,913   5,977 

Warrant holders’ interest

  47,964   47,964 

Accumulated other comprehensive income (loss)

  45   18,717 

Total partners’ capital

 $499,760  $477,457 

Total liabilities and partners' capital

 $820,259  $877,131 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

 

 

NATURAL RESOURCE PARTNERS L.P.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(Unaudited)

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands, except per unit data)

 

2023

  

2022

  

2023

  

2022

 

Revenues and other income

                

Royalty and other mineral rights

 $61,007  $79,333  $137,278  $150,416 

Transportation and processing services

  3,270   5,612   6,868   9,408 

Equity in earnings of Sisecam Wyoming

  26,978   14,643   46,232   29,480 

Gain on asset sales and disposals

  5   345   101   345 

Total revenues and other income

 $91,260  $99,933  $190,479  $189,649 
                 

Operating expenses

                

Operating and maintenance expenses

 $7,930  $10,015  $15,093  $18,091 

Depreciation, depletion and amortization

  3,792   5,847   7,875   9,715 

General and administrative expenses

  5,643   5,052   11,488   9,519 

Asset impairments

  69   43   69   62 

Total operating expenses

 $17,434  $20,957  $34,525  $37,387 
                 

Income from operations

 $73,826  $78,976  $155,954  $152,262 
                 

Other expenses, net

                

Interest expense, net

 $(3,492) $(8,108) $(6,345) $(17,495)

Loss on extinguishment of debt

     (4,048)     (4,048)

Total other expenses, net

 $(3,492) $(12,156) $(6,345) $(21,543)
                 

Net income

 $70,334  $66,820  $149,609  $130,719 

Less: income attributable to preferred unitholders

  (4,971)  (7,500)  (11,632)  (15,000)

Less: redemption of preferred units

  (27,618)     (43,846)   

Net income attributable to common unitholders and the general partner

 $37,745  $59,320  $94,131  $115,719 
                 

Net income attributable to common unitholders

 $36,990  $58,134  $92,248  $113,405 

Net income attributable to the general partner

  755   1,186   1,883   2,314 
                 

Net income per common unit (see Note 5)

                

Basic

 $2.93  $4.65  $7.32  $9.10 

Diluted

  2.49   3.29   5.96   6.50 
                 

Net income

 $70,334  $66,820  $149,609  $130,719 

Comprehensive income (loss) from unconsolidated investment and other

  911   (4,013)  (18,672)  (1,468)

Comprehensive income

 $71,245  $62,807  $130,937  $129,251 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

 

 

NATURAL RESOURCE PARTNERS L.P.

CONSOLIDATED STATEMENTS OF PARTNERS CAPITAL

(Unaudited)

 

                  

Accumulated

     
                  

Other

  

Total

 
  

Common Unitholders

  

General

  

Warrant

  

Comprehensive

  

Partners'

 

(In thousands)

 

Units

  

Amounts

  

Partner

  

Holders

  

Income (Loss)

  

Capital

 

Balance at December 31, 2022

  12,506  $404,799  $5,977  $47,964  $18,717  $477,457 

Net income (1)

     77,690   1,585         79,275 

Redemption of preferred units

     (15,904)  (324)        (16,228)

Distributions to common unitholders and the general partner

     (40,082)  (818)        (40,900)

Distributions to preferred unitholders

     (7,924)  (162)        (8,086)

Issuance of unit-based awards

  129                

Unit-based awards amortization and vesting, net

     (1,178)           (1,178)

Capital contribution

        142         142 

Comprehensive loss from unconsolidated investment and other

              (19,583)  (19,583)

Balance at March 31, 2023

  12,635  $417,401  $6,400  $47,964  $(866) $470,899 

Net income (2)

     68,927   1,407         70,334 

Redemption of preferred units

     (27,065)  (553)        (27,618)

Distributions to common unitholders and the general partner

     (9,476)  (193)        (9,669)

Distributions to preferred unitholders

     (7,248)  (148)        (7,396)

Unit-based awards amortization and vesting

     2,299            2,299 

Comprehensive income from unconsolidated investment and other

              911   911 

Balance at June 30, 2023

  12,635  $444,838  $6,913  $47,964  $45  $499,760 
         

(1)

Net income includes $6.7 million of income attributable to preferred unitholders that accumulated during the period, of which $6.5 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.

(2) Net income includes $5.0 million of income attributable to preferred unitholders that accumulated during the period, of which $4.9 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.

 

                  

Accumulated

     
                  

Other

  

Total

 
  

Common Unitholders

  

General

  

Warrant

  

Comprehensive

  

Partners'

 

(In thousands)

 

Units

  

Amounts

  

Partner

  

Holders

  

Income

  

Capital

 

Balance at December 31, 2021

  12,351  $203,062  $1,787  $47,964  $3,211  $256,024 

Net income (1)

     62,621   1,278         63,899 

Distributions to common unitholders and the general partner

     (5,559)  (113)        (5,672)

Distributions to preferred unitholders

     (7,603)  (155)        (7,758)

Issuance of unit-based awards

  155                

Unit-based awards amortization and vesting, net

     (1,754)           (1,754)

Capital contribution

        112         112 

Comprehensive income from unconsolidated investment and other

              2,545   2,545 

Balance at March 31, 2022

  12,506  $250,767  $2,909  $47,964  $5,756  $307,396 

Net income (1)

     65,484   1,336         66,820 

Distributions to common unitholders and the general partner

     (9,379)  (191)        (9,570)

Distributions to preferred unitholders

     (7,350)  (150)        (7,500)

Unit-based awards amortization and vesting

     1,231            1,231 

Comprehensive loss from unconsolidated investment and other

              (4,013)  (4,013)

Balance at June 30, 2022

  12,506  $300,753  $3,904  $47,964  $1,743  $354,364 
         

(1)

Net income includes $7.5 million of income attributable to preferred unitholders that accumulated during the period, of which $7.4 million is allocated to the common unitholders and $0.2 million is allocated to the general partner.

 

The accompanying notes are an integral part of these consolidated financial statements.

 

 

 

NATURAL RESOURCE PARTNERS L.P.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

 

  

For the Six Months Ended June 30,

 

(In thousands)

 

2023

  

2022

 

Cash flows from operating activities

        

Net income

 $149,609  $130,719 

Adjustments to reconcile net income to net cash provided by operating activities:

        

Depreciation, depletion and amortization

  7,875   9,715 

Distributions from unconsolidated investment

  43,130   23,716 

Equity earnings from unconsolidated investment

  (46,232)  (29,480)

Gain on asset sales and disposals

  (101)  (345)

Loss on extinguishment of debt

     4,048 

Asset impairments

  69   62 

Bad debt expense

  (808)  640 

Unit-based compensation expense

  5,137   2,787 

Amortization of debt issuance costs and other

  566   1,672 

Change in operating assets and liabilities:

        

Accounts receivable

  6,700   (12,612)

Accounts payable

  (469)  13 

Accrued liabilities

  (6,786)  (5,109)

Accrued interest

  (364)  (163)

Deferred revenue

  (2,800)  (9,575)

Other items, net

  (1,276)  (634)

Net cash provided by operating activities

 $154,250  $115,454 
         

Cash flows from investing activities

        

Proceeds from asset sales and disposals

 $106  $346 

Return of long-term contract receivable

  1,208   563 

Capital expenditures

  (10)   

Net cash provided by investing activities

 $1,304  $909 
         

Cash flows from financing activities

        

Debt borrowings

 $165,034  $ 

Debt repayments

  (151,061)  (137,171)

Distributions to common unitholders and the general partner

  (50,569)  (15,242)

Distributions to preferred unitholders

  (15,482)  (15,258)

Redemption of preferred units

  (128,333)   

Redemption of preferred units paid-in-kind

     (19,321)

Other items, net

  (3,504)  (5,535)

Net cash used in financing activities

 $(183,915) $(192,527)
         

Net decrease in cash and cash equivalents

 $(28,361) $(76,164)

Cash and cash equivalents at beginning of period

  39,091   135,520 

Cash and cash equivalents at end of period

 $10,730  $59,356 
         

Supplemental cash flow information:

        

Cash paid for interest

 $6,434  $16,772 

 

The accompanying notes are an integral part of these consolidated financial statements.

 

 

 

NATURAL RESOURCE PARTNERS L.P.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

 

1.    Basis of Presentation

 

Nature of Business

 

Natural Resource Partners L.P. (the "Partnership") engages principally in the business of owning, managing and leasing a diversified portfolio of mineral properties in the United States, including interests in coal and other natural resources and owns a non-controlling 49% interest in Sisecam Wyoming LLC ("Sisecam Wyoming"), a trona ore mining and soda ash production business. The Partnership is organized into two operating segments further described in Note 6. Segment Information. The Partnership’s operations are conducted through, and its operating assets are owned by, its subsidiaries. The Partnership owns its subsidiaries through one wholly owned operating company, NRP (Operating) LLC ("Opco"). As used in these Notes to Consolidated Financial Statements, the terms "NRP," "we," "us" and "our" refer to Natural Resource Partners L.P. and its subsidiaries, unless otherwise stated or indicated by context.

 

Principles of Consolidation and Reporting

 

The accompanying unaudited Consolidated Financial Statements of the Partnership have been prepared in accordance with generally accepted accounting principles in the United States of America ("GAAP") for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. These financial statements should be read in conjunction with the financial statements for the year ended December 31, 2022 and notes thereto included in the Partnership's Annual Report on Form 10-K, which was filed with the SEC on March 3, 2023. Reclassifications have been made to prior year amounts in the Consolidated Financial Statements to conform with current year presentation. These reclassifications had no impact on previously reported total assets, total liabilities, partners' capital, net income, or cash flows from operating, investing or financing activities.

 

Recently Adopted Accounting Standard

 

On January 1, 2023, NRP adopted Accounting Standards Update ("ASU") 2020-06, Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40) (“ASU 2020-06)”. The ASU includes targeted improvements to earnings per share, which the Partnership adopted on a modified retrospective basis. The adoption of this ASU did not have a material impact on the Partnership’s Consolidated Financial Statements. See Note 5. Net Income Per Common Unit for the calculations of our basic and diluted net income per common unit. See Note 3. Class A Convertible Preferred Units and Warrants for disclosures related to our convertible preferred units and warrants.

 

5

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

2.    Revenues from Contracts with Customers

 

The following table presents the Partnership's Mineral Rights segment revenues by major source:

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Coal royalty revenues

 $47,960  $62,945  $105,983  $118,394 

Production lease minimum revenues

  562   65   1,175   1,657 

Minimum lease straight-line revenues

  4,447   4,674   8,950   9,457 

Carbon neutral initiative revenues

  115      2,233    

Property tax revenues

  1,470   1,695   2,940   3,167 

Wheelage revenues

  3,284   4,379   7,153   8,096 

Coal overriding royalty revenues

  150   682   338   940 

Lease amendment revenues

  848   811   1,699   1,691 

Aggregates royalty revenues

  686   1,037   1,439   1,807 

Oil and gas royalty revenues

  1,214   2,906   4,802   4,720 

Other revenues

  271   139   566   487 

Royalty and other mineral rights revenues

 $61,007  $79,333  $137,278  $150,416 

Transportation and processing services revenues (1)

  3,270   5,612   6,868   9,408 

Total Mineral Rights segment revenues

 $64,277  $84,945  $144,146  $159,824 
     
(1)

Transportation and processing services revenues from contracts with customers as defined under ASC 606 was $2.7 million and $4.9 million for the three months ended June 30, 2023 and 2022, respectively and $5.6 million and $8.0 million for the six months ended June 30, 2023 and 2022, respectively. The remaining transportation and processing services revenues of $0.6 million and $0.7 million for the three months ended June 30, 2023 and 2022, respectively, and $1.3 million and $1.4 million for the six months ended June 30, 2023 and 2022, respectively, related to other NRP-owned infrastructure leased to and operated by third-party operators accounted for under other guidance. See Note 15. Financing Transaction for more information.

 

The following table details the Partnership's Mineral Rights segment receivables and liabilities resulting from contracts with customers:

 

  

June 30,

  

December 31,

 

(In thousands)

 

2023

  

2022

 

Receivables

        

Accounts receivable, net

 $33,370  $39,004 

Other current assets, net (1)

  2,155    

Other long-term assets, net (2)

     75 
         

Contract liabilities

        

Current portion of deferred revenue

 $6,823  $6,256 

Deferred revenue

  36,815   40,181 
     
(1)

Other current assets, net includes short-term notes receivables from contracts with customers.

(2)

Other long-term assets, net includes long-term lease amendment fee receivables from contracts with customers.

 

The following table shows the activity related to the Partnership's Mineral Rights segment deferred revenue:

 

  

For the Six Months Ended June 30,

 

(In thousands)

 

2023

  

2022

 

Balance at beginning of period (current and non-current)

 $46,437  $61,862 

Increase due to minimums and lease amendment fees

  10,810   7,997 

Recognition of previously deferred revenue

  (13,609)  (17,573)

Balance at end of period (current and non-current)

 $43,638  $52,286 

 

The Partnership's non-cancelable annual minimum payments due under the lease terms of its coal and aggregates royalty leases are as follows as of  June 30, 2023 (in thousands):

 

Lease Term (1)

 

Weighted Average Remaining Years

  

Annual Minimum Payments

 

0 - 5 years

  1.7  $22,230 

5 - 10 years

  3.1   7,417 

10+ years

  12.1   27,129 

Total

  6.8  $56,776 
     
(1)

Lease term does not include renewal periods.

 

6

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

3.      Class A Convertible Preferred Units and Warrants

 

On March 2, 2017, NRP issued $250 million of Class A Convertible Preferred Units representing limited partner interests in NRP (the "preferred units") to certain entities controlled by funds affiliated with The Blackstone Group Inc. (collectively referred to as "Blackstone") and certain affiliates of GoldenTree Asset Management LP (collectively referred to as "GoldenTree") (together the "preferred purchasers") pursuant to a Preferred Unit and Warrant Purchase Agreement. NRP issued 250,000 preferred units to the preferred purchasers at a price of $1,000 per preferred unit (the "per unit purchase price"), less a 2.5% structuring and origination fee. The preferred units entitle the preferred purchasers to receive cumulative distributions at a rate of 12% of the purchase price per year, up to one half of which NRP may pay in additional preferred units (such additional preferred units, the "PIK units"). The preferred units have a perpetual term, unless converted or redeemed as described below.

 

NRP also issued two tranches of warrants (the "warrants") to purchase common units to the preferred purchasers (warrants to purchase 1.75 million common units with a strike price of $22.81 and warrants to purchase 2.25 million common units with a strike price of $34.00). The warrants may be exercised by the holders thereof at any time before the eighth anniversary of the closing date. Upon exercise of the warrants, NRP may, at its option, elect to settle the warrants in common units or cash, each on a net basis.

 

After March 2, 2022 and prior to March 2, 2025, the holders of the preferred units may elect to convert up to 33% of the outstanding preferred units in any 12-month period into common units if the volume weighted average trading price of our common units (the "VWAP") for the 30 trading days immediately prior to date notice is provided is greater than $51.00. In such case, the number of common units to be issued upon conversion would be equal to the per unit purchase price plus the value of any accrued and unpaid distributions divided by an amount equal to a 7.5% discount to the VWAP for the 30 trading days immediately prior to the notice of conversion. Rather than have the preferred units convert to common units in accordance with the provisions of this paragraph, NRP would have the option to elect to redeem the preferred units proposed to be converted for cash at a price equal to the per unit purchase price plus the value of any accrued and unpaid distributions.

 

On or after March 2, 2025, the holders of the preferred units may elect to convert the preferred units to common units at a conversion rate equal to the Liquidation Value divided by an amount equal to a 10% discount to the VWAP for the 30 trading days immediately prior to the notice of conversion. The “liquidation value” will be an amount equal to the greater of: (1) (a) the per unit purchase price multiplied by (i) prior to March 2, 2020, 1.50, (ii) on or after March 2, 2020 and prior to March 2, 2021, 1.70 and (iii) on or after March 2, 2021, 1.85, less (b)(i) all preferred unit distributions previously made by NRP and (ii) all cash payments previously made in respect of redemption of any PIK units; and (2) the per unit purchase price plus the value of all accrued and unpaid distributions.

 

To the extent the holders of the preferred units have not elected to convert their preferred units before March 2, 2029, NRP has the right to force conversion of the preferred units at a price equal to the liquidation value divided by an amount equal to a 10% discount to the VWAP for the 30 trading days immediately prior to the notice of conversion.

 

In addition, NRP has the ability to redeem at any time (subject to compliance with its debt agreements) all or any portion of the preferred units and any outstanding PIK units for cash. The redemption price for each outstanding PIK unit is $1,000 plus the value of any accrued and unpaid distributions per PIK unit. The redemption price for each preferred unit is the liquidation value divided by the number of outstanding preferred units. The preferred units are redeemable at the option of the preferred purchasers only upon a change in control.

 

The terms of the preferred units contain certain restrictions on NRP's ability to pay distributions on its common units. To the extent that either (i) NRP's consolidated Leverage Ratio, as defined in the Partnership's Fifth Amended and Restated Partnership Agreement dated March 2, 2017 (the "restated partnership agreement"), is greater than 3.25x, or (ii) the ratio of NRP's Distributable Cash Flow (as defined in the Restated Partnership Agreement) to cash distributions made or proposed to be made is less than 1.2x (in each case, with respect to the most recently completed four-quarter period), NRP may not increase the quarterly distribution above $0.45 per quarter without the approval of the holders of a majority of the outstanding preferred units. In addition, if at any time after January 1, 2022, any PIK units are outstanding, NRP may not make distributions on its common units until it has redeemed all PIK units for cash.

 

The holders of the preferred units have the right to vote with holders of NRP’s common units on an as-converted basis and have other customary approval rights with respect to changes of the terms of the preferred units. In addition, Blackstone has certain approval rights over certain matters as identified in the restated partnership agreement. GoldenTree also has more limited approval rights that will expand once Blackstone's ownership goes below the minimum preferred unit threshold (as defined below). These approval rights are not transferrable without NRP's consent. In addition, the approval rights held by Blackstone and GoldenTree will terminate at such time that Blackstone (together with their affiliates) or GoldenTree (together with their affiliates), as applicable, no longer own at least 20% of the total number of preferred units issued on the closing date, together with all PIK units that have been issued but not redeemed (the "minimum preferred unit threshold").

 

At the closing, pursuant to the Board Representation and Observation Rights Agreement, the Preferred Purchasers received certain board appointment and observation rights, and Blackstone appointed one director and one observer to the Board of Directors.

 

NRP also entered into a registration rights agreement (the "preferred unit and warrant registration rights agreement") with the preferred purchasers, pursuant to which NRP is required to file (i) a shelf registration statement to register the common units issuable upon exercise of the warrants and to cause such registration statement to become effective not later than 90 days following the closing date and (ii) a shelf registration statement to register the common units issuable upon conversion of the preferred units and to cause such registration statement to become effective not later than the earlier of the fifth anniversary of the closing date or 90 days following the first issuance of any common units upon conversion of preferred units (the "registration deadlines"). In addition, the preferred unit and warrant registration rights agreement gives the preferred purchasers piggyback registration and demand underwritten offering rights under certain circumstances. The shelf registration statement to register the common units issuable upon exercise of the warrants became effective on April 20, 2017. If the shelf registration statement to register the common units issuable upon conversion of the preferred units is not effective by the applicable registration deadline, NRP will be required to pay the preferred purchasers liquidated damages in the amounts and upon the term set forth in the preferred unit and warrant registration rights agreement.

 

7

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

Accounting for the Preferred Units and Warrants

 

Classification

 

The preferred units are accounted for as temporary equity on NRP's Consolidated Balance Sheets due to certain contingent redemption rights that may be exercised at the election of preferred purchasers. The warrants are accounted for as equity on NRP's Consolidated Balance Sheets.

 

Initial Measurement

 

The net transaction price was allocated to the preferred units and warrants based on their relative fair values at inception date. NRP allocated the transaction issuance costs to the preferred units and warrants primarily on a pro-rata basis based on their relative inception date allocated values.

 

Subsequent Measurement

 

Preferred Units

 

Subsequent adjustment of the preferred units will not occur until NRP has determined that the conversion or redemption of all or a portion of the preferred units is probable of occurring. Once conversion or redemption becomes probable of occurring, the carrying amount of the preferred units will be accreted to their redemption value over the period from the date the feature is probable of occurring to the date the preferred units can first be converted or redeemed. 

 

In  February 2023, the Partnership received a notice from holders of the Class A Preferred Units exercising their right to either convert or redeem, at the election of NRP, an aggregate of 47,499 Class A Preferred Units. The Partnership chose to redeem the preferred units for $47.5 million in cash rather than issuing common units. In May 2023, the Partnership received a notice from holders of the Class A Preferred Units exercising their right to either convert or redeem, at the election of NRP, an aggregate of 35,834 Class A Preferred Units. The Partnership chose to redeem the preferred units for $35.8 million in cash rather than issuing common units. In June 2023, the Partnership executed a negotiated transaction with holders of the Class A Preferred Units pursuant to which it repurchased and retired an aggregate of 45,000 Class A Preferred Units for $45.0 million in cash. Of the originally issued 250,000 Class A Preferred Units, 121,667 Class A Preferred Units remain outstanding as of June 30, 2023.

 

Activity related to the preferred units is as follows:

 

  

Units

  

Financial

 

(In thousands, except unit data)

 

Outstanding

  

Position

 

Balance at December 31, 2021

  269,321  $183,908 

Redemption of preferred units paid-in-kind

  (19,321)  (19,321)

Balance at December 31, 2022

  250,000  $164,587 

Redemption of preferred units

  (128,333)  (84,488)

Balance at June 30, 2023

  121,667  $80,099 

 

Warrants

 

As of June 30, 2023 and December 31, 2022 there were 3.0 million warrants outstanding, which included warrants to purchase 0.75 million common units at a strike price of $22.81 and warrants to purchase 2.25 million common units with a strike price of $34.00. These warrants had a $48.0 million carrying value included in warrant holders' interest within partners' capital on the Partnership's Consolidated Balance Sheets at June 30, 2023 and December 31, 2022. Subsequent adjustment of the warrants will not occur until the warrants are exercised, at which time, NRP may, at its option, elect to settle the warrants in common units or cash, each on a net basis. The net basis will be equal to the difference between the Partnership's common unit price and the strike price of the warrant. Once warrant exercise occurs, the difference between the carrying amount of the warrants and the net settlement amount will be allocated on a pro-rata basis to the common unitholders and general partner.

 

Embedded Features

 

Certain embedded features within the preferred unit and warrant purchase agreement are accounted for at fair value and are remeasured each quarter. See Note 10. Fair Value Measurements for further information regarding valuation of these embedded derivatives.

 

8

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

4.    Common and Preferred Unit Distributions

 

The Partnership makes cash distributions to common and preferred unitholders on a quarterly basis, subject to approval by the Board of Directors of GP Natural Resource Partners LLC (the "Board of Directors"). NRP recognizes both common unit and preferred unit distributions on the date the distribution is declared.

 

Distributions made on the common units and the general partner's general partner ("GP") interest are made on a pro-rata basis in accordance with their relative percentage interests in the Partnership. The general partner is entitled to receive 2% of such distributions.

 

Income available to common unitholders and the general partner is reduced by preferred unit distributions that accumulated during the period. NRP reduced net income available to common unitholders and the general partner by $5.0 million and $7.5 million during the three months ended June 30, 2023 and 2022, respectively, and $11.6 million and $15.0 million for the six months ended June 30, 2023 and 2022, respectively, as a result of accumulated preferred unit distributions earned during the period. Of the $6.7 million in accumulated preferred unit distributions earned during March 31, 2023, $0.6 million was paid in February 2023 in connection with the preferred units that were redeemed in February. Of the $5.0 million in accumulated preferred unit distributions earned during June 30, 2023, $0.4 million was paid in May 2023 and $0.9 million was paid in June 2023 in connection with the preferred units that were redeemed during those months. Income available to common unitholders and the general partner is also reduced by the difference between the fair value of the consideration paid upon redemption and the carrying value of the preferred units. As such, NRP reduced net income available to common unitholders and the general partner by $27.6 million and $43.8 million during the three and six months ended June 30, 2023, respectively. 

 

The following table shows the cash distributions declared and paid to common and preferred unitholders during the six months ended June 30, 2023 and 2022, respectively:

 

                   
    

Common Units

  

Preferred Units

 

Month Paid

 

Period Covered by Distribution

 

Distribution per Unit

  

Total Distribution (1) (In thousands)

  

Distribution per Unit

  

Total Distribution (In thousands)

 

2023

                  

February 2023

 

October 1 - December 31, 2022

 $0.75  $9,571  $30.00  $7,500 

February 2023 (2)

 

January 1 - February 8, 2023

        12.33   586 

March 2023 (3)

 

Special Distribution

  2.43   31,329       

May 2023

 

January 1 - March 31, 2023

  0.75   9,669   30.00   6,075 

May 2023 (4)

 

April 1 - May 5, 2023

        11.33   406 

June 2023 (5)

 

April 1 - June 2, 2023

        20.33   915 
                   

2022

                  

February 2022

 

October 1 - December 31, 2021

 $0.45  $5,672  $30.00  $7,500 

February 2022 (6)

 

January 1 - February 8, 2022

        13.35   258 

May 2022

 

January 1 - March 31, 2022

  0.75   9,570   30.00   7,500 
     
(1)

Totals include the amount paid to NRP's general partner in accordance with the general partner's 2% general partner interest.

(2)Relates to accrued distribution paid upon the redemption of 47,499 preferred units in February 2023.
(3)Special distribution was made to help cover unitholder tax liabilities associated with owning NRP's common units during 2022.
(4)Relates to accrued distribution paid upon the redemption of 35,834 preferred units in May 2023.
(5)Relates to accrued distribution paid upon the redemption of 45,000 preferred units in June 2023.
(6)Relates to accrued distribution paid upon the redemption of 19,321 preferred units paid-in-kind in February 2022.

 

9

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

5.    Net Income Per Common Unit

 

Basic net income per common unit is computed by dividing net income, after considering income attributable to preferred unitholders, the difference between the fair value of the consideration paid upon redemption and the carrying value of the preferred units and the general partner’s general partner interest, by the weighted average number of common units outstanding. Diluted net income per common unit includes the effect of NRP's preferred units, warrants, and unvested unit-based awards if the inclusion of these items is dilutive.

 

The dilutive effect of the preferred units is calculated using the if-converted method. Under the if-converted method, the preferred units are assumed to be converted at the beginning of the period, and the resulting common units are included in the denominator of the diluted net income per unit calculation for the period being presented. Distributions declared in the period and undeclared distributions on the preferred units that accumulated during the period are added back to the numerator for purposes of the if-converted calculation. The calculation of diluted net income per common unit for the three and six months ended June 30, 2023 includes the assumed conversion of the remaining preferred units while it does not include the assumed conversion of the preferred units that were redeemed during the three and six months ended June 30, 2023 as the inclusion of these units would be anti-dilutive. The calculation of diluted net income per common unit for the three and six months ended June 30, 2022 includes the assumed conversion of the preferred units.

 

The dilutive effect of the warrants is calculated using the treasury stock method, which assumes that the proceeds from the exercise of these instruments are used to purchase common units at the average market price for the period. The calculation of diluted net income per common unit for the three and six months ended June 30, 2023 and 2022 includes the net settlement of warrants to purchase 0.75 million common units at a strike price of $22.81 and the net settlement of warrants to purchase 2.25 million common units with a strike price of $34.00.

 

The following table reconciles the numerator and denominator of the basic and diluted net income per common unit computations and calculates basic and diluted net income per common unit:

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands, except per unit data)

 

2023

  

2022

  

2023

  

2022

 

Basic net income per common unit

                

Net income attributable to common unitholders

 $36,990  $58,134  $92,248  $113,405 

Weighted average common units—basic

  12,635   12,506   12,603   12,461 

Basic net income per common unit

 $2.93  $4.65  $7.32  $9.10 
                 

Diluted net income per common unit

                

Weighted average common units—basic

  12,635   12,506   12,603   12,461 

Plus: dilutive effect of preferred units

  2,420   6,292   3,099   6,292 

Plus: dilutive effect of warrants

  1,139   937   1,197   734 

Plus: dilutive effect of unvested unit-based awards

  122   178   165   209 

Weighted average common units—diluted

  16,316   19,913   17,064   19,696 
                 

Net income

 $70,334  $66,820  $149,609  $130,719 

Less: income attributable to preferred unitholders

  (1,321)     (1,907)   

Less: redemption of preferred units

  (27,618)     (43,846)   

Diluted net income attributable to common unitholders and the general partner

 $41,395  $66,820  $103,856  $130,719 

Less: diluted net income attributable to the general partner

  (828)  (1,336)  (2,077)  (2,614)

Diluted net income attributable to common unitholders

 $40,567  $65,484  $101,779  $128,105 
                 

Diluted net income per common unit

 $2.49  $3.29  $5.96  $6.50 

 

10

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

6.    Segment Information

 

The Partnership's segments are strategic business units that offer distinct products and services to different customers in different geographies within the U.S. and that are managed accordingly. NRP has the following two operating segments:

 

Mineral Rights—consists of mineral interests and other subsurface rights across the United States. NRP's ownership provides critical inputs for the manufacturing of steel, electricity and basic building materials, as well as opportunities for carbon sequestration and renewable energy. The Partnership is working to strategically redefine its business as a key player in the transitional energy economy in the years to come.

 

Soda Ash—consists of the Partnership's 49% non-controlling equity interest in Sisecam Wyoming, a trona ore mining operation and soda ash refinery in the Green River Basin of Wyoming. Sisecam Wyoming mines trona and processes it into soda ash that is sold both domestically and internationally to the glass and chemicals industries.

 

Direct segment costs and certain other costs incurred at the corporate level that are identifiable and that benefit the Partnership's segments are allocated to the operating segments accordingly. These allocated costs generally include salaries and benefits, insurance, property taxes, legal, royalty, information technology and shared facilities services and are included in operating and maintenance expenses on the Partnership's Consolidated Statements of Comprehensive Income.

 

Corporate and Financing includes functional corporate departments that do not earn revenues. Costs incurred by these departments include interest and financing, corporate headquarters and overhead, centralized treasury, legal and accounting and other corporate-level activity not specifically allocated to a segment and are included in general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income.

 

The following table summarizes certain financial information for each of the Partnership's business segments:

 

  

Operating Segments

         

(In thousands)

 

Mineral Rights

  

Soda Ash

  

Corporate and Financing

  

Total

 

For the Three Months Ended June 30, 2023

                

Revenues

 $64,277  $26,978  $  $91,255 

Gain on asset sales and disposals

  5         5 

Operating and maintenance expenses

  7,916   14      7,930 

Depreciation, depletion and amortization

  3,787      5   3,792 

General and administrative expenses

        5,643   5,643 

Asset impairments

  69         69 

Other expenses, net

        3,492   3,492 

Net income (loss)

  52,510   26,964   (9,140)  70,334 
                 

For the Three Months Ended June 30, 2022

                

Revenues

 $84,945  $14,643  $  $99,588 

Gain on asset sales and disposals

  345         345 

Operating and maintenance expenses

  9,992   23      10,015 

Depreciation, depletion and amortization

  5,847         5,847 

General and administrative expenses

        5,052   5,052 

Asset impairments

  43         43 

Other expenses, net

        12,156   12,156 

Net income (loss)

  69,408   14,620   (17,208)  66,820 
                 

For the Six Months Ended June 30, 2023

                

Revenues

 $144,146  $46,232  $  $190,378 

Gain on asset sales and disposals

  101         101 

Operating and maintenance expenses

  14,921   172      15,093 

Depreciation, depletion and amortization

  7,866      9   7,875 

General and administrative expenses

        11,488   11,488 

Asset impairments

  69         69 

Other expenses, net

        6,345   6,345 

Net income (loss)

  121,391   46,060   (17,842)  149,609 
                 

For the Six Months Ended June 30, 2022

                

Revenues

 $159,824  $29,480  $  $189,304 

Gain on asset sales and disposals

  345         345 

Operating and maintenance expenses

  18,017   74      18,091 

Depreciation, depletion and amortization

  9,715         9,715 

General and administrative expenses

        9,519   9,519 

Asset impairments

  62         62 

Other expenses, net

        21,543   21,543 

Net income (loss)

  132,375   29,406   (31,062)  130,719 

 

11

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

7.    Equity Investment

 

The Partnership accounts for its 49% investment in Sisecam Wyoming using the equity method of accounting. Activity related to this investment is as follows: 

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Balance at beginning of period

 $295,361  $280,156  $306,470  $276,004 

Income allocation to NRP’s equity interests (1)

  28,212   15,804   48,576   31,869 

Amortization of basis difference

  (1,234)  (1,161)  (2,344)  (2,389)

Other comprehensive income (loss)

  911   (4,013)  (18,672)  (1,468)

Distribution

  (32,350)  (10,486)  (43,130)  (23,716)

Balance at end of period

 $290,900  $280,300  $290,900  $280,300 
     
(1)Amounts reclassified into income out of accumulated other comprehensive loss were $2.3 million and $(3.0) million for the three months ended June 30, 2023 and 2022, respectively, and $(18.3) million and $(4.7) million for the six months ended June 30, 2023 and 2022, respectively. 

 

The following table represents summarized financial information for Sisecam Wyoming as derived from their respective unaudited financial statements for the three and six months ended June 30, 2023 and 2022:

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Net sales

 $201,365  $189,068  $408,493  $352,505 

Gross profit

  64,554   40,279   113,609   80,044 

Net income

  57,574   32,253   99,134   65,039 

 

 

8.    Mineral Rights, Net

 

The Partnership’s mineral rights consist of the following:

 

  

June 30, 2023

  

December 31, 2022

 

(In thousands)

 

Carrying Value

  

Accumulated Depletion

  

Net Book Value

  

Carrying Value

  

Accumulated Depletion

  

Net Book Value

 

Coal properties

 $661,743  $(276,085) $385,658  $661,812  $(269,037) $392,775 

Aggregates properties

  8,655   (3,618)  5,037   8,655   (3,410)  5,245 

Oil and gas royalty properties

  12,354   (9,841)  2,513   12,354   (9,600)  2,754 

Other

  13,145   (1,612)  11,533   13,150   (1,612)  11,538 

Total mineral rights, net

 $695,897  $(291,156) $404,741  $695,971  $(283,659) $412,312 

 

Depletion expense related to the Partnership’s mineral rights is included in depreciation, depletion and amortization on its Consolidated Statements of Comprehensive Income and totaled $3.6 million and $5.4 million for the three months ended June 30, 2023 and 2022, respectively and $7.5 million and $9.1 million for the six months ended June 30, 2023 and 2022, respectively.

 

The Partnership has developed procedures to evaluate its long-lived assets for possible impairment periodically or whenever events or changes in circumstances indicate an asset's net book value may not be recoverable. Potential events or circumstances include, but are not limited to, specific events such as a reduction in economically recoverable reserves or production ceasing on a property for an extended period. This analysis is based on historic, current and future performance and considers both quantitative and qualitative information. As a result of the analysis, the Partnership recorded immaterial impairment expenses during the three and six months ended June 30, 2023 and 2022. 

 

12

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

9.    Debt, Net

 

The Partnership's debt consists of the following:

 

  

June 30,

  

December 31,

 

(In thousands)

 

2023

  

2022

 

Opco Credit Facility

 $103,034  $70,000 

Opco Senior Notes

        

5.55% with semi-annual interest payments in June and December, with annual principal payments in June, due June 2023

 $  $2,366 

4.73% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2023

  6,004   6,004 

5.82% with semi-annual interest payments in March and September, with annual principal payments in March, due March 2024

  12,684   25,368 

8.92% with semi-annual interest payments in March and September, with annual principal payments in March, due March 2024

  4,011   8,023 

5.03% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026

  45,683   45,683 

5.18% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026

  11,643   11,643 

Total Opco Senior Notes

 $80,025  $99,087 

Total debt at face value

 $183,059  $169,087 

Net unamortized debt issuance costs

  (623)  (806)

Total debt, net

 $182,436  $168,281 

Less: current portion of long-term debt

  (36,743)  (39,076)

Total long-term debt, net

 $145,693  $129,205 

 

Opco Debt

 

All of Opco’s debt is guaranteed by its wholly owned subsidiaries and is secured by certain of the assets of Opco and its wholly owned subsidiaries, other than BRP LLC and NRP Trona LLC. As of June 30, 2023 and December 31, 2022, Opco was in compliance with the terms of the financial covenants contained in its debt agreements.

 

Opco Credit Facility

 

In May 2023, the Partnership entered into the Sixth Amendment (the "Sixth Amendment) to the Opco Credit Facility (the "Opco Credit Facility"). The Sixth Amendment maintained the term of the Opco Credit Facility until August 2027. Lender commitments under the Opco Credit Facility increased from $130.0 million to $155.0 million, with the ability to expand such commitments to $200.0 million with the addition of future commitments and. The Sixth Amendment also includes modifications to Opco’s ability to declare and make certain restricted payments. The Opco Credit Facility contains financial covenants requiring Opco to maintain:

 

A leverage ratio of consolidated indebtedness to EBITDDA (in each case as defined in the Opco Credit Facility) not to exceed 3.0x; provided, and

 

an interest coverage ratio of consolidated EBITDDA to the sum of consolidated interest expense and consolidated lease expense (in each case as defined in the Opco Credit Facility) of not less than 3.5 to 1.0.

 

As of December 31, 2022, the Partnership had $70.0 million in borrowings outstanding under the Opco Credit Facility. During the six months ended June 30, 2023, the Partnership borrowed $165.0 million and repaid $132.0 million, resulting in $103.0 million in borrowings outstanding under the Opco Credit Facility as of June 30, 2023. The weighted average interest rate for the borrowings outstanding under the Opco Credit Facility for the three and six months ended June 30, 2023 was 8.61% and 8.44%, respectively. During the three and six months ended June 30, 2022, the Partnership did not have any borrowings outstanding under the Opco Credit Facility. The Partnership had $52.0 million and $60.0 million of available borrowing capacity as of June 30, 2023 and December 31, 2022, respectively.

 

The Opco Credit Facility is collateralized and secured by liens on certain of Opco’s assets with carrying values of $320.0 million and $326.4 million classified as mineral rights, net and other long-term assets, net on the Partnership’s Consolidated Balance Sheets as of June 30, 2023 and December 31, 2022, respectively.

 

Opco Senior Notes   

 

Opco has issued several series of private placement senior notes (the "Opco Senior Notes") with various interest rates and principal due dates. As of June 30, 2023 and December 31, 2022, the Opco Senior Notes had cumulative principal balances of $80.0 million and $99.1 million, respectively. Opco made mandatory principal payments of $19.1 million during the six months ended June 30, 2023 and 2022.

 

The 8.92% Opco Senior Notes also provides that in the event that Opco’s leverage ratio of consolidated indebtedness to consolidated EBITDDA (as defined in the Note Purchase Agreements) exceeds 3.75 to 1.00 at the end of any fiscal quarter, then in addition to all other interest accruing on these notes, additional interest in the amount of 2.00% per annum shall accrue on the notes for the two succeeding quarters and for as long thereafter as the leverage ratio remains above 3.75 to 1.00. Opco has not exceeded the 3.75 to 1.00 ratio at the end of any fiscal quarter through June 30, 2023.

 

13

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

10.    Fair Value Measurements

 

Fair Value of Financial Assets and Liabilities

 

The Partnership’s financial assets and liabilities consist of cash and cash equivalents, a contract receivable and debt. The carrying amounts reported on the Consolidated Balance Sheets for cash and cash equivalents approximate fair value due to their short-term nature. The Partnership uses available market data and valuation methodologies to estimate the fair value of its debt and contract receivable.

 

The following table shows the carrying value and estimated fair value of the Partnership's debt and contract receivable:

 

      

June 30, 2023

  

December 31, 2022

 
  

Fair Value

  

Carrying

  

Estimated

  

Carrying

  

Estimated

 

(In thousands)

 

Hierarchy Level

  

Value

  

Fair Value

  

Value

  

Fair Value

 

Debt:

                    

Opco Senior Notes (1)

  3  $79,402  $75,848  $98,281  $96,060 

Opco Credit Facility (2)

  3   103,034   103,034   70,000   70,000 
                     

Assets:

                    

Contract receivable, net (current and long-term) (3)

  3  $30,182  $25,254  $31,371  $24,833 
     
(1)The fair value of the Opco Senior Notes at June 30, 2023 and December 31, 2022 were estimated by management utilizing the present value replacement method incorporating the interest rate of the Opco Credit facility at June 30, 2023 and December 31, 2022, respectively.
(2)The fair value of the Opco Credit Facility approximates the outstanding borrowing amount because the interest rates are variable and reflective of market rates and the terms of the credit facility allow the Partnership to repay the debt at any time without penalty.
(3)The fair value of the Partnership's contract receivable is determined based on the present value of future cash flow projections related to the underlying asset at a discount rate of 15% at June 30, 2023 and December 31, 2022.

 

NRP has embedded derivatives in the preferred units related to certain conversion options, redemption features and the change of control provision that are accounted for separately from the preferred units as assets and liabilities at fair value on the Partnership's Consolidated Balance Sheets. Level 3 valuation of the embedded derivatives are based on numerous factors including the likelihood of the event occurring. The embedded derivatives are revalued quarterly and changes in their fair value would be recorded in other expenses, net on the Partnership's Consolidated Statements of Comprehensive Income. The embedded derivatives had zero value as of June 30, 2023 and December 31, 2022.

 

 

11.    Related Party Transactions

 

Affiliates of our General Partner

 

The Partnership’s general partner does not receive any management fee or other compensation for its management of NRP. However, in accordance with the partnership agreement, the general partner and its affiliates are reimbursed for services provided to the Partnership and for expenses incurred on the Partnership’s behalf. Employees of Quintana Minerals Corporation ("QMC") and Western Pocahontas Properties Limited Partnership ("WPPLP"), affiliates of the Partnership, provide their services to manage the Partnership's business. QMC and WPPLP charge the Partnership the portion of their employee salary and benefits costs related to their employee services provided to NRP. These QMC and WPPLP employee management service costs are presented as operating and maintenance expenses and general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income. NRP also reimburses overhead costs incurred by its affiliates, including Quintana Infrastructure Development ("QID"), to manage the Partnership's business. These overhead costs include certain rent, information technology, administration of employee benefits and other corporate services incurred by or on behalf of the Partnership’s general partner and its affiliates and are presented as operating and maintenance expenses and general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income.

 

Direct general and administrative expenses charged to the Partnership by QMC, WPPLP and QID are included on the Partnership's Consolidated Statement of Comprehensive Income as follows:

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Operating and maintenance expenses

 $1,712  $1,698  $3,431  $3,357 

General and administrative expenses

  1,253   1,225   2,573   2,465 

 

The Partnership had accounts payable to QMC of $0.4 million on its Consolidated Balance Sheets at both  June 30, 2023 and December 31, 2022, and $0.8 million and $1.0 million of accounts payable to WPPLP at June 30, 2023 and December 31, 2022, respectively.

 

During the three months ended June 30, 2023 and 2022, the Partnership recognized $2.0 million and $2.7 million, respectively, in operating and maintenance expenses on its Consolidated Statements of Comprehensive Income related to an overriding royalty agreement with WPPLP. These amounts were $4.0 million and $4.3 million during the six months ended June 30, 2023 and 2022, respectively. 

 

14

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

12.    Major Customers 

 

Revenues from customers that exceeded 10 percent of total revenues for any of the periods presented below are as follows:

 

  

For the Three Months Ended June 30,

  

For the Six Months Ended June 30,

 
  

2023

  

2022

  

2023

  

2022

 

(In thousands)

 

Revenues

  

Percent

  

Revenues

  

Percent

  

Revenues

  

Percent

  

Revenues

  

Percent

 

Alpha Metallurgical Resources, Inc. (1)

 $19,685   22% $32,895   33% $43,903   23% $60,638   32%

Foresight Energy Resources LLC ("Foresight") (1)

 $12,324   14% $16,497   17% $24,853   13% $27,747   15%
     

(1)

Revenues from Alpha Metallurgical Resources, Inc. and Foresight are included within the Partnership's Mineral Rights segment.

 

 

13.    Commitments and Contingencies

 

NRP is involved, from time to time, in various legal proceedings arising in the ordinary course of business. While the ultimate results of these proceedings cannot be predicted with certainty, Partnership management believes these ordinary course matters will not have a material effect on the Partnership’s financial position, liquidity or operations.

 

 

14.    Unit-Based Compensation

 

During the three and six months ended June 30, 2023, the Partnership granted service, performance and market-based awards under its 2017 Long-Term Incentive Plan and during the six months ended June 30, 2022, the Partnership granted service-based awards. The Partnership's service and performance-based awards are valued using the closing price of NRP's common units as of the grant date while the Partnership's market-based awards are valued using a Monte Carlo simulation. The grant date fair value of these awards granted during the three months ended June 30, 2023 was $0.1 million. The grant date fair value of these awards granted during six months ended June 30, 2023 and 2022 was $16.0 million and $7.9 million, respectively. Total unit-based compensation expense associated with these awards was $2.6 million and $1.3 million for the three months ended June 30, 2023 and 2022, respectively, and $5.1 million and $2.8 million for the six months ended June 30, 2023 and 2022, respectively, and is included in general and administrative expenses and operating and maintenance expenses on the Partnership's Consolidated Statements of Comprehensive Income. The unamortized cost associated with unvested outstanding awards as of June 30, 2023 is $18.2 million, which is to be recognized over a weighted average period of 2.3 years. The unamortized cost associated with unvested outstanding awards as of  December 31, 2022 was $6.3 million.

 

A summary of the unit activity in the outstanding grants during 2023 is as follows:

 

(In thousands)

 

Common Units

  

Weighted Average Grant Date Fair Value per Common Unit

 

Outstanding at January 1, 2023

  386  $28.96 

Granted

  281  $56.84 

Fully vested and issued

  (184) $26.30 

Outstanding at June 30, 2023

  483  $46.21 

 

15

NATURAL RESOURCE PARTNERS L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED
(Unaudited)
 

15.    Financing Transaction

 

The Partnership owns rail loadout and associated infrastructure at the Sugar Camp mine in the Illinois Basin operated by a subsidiary of Foresight. The infrastructure at the Sugar Camp mine is leased to a subsidiary of Foresight and is accounted for as a financing transaction (the "Sugar Camp lease"). The Sugar Camp lease expires in 2032 with renewal options for up to 80 additional years. Minimum payments are $5.0 million per year through the end of the lease term. The Partnership is also entitled to variable payments in the form of throughput fees based on the amount of coal transported and processed utilizing the Partnership's assets. In the event the Sugar Camp lease is renewed beyond 2032, payments become a fixed ten thousand dollars per year for the remainder of the renewed term.

 

 

16.    Credit Losses

 

The Partnership is exposed to credit losses through collection of its short-term trade receivables resulting from contracts with customers and a long-term receivable resulting from a financing transaction with a customer. The Partnership records an allowance for current expected credit losses on these receivables based on the loss-rate method. NRP assessed the likelihood of collection of its receivables utilizing historical loss rates, current market conditions, industry and macroeconomic factors, reasonable and supportable forecasts and facts or circumstances of individual customers and properties. Examples of these facts or circumstances include, but are not limited to, contract disputes or renegotiations with the customer and evaluation of short and long-term economic viability of the contracted property. For its long-term contract receivable, management reverts to the historical loss experience immediately after the reasonable and supportable forecast period ends.

 

As of June 30, 2023 and December 31, 2022, NRP had the following current expected credit loss (“CECL”) allowance related to its receivables and long-term contract receivable:

 

  

June 30, 2023

  

December 31, 2022

 

(In thousands)

 

Gross

  

CECL Allowance

  

Net

  

Gross

  

CECL Allowance

  

Net

 

Receivables

 $42,974  $(3,699) $39,275  $47,237  $(4,461) $42,776 

Long-term contract receivable

  28,652   (993)  27,659   29,984   (1,038)  28,946 

Total

 $71,626  $(4,692) $66,934  $77,221  $(5,499) $71,722 

 

NRP recorded a reversal of $0.2 million and $0.4 million of operating and maintenance expenses on its Consolidated Statements of Comprehensive Income related to the change in the CECL allowance during the three months ended June 30, 2023 and 2022, respectively and a reversal of $0.8 million and expense of $0.6 million during the six months ended June 30, 2023 and 2022, respectively. 

 

NRP has procedures in place to monitor its ongoing credit exposure through timely review of counterparty balances against contract terms and due dates, account and financing receivable reconciliation, bankruptcy monitoring, lessee audits and dispute resolution. The Partnership may employ legal counsel or collection specialists to pursue recovery of defaulted receivables.

 

 

17.    Subsequent Events

 

The following represents material events that have occurred subsequent to June 30, 2023 through the time of the Partnership’s filing of its Quarterly Report on Form 10-Q with the SEC:

 

Common Unit and Preferred Unit Distributions

 

In August 2023, the Board of Directors declared a distribution of $0.75 per common unit with respect to the second quarter of 2023. The Board of Directors also declared a $3.7 million cash distribution on NRP's outstanding preferred units with respect to the second quarter of 2023.

 

 

16

 

 

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

The following review of operations for the three and six month periods ended June 30, 2023 and 2022 should be read in conjunction with our Consolidated Financial Statements and the Notes to Consolidated Financial Statements included in this Form 10-Q and with the Consolidated Financial Statements, Notes to Consolidated Financial Statements and Management’s Discussion and Analysis included in the Natural Resource Partners L.P. Annual Report on Form 10-K for the year ended December 31, 2022.

 

As used herein, unless the context otherwise requires: "we," "our," "us" and the "Partnership" refer to Natural Resource Partners L.P. and, where the context requires, our subsidiaries. References to "NRP" and "Natural Resource Partners" refer to Natural Resource Partners L.P. only, and not to NRP (Operating) LLC or any of Natural Resource Partners L.P.’s subsidiaries. References to "Opco" refer to NRP (Operating) LLC, a wholly owned subsidiary of NRP, and its subsidiaries. NRP Finance Corporation ("NRP Finance") is a wholly owned subsidiary of NRP and was a co-issuer with NRP on the 9.125% senior notes due 2025 (the "2025 Senior Notes").

 

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

 

Statements included in this 10-Q may constitute forward-looking statements. In addition, we and our representatives may from time to time make other oral or written statements which are also forward-looking statements. Such forward-looking statements include, among other things, statements regarding: the effects of the global COVID-19 pandemic; future distributions on our common and preferred units; our business strategy; our liquidity and access to capital and financing sources; our financial strategy; prices of and demand for coal, trona and soda ash, and other natural resources; estimated revenues, expenses and results of operations; projected future performance by our lessees; Sisecam Wyoming LLC’s ("Sisecam Wyoming's") trona mining and soda ash refinery operations; distributions from our soda ash joint venture; the impact of governmental policies, laws and regulations, as well as regulatory and legal proceedings involving us, and of scheduled or potential regulatory or legal changes; and global and U.S. economic conditions.

 

These forward-looking statements speak only as of the date hereof and are made based upon our current plans, expectations, estimates, assumptions and beliefs concerning future events impacting us and involve a number of risks and uncertainties. We caution that forward-looking statements are not guarantees and that actual results could differ materially from those expressed or implied in the forward-looking statements. You should not put undue reliance on any forward-looking statements. See "Item 1A. Risk Factors" included in this Form 10-Q and in our Annual Report on Form 10-K for the year ended December 31, 2022 for important factors that could cause our actual results of operations or our actual financial condition to differ.

 

NON-GAAP FINANCIAL MEASURES

 

Adjusted EBITDA

 

Adjusted EBITDA is a non-GAAP financial measure that we define as net income (loss) less equity earnings from unconsolidated investment; plus total distributions from unconsolidated investment, interest expense, net, debt modification expense, loss on extinguishment of debt, depreciation, depletion and amortization and asset impairments. Adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income or loss, net income or loss attributable to partners, operating income or loss, cash flows from operating activities or any other measure of financial performance presented in accordance with GAAP as measures of operating performance, liquidity or ability to service debt obligations. There are significant limitations to using Adjusted EBITDA as a measure of performance, including the inability to analyze the effect of certain recurring items that materially affect our net income, the lack of comparability of results of operations of different companies and the different methods of calculating Adjusted EBITDA reported by different companies. In addition, Adjusted EBITDA presented below is not calculated or presented on the same basis as Consolidated EBITDA as defined in our partnership agreement or Consolidated EBITDDA as defined in Opco's debt agreements. For a description of Opco's debt agreements, see Note 9. Debt, Net in the Notes to Consolidated Financial Statements included herein as well as in "Item 8. Financial Statements and Supplementary Data—Note 11. Debt, Net" in our Annual Report on Form 10-K for the year ended December 31, 2022. Adjusted EBITDA is a supplemental performance measure used by our management and by external users of our financial statements, such as investors, commercial banks, research analysts and others to assess the financial performance of our assets without regard to financing methods, capital structure or historical cost basis.

 

Distributable Cash Flow

 

Distributable cash flow ("DCF") represents net cash provided by (used in) operating activities plus distributions from unconsolidated investment in excess of cumulative earnings, proceeds from asset sales and disposals, including sales of discontinued operations, and return of long-term contract receivable; less maintenance capital expenditures. DCF is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating, investing or financing activities. DCF may not be calculated the same for us as for other companies. In addition, DCF presented below is not calculated or presented on the same basis as distributable cash flow as defined in our partnership agreement, which is used as a metric to determine whether we are able to increase quarterly distributions to our common unitholders. DCF is a supplemental liquidity measure used by our management and by external users of our financial statements, such as investors, commercial banks, research analysts and others to assess our ability to make cash distributions and repay debt.

 

Free Cash Flow

 

Free cash flow ("FCF") represents net cash provided by (used in) operating activities plus distributions from unconsolidated investment in excess of cumulative earnings and return of long-term contract receivable; less maintenance and expansion capital expenditures and cash flow used in acquisition costs classified as investing or financing activities. FCF is calculated before mandatory debt repayments. FCF is not a measure of financial performance under GAAP and should not be considered as an alternative to cash flows from operating, investing or financing activities. FCF may not be calculated the same for us as for other companies. FCF is a supplemental liquidity measure used by our management and by external users of our financial statements, such as investors, commercial banks, research analysts and others to assess our ability to make cash distributions and repay debt.

 

Leverage Ratio

 

Leverage ratio represents the outstanding principal of our debt at the end of the period divided by the last twelve months' Adjusted EBITDA as defined above. We believe that leverage ratio is a useful measure to management and investors to evaluate and monitor our indebtedness relative to our ability to generate income to service such debt and in understanding trends in our overall financial condition. Leverage ratio may not be calculated the same for us as for other companies and is not a substitute for, and should not be used in conjunction with, GAAP financial ratios. 

 

 

Introduction

 

The following discussion and analysis presents management's view of our business, financial condition and overall performance. Our discussion and analysis consists of the following subjects:

•    Executive Overview

•    Results of Operations

•    Liquidity and Capital Resources

•    Off-Balance Sheet Transactions

•    Related Party Transactions

•    Summary of Critical Accounting Estimates

•    Recent Accounting Standards

 

Executive Overview

 

We are a diversified natural resource company engaged principally in the business of owning, managing and leasing a diversified portfolio of mineral properties in the United States, including interests in coal and other natural resources and own a non-controlling 49% interest in Sisecam Wyoming, a trona ore mining and soda ash production business. Our common units trade on the New York Stock Exchange under the symbol "NRP." Our business is organized into two operating segments:

 

Mineral Rights—consists of approximately 13 million acres of mineral interests and other subsurface rights across the United States. If combined in a single tract, our ownership would cover roughly 20,000 square miles. Our ownership provides critical inputs for the manufacturing of steel, electricity and basic building materials, as well as opportunities for carbon sequestration and renewable energy. We are working to strategically redefine our business as a key player in the transitional energy economy in the years to come.

 

Soda Ash—consists of our 49% non-controlling equity interest in Sisecam Wyoming, a trona ore mining and soda ash production business located in the Green River Basin of Wyoming. Sisecam Wyoming mines the trona and processes it into soda ash that is sold both domestically and internationally into the glass and chemicals industries.

 

Corporate and Financing includes functional corporate departments that do not earn revenues. Costs incurred by these departments include interest and financing, corporate headquarters and overhead, centralized treasury, legal and accounting and other corporate-level activity not specifically allocated to a segment.

 

Our financial results by segment for the six months ended June 30, 2023 are as follows:

 

   

Operating Segments

                 

(In thousands)

 

Mineral Rights

   

Soda Ash

   

Corporate and Financing

   

Total

 

Revenues and other income

  $ 144,247     $ 46,232     $     $ 190,479  

Net income (loss)

  $ 121,391     $ 46,060     $ (17,842 )   $ 149,609  

Adjusted EBITDA (1)

  $ 129,326     $ 42,958     $ (11,488 )   $ 160,796  
                                 

Cash flow provided by (used in) continuing operations

                               

Operating activities

  $ 128,898     $ 42,943     $ (17,591 )   $ 154,250  

Investing activities

  $ 1,314     $     $ (10 )   $ 1,304  

Financing activities

  $ (583 )   $     $ (183,332 )   $ (183,915 )

Distributable cash flow (1)

  $ 130,212     $ 42,943     $ (17,601 )   $ 155,554  

Free cash flow (1)

  $ 130,106     $ 42,943     $ (17,601 )   $ 155,448  
         

(1)

See "—Results of Operations" below for reconciliations to the most comparable GAAP financial measures.

 

Current Results/Market Commentary

 

Financial Results and Quarterly Distributions

 

We generated $154.3 million of operating cash flow and $155.4 million of free cash flow during the six months ended June 30, 2023, and ended the quarter with $62.7 million of liquidity consisting of $10.7 million of cash and cash equivalents and $52.0 million of borrowing capacity under our Opco Credit Facility. As of June 30, 2023 our leverage ratio was 0.6 x.

 

In May 2023, we declared and paid a cash distribution of $0.75 per common unit of NRP with respect to the first quarter of 2023 as well as a $6.1 million cash distribution on the preferred units with respect to the first quarter of 2023. Future distributions on our common and preferred units will be determined on a quarterly basis by the Board of Directors. The Board of Directors considers numerous factors each quarter in determining cash distributions, including profitability, cash flow, debt service obligations, market conditions and outlook, estimated unitholder income tax liability and the level of cash reserves that the Board determines is necessary for future operating and capital needs. 

 

In February 2023, we received a notice from holders of the Class A Preferred Units exercising their right to either convert or redeem, at the election of NRP, an aggregate of 47,499 Class A Preferred Units. We chose to redeem the preferred units for $47.5 million in cash rather than issuing common units. In May 2023, we received a notice from holders of our Class A Preferred Units exercising their right to either convert or redeem, at the election of NRP, an aggregate of 35,834 Class A Preferred Units. We chose to redeem the preferred units for $35.8 million in cash rather than issuing common units. In June 2023, we executed a negotiated transaction with holders of our Class A Preferred Units pursuant to which we repurchased and retired an aggregate of 45,000 Class A Preferred Units for $45.0 million in cash. Of the originally issued 250,000 Class A Preferred Units, 121,667 Class A Preferred Units remain outstanding.

 

 

Mineral Rights Business Segment

 

Revenues and other income in the first six months of 2023 decreased $15.9 million, or 10%, as compared to the prior year period primarily due to decreased metallurgical coal sales prices. Cash provided by operating activities and free cash flow increased $10.4 million and $11.0 million, respectively, compared to the prior year period primarily due to the timing of minimum and royalty payments and prior year recoupments, partially offset by lower revenues and other income in the second quarter of 2023 as compared to the prior year period primarily due to lower met coal sales prices. 

 

While metallurgical and thermal coal prices have decreased from the beginning of the year and decreased significantly from the record highs seen in 2022, they both remain strong relative to historical norms. Transportation and logistics challenges, limited access to capital, and qualified labor shortages limit operators' ability to increase production and sales which should provide continued price support at current levels.

 

 We continue to explore opportunities for carbon neutral revenue across our large portfolio of land, mineral, and timber assets, including the sequestration of carbon dioxide underground and in standing forests, and the generation of electricity using geothermal, solar, and wind energy.

 

Soda Ash Business Segment

 

Revenues and other income in the first six months of 2023increased $16.8 million, or 57%, as compared to the prior year period driven by strong demand in domestic and international markets, partially offset by lower soda ash production and sales volumes. Cash provided by operating activities and free cash flow in the first six months of 2023increased $19.3 million as compared to the prior year period due to the early timing of distributions received from Sisecam Wyoming and a higher distribution amount driven by Sisecam Wyoming's strong operating performance in the second quarter of 2023.

 

After starting the year at historically high levels, global soda ash prices have fallen throughout the first half of the year. New supply from China entering the market in the second half of the year is expected to continue to put downward pressure on international soda ash pricing. However, we expect Sisecam Wyoming's domestic soda ash sales prices to remain strong in the second half of the year as a result of negotiated 2023 domestic sales contracts entered into at the end of 2022.

 

Results of Operations

 

Second Quarter of 2023 and 2022 Compared

 

Revenues and Other Income

 

The following table includes our revenues and other income by operating segment:

 

      For the Three Months Ended June 30,     Increase     Percentage  

Operating Segment (In thousands)

 

2023

   

2022

   

(Decrease)

   

Change

 

Mineral Rights

  $ 64,282     $ 85,290     $ (21,008 )     (25 )%

Soda Ash

    26,978       14,643       12,335       84 %

Total

  $ 91,260     $ 99,933     $ (8,673 )     (9 )%

 

The changes in revenues and other income are discussed for each of the operating segments below:

 

 

Mineral Rights

 

The following table presents coal sales volumes, coal royalty revenue per ton and coal royalty revenues by major coal producing region, the significant categories of other revenues and other income:

 

    For the Three Months Ended June 30,    

Increase

   

Percentage

 

(In thousands, except per ton data)

 

2023

   

2022

   

(Decrease)

   

Change

 

Coal sales volumes (tons)

                               

Appalachia

                               

Northern

    390       392       (2 )     (1 )%

Central

    3,352       3,484       (132 )     (4 )%

Southern

    693       312       381       122 %

Total Appalachia

    4,435       4,188       247       6 %

Illinois Basin

    1,631       3,403       (1,772 )     (52 )%

Northern Powder River Basin

    881       699       182       26 %

Gulf Coast

    139       67       72       107 %

Total coal sales volumes

    7,086       8,357       (1,271 )     (15 )%
                                 

Coal royalty revenue per ton

                               

Appalachia

                               

Northern

  $ 6.87     $ 11.84     $ (4.97 )     (42 )%

Central

    8.49       12.19       (3.70 )     (30 )%

Southern

    10.85       17.67       (6.82 )     (39 )%

Illinois Basin

    3.15       2.07       1.08       52 %

Northern Powder River Basin

    4.62       4.74       (0.12 )     (3 )%

Gulf Coast

    0.71       0.57       0.14       25 %

Combined average coal royalty revenue per ton

    6.77       7.54       (0.77 )     (10 )%
                                 

Coal royalty revenues

                               

Appalachia

                               

Northern

  $ 2,681     $ 4,640     $ (1,959 )     (42 )%

Central

    28,445       42,461       (14,016 )     (33 )%

Southern

    7,521       5,513       2,008       36 %

Total Appalachia

    38,647       52,614       (13,967 )     (27 )%

Illinois Basin

    5,141       7,061       (1,920 )     (27 )%

Northern Powder River Basin

    4,066       3,314       752       23 %

Gulf Coast

    98       38       60       158 %

Unadjusted coal royalty revenues

    47,952       63,027       (15,075 )     (24 )%

Coal royalty adjustment for minimum leases

    8       (82 )     90       110 %

Total coal royalty revenues

  $ 47,960     $ 62,945     $ (14,985 )     (24 )%
                                 

Other revenues

                               

Production lease minimum revenues

  $ 562     $ 65     $ 497       765 %

Minimum lease straight-line revenues

    4,447       4,674       (227 )     (5 )%

Carbon neutral initiative revenues

    115             115       100 %

Wheelage revenues

    3,284       4,379       (1,095 )     (25 )%

Property tax revenues

    1,470       1,695       (225 )     (13 )%

Coal overriding royalty revenues

    150       682       (532 )     (78 )%

Lease amendment revenues

    848       811       37       5 %

Aggregates royalty revenues

    686       1,037       (351 )     (34 )%

Oil and gas royalty revenues

    1,214       2,906       (1,692 )     (58 )%

Other revenues

    271       139       132       95 %

Total other revenues

  $ 13,047     $ 16,388     $ (3,341 )     (20 )%

Royalty and other mineral rights

  $ 61,007     $ 79,333     $ (18,326 )     (23 )%

Transportation and processing services revenues

    3,270       5,612       (2,342 )     (42 )%

Gain on asset sales and disposals

    5       345       (340 )     (99 )%

Total Mineral Rights segment revenues and other income

  $ 64,282     $ 85,290     $ (21,008 )     (25 )%

 

 

Coal Royalty Revenues

 

Approximately 70% of coal royalty revenues and approximately 55% of coal royalty sales volumes were derived from metallurgical coal during the three months ended June 30, 2023. Total coal royalty revenues decreased $15.0 million as compared to the prior year quarter. The discussion by region is as follows:

 

Appalachia: Coal royalty revenues decreased $14.0 million primarily due to decreased metallurgical coal sales prices during the three months ended June 30, 2023, as compared to the prior year quarter.

 

Illinois Basin: Coal royalty revenues decreased $1.9 million primarily due to decreased sales volumes during the three months ended June 30, 2023, as compared to the prior year quarter. This decrease in sales volumes is primarily a result of a temporary relocation off of NRP's coal reserves. However, the decrease in sales volumes was partially offset by an increase in sales prices and increased wheelage revenues associated with the transportation of non-NRP coal across NRP property.

 

Other Revenues

 

Total other revenues decreased $3.3 million during the three months ended June 30, 2023, as compared to the prior year quarter primarily due a $1.7 million decrease in oil and gas royalty revenues and a $1.1 million decrease in wheelage revenues as compared to the prior year period. Oil and gas royalty revenues decreased primarily as a result of decreased natural gas prices as compared to the prior year quarter and wheelage revenues decreased primarily due to lower met coal sales prices resulting in a lower wheelage revenue received per ton of coal transported. 

 

Transportation and Processing Services Revenues

 

Transportation and processing services revenues decreased $2.3 million during the three months ended June 30, 2023, as compared to the prior year quarter primarily due to a temporary relocation of certain production off of NRP's coal reserves. The fee per ton associated with the transportation and processing of the non-NRP coal is less than the fee per ton associated with the transportation and processing of NRP coal. 

 

Soda Ash

 

Revenues and other income related to our Soda Ash segment increased $12.3 million compared to the prior year quarter primarily due to higher sales prices driven by strong demand in domestic and international markets, partially offset by lower soda ash production and sales volumes.

 

Operating and Other Expenses

 

The following table presents the significant categories of our consolidated operating and other expenses:

 

   

For the Three Months Ended June 30,

   

Increase

   

Percentage

 

(In thousands)

 

2023

   

2022

   

(Decrease)

   

Change

 

Operating expenses

                               

Operating and maintenance expenses

  $ 7,930     $ 10,015     $ (2,085 )     (21 )%

Depreciation, depletion and amortization

    3,792       5,847       (2,055 )     (35 )%

General and administrative expenses

    5,643       5,052       591       12 %

Asset impairments

    69       43       26       60 %

Total operating expenses

  $ 17,434     $ 20,957     $ (3,523 )     (17 )%
                                 

Other expenses, net

                               

Interest expense, net

  $ 3,492     $ 8,108     $ (4,616 )     (57 )%

Loss on extinguishment of debt

          4,048       (4,048 )     (100 )%

Total other expenses, net

  $ 3,492     $ 12,156     $ (8,664 )     (71 )%

 

Total operating expenses decreased $3.5 million as compared to the prior year quarter primarily due to a $2.1 million decrease in operating and maintenance expenses and a $2.1 million decrease in depreciation, depletion and amortization. The decrease in operating and maintenance expenses was primarily driven by lower overriding royalty expense from an agreement with WPPLP in the second quarter of 2023 as compared to second quarter of 2022. This overriding royalty expense is fully offset by coal royalty revenue we receive from this property. The decrease in depreciation, depletion and amortization was primarily driven by lower Illinois Basin coal sales volumes during the second quarter of 2023 as compared to the second quarter of 2022 as explained in the coal royalty revenues section above.

 

Other expenses, net decreased $8.7 million as a result of less debt outstanding as compared to the prior year quarter, in addition to the loss on extinguishment of debt recognized in 2022 related to the partial retirement of the 2025 Senior Notes during the second quarter of 2022.

 

 

Adjusted EBITDA (Non-GAAP Financial Measure)

 

The following table reconciles net income (loss) (the most comparable GAAP financial measure) to Adjusted EBITDA by business segment:

 

   

Operating Segments

                 

For the Three Months Ended (In thousands)

 

Mineral Rights

   

Soda Ash

   

Corporate and Financing

   

Total

 

June 30, 2023

                               

Net income (loss)

  $ 52,510     $ 26,964     $ (9,140 )   $ 70,334  

Less: equity earnings from unconsolidated investment

          (26,978 )           (26,978 )

Add: total distributions from unconsolidated investment

          32,350             32,350  

Add: interest expense, net

                3,492       3,492  

Add: depreciation, depletion and amortization

    3,787             5       3,792  

Add: asset impairments

    69                   69  

Adjusted EBITDA

  $ 56,366     $ 32,336     $ (5,643 )   $ 83,059  
                                 

June 30, 2022

                               

Net income (loss)

  $ 69,408     $ 14,620     $ (17,208 )   $ 66,820  

Less: equity earnings from unconsolidated investment

          (14,643 )           (14,643 )

Add: total distributions from unconsolidated investment

          10,486             10,486  

Add: interest expense, net

                8,108       8,108  

Add: loss on extinguishment of debt

                4,048       4,048  

Add: depreciation, depletion and amortization

    5,847                   5,847  

Add: asset impairments

    43                   43  

Adjusted EBITDA

  $ 75,298     $ 10,463     $ (5,052 )   $ 80,709  

 

Net income increased $3.5 million primarily due to the decrease in operating and other expenses, partially offset by the decrease in revenues and other income, all discussed above. Adjusted EBITDA increased $2.4 million as compared to the prior year quarter primarily due to a $21.9 million increase in Adjusted EBITDA within our Soda Ash segment due to the early timing of distributions received from Sisecam Wyoming and a higher distribution amount driven by Sisecam Wyoming's strong operating performance in the second quarter of 2023. This increase in Adjusted EBITDA was partially offset by an $18.9 million decrease in Adjusted EBITDA within our Mineral Rights segment primarily as a result of lower revenues and other income as discussed above.

 

Distributable Cash Flow ("DCF") and Free Cash Flow ("FCF") (Non-GAAP Financial Measures)

 

The following table presents the three major categories of the statement of cash flows by business segment:

 

   

Operating Segments

                 

For the Three Months Ended (In thousands)

 

Mineral Rights

   

Soda Ash

   

Corporate and Financing

   

Total

 

June 30, 2023

                               

Cash flow provided by (used in)

                               

Operating activities

  $ 55,040     $ 32,326     $ (6,016 )   $ 81,350  

Investing activities

    615             (8 )     607  

Financing activities

                (88,882 )     (88,882 )
                                 

June 30, 2022

                               

Cash flow provided by (used in)

                               

Operating activities

  $ 70,351     $ 10,430     $ (17,658 )   $ 63,123  

Investing activities

    909                   909  

Financing activities

                (140,266 )     (140,266 )

 

 

The following table reconciles net cash provided by (used in) operating activities (the most comparable GAAP financial measure) by business segment to DCF and FCF:

 

   

Operating Segments

                 

For the Three Months Ended (In thousands)

 

Mineral Rights

   

Soda Ash

   

Corporate and Financing

   

Total

 

June 30, 2023

                               

Net cash provided by (used in) operating activities

  $ 55,040     $ 32,326     $ (6,016 )   $ 81,350  

Add: proceeds from asset sales and disposals

    5                   5  

Add: return of long-term contract receivable

    610                   610  

Less: maintenance capital expenditures

                (8 )     (8 )

Distributable cash flow

  $ 55,655     $ 32,326     $ (6,024 )   $ 81,957  

Less: proceeds from asset sales and disposals

    (5 )                 (5 )

Free cash flow

  $ 55,650     $ 32,326     $ (6,024 )   $ 81,952  
                                 

June 30, 2022

                               

Net cash provided by (used in) operating activities

  $ 70,351     $ 10,430     $ (17,658 )   $ 63,123  

Add: proceeds from asset sales and disposals

    346                   346  

Add: return of long-term contract receivable

    563                   563  

Distributable cash flow

  $ 71,260     $ 10,430     $ (17,658 )   $ 64,032  

Less: proceeds from asset sales and disposals

    (346 )                 (346 )

Free cash flow

  $ 70,914     $ 10,430     $ (17,658 )   $ 63,686  

 

Operating cash flow, DCF and FCF increased $18.2 million, $17.9 million and $18.3 million, respectively, primarily due to an increase in cash flow within our Soda Ash and Corporate and Financing segments, partially offset by a decrease in cash flow within our Mineral Rights segment. The discussion by segment is as follows:

 

Mineral Rights Segment

 

Operating cash flow, DCF and FCF decreased $15.3 million, $15.6 million and $15.3 million, respectively, primarily due to lower revenues and other income as discussed above primarily driven by lower met coal sales prices. 

 

Soda Ash Segment

 

Operating cash flow, DCF and FCF increased $21.9 million due to the early timing of distributions received from Sisecam Wyoming and a higher distribution amount driven by Sisecam Wyoming's strong operating performance in the second quarter of 2023.

 

Corporate and Financing Segment 

 

Operating cash flow, DCF and FCF increased $11.6 million primarily due to lower cash paid for interest as a result of the retirement of the 2025 Senior Notes in 2022.

     

First Six Months of 2023 and 2022 Compared

 

Revenues and Other Income

 

The following table includes our revenues and other income by operating segment:

 

      For the Six Months Ended June 30,     Increase     Percentage  

Operating Segment (In thousands)

 

2023

   

2022

   

(Decrease)

   

Change

 

Mineral Rights

  $ 144,247     $ 160,169     $ (15,922 )     (10 )%

Soda Ash

    46,232       29,480       16,752       57 %

Total

  $ 190,479     $ 189,649     $ 830       0 %

 

The changes in revenues and other income are discussed for each of the operating segments below:

 

 

Mineral Rights

 

The following table presents coal sales volumes, coal royalty revenue per ton and coal royalty revenues by major coal producing region, the significant categories of other revenues and other income:

 

   

For the Six Months Ended June 30,

   

Increase

   

Percentage

 

(In thousands, except per ton data)

 

2023

   

2022

   

(Decrease)

   

Change

 

Coal sales volumes (tons)

                               

Appalachia

                               

Northern

    769       820       (51 )     (6 )%

Central

    6,961       6,735       226       3 %

Southern

    1,275       673       602       89 %

Total Appalachia

    9,005       8,228       777       9 %

Illinois Basin

    2,941       4,905       (1,964 )     (40 )%

Northern Powder River Basin

    1,966       1,937       29       1 %

Gulf Coast

    197       136       61       45 %

Total coal sales volumes

    14,109       15,206       (1,097 )     (7 )%
                                 

Coal royalty revenue per ton

                               

Appalachia

                               

Northern

  $ 8.35     $ 10.95     $ (2.60 )     (24 )%

Central

    9.23       11.80       (2.57 )     (22 )%

Southern

    12.72       17.61       (4.89 )     (28 )%

Illinois Basin

    3.34       2.11       1.23       58 %

Northern Powder River Basin

    4.65       4.10       0.55       13 %

Gulf Coast

    0.66       0.56       0.10       18 %

Combined average coal royalty revenue per ton

    7.51       7.80       (0.29 )     (4 )%
                                 

Coal royalty revenues

                               

Appalachia

                               

Northern

  $ 6,418     $ 8,981     $ (2,563 )     (29 )%

Central

    64,251       79,441       (15,190 )     (19 )%

Southern

    16,218       11,853       4,365       37 %

Total Appalachia

    86,887       100,275       (13,388 )     (13 )%

Illinois Basin

    9,816       10,364       (548 )     (5 )%

Northern Powder River Basin

    9,141       7,946       1,195       15 %

Gulf Coast

    131       76       55       72 %

Unadjusted coal royalty revenues

    105,975       118,661       (12,686 )     (11 )%

Coal royalty adjustment for minimum leases

    8       (267 )     275       103 %

Total coal royalty revenues

  $ 105,983     $ 118,394     $ (12,411 )     (10 )%
                                 

Other revenues

                               

Production lease minimum revenues

  $ 1,175     $ 1,657     $ (482 )     (29 )%

Minimum lease straight-line revenues

    8,950       9,457       (507 )     (5 )%

Carbon neutral initiative revenues

    2,233             2,233       100 %

Wheelage revenues

    7,153       8,096       (943 )     (12 )%

Property tax revenues

    2,940       3,167       (227 )     (7 )%

Coal overriding royalty revenues

    338       940       (602 )     (64 )%

Lease amendment revenues

    1,699       1,691       8       0 %

Aggregates royalty revenues

    1,439       1,807       (368 )     (20 )%

Oil and gas royalty revenues

    4,802       4,720       82       2 %

Other revenues

    566       487       79       16 %

Total other revenues

  $ 31,295     $ 32,022     $ (727 )     (2 )%

Royalty and other mineral rights

  $ 137,278     $ 150,416     $ (13,138 )     (9 )%

Transportation and processing services revenues

    6,868       9,408       (2,540 )     (27 )%

Gain on asset sales and disposals

    101       345       (244 )     (71 )%

Total Mineral Rights segment revenues and other income

  $ 144,247     $ 160,169     $ (15,922 )     (10 )%

 

 

Coal Royalty Revenues

 

Approximately 70% of coal royalty revenues and approximately 55% of coal royalty sales volumes were derived from metallurgical coal during the six months ended June 30, 2023. Total coal royalty revenues decreased $12.4 million as compared to the prior year period. The discussion by region is as follows:

 

Appalachia: Coal royalty revenues decreased $13.4 million primarily due to decreased metallurgical coal sales prices during the six months ended June 30, 2023, as compared to the prior year quarter.

 

Illinois Basin: Coal royalty revenues decreased $0.5 million primarily due to decreased sales volumes during the six months ended June 30, 2023, as compared to the prior year period. This decrease in sales volumes is primarily a result of a temporary relocation of certain production off of NRP's coal reserves. However, the decrease in sales volumes was partially offset by an increase in sales prices and increased wheelage revenues associated with the transportation of non-NRP coal across NRP property.

 

Transportation and Processing Services Revenues

 

Transportation and processing services revenues decreased $2.5 million during the six months ended June 30, 2023, as compared to the prior year period primarily due to a temporary relocation of certain production off of NRP's coal reserves. The fee per ton on associated with the transportation and processing of the non-NRP coal is less than the fee per ton associated with the transportation and processing of NRP coal. 

 

Soda Ash

 

Revenues and other income related to our Soda Ash segment increased $16.8 million compared to the prior year period primarily due to higher sales prices driven by strong demand in domestic and international markets, partially offset by lower soda ash production and sales volumes.

 

Operating Expenses

 

The following table presents the significant categories of our consolidated operating and other expenses:

 

   

For the Six Months Ended June 30,

   

Increase

   

Percentage

 

(In thousands)

 

2023

   

2022

   

(Decrease)

   

Change

 

Operating expenses

                               

Operating and maintenance expenses

  $ 15,093     $ 18,091     $ (2,998 )     (17 )%

Depreciation, depletion and amortization

    7,875       9,715       (1,840 )     (19 )%

General and administrative expenses

    11,488       9,519       1,969       21 %

Asset impairments

    69       62       7       11 %

Total operating expenses

  $ 34,525     $ 37,387     $ (2,862 )     (8 )%
                                 

Other expenses, net

                               

Interest expense, net

  $ 6,345     $ 17,495     $ (11,150 )     (64 )%

Loss on extinguishment of debt

          4,048       (4,048 )     (100 )%

Total other expenses, net

  $ 6,345     $ 21,543     $ (15,198 )     (71 )%

 

Total operating expenses decreased $2.9 million primarily due to a $3.0 million decrease in operating and maintenance expenses, primarily driven by lower overriding royalty expense from an agreement with WPPLP as discussed above.

 

Total other expenses, net decreased $15.2 million as a result of less debt outstanding as compared to the prior year period, in addition to the loss on extinguishment of debt recognized in 2022 related to the partial retirement of the 2025 Senior Notes during the second quarter of 2022.

 

 

Adjusted EBITDA (Non-GAAP Financial Measure)

 

The following table reconciles net income (loss) (the most comparable GAAP financial measure) to Adjusted EBITDA by business segment:

 

   

Operating Segments

                 

For the Six Months Ended (In thousands)

 

Mineral Rights

   

Soda Ash

   

Corporate and Financing

   

Total

 

June 30, 2023

                               

Net income (loss)

  $ 121,391     $ 46,060     $ (17,842 )   $ 149,609  

Less: equity earnings from unconsolidated investment

          (46,232 )           (46,232 )

Add: total distributions from unconsolidated investment

          43,130             43,130  

Add: interest expense, net

                6,345       6,345  

Add: depreciation, depletion and amortization

    7,866             9       7,875  

Add: asset impairments

    69                   69  

Adjusted EBITDA

  $ 129,326     $ 42,958     $ (11,488 )   $ 160,796  
                                 

June 30, 2022

                               

Net income (loss)

  $ 132,375     $ 29,406     $ (31,062 )   $ 130,719  

Less: equity earnings from unconsolidated investment

          (29,480 )           (29,480 )

Add: total distributions from unconsolidated investment

          23,716             23,716  

Add: interest expense, net

                17,495       17,495  

Add: loss on extinguishment of debt

                4,048       4,048  

Add: depreciation, depletion and amortization

    9,715                   9,715  

Add: asset impairments

    62                   62  

Adjusted EBITDA

  $ 142,152     $ 23,642     $ (9,519 )   $ 156,275  

 

Net income increased $18.9 million primarily due to the decrease in operating and other expenses as discussed above. Adjusted EBITDA increased $4.5 million as compared to the prior year period primarily due to a $19.3 million increase in Adjusted EBITDA within our Soda Ash segment due to the early timing of distributions received from Sisecam Wyoming and a higher distribution amount driven by Sisecam Wyoming's strong operating performance in the second quarter of 2023. This increase in Adjusted EBITDA was partially offset by a $12.8 million decrease in Adjusted EBITDA within our Mineral Rights segment as a result of lower revenues and other income as discussed above. 

 

Distributable Cash Flow ("DCF") and Free Cash Flow ("FCF") (Non-GAAP Financial Measures)

 

The following table presents the three major categories of the statement of cash flows by business segment:

 

   

Operating Segments

                 

For the Six Months Ended (In thousands)

 

Mineral Rights

   

Soda Ash

   

Corporate and Financing

   

Total

 

June 30, 2023

                               

Cash flow provided by (used in)

                               

Operating activities

  $ 128,898     $ 42,943     $ (17,591 )   $ 154,250  

Investing activities

    1,314             (10 )     1,304  

Financing activities

    (583 )           (183,332 )     (183,915 )
                                 

June 30, 2022

                               

Cash flow provided by (used in)

                               

Operating activities

  $ 118,527     $ 23,625     $ (26,698 )   $ 115,454  

Investing activities

    909                   909  

Financing activities

    (614 )           (191,913 )     (192,527 )

 

 

The following table reconciles net cash provided by (used in) operating activities (the most comparable GAAP financial measure) by business segment to DCF and FCF:

 

   

Operating Segments

                 

For the Six Months Ended (In thousands)

 

Mineral Rights

   

Soda Ash

   

Corporate and Financing

   

Total

 

June 30, 2023

                               

Net cash provided by (used in) operating activities

  $ 128,898     $ 42,943     $ (17,591 )   $ 154,250  

Add: proceeds from asset sales and disposals

    106                   106  

Add: return of long-term contract receivable

    1,208                   1,208  

Less: maintenance capital expenditures

                (10 )     (10 )

Distributable cash flow

  $ 130,212     $ 42,943     $ (17,601 )   $ 155,554  

Less: proceeds from asset sales and disposals

    (106 )                 (106 )

Free cash flow

  $ 130,106     $ 42,943     $ (17,601 )   $ 155,448  
                                 

June 30, 2022

                               

Net cash provided by (used in) operating activities

  $ 118,527     $ 23,625     $ (26,698 )   $ 115,454  

Add: proceeds from asset sales and disposals

    346                   346  

Add: return of long-term contract receivable

    563                   563  

Distributable cash flow

  $ 119,436     $ 23,625     $ (26,698 )   $ 116,363  

Less: proceeds from asset sales and disposals

    (346 )                 (346 )

Free cash flow

  $ 119,090     $ 23,625     $ (26,698 )   $ 116,017  

 

Operating cash flow, DCF and FCF increased $38.8 million, $39.2 million and $39.4 million, respectively, as compared to the prior year period due to increased cash flow within our Soda Ash, Corporate and Financing and Mineral Rights segments. The discussion by segment is as follows:

 

Mineral Rights Segment

 

Operating cash flow, DCF and FCF increased $10.4 million, $10.8 million and $11.0 million, respectively, primarily due to the timing of minimum and royalty payments and prior year recoupments, partially offset by lower revenues and other income in the second quarter of 2023 as compared to the prior year period primarily driven by lower met coal sales prices. 

 

Soda Ash Segment

 

Operating cash flow, DCF and FCF increased  $19.3 million due to the early timing of distributions received from Sisecam Wyoming and a higher distribution amount driven by Sisecam Wyoming's strong operating performance in the second quarter of 2023.

 

Corporate and Financing Segment 

 

Operating cash flow, DCF and FCF increased $9.1 million primarily due to lower cash paid for interest as a result of the retirement of the 2025 Senior Notes in 2022.

  

Liquidity and Capital Resources

 

Current Liquidity

 

As of June 30, 2023, we had total liquidity of $62.7 million, consisting of $10.7 million of cash and cash equivalents and $52.0 million of borrowing capacity under our Opco Credit Facility. We have debt service obligations, including approximately $20 million of principal repayments on Opco’s senior notes, throughout the remainder of 2023. The following table calculates our leverage ratio as of June 30, 2023: 

 

   

For the Three Months Ended

         

(In thousands)

 

September 30, 2022

   

December 31, 2022

   

March 31, 2023

   

June 30, 2023

   

Last 12 Months

 

Net income

  $ 74,555     $ 63,218     $ 79,275     $ 70,334     $ 287,382  

Less: equity earnings from unconsolidated investment

    (14,556 )     (15,759 )     (19,254 )     (26,978 )     (76,547 )

Add: total distributions from unconsolidated investment

    10,339       10,780       10,780       32,350       64,249  

Add: interest expense, net

    5,141       3,638       2,853       3,492       15,124  

Add: loss on extinguishment of debt

    2,484       3,933                   6,417  

Add: depreciation, depletion and amortization

    6,850       5,954       4,083       3,792       20,679  

Add: asset impairments

    812       3,583             69       4,464  

Adjusted EBITDA

  $ 85,625     $ 75,347     $ 77,737     $ 83,059     $ 321,768  
                                         

Debt—at June 30, 2023

                                  $ 183,059  
                                         

Leverage Ratio

                                 

0.6 x

 

 

 

Cash Flows

 

Cash flows provided by operating activities increased $38.8 million, from $115.5 million in the six months ended June 30, 2022 to $154.3 million in the six months ended June 30, 2023, due to an increased cash flow within our Soda Ash, Corporate and Financing and Mineral Rights segments, all discussed above.

 

Cash used in financing activities decreased $8.6 million, from $192.5 million used in the six months ended June 30, 2022 to $183.9 million used in the six months ended June 30, 2023, primarily due to the following:

 

$165.0 million of borrowings on the Opco Credit Facility in 2023;

 

$118.1 million of cash used to retire a portion of the 2025 Senior Notes in the second quarter of 2022; and

 

$19.3 million of cash used to redeem the preferred units paid-in-kind during the first quarter of 2022.

 

These decreases in cash flow used were partially offset by the following:

 

$132.0 million of cash used to repay a portion of the Opco Credit Facility in 2023;

 

$128.3 million of cash used to redeem the preferred units in 2023; and

 

$35.3 million of increased cash distributions to common unitholders and the general partner as a result of increasing our quarterly cash distribution to $0.75/unit beginning in the second quarter of 2022 in addition to the special distribution paid in the first quarter of 2023.

Capital Resources and Obligations

 

Debt, Net

 

We had the following debt outstanding as of June 30, 2023 and December 31, 2022:

 

   

June 30,

   

December 31,

 

(In thousands)

 

2023

   

2022

 

Current portion of long-term debt, net

  $ 36,743     $ 39,076  

Long-term debt, net

    145,693       129,205  

Total debt, net

  $ 182,436     $ 168,281  

 

We have been and continue to be in compliance with the terms of the financial covenants contained in our debt agreements. For additional information regarding our debt and the agreements governing our debt, including the covenants contained therein, see Note 9. Debt, Net to the Consolidated Financial Statements included elsewhere in this Quarterly Report on Form 10-Q.

 

Off-Balance Sheet Transactions

 

We do not have any off-balance sheet arrangements with unconsolidated entities or related parties and accordingly, there are no off-balance sheet risks to our liquidity and capital resources from unconsolidated entities.

 

Related Party Transactions

 

The information required set forth under Note 11. Related Party Transactions to the Consolidated Financial Statements is incorporated herein by reference.

 

Summary of Critical Accounting Estimates

 

The preparation of Consolidated Financial Statements in conformity with generally accepted accounting principles in the United States of America requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and the accompanying notes. There have been no significant changes to our critical accounting estimates from those disclosed in our Annual Report on Form 10-K for the year ended December 31, 2022.

 

Recent Accounting Standards

 

We do not believe that any other recently issued, but not yet effective, accounting standards, if currently adopted, would have a material effect on our financial statements.

 

 

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

 

We are exposed to market risk, which includes adverse changes in commodity prices and interest rates as discussed below:

 

Commodity Price Risk

 

Our revenues, operating results, financial condition and ability to borrow funds or obtain additional capital depend substantially on prevailing commodity prices. Historically, coal prices have been volatile, with prices fluctuating widely, and are likely to continue to be volatile. Depressed prices in the future would have a negative impact on our future financial results. In particular, substantially lower prices would significantly reduce revenues and could potentially trigger an impairment of our coal properties or a violation of certain financial debt covenants. Because substantially all our reserves are coal, changes in coal prices have a more significant impact on our financial results. 

 

We are dependent upon the effective marketing of the coal mined by our lessees. Our lessees sell the coal under various long-term and short-term contracts as well as on the spot market. Current conditions in the coal industry may make it difficult for our lessees to extend existing contracts or enter into supply contracts with terms of one year or more. Our lessees' failure to negotiate long-term contracts could adversely affect the stability and profitability of our lessees' operations and adversely affect our future financial results. If more coal is sold on the spot market, coal royalty revenues may become more volatile due to fluctuations in spot coal prices. 

 

The market price of soda ash and energy costs directly affects the profitability of Sisecam Wyoming's operations. If the market price for soda ash declines, Sisecam Wyoming's sales revenues will decrease. Historically, the global market and, to a lesser extent, the domestic market for soda ash have been volatile and are likely to remain volatile in the future. 

 

Interest Rate Risk

 

Our exposure to changes in interest rates results from our borrowings under the Opco Credit Facility, which is subject to variably interest rates based upon SOFR. At June 30, 2023, we had $103.0 million in borrowings outstanding under the Opco Credit Facility. If interest rates were to increase by 1%, annual interest expense would increase approximately $1.0 million, assuming the same principal amount remained outstanding during the year.

 

ITEM 4. CONTROLS AND PROCEDURES

 

Evaluation of Disclosure Controls and Procedures

 

NRP carried out an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) as of the end of the period covered by this report. This evaluation was performed under the supervision and with the participation of NRP management, including the Chief Executive Officer and Chief Financial Officer of the general partner of the general partner of NRP. Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that these disclosure controls and procedures are effective in providing reasonable assurance that (a) the information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms, and (b) such information is accumulated and communicated to our management, including our CEO and CFO, as appropriate to allow timely decisions regarding required disclosure.

 

Changes in the Partnerships Internal Control Over Financial Reporting

 

There were no material changes in the Partnership’s internal control over financial reporting during the first six months of 2023 that materially affected, or were reasonably likely to materially affect, the Partnership’s internal control over financial reporting.

 

 

PART II

ITEM 1. LEGAL PROCEEDINGS

 

From time to time, we are involved in various legal proceedings arising in the ordinary course of business. While the ultimate results of these proceedings cannot be predicted with certainty, we believe these ordinary course matters will not have a material effect on our financial position, liquidity or operations.

 

ITEM 1A. RISK FACTORS

 

During the period covered by this report, there were no material changes from the risk factors previously disclosed in Natural Resource Partners L.P.’s Annual Report on Form 10-K for the year ended December 31, 2022.

 

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

 

None.

 

ITEM 3. DEFAULTS UPON SENIOR SECURITIES

 

None. 

 

ITEM 4. MINE SAFETY DISCLOSURES

 

None.

 

ITEM 5. OTHER INFORMATION

 

None.

 

ITEM 6. EXHIBITS

 

Exhibit

Number

 

Description

3.1

 

Fifth Amended and Restated Agreement of Limited Partnership of Natural Resource Partners L.P., dated as of March 2, 2017 (incorporated by reference to Exhibit 3.1 to Current Report on Form 8-K filed on March 6, 2017).

3.2

 

Fifth Amended and Restated Agreement of Limited Partnership of NRP (GP) LP, dated as of December 16, 2011 (incorporated by reference to Exhibit 3.1 to Current Report on Form 8-K filed on December 16, 2011).

3.3

 

Fifth Amended and Restated Limited Liability Company Agreement of GP Natural Resource Partners LLC, dated as of October 31, 2013 (incorporated by reference to Exhibit 3.1 to Current Report on Form 8-K filed on October 31, 2013).

3.4

 

Certificate of Limited Partnership of Natural Resource Partners L.P. (incorporated by reference to Exhibit 3.1 to the Registration Statement on Form S-1 filed April 19, 2002, File No. 333-86582).

10.1   Sixth Amendment to the Third Amended and Restated Credit Agreement, dated as of May 11, 2023, by and among NRP (Operating) LLC, the lenders party thereto and Zions Bancorporation, N.A. dba Amegy Bank, as administrative agent and collateral agent (incorporated by reference to Exhibit 10.1 to Current Report on Form 8-K filed on May 15, 2023). 

10.2

  New Lender Agreement, dated as of May 11, 2023, by and among NRP (Operating) LLC, Zions Bancorporation, N.A. dba Amegy Bank, and Gulf Capital Bank (incorporated by reference to Exhibit 10.2 to Current Report on Form 8-K filed on May 15, 2023). 
31.1*   Certification of Chief Executive Officer pursuant to Section 302 of Sarbanes-Oxley.
31.2*   Certification of Chief Financial Officer pursuant to Section 302 of Sarbanes-Oxley.
32.1**   Certification of Chief Executive Officer pursuant to 18 U.S.C. § 1350.
32.2**   Certification of Chief Financial Officer pursuant to 18 U.S.C. § 1350.

101.INS*

 

Inline XBRL Instance Document

101.SCH*

 

Inline XBRL Taxonomy Extension Schema Document

101.CAL*

 

Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF*

 

Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB*

 

Inline XBRL Taxonomy Extension Labels Linkbase Document

101.PRE*

 

Inline XBRL Taxonomy Extension Presentation Linkbase Document

104*

 

Cover Page Interactive Data File (formatted as inline XBRL with applicable taxonomy extension information contained in Exhibits 101)

     

*

 

Filed herewith

**

 

Furnished herewith

 

 

SIGNATURES

 

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned and thereunto duly authorized.

 

 

NATURAL RESOURCE PARTNERS L.P.

 

By:

NRP (GP) LP, its general partner

 

By:

GP NATURAL RESOURCE

   

PARTNERS LLC, its general partner

     

Date: August 4, 2023

By:

/s/ Corbin J. Robertson, Jr.
   

Corbin J. Robertson, Jr.

   

Chairman of the Board and

   

Chief Executive Officer

   

(Principal Executive Officer)

     

 

Date: August 4, 2023

By:

/s/ Christopher J. Zolas

   

Christopher J. Zolas

   

Chief Financial Officer

   

(Principal Financial and Accounting Officer)

   

31

Exhibit 31.1

 

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

 

I, Corbin J. Robertson, Jr., certify that: 

 

1

I have reviewed this report on Form 10-Q of Natural Resource Partners L.P.

 

2

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

 

3

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 

4

The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

 

a.

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

 

b.

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

 

c.

Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

 

d.

Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 

5

The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions);

 

 

a.

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

 

 

b.

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 

   

By:

/s/ Corbin J. Robertson, Jr.
 

Corbin J. Robertson, Jr.

 

Chief Executive Officer

   

Date:

August 4, 2023

 

 

Exhibit 31.2

 

CERTIFICATION OF CHIEF FINANCIAL OFFICER

 

I, Christopher J. Zolas, certify that:

 

 

1

I have reviewed this report on Form 10-Q of Natural Resource Partners L.P.

 

2

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

 

3

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

 

4

The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

 

 

a.

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

 

 

b.

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

 

 

c.

Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

 

 

d.

Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

 

5

The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions);

 

 

a.

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

 

 

b.

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 

   

By:

/s/ Christopher J. Zolas
  Christopher J. Zolas
 

Chief Financial Officer

   

Date:

August 4, 2023

 

 

Exhibit 32.1

 

 

CERTIFICATION OF

CHIEF EXECUTIVE OFFICER

OF GP NATURAL RESOURCE PARTNERS LLC

PURSUANT TO 18 U.S.C. § 1350

 

In connection with the accompanying report on Form 10-Q for the quarter ended June 30, 2023 filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Corbin J. Robertson, Jr., Chief Executive Officer of GP Natural Resource Partners LLC, the general partner of the general partner of Natural Resource Partners L.P. (the “Company”), hereby certify, to my knowledge, that:

 

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

 

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

 

By:

/s/ Corbin J. Robertson, Jr.
 

Corbin J. Robertson, Jr.

 

Chief Executive Officer

   

Date:

August 4, 2023

 

Exhibit 32.2

 

 

CERTIFICATION OF

CHIEF FINANCIAL OFFICER

OF GP NATURAL RESOURCE PARTNERS LLC

PURSUANT TO 18 U.S.C. § 1350

 

In connection with the accompanying report on Form 10-Q for the quarter ended June 30, 2023 filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Christopher J. Zolas, Chief Financial Officer of GP Natural Resource Partners LLC, the general partner of the general partner of Natural Resource Partners L.P. (the “Company”), hereby certify, to my knowledge, that:

 

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

 

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

 

By:

/s/ Christopher J. Zolas
 

Christopher J. Zolas

 

Chief Financial Officer

   

Date:

August 4, 2023

 
v3.23.2
Document And Entity Information
6 Months Ended
Jun. 30, 2023
shares
Document Information [Line Items]  
Entity Central Index Key 0001171486
Entity Registrant Name NATURAL RESOURCE PARTNERS LP
Amendment Flag false
Current Fiscal Year End Date --12-31
Document Fiscal Period Focus Q2
Document Fiscal Year Focus 2023
Document Type 10-Q
Document Quarterly Report true
Document Period End Date Jun. 30, 2023
Document Transition Report false
Entity File Number 001-31465
Entity Incorporation, State or Country Code DE
Entity Tax Identification Number 35-2164875
Entity Address, Address Line One 1415 Louisiana Street, Suite 3325
Entity Address, City or Town Houston
Entity Address, State or Province TX
Entity Address, Postal Zip Code 77002
City Area Code 713
Local Phone Number 751-7507
Title of 12(b) Security Common Units representing limited partner interests
Trading Symbol NRP
Security Exchange Name NYSE
Entity Current Reporting Status Yes
Entity Interactive Data Current Yes
Entity Filer Category Accelerated Filer
Entity Small Business false
Entity Emerging Growth Company false
Entity Shell Company false
Entity Common Stock, Shares Outstanding 12,634,642
v3.23.2
Consolidated Balance Sheets (Current Period Unaudited) - USD ($)
$ in Thousands
Jun. 30, 2023
Dec. 31, 2022
Current assets    
Cash and cash equivalents $ 10,730 $ 39,091
Accounts receivable, net 37,120 42,701
Other current assets, net 2,865 1,822
Total current assets 50,715 83,614
Land 24,008 24,008
Mineral rights, net 404,741 412,312
Intangible assets, net 14,432 14,713
Equity in unconsolidated investment 290,900 306,470
Long-term contract receivable, net 27,659 28,946
Other long-term assets, net 7,804 7,068
Total assets 820,259 877,131
Current liabilities    
Accounts payable 1,524 1,992
Accrued liabilities 5,715 11,916
Accrued interest 625 989
Current portion of deferred revenue 6,823 6,256
Current portion of long-term debt, net 36,743 39,076
Total current liabilities 51,430 60,229
Deferred revenue 36,815 40,181
Long-term debt, net 145,693 129,205
Other non-current liabilities 6,462 5,472
Total liabilities 240,400 235,087
Commitments and contingencies (see Note 13)
Class A Convertible Preferred Units (121,667 and 250,000 units issued and outstanding at June 30, 2023 and December 31, 2022, respectively, at $1,000 par value per unit; liquidation preference of $1,850 per unit at June 30, 2023 and December 31, 2022) (See Note 3) 80,099 164,587
Partners’ capital    
Common unitholders’ interest (12,634,642 and 12,505,996 units issued and outstanding at June 30, 2023 and December 31, 2022, respectively) 444,838 404,799
General partner’s interest 6,913 5,977
Warrant holders’ interest 47,964 47,964
Accumulated other comprehensive income (loss) 45 18,717
Total partners’ capital 499,760 477,457
Total liabilities and partners' capital $ 820,259 $ 877,131
v3.23.2
Consolidated Balance Sheets (Current Period Unaudited) (Parentheticals) - $ / shares
Jun. 30, 2023
Dec. 31, 2022
Temporary Equity, shares issued (in shares) 121,667 250,000
Temporary Equity, shares outstanding (in shares) 121,667 250,000
Temporary Equity, par value (in dollars per share) $ 1,000 $ 1,000
Temporary Equity, liquidation (in dollars per share) $ 1,850 $ 1,850
Common unitholders interest, issued (in shares) 12,634,642 12,505,996
Common unitholders interest, outstanding (in shares) 12,634,642 12,505,996
v3.23.2
Consolidated Statements of Comprehensive Income (Unaudited) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Revenues and other income        
Equity in earnings of Sisecam Wyoming $ 26,978 $ 14,643 $ 46,232 $ 29,480
Gain on asset sales and disposals 5 345 101 345
Total revenues and other income 91,260 99,933 190,479 189,649
Operating expenses        
Operating and maintenance expenses 7,930 10,015 15,093 18,091
Depreciation, depletion and amortization 3,792 5,847 7,875 9,715
General and administrative expenses 5,643 5,052 11,488 9,519
Asset impairments 69 43 69 62
Total operating expenses 17,434 20,957 34,525 37,387
Income from operations 73,826 78,976 155,954 152,262
Other expenses, net        
Interest expense, net (3,492) (8,108) (6,345) (17,495)
Loss on extinguishment of debt 0 (4,048) 0 (4,048)
Total other expenses, net (3,492) (12,156) (6,345) (21,543)
Net income 70,334 [1] 66,820 [2] 149,609 130,719
Less: income attributable to preferred unitholders (4,971) (7,500) (11,632) (15,000)
Less: redemption of preferred units (27,618) 0 (43,846) 0
Net income attributable to common unitholders and the general partner 37,745 59,320 94,131 115,719
Net income attributable to common unitholders 36,990 58,134 92,248 113,405
Net income attributable to the general partner $ 755 $ 1,186 $ 1,883 $ 2,314
Net income per common unit (see Note 5)        
Basic (in dollars per share) $ 2.93 $ 4.65 $ 7.32 $ 9.10
Diluted (in dollars per share) $ 2.49 $ 3.29 $ 5.96 $ 6.50
Net income $ 70,334 [1] $ 66,820 [2] $ 149,609 $ 130,719
Comprehensive income (loss) from unconsolidated investment and other 911 (4,013) (18,672) (1,468)
Comprehensive income 71,245 62,807 130,937 129,251
Mineral Rights Segment [Member]        
Operating expenses        
Depreciation, depletion and amortization 3,600 5,400 7,500 9,100
Royalty and Other Mineral Rights [Member] | Mineral Rights Segment [Member]        
Revenues and other income        
Revenues 61,007 79,333 137,278 150,416
Transportation and Processing Services [Member] | Mineral Rights Segment [Member]        
Revenues and other income        
Revenues [3] $ 3,270 $ 5,612 $ 6,868 $ 9,408
[1] Net income includes $5.0 million of income attributable to preferred unitholders that accumulated during the period, of which $4.9 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.
[2] Net income includes $7.5 million of income attributable to preferred unitholders that accumulated during the period, of which $7.4 million is allocated to the common unitholders and $0.2 million is allocated to the general partner.
[3] Transportation and processing services revenues from contracts with customers as defined under ASC 606 was $2.7 million and $4.9 million for the three months ended June 30, 2023 and 2022, respectively and $5.6 million and $8.0 million for the six months ended June 30, 2023 and 2022, respectively. The remaining transportation and processing services revenues of $0.6 million and $0.7 million for the three months ended June 30, 2023 and 2022, respectively, and $1.3 million and $1.4 million for the six months ended June 30, 2023 and 2022, respectively, related to other NRP-owned infrastructure leased to and operated by third-party operators accounted for under other guidance. See Note 15. Financing Transaction for more information.
v3.23.2
Consolidated Statements of Partners' Capital (Unaudited) - USD ($)
shares in Thousands, $ in Thousands
Total
Limited Partner [Member]
General Partner [Member]
Warrant Holder [Member]
AOCI Attributable to Parent [Member]
Balance (in shares) at Dec. 31, 2021   12,351      
Balance at Dec. 31, 2021 $ 256,024 $ 203,062 $ 1,787 $ 47,964 $ 3,211
Net income [1] 63,899 62,621 1,278 0 0
Distributions to common unitholders and the general partner (5,672) (5,559) (113) 0 0
Distributions to preferred unitholders (7,758) $ (7,603) (155) 0 0
Issuance of unit-based awards (in shares)   155      
Unit-based awards amortization and vesting, net (1,754) $ (1,754) 0 0 0
Capital contribution 112 0 112 0 0
Comprehensive loss from unconsolidated investment and other 2,545 $ 0 0 0 2,545
Balance (in shares) at Mar. 31, 2022   12,506      
Balance at Mar. 31, 2022 307,396 $ 250,767 2,909 47,964 5,756
Balance (in shares) at Dec. 31, 2021   12,351      
Balance at Dec. 31, 2021 256,024 $ 203,062 1,787 47,964 3,211
Net income 130,719        
Comprehensive loss from unconsolidated investment and other (1,468)        
Balance (in shares) at Jun. 30, 2022   12,506      
Balance at Jun. 30, 2022 354,364 $ 300,753 3,904 47,964 1,743
Balance (in shares) at Mar. 31, 2022   12,506      
Balance at Mar. 31, 2022 307,396 $ 250,767 2,909 47,964 5,756
Net income [1] 66,820 65,484 1,336 0 0
Distributions to common unitholders and the general partner (9,570) (9,379) (191) 0 0
Distributions to preferred unitholders (7,500) (7,350) (150) 0 0
Unit-based awards amortization and vesting, net 1,231 1,231 0 0 0
Comprehensive loss from unconsolidated investment and other (4,013) $ 0 0 0 (4,013)
Balance (in shares) at Jun. 30, 2022   12,506      
Balance at Jun. 30, 2022 354,364 $ 300,753 3,904 47,964 1,743
Balance (in shares) at Dec. 31, 2022   12,506      
Balance at Dec. 31, 2022 477,457 $ 404,799 5,977 47,964 18,717
Net income [2] 79,275 $ 77,690 1,585    
Redemption of preferred units (in shares)   0      
Redemption of preferred units (16,228) $ (15,904) (324)    
Distributions to common unitholders and the general partner (40,900) (40,082) (818)    
Distributions to preferred unitholders (8,086) $ (7,924) (162)    
Issuance of unit-based awards (in shares)   129      
Unit-based awards amortization and vesting, net (1,178) $ (1,178)      
Capital contribution 142   142    
Comprehensive loss from unconsolidated investment and other (19,583)       (19,583)
Balance (in shares) at Mar. 31, 2023   12,635      
Balance at Mar. 31, 2023 470,899 $ 417,401 6,400 47,964 (866)
Balance (in shares) at Dec. 31, 2022   12,506      
Balance at Dec. 31, 2022 477,457 $ 404,799 5,977 47,964 18,717
Net income 149,609        
Comprehensive loss from unconsolidated investment and other (18,672)        
Balance (in shares) at Jun. 30, 2023   12,635      
Balance at Jun. 30, 2023 499,760 $ 444,838 6,913 47,964 45
Balance (in shares) at Mar. 31, 2023   12,635      
Balance at Mar. 31, 2023 470,899 $ 417,401 6,400 47,964 (866)
Net income [3] 70,334 68,927 1,407 0 0
Redemption of preferred units (27,618) (27,065) (553) 0 0
Distributions to common unitholders and the general partner (9,669) (9,476) (193) 0 0
Distributions to preferred unitholders (7,396) (7,248) (148) 0 0
Unit-based awards amortization and vesting, net 2,299 2,299 0 0 0
Comprehensive loss from unconsolidated investment and other 911 $ 0 0 0 911
Balance (in shares) at Jun. 30, 2023   12,635      
Balance at Jun. 30, 2023 $ 499,760 $ 444,838 $ 6,913 $ 47,964 $ 45
[1] Net income includes $7.5 million of income attributable to preferred unitholders that accumulated during the period, of which $7.4 million is allocated to the common unitholders and $0.2 million is allocated to the general partner.
[2] Net income includes $6.7 million of income attributable to preferred unitholders that accumulated during the period, of which $6.5 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.
[3] Net income includes $5.0 million of income attributable to preferred unitholders that accumulated during the period, of which $4.9 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.
v3.23.2
Consolidated Statements of Partners' Capital (Unaudited) (Parentheticals) - USD ($)
$ in Thousands
3 Months Ended
Jun. 30, 2023
Mar. 31, 2023
Jun. 30, 2022
Mar. 31, 2022
Allocation to unitholders $ 4,971 $ 6,700 $ 7,500 $ 7,500
Limited Partner [Member]        
Allocation to unitholders 4,900 6,500 7,400 7,400
General Partner [Member]        
Allocation to unitholders $ 100 $ 100 $ 200 $ 200
v3.23.2
Consolidated Statements of Cash Flows (Unaudited) - USD ($)
$ in Thousands
6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Cash flows from operating activities    
Net income $ 149,609 $ 130,719
Adjustments to reconcile net income to net cash provided by operating activities:    
Depreciation, depletion and amortization 7,875 9,715
Distributions from unconsolidated investment 43,130 23,716
Equity earnings from unconsolidated investment (46,232) (29,480)
Gain on asset sales and disposals (101) (345)
Loss on extinguishment of debt 0 4,048
Asset impairments 69 62
Bad debt expense (808) 640
Unit-based compensation expense 5,137 2,787
Amortization of debt issuance costs and other 566 1,672
Change in operating assets and liabilities:    
Accounts receivable 6,700 (12,612)
Accounts payable (469) 13
Accrued liabilities (6,786) (5,109)
Accrued interest (364) (163)
Deferred revenue (2,800) (9,575)
Other items, net (1,276) (634)
Net cash provided by operating activities 154,250 115,454
Cash flows from investing activities    
Proceeds from asset sales and disposals 106 346
Return of long-term contract receivable 1,208 563
Capital expenditures (10) 0
Net cash provided by investing activities 1,304 909
Cash flows from financing activities    
Debt borrowings 165,034 0
Debt repayments (151,061) (137,171)
Redemption of preferred units (128,333) 0
Redemption of preferred units paid-in-kind 0 (19,321)
Other items, net (3,504) (5,535)
Net cash used in financing activities (183,915) (192,527)
Net decrease in cash and cash equivalents (28,361) (76,164)
Cash and cash equivalents at beginning of period 39,091 135,520
Cash and cash equivalents at end of period 10,730 59,356
Supplemental cash flow information:    
Cash paid for interest 6,434 16,772
Common Unitholders And General Partner [Member]    
Cash flows from financing activities    
Distributions to unitholders (50,569) (15,242)
Preferred Partner [Member]    
Cash flows from financing activities    
Distributions to unitholders $ (15,482) $ (15,258)
v3.23.2
Note 1 - Basis of Presentation
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Basis of Presentation and Significant Accounting Policies [Text Block]

1.    Basis of Presentation

 

Nature of Business

 

Natural Resource Partners L.P. (the "Partnership") engages principally in the business of owning, managing and leasing a diversified portfolio of mineral properties in the United States, including interests in coal and other natural resources and owns a non-controlling 49% interest in Sisecam Wyoming LLC ("Sisecam Wyoming"), a trona ore mining and soda ash production business. The Partnership is organized into two operating segments further described in Note 6. Segment Information. The Partnership’s operations are conducted through, and its operating assets are owned by, its subsidiaries. The Partnership owns its subsidiaries through one wholly owned operating company, NRP (Operating) LLC ("Opco"). As used in these Notes to Consolidated Financial Statements, the terms "NRP," "we," "us" and "our" refer to Natural Resource Partners L.P. and its subsidiaries, unless otherwise stated or indicated by context.

 

Principles of Consolidation and Reporting

 

The accompanying unaudited Consolidated Financial Statements of the Partnership have been prepared in accordance with generally accepted accounting principles in the United States of America ("GAAP") for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. These financial statements should be read in conjunction with the financial statements for the year ended December 31, 2022 and notes thereto included in the Partnership's Annual Report on Form 10-K, which was filed with the SEC on March 3, 2023. Reclassifications have been made to prior year amounts in the Consolidated Financial Statements to conform with current year presentation. These reclassifications had no impact on previously reported total assets, total liabilities, partners' capital, net income, or cash flows from operating, investing or financing activities.

 

Recently Adopted Accounting Standard

 

On January 1, 2023, NRP adopted Accounting Standards Update ("ASU") 2020-06, Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40) (“ASU 2020-06)”. The ASU includes targeted improvements to earnings per share, which the Partnership adopted on a modified retrospective basis. The adoption of this ASU did not have a material impact on the Partnership’s Consolidated Financial Statements. See Note 5. Net Income Per Common Unit for the calculations of our basic and diluted net income per common unit. See Note 3. Class A Convertible Preferred Units and Warrants for disclosures related to our convertible preferred units and warrants.

 

v3.23.2
Note 2 - Revenues From Contracts With Customers
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Revenue from Contract with Customer [Text Block]

2.    Revenues from Contracts with Customers

 

The following table presents the Partnership's Mineral Rights segment revenues by major source:

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Coal royalty revenues

 $47,960  $62,945  $105,983  $118,394 

Production lease minimum revenues

  562   65   1,175   1,657 

Minimum lease straight-line revenues

  4,447   4,674   8,950   9,457 

Carbon neutral initiative revenues

  115      2,233    

Property tax revenues

  1,470   1,695   2,940   3,167 

Wheelage revenues

  3,284   4,379   7,153   8,096 

Coal overriding royalty revenues

  150   682   338   940 

Lease amendment revenues

  848   811   1,699   1,691 

Aggregates royalty revenues

  686   1,037   1,439   1,807 

Oil and gas royalty revenues

  1,214   2,906   4,802   4,720 

Other revenues

  271   139   566   487 

Royalty and other mineral rights revenues

 $61,007  $79,333  $137,278  $150,416 

Transportation and processing services revenues (1)

  3,270   5,612   6,868   9,408 

Total Mineral Rights segment revenues

 $64,277  $84,945  $144,146  $159,824 
     
(1)

Transportation and processing services revenues from contracts with customers as defined under ASC 606 was $2.7 million and $4.9 million for the three months ended June 30, 2023 and 2022, respectively and $5.6 million and $8.0 million for the six months ended June 30, 2023 and 2022, respectively. The remaining transportation and processing services revenues of $0.6 million and $0.7 million for the three months ended June 30, 2023 and 2022, respectively, and $1.3 million and $1.4 million for the six months ended June 30, 2023 and 2022, respectively, related to other NRP-owned infrastructure leased to and operated by third-party operators accounted for under other guidance. See Note 15. Financing Transaction for more information.

 

The following table details the Partnership's Mineral Rights segment receivables and liabilities resulting from contracts with customers:

 

  

June 30,

  

December 31,

 

(In thousands)

 

2023

  

2022

 

Receivables

        

Accounts receivable, net

 $33,370  $39,004 

Other current assets, net (1)

  2,155    

Other long-term assets, net (2)

     75 
         

Contract liabilities

        

Current portion of deferred revenue

 $6,823  $6,256 

Deferred revenue

  36,815   40,181 
     
(1)

Other current assets, net includes short-term notes receivables from contracts with customers.

(2)

Other long-term assets, net includes long-term lease amendment fee receivables from contracts with customers.

 

The following table shows the activity related to the Partnership's Mineral Rights segment deferred revenue:

 

  

For the Six Months Ended June 30,

 

(In thousands)

 

2023

  

2022

 

Balance at beginning of period (current and non-current)

 $46,437  $61,862 

Increase due to minimums and lease amendment fees

  10,810   7,997 

Recognition of previously deferred revenue

  (13,609)  (17,573)

Balance at end of period (current and non-current)

 $43,638  $52,286 

 

The Partnership's non-cancelable annual minimum payments due under the lease terms of its coal and aggregates royalty leases are as follows as of  June 30, 2023 (in thousands):

 

Lease Term (1)

 

Weighted Average Remaining Years

  

Annual Minimum Payments

 

0 - 5 years

  1.7  $22,230 

5 - 10 years

  3.1   7,417 

10+ years

  12.1   27,129 

Total

  6.8  $56,776 
     
(1)

Lease term does not include renewal periods.

 

v3.23.2
Note 3 - Class A Convertible Preferred Units and Warrants
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Preferred Stock [Text Block]

3.      Class A Convertible Preferred Units and Warrants

 

On March 2, 2017, NRP issued $250 million of Class A Convertible Preferred Units representing limited partner interests in NRP (the "preferred units") to certain entities controlled by funds affiliated with The Blackstone Group Inc. (collectively referred to as "Blackstone") and certain affiliates of GoldenTree Asset Management LP (collectively referred to as "GoldenTree") (together the "preferred purchasers") pursuant to a Preferred Unit and Warrant Purchase Agreement. NRP issued 250,000 preferred units to the preferred purchasers at a price of $1,000 per preferred unit (the "per unit purchase price"), less a 2.5% structuring and origination fee. The preferred units entitle the preferred purchasers to receive cumulative distributions at a rate of 12% of the purchase price per year, up to one half of which NRP may pay in additional preferred units (such additional preferred units, the "PIK units"). The preferred units have a perpetual term, unless converted or redeemed as described below.

 

NRP also issued two tranches of warrants (the "warrants") to purchase common units to the preferred purchasers (warrants to purchase 1.75 million common units with a strike price of $22.81 and warrants to purchase 2.25 million common units with a strike price of $34.00). The warrants may be exercised by the holders thereof at any time before the eighth anniversary of the closing date. Upon exercise of the warrants, NRP may, at its option, elect to settle the warrants in common units or cash, each on a net basis.

 

After March 2, 2022 and prior to March 2, 2025, the holders of the preferred units may elect to convert up to 33% of the outstanding preferred units in any 12-month period into common units if the volume weighted average trading price of our common units (the "VWAP") for the 30 trading days immediately prior to date notice is provided is greater than $51.00. In such case, the number of common units to be issued upon conversion would be equal to the per unit purchase price plus the value of any accrued and unpaid distributions divided by an amount equal to a 7.5% discount to the VWAP for the 30 trading days immediately prior to the notice of conversion. Rather than have the preferred units convert to common units in accordance with the provisions of this paragraph, NRP would have the option to elect to redeem the preferred units proposed to be converted for cash at a price equal to the per unit purchase price plus the value of any accrued and unpaid distributions.

 

On or after March 2, 2025, the holders of the preferred units may elect to convert the preferred units to common units at a conversion rate equal to the Liquidation Value divided by an amount equal to a 10% discount to the VWAP for the 30 trading days immediately prior to the notice of conversion. The “liquidation value” will be an amount equal to the greater of: (1) (a) the per unit purchase price multiplied by (i) prior to March 2, 2020, 1.50, (ii) on or after March 2, 2020 and prior to March 2, 2021, 1.70 and (iii) on or after March 2, 2021, 1.85, less (b)(i) all preferred unit distributions previously made by NRP and (ii) all cash payments previously made in respect of redemption of any PIK units; and (2) the per unit purchase price plus the value of all accrued and unpaid distributions.

 

To the extent the holders of the preferred units have not elected to convert their preferred units before March 2, 2029, NRP has the right to force conversion of the preferred units at a price equal to the liquidation value divided by an amount equal to a 10% discount to the VWAP for the 30 trading days immediately prior to the notice of conversion.

 

In addition, NRP has the ability to redeem at any time (subject to compliance with its debt agreements) all or any portion of the preferred units and any outstanding PIK units for cash. The redemption price for each outstanding PIK unit is $1,000 plus the value of any accrued and unpaid distributions per PIK unit. The redemption price for each preferred unit is the liquidation value divided by the number of outstanding preferred units. The preferred units are redeemable at the option of the preferred purchasers only upon a change in control.

 

The terms of the preferred units contain certain restrictions on NRP's ability to pay distributions on its common units. To the extent that either (i) NRP's consolidated Leverage Ratio, as defined in the Partnership's Fifth Amended and Restated Partnership Agreement dated March 2, 2017 (the "restated partnership agreement"), is greater than 3.25x, or (ii) the ratio of NRP's Distributable Cash Flow (as defined in the Restated Partnership Agreement) to cash distributions made or proposed to be made is less than 1.2x (in each case, with respect to the most recently completed four-quarter period), NRP may not increase the quarterly distribution above $0.45 per quarter without the approval of the holders of a majority of the outstanding preferred units. In addition, if at any time after January 1, 2022, any PIK units are outstanding, NRP may not make distributions on its common units until it has redeemed all PIK units for cash.

 

The holders of the preferred units have the right to vote with holders of NRP’s common units on an as-converted basis and have other customary approval rights with respect to changes of the terms of the preferred units. In addition, Blackstone has certain approval rights over certain matters as identified in the restated partnership agreement. GoldenTree also has more limited approval rights that will expand once Blackstone's ownership goes below the minimum preferred unit threshold (as defined below). These approval rights are not transferrable without NRP's consent. In addition, the approval rights held by Blackstone and GoldenTree will terminate at such time that Blackstone (together with their affiliates) or GoldenTree (together with their affiliates), as applicable, no longer own at least 20% of the total number of preferred units issued on the closing date, together with all PIK units that have been issued but not redeemed (the "minimum preferred unit threshold").

 

At the closing, pursuant to the Board Representation and Observation Rights Agreement, the Preferred Purchasers received certain board appointment and observation rights, and Blackstone appointed one director and one observer to the Board of Directors.

 

NRP also entered into a registration rights agreement (the "preferred unit and warrant registration rights agreement") with the preferred purchasers, pursuant to which NRP is required to file (i) a shelf registration statement to register the common units issuable upon exercise of the warrants and to cause such registration statement to become effective not later than 90 days following the closing date and (ii) a shelf registration statement to register the common units issuable upon conversion of the preferred units and to cause such registration statement to become effective not later than the earlier of the fifth anniversary of the closing date or 90 days following the first issuance of any common units upon conversion of preferred units (the "registration deadlines"). In addition, the preferred unit and warrant registration rights agreement gives the preferred purchasers piggyback registration and demand underwritten offering rights under certain circumstances. The shelf registration statement to register the common units issuable upon exercise of the warrants became effective on April 20, 2017. If the shelf registration statement to register the common units issuable upon conversion of the preferred units is not effective by the applicable registration deadline, NRP will be required to pay the preferred purchasers liquidated damages in the amounts and upon the term set forth in the preferred unit and warrant registration rights agreement.

 

Accounting for the Preferred Units and Warrants

 

Classification

 

The preferred units are accounted for as temporary equity on NRP's Consolidated Balance Sheets due to certain contingent redemption rights that may be exercised at the election of preferred purchasers. The warrants are accounted for as equity on NRP's Consolidated Balance Sheets.

 

Initial Measurement

 

The net transaction price was allocated to the preferred units and warrants based on their relative fair values at inception date. NRP allocated the transaction issuance costs to the preferred units and warrants primarily on a pro-rata basis based on their relative inception date allocated values.

 

Subsequent Measurement

 

Preferred Units

 

Subsequent adjustment of the preferred units will not occur until NRP has determined that the conversion or redemption of all or a portion of the preferred units is probable of occurring. Once conversion or redemption becomes probable of occurring, the carrying amount of the preferred units will be accreted to their redemption value over the period from the date the feature is probable of occurring to the date the preferred units can first be converted or redeemed. 

 

In  February 2023, the Partnership received a notice from holders of the Class A Preferred Units exercising their right to either convert or redeem, at the election of NRP, an aggregate of 47,499 Class A Preferred Units. The Partnership chose to redeem the preferred units for $47.5 million in cash rather than issuing common units. In May 2023, the Partnership received a notice from holders of the Class A Preferred Units exercising their right to either convert or redeem, at the election of NRP, an aggregate of 35,834 Class A Preferred Units. The Partnership chose to redeem the preferred units for $35.8 million in cash rather than issuing common units. In June 2023, the Partnership executed a negotiated transaction with holders of the Class A Preferred Units pursuant to which it repurchased and retired an aggregate of 45,000 Class A Preferred Units for $45.0 million in cash. Of the originally issued 250,000 Class A Preferred Units, 121,667 Class A Preferred Units remain outstanding as of June 30, 2023.

 

Activity related to the preferred units is as follows:

 

  

Units

  

Financial

 

(In thousands, except unit data)

 

Outstanding

  

Position

 

Balance at December 31, 2021

  269,321  $183,908 

Redemption of preferred units paid-in-kind

  (19,321)  (19,321)

Balance at December 31, 2022

  250,000  $164,587 

Redemption of preferred units

  (128,333)  (84,488)

Balance at June 30, 2023

  121,667  $80,099 

 

Warrants

 

As of June 30, 2023 and December 31, 2022 there were 3.0 million warrants outstanding, which included warrants to purchase 0.75 million common units at a strike price of $22.81 and warrants to purchase 2.25 million common units with a strike price of $34.00. These warrants had a $48.0 million carrying value included in warrant holders' interest within partners' capital on the Partnership's Consolidated Balance Sheets at June 30, 2023 and December 31, 2022. Subsequent adjustment of the warrants will not occur until the warrants are exercised, at which time, NRP may, at its option, elect to settle the warrants in common units or cash, each on a net basis. The net basis will be equal to the difference between the Partnership's common unit price and the strike price of the warrant. Once warrant exercise occurs, the difference between the carrying amount of the warrants and the net settlement amount will be allocated on a pro-rata basis to the common unitholders and general partner.

 

Embedded Features

 

Certain embedded features within the preferred unit and warrant purchase agreement are accounted for at fair value and are remeasured each quarter. See Note 10. Fair Value Measurements for further information regarding valuation of these embedded derivatives.

 

v3.23.2
Note 4 - Common and Preferred Unit Distributions
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Partners' Capital Notes Disclosure [Text Block]

4.    Common and Preferred Unit Distributions

 

The Partnership makes cash distributions to common and preferred unitholders on a quarterly basis, subject to approval by the Board of Directors of GP Natural Resource Partners LLC (the "Board of Directors"). NRP recognizes both common unit and preferred unit distributions on the date the distribution is declared.

 

Distributions made on the common units and the general partner's general partner ("GP") interest are made on a pro-rata basis in accordance with their relative percentage interests in the Partnership. The general partner is entitled to receive 2% of such distributions.

 

Income available to common unitholders and the general partner is reduced by preferred unit distributions that accumulated during the period. NRP reduced net income available to common unitholders and the general partner by $5.0 million and $7.5 million during the three months ended June 30, 2023 and 2022, respectively, and $11.6 million and $15.0 million for the six months ended June 30, 2023 and 2022, respectively, as a result of accumulated preferred unit distributions earned during the period. Of the $6.7 million in accumulated preferred unit distributions earned during March 31, 2023, $0.6 million was paid in February 2023 in connection with the preferred units that were redeemed in February. Of the $5.0 million in accumulated preferred unit distributions earned during June 30, 2023, $0.4 million was paid in May 2023 and $0.9 million was paid in June 2023 in connection with the preferred units that were redeemed during those months. Income available to common unitholders and the general partner is also reduced by the difference between the fair value of the consideration paid upon redemption and the carrying value of the preferred units. As such, NRP reduced net income available to common unitholders and the general partner by $27.6 million and $43.8 million during the three and six months ended June 30, 2023, respectively. 

 

The following table shows the cash distributions declared and paid to common and preferred unitholders during the six months ended June 30, 2023 and 2022, respectively:

 

                   
    

Common Units

  

Preferred Units

 

Month Paid

 

Period Covered by Distribution

 

Distribution per Unit

  

Total Distribution (1) (In thousands)

  

Distribution per Unit

  

Total Distribution (In thousands)

 

2023

                  

February 2023

 

October 1 - December 31, 2022

 $0.75  $9,571  $30.00  $7,500 

February 2023 (2)

 

January 1 - February 8, 2023

        12.33   586 

March 2023 (3)

 

Special Distribution

  2.43   31,329       

May 2023

 

January 1 - March 31, 2023

  0.75   9,669   30.00   6,075 

May 2023 (4)

 

April 1 - May 5, 2023

        11.33   406 

June 2023 (5)

 

April 1 - June 2, 2023

        20.33   915 
                   

2022

                  

February 2022

 

October 1 - December 31, 2021

 $0.45  $5,672  $30.00  $7,500 

February 2022 (6)

 

January 1 - February 8, 2022

        13.35   258 

May 2022

 

January 1 - March 31, 2022

  0.75   9,570   30.00   7,500 
     
(1)

Totals include the amount paid to NRP's general partner in accordance with the general partner's 2% general partner interest.

(2)Relates to accrued distribution paid upon the redemption of 47,499 preferred units in February 2023.
(3)Special distribution was made to help cover unitholder tax liabilities associated with owning NRP's common units during 2022.
(4)Relates to accrued distribution paid upon the redemption of 35,834 preferred units in May 2023.
(5)Relates to accrued distribution paid upon the redemption of 45,000 preferred units in June 2023.
(6)Relates to accrued distribution paid upon the redemption of 19,321 preferred units paid-in-kind in February 2022.

 

v3.23.2
Note 5 - Net Income Per Common Unit
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Earnings Per Share [Text Block]

5.    Net Income Per Common Unit

 

Basic net income per common unit is computed by dividing net income, after considering income attributable to preferred unitholders, the difference between the fair value of the consideration paid upon redemption and the carrying value of the preferred units and the general partner’s general partner interest, by the weighted average number of common units outstanding. Diluted net income per common unit includes the effect of NRP's preferred units, warrants, and unvested unit-based awards if the inclusion of these items is dilutive.

 

The dilutive effect of the preferred units is calculated using the if-converted method. Under the if-converted method, the preferred units are assumed to be converted at the beginning of the period, and the resulting common units are included in the denominator of the diluted net income per unit calculation for the period being presented. Distributions declared in the period and undeclared distributions on the preferred units that accumulated during the period are added back to the numerator for purposes of the if-converted calculation. The calculation of diluted net income per common unit for the three and six months ended June 30, 2023 includes the assumed conversion of the remaining preferred units while it does not include the assumed conversion of the preferred units that were redeemed during the three and six months ended June 30, 2023 as the inclusion of these units would be anti-dilutive. The calculation of diluted net income per common unit for the three and six months ended June 30, 2022 includes the assumed conversion of the preferred units.

 

The dilutive effect of the warrants is calculated using the treasury stock method, which assumes that the proceeds from the exercise of these instruments are used to purchase common units at the average market price for the period. The calculation of diluted net income per common unit for the three and six months ended June 30, 2023 and 2022 includes the net settlement of warrants to purchase 0.75 million common units at a strike price of $22.81 and the net settlement of warrants to purchase 2.25 million common units with a strike price of $34.00.

 

The following table reconciles the numerator and denominator of the basic and diluted net income per common unit computations and calculates basic and diluted net income per common unit:

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands, except per unit data)

 

2023

  

2022

  

2023

  

2022

 

Basic net income per common unit

                

Net income attributable to common unitholders

 $36,990  $58,134  $92,248  $113,405 

Weighted average common units—basic

  12,635   12,506   12,603   12,461 

Basic net income per common unit

 $2.93  $4.65  $7.32  $9.10 
                 

Diluted net income per common unit

                

Weighted average common units—basic

  12,635   12,506   12,603   12,461 

Plus: dilutive effect of preferred units

  2,420   6,292   3,099   6,292 

Plus: dilutive effect of warrants

  1,139   937   1,197   734 

Plus: dilutive effect of unvested unit-based awards

  122   178   165   209 

Weighted average common units—diluted

  16,316   19,913   17,064   19,696 
                 

Net income

 $70,334  $66,820  $149,609  $130,719 

Less: income attributable to preferred unitholders

  (1,321)     (1,907)   

Less: redemption of preferred units

  (27,618)     (43,846)   

Diluted net income attributable to common unitholders and the general partner

 $41,395  $66,820  $103,856  $130,719 

Less: diluted net income attributable to the general partner

  (828)  (1,336)  (2,077)  (2,614)

Diluted net income attributable to common unitholders

 $40,567  $65,484  $101,779  $128,105 
                 

Diluted net income per common unit

 $2.49  $3.29  $5.96  $6.50 

 

v3.23.2
Note 6 - Segment Information
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Segment Reporting Disclosure [Text Block]

6.    Segment Information

 

The Partnership's segments are strategic business units that offer distinct products and services to different customers in different geographies within the U.S. and that are managed accordingly. NRP has the following two operating segments:

 

Mineral Rights—consists of mineral interests and other subsurface rights across the United States. NRP's ownership provides critical inputs for the manufacturing of steel, electricity and basic building materials, as well as opportunities for carbon sequestration and renewable energy. The Partnership is working to strategically redefine its business as a key player in the transitional energy economy in the years to come.

 

Soda Ash—consists of the Partnership's 49% non-controlling equity interest in Sisecam Wyoming, a trona ore mining operation and soda ash refinery in the Green River Basin of Wyoming. Sisecam Wyoming mines trona and processes it into soda ash that is sold both domestically and internationally to the glass and chemicals industries.

 

Direct segment costs and certain other costs incurred at the corporate level that are identifiable and that benefit the Partnership's segments are allocated to the operating segments accordingly. These allocated costs generally include salaries and benefits, insurance, property taxes, legal, royalty, information technology and shared facilities services and are included in operating and maintenance expenses on the Partnership's Consolidated Statements of Comprehensive Income.

 

Corporate and Financing includes functional corporate departments that do not earn revenues. Costs incurred by these departments include interest and financing, corporate headquarters and overhead, centralized treasury, legal and accounting and other corporate-level activity not specifically allocated to a segment and are included in general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income.

 

The following table summarizes certain financial information for each of the Partnership's business segments:

 

  

Operating Segments

         

(In thousands)

 

Mineral Rights

  

Soda Ash

  

Corporate and Financing

  

Total

 

For the Three Months Ended June 30, 2023

                

Revenues

 $64,277  $26,978  $  $91,255 

Gain on asset sales and disposals

  5         5 

Operating and maintenance expenses

  7,916   14      7,930 

Depreciation, depletion and amortization

  3,787      5   3,792 

General and administrative expenses

        5,643   5,643 

Asset impairments

  69         69 

Other expenses, net

        3,492   3,492 

Net income (loss)

  52,510   26,964   (9,140)  70,334 
                 

For the Three Months Ended June 30, 2022

                

Revenues

 $84,945  $14,643  $  $99,588 

Gain on asset sales and disposals

  345         345 

Operating and maintenance expenses

  9,992   23      10,015 

Depreciation, depletion and amortization

  5,847         5,847 

General and administrative expenses

        5,052   5,052 

Asset impairments

  43         43 

Other expenses, net

        12,156   12,156 

Net income (loss)

  69,408   14,620   (17,208)  66,820 
                 

For the Six Months Ended June 30, 2023

                

Revenues

 $144,146  $46,232  $  $190,378 

Gain on asset sales and disposals

  101         101 

Operating and maintenance expenses

  14,921   172      15,093 

Depreciation, depletion and amortization

  7,866      9   7,875 

General and administrative expenses

        11,488   11,488 

Asset impairments

  69         69 

Other expenses, net

        6,345   6,345 

Net income (loss)

  121,391   46,060   (17,842)  149,609 
                 

For the Six Months Ended June 30, 2022

                

Revenues

 $159,824  $29,480  $  $189,304 

Gain on asset sales and disposals

  345         345 

Operating and maintenance expenses

  18,017   74      18,091 

Depreciation, depletion and amortization

  9,715         9,715 

General and administrative expenses

        9,519   9,519 

Asset impairments

  62         62 

Other expenses, net

        21,543   21,543 

Net income (loss)

  132,375   29,406   (31,062)  130,719 

 

v3.23.2
Note 7 - Equity Investment
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Equity Method Investments and Joint Ventures Disclosure [Text Block]

7.    Equity Investment

 

The Partnership accounts for its 49% investment in Sisecam Wyoming using the equity method of accounting. Activity related to this investment is as follows: 

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Balance at beginning of period

 $295,361  $280,156  $306,470  $276,004 

Income allocation to NRP’s equity interests (1)

  28,212   15,804   48,576   31,869 

Amortization of basis difference

  (1,234)  (1,161)  (2,344)  (2,389)

Other comprehensive income (loss)

  911   (4,013)  (18,672)  (1,468)

Distribution

  (32,350)  (10,486)  (43,130)  (23,716)

Balance at end of period

 $290,900  $280,300  $290,900  $280,300 
     
(1)Amounts reclassified into income out of accumulated other comprehensive loss were $2.3 million and $(3.0) million for the three months ended June 30, 2023 and 2022, respectively, and $(18.3) million and $(4.7) million for the six months ended June 30, 2023 and 2022, respectively. 

 

The following table represents summarized financial information for Sisecam Wyoming as derived from their respective unaudited financial statements for the three and six months ended June 30, 2023 and 2022:

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Net sales

 $201,365  $189,068  $408,493  $352,505 

Gross profit

  64,554   40,279   113,609   80,044 

Net income

  57,574   32,253   99,134   65,039 

 

v3.23.2
Note 8 - Mineral Rights, Net
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Mineral Industries Disclosures [Text Block]

8.    Mineral Rights, Net

 

The Partnership’s mineral rights consist of the following:

 

  

June 30, 2023

  

December 31, 2022

 

(In thousands)

 

Carrying Value

  

Accumulated Depletion

  

Net Book Value

  

Carrying Value

  

Accumulated Depletion

  

Net Book Value

 

Coal properties

 $661,743  $(276,085) $385,658  $661,812  $(269,037) $392,775 

Aggregates properties

  8,655   (3,618)  5,037   8,655   (3,410)  5,245 

Oil and gas royalty properties

  12,354   (9,841)  2,513   12,354   (9,600)  2,754 

Other

  13,145   (1,612)  11,533   13,150   (1,612)  11,538 

Total mineral rights, net

 $695,897  $(291,156) $404,741  $695,971  $(283,659) $412,312 

 

Depletion expense related to the Partnership’s mineral rights is included in depreciation, depletion and amortization on its Consolidated Statements of Comprehensive Income and totaled $3.6 million and $5.4 million for the three months ended June 30, 2023 and 2022, respectively and $7.5 million and $9.1 million for the six months ended June 30, 2023 and 2022, respectively.

 

The Partnership has developed procedures to evaluate its long-lived assets for possible impairment periodically or whenever events or changes in circumstances indicate an asset's net book value may not be recoverable. Potential events or circumstances include, but are not limited to, specific events such as a reduction in economically recoverable reserves or production ceasing on a property for an extended period. This analysis is based on historic, current and future performance and considers both quantitative and qualitative information. As a result of the analysis, the Partnership recorded immaterial impairment expenses during the three and six months ended June 30, 2023 and 2022. 

 

v3.23.2
Note 9 - Debt, Net
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Debt Disclosure [Text Block]

9.    Debt, Net

 

The Partnership's debt consists of the following:

 

  

June 30,

  

December 31,

 

(In thousands)

 

2023

  

2022

 

Opco Credit Facility

 $103,034  $70,000 

Opco Senior Notes

        

5.55% with semi-annual interest payments in June and December, with annual principal payments in June, due June 2023

 $  $2,366 

4.73% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2023

  6,004   6,004 

5.82% with semi-annual interest payments in March and September, with annual principal payments in March, due March 2024

  12,684   25,368 

8.92% with semi-annual interest payments in March and September, with annual principal payments in March, due March 2024

  4,011   8,023 

5.03% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026

  45,683   45,683 

5.18% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026

  11,643   11,643 

Total Opco Senior Notes

 $80,025  $99,087 

Total debt at face value

 $183,059  $169,087 

Net unamortized debt issuance costs

  (623)  (806)

Total debt, net

 $182,436  $168,281 

Less: current portion of long-term debt

  (36,743)  (39,076)

Total long-term debt, net

 $145,693  $129,205 

 

Opco Debt

 

All of Opco’s debt is guaranteed by its wholly owned subsidiaries and is secured by certain of the assets of Opco and its wholly owned subsidiaries, other than BRP LLC and NRP Trona LLC. As of June 30, 2023 and December 31, 2022, Opco was in compliance with the terms of the financial covenants contained in its debt agreements.

 

Opco Credit Facility

 

In May 2023, the Partnership entered into the Sixth Amendment (the "Sixth Amendment) to the Opco Credit Facility (the "Opco Credit Facility"). The Sixth Amendment maintained the term of the Opco Credit Facility until August 2027. Lender commitments under the Opco Credit Facility increased from $130.0 million to $155.0 million, with the ability to expand such commitments to $200.0 million with the addition of future commitments and. The Sixth Amendment also includes modifications to Opco’s ability to declare and make certain restricted payments. The Opco Credit Facility contains financial covenants requiring Opco to maintain:

 

A leverage ratio of consolidated indebtedness to EBITDDA (in each case as defined in the Opco Credit Facility) not to exceed 3.0x; provided, and

 

an interest coverage ratio of consolidated EBITDDA to the sum of consolidated interest expense and consolidated lease expense (in each case as defined in the Opco Credit Facility) of not less than 3.5 to 1.0.

 

As of December 31, 2022, the Partnership had $70.0 million in borrowings outstanding under the Opco Credit Facility. During the six months ended June 30, 2023, the Partnership borrowed $165.0 million and repaid $132.0 million, resulting in $103.0 million in borrowings outstanding under the Opco Credit Facility as of June 30, 2023. The weighted average interest rate for the borrowings outstanding under the Opco Credit Facility for the three and six months ended June 30, 2023 was 8.61% and 8.44%, respectively. During the three and six months ended June 30, 2022, the Partnership did not have any borrowings outstanding under the Opco Credit Facility. The Partnership had $52.0 million and $60.0 million of available borrowing capacity as of June 30, 2023 and December 31, 2022, respectively.

 

The Opco Credit Facility is collateralized and secured by liens on certain of Opco’s assets with carrying values of $320.0 million and $326.4 million classified as mineral rights, net and other long-term assets, net on the Partnership’s Consolidated Balance Sheets as of June 30, 2023 and December 31, 2022, respectively.

 

Opco Senior Notes   

 

Opco has issued several series of private placement senior notes (the "Opco Senior Notes") with various interest rates and principal due dates. As of June 30, 2023 and December 31, 2022, the Opco Senior Notes had cumulative principal balances of $80.0 million and $99.1 million, respectively. Opco made mandatory principal payments of $19.1 million during the six months ended June 30, 2023 and 2022.

 

The 8.92% Opco Senior Notes also provides that in the event that Opco’s leverage ratio of consolidated indebtedness to consolidated EBITDDA (as defined in the Note Purchase Agreements) exceeds 3.75 to 1.00 at the end of any fiscal quarter, then in addition to all other interest accruing on these notes, additional interest in the amount of 2.00% per annum shall accrue on the notes for the two succeeding quarters and for as long thereafter as the leverage ratio remains above 3.75 to 1.00. Opco has not exceeded the 3.75 to 1.00 ratio at the end of any fiscal quarter through June 30, 2023.

 

v3.23.2
Note 10 - Fair Value Measurements
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Fair Value Disclosures [Text Block]

10.    Fair Value Measurements

 

Fair Value of Financial Assets and Liabilities

 

The Partnership’s financial assets and liabilities consist of cash and cash equivalents, a contract receivable and debt. The carrying amounts reported on the Consolidated Balance Sheets for cash and cash equivalents approximate fair value due to their short-term nature. The Partnership uses available market data and valuation methodologies to estimate the fair value of its debt and contract receivable.

 

The following table shows the carrying value and estimated fair value of the Partnership's debt and contract receivable:

 

      

June 30, 2023

  

December 31, 2022

 
  

Fair Value

  

Carrying

  

Estimated

  

Carrying

  

Estimated

 

(In thousands)

 

Hierarchy Level

  

Value

  

Fair Value

  

Value

  

Fair Value

 

Debt:

                    

Opco Senior Notes (1)

  3  $79,402  $75,848  $98,281  $96,060 

Opco Credit Facility (2)

  3   103,034   103,034   70,000   70,000 
                     

Assets:

                    

Contract receivable, net (current and long-term) (3)

  3  $30,182  $25,254  $31,371  $24,833 
     
(1)The fair value of the Opco Senior Notes at June 30, 2023 and December 31, 2022 were estimated by management utilizing the present value replacement method incorporating the interest rate of the Opco Credit facility at June 30, 2023 and December 31, 2022, respectively.
(2)The fair value of the Opco Credit Facility approximates the outstanding borrowing amount because the interest rates are variable and reflective of market rates and the terms of the credit facility allow the Partnership to repay the debt at any time without penalty.
(3)The fair value of the Partnership's contract receivable is determined based on the present value of future cash flow projections related to the underlying asset at a discount rate of 15% at June 30, 2023 and December 31, 2022.

 

NRP has embedded derivatives in the preferred units related to certain conversion options, redemption features and the change of control provision that are accounted for separately from the preferred units as assets and liabilities at fair value on the Partnership's Consolidated Balance Sheets. Level 3 valuation of the embedded derivatives are based on numerous factors including the likelihood of the event occurring. The embedded derivatives are revalued quarterly and changes in their fair value would be recorded in other expenses, net on the Partnership's Consolidated Statements of Comprehensive Income. The embedded derivatives had zero value as of June 30, 2023 and December 31, 2022.

 

v3.23.2
Note 11 - Related Party Transactions
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Related Party Transactions Disclosure [Text Block]

11.    Related Party Transactions

 

Affiliates of our General Partner

 

The Partnership’s general partner does not receive any management fee or other compensation for its management of NRP. However, in accordance with the partnership agreement, the general partner and its affiliates are reimbursed for services provided to the Partnership and for expenses incurred on the Partnership’s behalf. Employees of Quintana Minerals Corporation ("QMC") and Western Pocahontas Properties Limited Partnership ("WPPLP"), affiliates of the Partnership, provide their services to manage the Partnership's business. QMC and WPPLP charge the Partnership the portion of their employee salary and benefits costs related to their employee services provided to NRP. These QMC and WPPLP employee management service costs are presented as operating and maintenance expenses and general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income. NRP also reimburses overhead costs incurred by its affiliates, including Quintana Infrastructure Development ("QID"), to manage the Partnership's business. These overhead costs include certain rent, information technology, administration of employee benefits and other corporate services incurred by or on behalf of the Partnership’s general partner and its affiliates and are presented as operating and maintenance expenses and general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income.

 

Direct general and administrative expenses charged to the Partnership by QMC, WPPLP and QID are included on the Partnership's Consolidated Statement of Comprehensive Income as follows:

 

  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Operating and maintenance expenses

 $1,712  $1,698  $3,431  $3,357 

General and administrative expenses

  1,253   1,225   2,573   2,465 

 

The Partnership had accounts payable to QMC of $0.4 million on its Consolidated Balance Sheets at both  June 30, 2023 and December 31, 2022, and $0.8 million and $1.0 million of accounts payable to WPPLP at June 30, 2023 and December 31, 2022, respectively.

 

During the three months ended June 30, 2023 and 2022, the Partnership recognized $2.0 million and $2.7 million, respectively, in operating and maintenance expenses on its Consolidated Statements of Comprehensive Income related to an overriding royalty agreement with WPPLP. These amounts were $4.0 million and $4.3 million during the six months ended June 30, 2023 and 2022, respectively. 

 

v3.23.2
Note 12 - Major Customers
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Concentration Risk Disclosure [Text Block]

12.    Major Customers 

 

Revenues from customers that exceeded 10 percent of total revenues for any of the periods presented below are as follows:

 

  

For the Three Months Ended June 30,

  

For the Six Months Ended June 30,

 
  

2023

  

2022

  

2023

  

2022

 

(In thousands)

 

Revenues

  

Percent

  

Revenues

  

Percent

  

Revenues

  

Percent

  

Revenues

  

Percent

 

Alpha Metallurgical Resources, Inc. (1)

 $19,685   22% $32,895   33% $43,903   23% $60,638   32%

Foresight Energy Resources LLC ("Foresight") (1)

 $12,324   14% $16,497   17% $24,853   13% $27,747   15%
     

(1)

Revenues from Alpha Metallurgical Resources, Inc. and Foresight are included within the Partnership's Mineral Rights segment.

 

v3.23.2
Note 13 - Commitments and Contingencies
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Commitments and Contingencies Disclosure [Text Block]

13.    Commitments and Contingencies

 

NRP is involved, from time to time, in various legal proceedings arising in the ordinary course of business. While the ultimate results of these proceedings cannot be predicted with certainty, Partnership management believes these ordinary course matters will not have a material effect on the Partnership’s financial position, liquidity or operations.

 

v3.23.2
Note 14 - Unit-Based Compensation
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Share-Based Payment Arrangement [Text Block]

14.    Unit-Based Compensation

 

During the three and six months ended June 30, 2023, the Partnership granted service, performance and market-based awards under its 2017 Long-Term Incentive Plan and during the six months ended June 30, 2022, the Partnership granted service-based awards. The Partnership's service and performance-based awards are valued using the closing price of NRP's common units as of the grant date while the Partnership's market-based awards are valued using a Monte Carlo simulation. The grant date fair value of these awards granted during the three months ended June 30, 2023 was $0.1 million. The grant date fair value of these awards granted during six months ended June 30, 2023 and 2022 was $16.0 million and $7.9 million, respectively. Total unit-based compensation expense associated with these awards was $2.6 million and $1.3 million for the three months ended June 30, 2023 and 2022, respectively, and $5.1 million and $2.8 million for the six months ended June 30, 2023 and 2022, respectively, and is included in general and administrative expenses and operating and maintenance expenses on the Partnership's Consolidated Statements of Comprehensive Income. The unamortized cost associated with unvested outstanding awards as of June 30, 2023 is $18.2 million, which is to be recognized over a weighted average period of 2.3 years. The unamortized cost associated with unvested outstanding awards as of  December 31, 2022 was $6.3 million.

 

A summary of the unit activity in the outstanding grants during 2023 is as follows:

 

(In thousands)

 

Common Units

  

Weighted Average Grant Date Fair Value per Common Unit

 

Outstanding at January 1, 2023

  386  $28.96 

Granted

  281  $56.84 

Fully vested and issued

  (184) $26.30 

Outstanding at June 30, 2023

  483  $46.21 

 

v3.23.2
Note 15 - Financing Transaction
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Financing Receivables [Text Block]

15.    Financing Transaction

 

The Partnership owns rail loadout and associated infrastructure at the Sugar Camp mine in the Illinois Basin operated by a subsidiary of Foresight. The infrastructure at the Sugar Camp mine is leased to a subsidiary of Foresight and is accounted for as a financing transaction (the "Sugar Camp lease"). The Sugar Camp lease expires in 2032 with renewal options for up to 80 additional years. Minimum payments are $5.0 million per year through the end of the lease term. The Partnership is also entitled to variable payments in the form of throughput fees based on the amount of coal transported and processed utilizing the Partnership's assets. In the event the Sugar Camp lease is renewed beyond 2032, payments become a fixed ten thousand dollars per year for the remainder of the renewed term.

 

v3.23.2
Note 16 - Credit Losses
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Credit Loss, Financial Instrument [Text Block]

16.    Credit Losses

 

The Partnership is exposed to credit losses through collection of its short-term trade receivables resulting from contracts with customers and a long-term receivable resulting from a financing transaction with a customer. The Partnership records an allowance for current expected credit losses on these receivables based on the loss-rate method. NRP assessed the likelihood of collection of its receivables utilizing historical loss rates, current market conditions, industry and macroeconomic factors, reasonable and supportable forecasts and facts or circumstances of individual customers and properties. Examples of these facts or circumstances include, but are not limited to, contract disputes or renegotiations with the customer and evaluation of short and long-term economic viability of the contracted property. For its long-term contract receivable, management reverts to the historical loss experience immediately after the reasonable and supportable forecast period ends.

 

As of June 30, 2023 and December 31, 2022, NRP had the following current expected credit loss (“CECL”) allowance related to its receivables and long-term contract receivable:

 

  

June 30, 2023

  

December 31, 2022

 

(In thousands)

 

Gross

  

CECL Allowance

  

Net

  

Gross

  

CECL Allowance

  

Net

 

Receivables

 $42,974  $(3,699) $39,275  $47,237  $(4,461) $42,776 

Long-term contract receivable

  28,652   (993)  27,659   29,984   (1,038)  28,946 

Total

 $71,626  $(4,692) $66,934  $77,221  $(5,499) $71,722 

 

NRP recorded a reversal of $0.2 million and $0.4 million of operating and maintenance expenses on its Consolidated Statements of Comprehensive Income related to the change in the CECL allowance during the three months ended June 30, 2023 and 2022, respectively and a reversal of $0.8 million and expense of $0.6 million during the six months ended June 30, 2023 and 2022, respectively. 

 

NRP has procedures in place to monitor its ongoing credit exposure through timely review of counterparty balances against contract terms and due dates, account and financing receivable reconciliation, bankruptcy monitoring, lessee audits and dispute resolution. The Partnership may employ legal counsel or collection specialists to pursue recovery of defaulted receivables.

 

v3.23.2
Note 17 - Subsequent Events
6 Months Ended
Jun. 30, 2023
Notes to Financial Statements  
Subsequent Events [Text Block]

17.    Subsequent Events

 

The following represents material events that have occurred subsequent to June 30, 2023 through the time of the Partnership’s filing of its Quarterly Report on Form 10-Q with the SEC:

 

Common Unit and Preferred Unit Distributions

 

In August 2023, the Board of Directors declared a distribution of $0.75 per common unit with respect to the second quarter of 2023. The Board of Directors also declared a $3.7 million cash distribution on NRP's outstanding preferred units with respect to the second quarter of 2023.

 

 

v3.23.2
Significant Accounting Policies (Policies)
6 Months Ended
Jun. 30, 2023
Accounting Policies [Abstract]  
Consolidation, Policy [Policy Text Block]

Principles of Consolidation and Reporting

 

The accompanying unaudited Consolidated Financial Statements of the Partnership have been prepared in accordance with generally accepted accounting principles in the United States of America ("GAAP") for interim financial information and with Rule 10-01 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. These financial statements should be read in conjunction with the financial statements for the year ended December 31, 2022 and notes thereto included in the Partnership's Annual Report on Form 10-K, which was filed with the SEC on March 3, 2023. Reclassifications have been made to prior year amounts in the Consolidated Financial Statements to conform with current year presentation. These reclassifications had no impact on previously reported total assets, total liabilities, partners' capital, net income, or cash flows from operating, investing or financing activities.

 

New Accounting Pronouncements, Policy [Policy Text Block]

Recently Adopted Accounting Standard

 

On January 1, 2023, NRP adopted Accounting Standards Update ("ASU") 2020-06, Debt – Debt with Conversion and Other Options (Subtopic 470-20) and Derivatives and Hedging – Contracts in Entity’s Own Equity (Subtopic 815-40) (“ASU 2020-06)”. The ASU includes targeted improvements to earnings per share, which the Partnership adopted on a modified retrospective basis. The adoption of this ASU did not have a material impact on the Partnership’s Consolidated Financial Statements. See Note 5. Net Income Per Common Unit for the calculations of our basic and diluted net income per common unit. See Note 3. Class A Convertible Preferred Units and Warrants for disclosures related to our convertible preferred units and warrants.

 

v3.23.2
Note 2 - Revenues From Contracts With Customers (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Disaggregation of Revenue [Table Text Block]
  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Coal royalty revenues

 $47,960  $62,945  $105,983  $118,394 

Production lease minimum revenues

  562   65   1,175   1,657 

Minimum lease straight-line revenues

  4,447   4,674   8,950   9,457 

Carbon neutral initiative revenues

  115      2,233    

Property tax revenues

  1,470   1,695   2,940   3,167 

Wheelage revenues

  3,284   4,379   7,153   8,096 

Coal overriding royalty revenues

  150   682   338   940 

Lease amendment revenues

  848   811   1,699   1,691 

Aggregates royalty revenues

  686   1,037   1,439   1,807 

Oil and gas royalty revenues

  1,214   2,906   4,802   4,720 

Other revenues

  271   139   566   487 

Royalty and other mineral rights revenues

 $61,007  $79,333  $137,278  $150,416 

Transportation and processing services revenues (1)

  3,270   5,612   6,868   9,408 

Total Mineral Rights segment revenues

 $64,277  $84,945  $144,146  $159,824 
Contract with Customer, Contract Asset, Contract Liability, and Receivable [Table Text Block]
  

June 30,

  

December 31,

 

(In thousands)

 

2023

  

2022

 

Receivables

        

Accounts receivable, net

 $33,370  $39,004 

Other current assets, net (1)

  2,155    

Other long-term assets, net (2)

     75 
         

Contract liabilities

        

Current portion of deferred revenue

 $6,823  $6,256 

Deferred revenue

  36,815   40,181 
  

For the Six Months Ended June 30,

 

(In thousands)

 

2023

  

2022

 

Balance at beginning of period (current and non-current)

 $46,437  $61,862 

Increase due to minimums and lease amendment fees

  10,810   7,997 

Recognition of previously deferred revenue

  (13,609)  (17,573)

Balance at end of period (current and non-current)

 $43,638  $52,286 
Lessor, Operating Lease, Payment to be Received, Maturity [Table Text Block]

Lease Term (1)

 

Weighted Average Remaining Years

  

Annual Minimum Payments

 

0 - 5 years

  1.7  $22,230 

5 - 10 years

  3.1   7,417 

10+ years

  12.1   27,129 

Total

  6.8  $56,776 
v3.23.2
Note 3 - Class A Convertible Preferred Units and Warrants (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Schedule of Preferred Units [Table Text Block]
  

Units

  

Financial

 

(In thousands, except unit data)

 

Outstanding

  

Position

 

Balance at December 31, 2021

  269,321  $183,908 

Redemption of preferred units paid-in-kind

  (19,321)  (19,321)

Balance at December 31, 2022

  250,000  $164,587 

Redemption of preferred units

  (128,333)  (84,488)

Balance at June 30, 2023

  121,667  $80,099 
v3.23.2
Note 4 - Common and Preferred Unit Distributions (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Distributions Made to Limited Partner, by Distribution [Table Text Block]
                   
    

Common Units

  

Preferred Units

 

Month Paid

 

Period Covered by Distribution

 

Distribution per Unit

  

Total Distribution (1) (In thousands)

  

Distribution per Unit

  

Total Distribution (In thousands)

 

2023

                  

February 2023

 

October 1 - December 31, 2022

 $0.75  $9,571  $30.00  $7,500 

February 2023 (2)

 

January 1 - February 8, 2023

        12.33   586 

March 2023 (3)

 

Special Distribution

  2.43   31,329       

May 2023

 

January 1 - March 31, 2023

  0.75   9,669   30.00   6,075 

May 2023 (4)

 

April 1 - May 5, 2023

        11.33   406 

June 2023 (5)

 

April 1 - June 2, 2023

        20.33   915 
                   

2022

                  

February 2022

 

October 1 - December 31, 2021

 $0.45  $5,672  $30.00  $7,500 

February 2022 (6)

 

January 1 - February 8, 2022

        13.35   258 

May 2022

 

January 1 - March 31, 2022

  0.75   9,570   30.00   7,500 
v3.23.2
Note 5 - Net Income Per Common Unit (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block]
  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands, except per unit data)

 

2023

  

2022

  

2023

  

2022

 

Basic net income per common unit

                

Net income attributable to common unitholders

 $36,990  $58,134  $92,248  $113,405 

Weighted average common units—basic

  12,635   12,506   12,603   12,461 

Basic net income per common unit

 $2.93  $4.65  $7.32  $9.10 
                 

Diluted net income per common unit

                

Weighted average common units—basic

  12,635   12,506   12,603   12,461 

Plus: dilutive effect of preferred units

  2,420   6,292   3,099   6,292 

Plus: dilutive effect of warrants

  1,139   937   1,197   734 

Plus: dilutive effect of unvested unit-based awards

  122   178   165   209 

Weighted average common units—diluted

  16,316   19,913   17,064   19,696 
                 

Net income

 $70,334  $66,820  $149,609  $130,719 

Less: income attributable to preferred unitholders

  (1,321)     (1,907)   

Less: redemption of preferred units

  (27,618)     (43,846)   

Diluted net income attributable to common unitholders and the general partner

 $41,395  $66,820  $103,856  $130,719 

Less: diluted net income attributable to the general partner

  (828)  (1,336)  (2,077)  (2,614)

Diluted net income attributable to common unitholders

 $40,567  $65,484  $101,779  $128,105 
                 

Diluted net income per common unit

 $2.49  $3.29  $5.96  $6.50 
v3.23.2
Note 6 - Segment Information (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Schedule of Segment Reporting Information, by Segment [Table Text Block]
  

Operating Segments

         

(In thousands)

 

Mineral Rights

  

Soda Ash

  

Corporate and Financing

  

Total

 

For the Three Months Ended June 30, 2023

                

Revenues

 $64,277  $26,978  $  $91,255 

Gain on asset sales and disposals

  5         5 

Operating and maintenance expenses

  7,916   14      7,930 

Depreciation, depletion and amortization

  3,787      5   3,792 

General and administrative expenses

        5,643   5,643 

Asset impairments

  69         69 

Other expenses, net

        3,492   3,492 

Net income (loss)

  52,510   26,964   (9,140)  70,334 
                 

For the Three Months Ended June 30, 2022

                

Revenues

 $84,945  $14,643  $  $99,588 

Gain on asset sales and disposals

  345         345 

Operating and maintenance expenses

  9,992   23      10,015 

Depreciation, depletion and amortization

  5,847         5,847 

General and administrative expenses

        5,052   5,052 

Asset impairments

  43         43 

Other expenses, net

        12,156   12,156 

Net income (loss)

  69,408   14,620   (17,208)  66,820 
                 

For the Six Months Ended June 30, 2023

                

Revenues

 $144,146  $46,232  $  $190,378 

Gain on asset sales and disposals

  101         101 

Operating and maintenance expenses

  14,921   172      15,093 

Depreciation, depletion and amortization

  7,866      9   7,875 

General and administrative expenses

        11,488   11,488 

Asset impairments

  69         69 

Other expenses, net

        6,345   6,345 

Net income (loss)

  121,391   46,060   (17,842)  149,609 
                 

For the Six Months Ended June 30, 2022

                

Revenues

 $159,824  $29,480  $  $189,304 

Gain on asset sales and disposals

  345         345 

Operating and maintenance expenses

  18,017   74      18,091 

Depreciation, depletion and amortization

  9,715         9,715 

General and administrative expenses

        9,519   9,519 

Asset impairments

  62         62 

Other expenses, net

        21,543   21,543 

Net income (loss)

  132,375   29,406   (31,062)  130,719 
v3.23.2
Note 7 - Equity Investment (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Equity Method Investments [Table Text Block]
  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Balance at beginning of period

 $295,361  $280,156  $306,470  $276,004 

Income allocation to NRP’s equity interests (1)

  28,212   15,804   48,576   31,869 

Amortization of basis difference

  (1,234)  (1,161)  (2,344)  (2,389)

Other comprehensive income (loss)

  911   (4,013)  (18,672)  (1,468)

Distribution

  (32,350)  (10,486)  (43,130)  (23,716)

Balance at end of period

 $290,900  $280,300  $290,900  $280,300 
  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Net sales

 $201,365  $189,068  $408,493  $352,505 

Gross profit

  64,554   40,279   113,609   80,044 

Net income

  57,574   32,253   99,134   65,039 
v3.23.2
Note 8 - Mineral Rights, Net (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Mineral Properties Disclosure [Table Text Block]
  

June 30, 2023

  

December 31, 2022

 

(In thousands)

 

Carrying Value

  

Accumulated Depletion

  

Net Book Value

  

Carrying Value

  

Accumulated Depletion

  

Net Book Value

 

Coal properties

 $661,743  $(276,085) $385,658  $661,812  $(269,037) $392,775 

Aggregates properties

  8,655   (3,618)  5,037   8,655   (3,410)  5,245 

Oil and gas royalty properties

  12,354   (9,841)  2,513   12,354   (9,600)  2,754 

Other

  13,145   (1,612)  11,533   13,150   (1,612)  11,538 

Total mineral rights, net

 $695,897  $(291,156) $404,741  $695,971  $(283,659) $412,312 
v3.23.2
Note 9 - Debt, Net (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Schedule of Long-Term Debt Instruments [Table Text Block]
  

June 30,

  

December 31,

 

(In thousands)

 

2023

  

2022

 

Opco Credit Facility

 $103,034  $70,000 

Opco Senior Notes

        

5.55% with semi-annual interest payments in June and December, with annual principal payments in June, due June 2023

 $  $2,366 

4.73% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2023

  6,004   6,004 

5.82% with semi-annual interest payments in March and September, with annual principal payments in March, due March 2024

  12,684   25,368 

8.92% with semi-annual interest payments in March and September, with annual principal payments in March, due March 2024

  4,011   8,023 

5.03% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026

  45,683   45,683 

5.18% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026

  11,643   11,643 

Total Opco Senior Notes

 $80,025  $99,087 

Total debt at face value

 $183,059  $169,087 

Net unamortized debt issuance costs

  (623)  (806)

Total debt, net

 $182,436  $168,281 

Less: current portion of long-term debt

  (36,743)  (39,076)

Total long-term debt, net

 $145,693  $129,205 
v3.23.2
Note 10 - Fair Value Measurements (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Fair Value Option, Disclosures [Table Text Block]
      

June 30, 2023

  

December 31, 2022

 
  

Fair Value

  

Carrying

  

Estimated

  

Carrying

  

Estimated

 

(In thousands)

 

Hierarchy Level

  

Value

  

Fair Value

  

Value

  

Fair Value

 

Debt:

                    

Opco Senior Notes (1)

  3  $79,402  $75,848  $98,281  $96,060 

Opco Credit Facility (2)

  3   103,034   103,034   70,000   70,000 
                     

Assets:

                    

Contract receivable, net (current and long-term) (3)

  3  $30,182  $25,254  $31,371  $24,833 
v3.23.2
Note 11 - Related Party Transactions (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Schedule of Related Party Transactions [Table Text Block]
  For the Three Months Ended June 30,  For the Six Months Ended June 30, 

(In thousands)

 

2023

  

2022

  

2023

  

2022

 

Operating and maintenance expenses

 $1,712  $1,698  $3,431  $3,357 

General and administrative expenses

  1,253   1,225   2,573   2,465 
v3.23.2
Note 12 - Major Customers (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Schedules of Concentration of Risk, by Risk Factor [Table Text Block]
  

For the Three Months Ended June 30,

  

For the Six Months Ended June 30,

 
  

2023

  

2022

  

2023

  

2022

 

(In thousands)

 

Revenues

  

Percent

  

Revenues

  

Percent

  

Revenues

  

Percent

  

Revenues

  

Percent

 

Alpha Metallurgical Resources, Inc. (1)

 $19,685   22% $32,895   33% $43,903   23% $60,638   32%

Foresight Energy Resources LLC ("Foresight") (1)

 $12,324   14% $16,497   17% $24,853   13% $27,747   15%
v3.23.2
Note 14 - Unit-Based Compensation (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Share-Based Payment Arrangement, Activity [Table Text Block]

(In thousands)

 

Common Units

  

Weighted Average Grant Date Fair Value per Common Unit

 

Outstanding at January 1, 2023

  386  $28.96 

Granted

  281  $56.84 

Fully vested and issued

  (184) $26.30 

Outstanding at June 30, 2023

  483  $46.21 
v3.23.2
Note 16 - Credit Losses (Tables)
6 Months Ended
Jun. 30, 2023
Notes Tables  
Accounts Receivable, Allowance for Credit Loss [Table Text Block]
  

June 30, 2023

  

December 31, 2022

 

(In thousands)

 

Gross

  

CECL Allowance

  

Net

  

Gross

  

CECL Allowance

  

Net

 

Receivables

 $42,974  $(3,699) $39,275  $47,237  $(4,461) $42,776 

Long-term contract receivable

  28,652   (993)  27,659   29,984   (1,038)  28,946 

Total

 $71,626  $(4,692) $66,934  $77,221  $(5,499) $71,722 
v3.23.2
Note 1 - Basis of Presentation (Details Textual)
6 Months Ended
Jun. 30, 2023
Number of Operating Segments 2
Number of Wholly Owned Operating Companies 1
Sisecam Wyoming [Member]  
Equity Method Investment, Ownership Percentage 49.00%
v3.23.2
Note 2 - Revenues From Contracts With Customers (Details Textual) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Revenue from Contract with Customer, Excluding Assessed Tax $ 61,007 $ 79,333 $ 137,278 $ 150,416
Mineral Rights Segment [Member] | Transportation and Processing Services [Member]        
Revenue from Contract with Customer, Excluding Assessed Tax 2,700 4,900 5,600 8,000
Sales-type Lease, Revenue $ 600 $ 700 $ 1,300 $ 1,400
v3.23.2
Note 2 - Revenues From Contracts With Customers - Disaggregation of Revenue (Details) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Revenue from contract with customers $ 61,007 $ 79,333 $ 137,278 $ 150,416
Mineral Rights Segment [Member] | Operating Segments [Member]        
Revenues 64,277 84,945 144,146 159,824
Coal Royalty Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 47,960 62,945 105,983 118,394
Production Lease Minimum Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 562 65 1,175 1,657
Minimum Lease Straight-line Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 4,447 4,674 8,950 9,457
Carbon Neutral Initiatives [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 115 0 2,233 0
Property Tax Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 1,470 1,695 2,940 3,167
Wheelage Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 3,284 4,379 7,153 8,096
Coal Overriding Royalty Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 150 682 338 940
Lease Amendment Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 848 811 1,699 1,691
Aggregates Royalty Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 686 1,037 1,439 1,807
Oil and Gas Royalty Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 1,214 2,906 4,802 4,720
Other Revenues [Member] | Mineral Rights Segment [Member]        
Revenue from contract with customers 271 139 566 487
Transportation and Processing Services [Member] | Mineral Rights Segment [Member]        
Revenues [1] $ 3,270 $ 5,612 $ 6,868 $ 9,408
[1] Transportation and processing services revenues from contracts with customers as defined under ASC 606 was $2.7 million and $4.9 million for the three months ended June 30, 2023 and 2022, respectively and $5.6 million and $8.0 million for the six months ended June 30, 2023 and 2022, respectively. The remaining transportation and processing services revenues of $0.6 million and $0.7 million for the three months ended June 30, 2023 and 2022, respectively, and $1.3 million and $1.4 million for the six months ended June 30, 2023 and 2022, respectively, related to other NRP-owned infrastructure leased to and operated by third-party operators accounted for under other guidance. See Note 15. Financing Transaction for more information.
v3.23.2
Note 2 - Revenue From Contracts With Customers - Assets and Liabilities (Details) - USD ($)
$ in Thousands
6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Dec. 31, 2022
Current portion of deferred revenue $ 6,823   $ 6,256
Deferred revenue 36,815   40,181
Balance 46,437 $ 61,862  
Increase due to minimums and lease amendment fees 10,810 7,997  
Recognition of previously deferred revenue (13,609) (17,573)  
Balance 43,638 $ 52,286  
Coal Royalty Revenues [Member]      
Current portion of deferred revenue 6,823   6,256
Deferred revenue 36,815   40,181
Coal Royalty Revenues [Member] | Accounts Receivable [Member]      
Contract with customer, current 33,370   39,004
Coal Royalty Revenues [Member] | Other Current Assets [Member]      
Contract with customer, current [1] 2,155   0
Coal Royalty Revenues [Member] | Other Noncurrent Assets [Member]      
Contract with customer, noncurrent [2] $ 0   $ 75
[1] Other current assets, net includes short-term notes receivables from contracts with customers.
[2] Other long-term assets, net includes long-term lease amendment fee receivables from contracts with customers.
v3.23.2
Note 2 - Revenue From Contracts With Customers - Operating Lease Payments Receivable (Details)
$ in Thousands
Jun. 30, 2023
USD ($)
Weighted average remaining years (Year) 6 years 9 months 18 days
Annual minimum payments $ 56,776 [1]
Lease Term, 0 to 5 Years [Member]  
Weighted average remaining years (Year) 1 year 8 months 12 days
Annual minimum payments $ 22,230 [1]
Lease Term, 5 to 10 Years [Member]  
Weighted average remaining years (Year) 3 years 1 month 6 days
Annual minimum payments $ 7,417 [1]
Lease Term, Greater Than 10 Years [Member]  
Weighted average remaining years (Year) 12 years 1 month 6 days
Annual minimum payments $ 27,129 [1]
[1] Lease term does not include renewal periods.
v3.23.2
Note 3 - Class A Convertible Preferred Units and Warrants (Details Textual)
$ / shares in Units, $ in Thousands
1 Months Ended 6 Months Ended
Mar. 02, 2017
USD ($)
$ / shares
shares
Jun. 30, 2023
USD ($)
$ / shares
shares
May 31, 2023
USD ($)
shares
Feb. 28, 2023
USD ($)
shares
Jun. 30, 2023
USD ($)
$ / shares
shares
Dec. 31, 2022
USD ($)
$ / shares
shares
Jun. 30, 2022
$ / shares
shares
Temporary Equity, Par or Stated Value Per Share (in dollars per share) | $ / shares   $ 1,000     $ 1,000 $ 1,000  
Preferred Units, Number of Redeemed Units (in shares)   (45,000) (35,834) (47,499) (128,333)    
Warrants and Rights Outstanding | $   $ 47,964     $ 47,964 $ 47,964  
Warrants at 22.81 Strike Price [Member]              
Class of Warrant or Right Warrants, Issued (in shares) 1,750,000            
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share) | $ / shares $ 22.81            
Warrants at 22.81 Strike Price [Member] | Warrant Holder [Member]              
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share) | $ / shares   $ 22.81     $ 22.81 $ 22.81 $ 22.81
Class of Warrant or Right, Number of Securities Called by Warrants or Rights (in shares)   750,000     750,000 750,000 750,000
Warrants at 34.00 Strike Price [Member]              
Class of Warrant or Right Warrants, Issued (in shares) 2,250,000            
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share) | $ / shares $ 34.00            
Warrants at 34.00 Strike Price [Member] | Warrant Holder [Member]              
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share) | $ / shares   $ 34.00     $ 34.00 $ 34.00 $ 34.00
Class of Warrant or Right, Number of Securities Called by Warrants or Rights (in shares)   2,250,000     2,250,000 2,250,000 2,250,000
Warrants to Purchase Common Units [Member]              
Class of Warrant or Right, Outstanding (in shares)   3,000,000.0     3,000,000.0 3,000,000.0  
Warrants to Purchase Common Units [Member] | Warrant Holders’ Interest [Member]              
Warrants and Rights Outstanding | $   $ 48,000     $ 48,000 $ 48,000  
Class A Convertible Preferred Units [Member]              
Preferred Units, Issued (in shares) 250,000            
Temporary Equity, Par or Stated Value Per Share (in dollars per share) | $ / shares $ 1,000            
Preferred Units Origination Fee Percent 2.50%            
Preferred Stock, Dividend Rate, Percentage 12.00%            
Convertible Preferred Units Maximum Redeemed Units Percent 33.00%            
Convertible Preferred Units, Redemption Price, Minimum (in dollars per share) | $ / shares $ 51.00            
Debt Instrument Covenants Consolidated Leverage Ratio Minimum 3.25            
Debt Instrument Covenants Distributable Cash Flow Ratio Maximum 1.2            
Partners' Capital, Distribution Amount Per Share (in dollars per share) | $ / shares $ 0.45            
Preferred Units Preferred Purchaser Approval Rights Ownership Threshold 20.00%            
Preferred Units, Number of Redeemed Units (in shares)   (45,000) (35,834) (47,499)      
Preferred Units, Value of Redeemed Units | $   $ 45,000 $ 35,800 $ 47,500      
Preferred Units, Outstanding (in shares)   121,667     121,667    
Class A Convertible Preferred Units [Member] | Debt Instrument, Redemption, Period One [Member]              
Convertible Preferred Units Conversion to Common Units Discount Percentage 7.50%            
Convertible Preferred Units Purchase Price Multiplier 1.50            
Class A Convertible Preferred Units [Member] | Debt Instrument, Redemption, Period Three [Member]              
Convertible Preferred Units Conversion to Common Units Discount Percentage 10.00%            
Convertible Preferred Units Purchase Price Multiplier 1.85            
Class A Convertible Preferred Units [Member] | Debt Instrument, Redemption, Period Two [Member]              
Convertible Preferred Units Purchase Price Multiplier 1.70            
Preferred Stock [Member]              
Proceeds from Issuance of Preferred Stock, Preference Stock, and Warrants, Total | $ $ 250,000            
v3.23.2
Note 3 - Class A Convertible Preferred Units and Warrants - Preferred Units Activity (Details) - USD ($)
$ in Thousands
1 Months Ended 6 Months Ended 12 Months Ended
Jun. 30, 2023
May 31, 2023
Feb. 28, 2023
Feb. 28, 2022
Jun. 30, 2023
Dec. 31, 2022
Beginning balance, units outstanding (in shares)         250,000  
Beginning balance, financial position         $ 164,587  
Redemption of preferred units paid-in-kind, units outstanding (in shares)       (19,321)    
Redemption of preferred units, units outstanding (in shares) (45,000) (35,834) (47,499)   (128,333)  
Redemption of preferred units, financial position         $ (84,488)  
Ending balance, units outstanding (in shares) 121,667       121,667 250,000
Ending balance, financial position $ 80,099       $ 80,099 $ 164,587
Preferred Partner [Member] | Preferred Stock [Member]            
Beginning balance, units outstanding (in shares)         250,000 269,321
Beginning balance, financial position         $ 164,587 $ 183,908
Redemption of preferred units paid-in-kind, units outstanding (in shares)           (19,321)
Redemption of preferred units paid-in-kind, financial position           $ (19,321)
Ending balance, units outstanding (in shares) 121,667       121,667 250,000
Ending balance, financial position $ 80,099       $ 80,099 $ 164,587
v3.23.2
Note 4 - Common and Preferred Unit Distributions (Details Textual) - USD ($)
$ in Thousands
1 Months Ended 3 Months Ended 6 Months Ended
Jun. 30, 2023
May 31, 2023
Feb. 28, 2023
Feb. 28, 2022
Jun. 30, 2023
Mar. 31, 2023
Jun. 30, 2022
Mar. 31, 2022
Jun. 30, 2023
Jun. 30, 2022
Allocation to unitholders         $ 4,971 $ 6,700 $ 7,500 $ 7,500 $ 11,632 $ 15,000
Preferred Stock Redemption Premium         27,618   (0)   $ 43,846 (0)
Preferred Units, Number of Redeemed Units (in shares) (45,000) (35,834) (47,499)           (128,333)  
Distribution Made to Limited Partner, Unit Redemption (in shares)       (19,321)            
Feb 2023 Redeemed Units [Member] | Preferred Partner [Member] | Preferred Stock [Member]                    
Dividends, Preferred Stock, Cash     $ 600              
May 2023 Redeemed Units [Member] | Preferred Partner [Member] | Preferred Stock [Member]                    
Dividends, Preferred Stock, Cash   $ 400                
June 2023 Redeemed Units [Member] | Preferred Partner [Member] | Preferred Stock [Member]                    
Dividends, Preferred Stock, Cash $ 900                  
Common Unitholders And General Partner [Member]                    
Allocation to unitholders         $ (5,000) $ (6,700) $ (7,500)   $ (11,600) $ (15,000)
Partner, General [Member]                    
Limited Liability Company or Limited Partnership, Members or Limited Partners, Ownership Interest           2.00%     2.00%  
v3.23.2
Note 4 - Common and Preferred Unit Distributions - Distributions Made to Partners (Details) - USD ($)
$ / shares in Units, $ in Thousands
1 Months Ended 3 Months Ended
Jun. 30, 2023
May 31, 2023
Mar. 31, 2023
[1]
Feb. 28, 2023
May 31, 2022
Feb. 28, 2022
Jun. 30, 2023
Mar. 31, 2023
Jun. 30, 2022
Mar. 31, 2022
Distributions, common units             $ 9,669 $ 40,900 $ 9,570 $ 5,672
Preferred Partner [Member] | Preferred Stock [Member]                    
Distribution per unit, common units (in dollars per share)   $ 30.00 $ 0 $ 30.00 $ 30.00 $ 30.00        
Distribution, preferred stock   $ 6,075 $ 0 $ 7,500 $ 7,500 $ 7,500        
Preferred Partner [Member] | Preferred Stock [Member] | Feb 2023 Redeemed Units [Member]                    
Distribution per unit, common units (in dollars per share) [2]       $ 12.33            
Distribution, preferred stock [2]       $ 586            
Preferred Partner [Member] | Preferred Stock [Member] | May 2023 Redeemed Units [Member]                    
Distribution per unit, common units (in dollars per share) [3]   $ 11.33                
Distribution, preferred stock [3]   $ 406                
Preferred Partner [Member] | Preferred Stock [Member] | June 2023 Redeemed Units [Member]                    
Distribution per unit, common units (in dollars per share) [4] $ 20.33                  
Distribution, preferred stock [4] $ 915                  
Preferred Partner [Member] | Preferred Stock [Member] | February 2022 Redeemed Units [Member]                    
Distribution per unit, common units (in dollars per share) [5]           $ 13.35        
Distribution, preferred stock [5]           $ 258        
Common Unitholders, General Partner [Member]                    
Distribution per unit, common units (in dollars per share)   $ 0.75 $ 2.43 $ 0.75 $ 0.75 $ 0.45        
Distributions, common units [6]   $ 9,669 $ 31,329 $ 9,571 $ 9,570 $ 5,672        
Common Unitholders, General Partner [Member] | Feb 2023 Redeemed Units [Member]                    
Distribution per unit, common units (in dollars per share) [2]       $ 0            
Distributions, common units [2],[6]       $ 0            
Common Unitholders, General Partner [Member] | May 2023 Redeemed Units [Member]                    
Distribution per unit, common units (in dollars per share) [3]   $ 0                
Distributions, common units [3],[6]   $ 0                
Common Unitholders, General Partner [Member] | June 2023 Redeemed Units [Member]                    
Distribution per unit, common units (in dollars per share) [4] $ 0                  
Distributions, common units [4],[6] $ 0                  
Common Unitholders, General Partner [Member] | February 2022 Redeemed Units [Member]                    
Distribution per unit, common units (in dollars per share) [5]           $ 0        
Distributions, common units [5],[6]           $ 0        
[1] Special distribution was made to help cover unitholder tax liabilities associated with owning NRP's common units during 2022.
[2] Relates to accrued distribution paid upon the redemption of 47,499 preferred units in February 2023.
[3] Relates to accrued distribution paid upon the redemption of 35,834 preferred units in May 2023.
[4] Relates to accrued distribution paid upon the redemption of 45,000 preferred units in June 2023.
[5] Relates to accrued distribution paid upon the redemption of 19,321 preferred units paid-in-kind in February 2022.
[6] Totals include the amount paid to NRP's general partner in accordance with the general partner's 2% general partner interest.
v3.23.2
Note 5 - Net Income Per Common Unit (Details Textual) - $ / shares
shares in Thousands
Jun. 30, 2023
Dec. 31, 2022
Jun. 30, 2022
Mar. 02, 2017
Warrants at 22.81 Strike Price [Member]        
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share)       $ 22.81
Warrants at 34.00 Strike Price [Member]        
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share)       $ 34.00
Warrant Holder [Member] | Warrants at 22.81 Strike Price [Member]        
Class of Warrant or Right, Number of Securities Called by Warrants or Rights (in shares) 750 750 750  
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share) $ 22.81 $ 22.81 $ 22.81  
Warrant Holder [Member] | Warrants at 34.00 Strike Price [Member]        
Class of Warrant or Right, Number of Securities Called by Warrants or Rights (in shares) 2,250 2,250 2,250  
Class of Warrant or Right, Exercise Price of Warrants or Rights (in dollars per share) $ 34.00 $ 34.00 $ 34.00  
v3.23.2
Note 5 - Net Income Per Common Unit - Schedule of Earnings Per Share (Details) - USD ($)
$ / shares in Units, $ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Mar. 31, 2023
[2]
Jun. 30, 2022
Mar. 31, 2022
[3]
Jun. 30, 2023
Jun. 30, 2022
Net income attributable to common unitholders $ 36,990   $ 58,134   $ 92,248 $ 113,405
Weighted average common units—basic (in shares) 12,635   12,506   12,603 12,461
Basic net income per common unit (in dollars per share) $ 2.93   $ 4.65   $ 7.32 $ 9.10
Plus: dilutive effect of preferred units (in shares) 2,420   6,292   3,099 6,292
Plus: dilutive effect of warrants (in shares) 1,139   937   1,197 734
Plus: dilutive effect of unvested unit-based awards (in shares) 122   178   165 209
Weighted average common units—diluted (in shares) 16,316   19,913   17,064 19,696
Net income $ 70,334 [1] $ 79,275 $ 66,820 [3] $ 63,899 $ 149,609 $ 130,719
Less: income attributable to preferred unitholders (1,321)   0   (1,907) 0
Less: redemption of preferred units (27,618)   0   (43,846) 0
Diluted net income attributable to common unitholders and the general partner 41,395   66,820   103,856 130,719
Less: diluted net income attributable to the general partner (828)   (1,336)   (2,077) (2,614)
Diluted net income attributable to common unitholders $ 40,567   $ 65,484   $ 101,779 $ 128,105
Diluted net income per common unit (in dollars per share) $ 2.49   $ 3.29   $ 5.96 $ 6.50
[1] Net income includes $5.0 million of income attributable to preferred unitholders that accumulated during the period, of which $4.9 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.
[2] Net income includes $6.7 million of income attributable to preferred unitholders that accumulated during the period, of which $6.5 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.
[3] Net income includes $7.5 million of income attributable to preferred unitholders that accumulated during the period, of which $7.4 million is allocated to the common unitholders and $0.2 million is allocated to the general partner.
v3.23.2
Note 6 - Segment Information (Details Textual)
6 Months Ended
Jun. 30, 2023
Number of Operating Segments 2
Sisecam Wyoming [Member]  
Equity Method Investment, Ownership Percentage 49.00%
v3.23.2
Note 6 - Segment Information - Information By Segment (Details) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Revenues $ 91,255 $ 99,588 $ 190,378 $ 189,304
Gain on asset sales and disposals 5 345 101 345
Operating and maintenance expenses 7,930 10,015 15,093 18,091
Depreciation, depletion and amortization 3,792 5,847 7,875 9,715
General and administrative expenses 5,643 5,052 11,488 9,519
Asset impairments 69 43 69 62
Other expenses, net 3,492 12,156 6,345 21,543
Net income (loss) 70,334 66,820 149,609 130,719
Corporate, Non-Segment [Member]        
Revenues 0 0 0 0
Gain on asset sales and disposals 0 0 0 0
Operating and maintenance expenses 0 0 0 0
Depreciation, depletion and amortization 5 0 9 0
General and administrative expenses 5,643 5,052 11,488 9,519
Asset impairments 0 0 0 0
Other expenses, net 3,492 12,156 6,345 21,543
Net income (loss) (9,140) (17,208) (17,842) (31,062)
Mineral Rights Segment [Member]        
Depreciation, depletion and amortization 3,600 5,400 7,500 9,100
Mineral Rights Segment [Member] | Operating Segments [Member]        
Revenues 64,277 84,945 144,146 159,824
Gain on asset sales and disposals 5 345 101 345
Operating and maintenance expenses 7,916 9,992 14,921 18,017
Depreciation, depletion and amortization 3,787 5,847 7,866 9,715
General and administrative expenses 0 0 0 0
Asset impairments 69 43 69 62
Other expenses, net 0 0 0 0
Net income (loss) 52,510 69,408 121,391 132,375
Soda Ash Segment [Member] | Operating Segments [Member]        
Revenues 26,978 14,643 46,232 29,480
Gain on asset sales and disposals 0 0 0 0
Operating and maintenance expenses 14 23 172 74
Depreciation, depletion and amortization 0 0 0 0
General and administrative expenses 0 0 0 0
Asset impairments 0 0 0 0
Other expenses, net 0 0 0 0
Net income (loss) $ 26,964 $ 14,620 $ 46,060 $ 29,406
v3.23.2
Note 7 - Equity Investment (Details Textual) - Sisecam Wyoming [Member] - USD ($)
$ in Millions
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Equity Method Investment, Ownership Percentage 49.00%   49.00%  
Reclassification Out Of Accumulated Other Comprehensive Income (Loss) $ 2.3 $ (3.0) $ (18.3) $ (4.7)
v3.23.2
Note 7 - Equity Investment - Investment Activity (Details) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Mar. 31, 2023
Jun. 30, 2022
Mar. 31, 2022
Jun. 30, 2023
Jun. 30, 2022
Beginning Balance   $ 306,470     $ 306,470  
Ending Balance $ 290,900       290,900  
Net income 70,334 [1] 79,275 [2] $ 66,820 [3] $ 63,899 [3] 149,609 $ 130,719
Sisecam Wyoming [Member]            
Net sales 201,365   189,068   408,493 352,505
Gross profit 64,554   40,279   113,609 80,044
Net income 57,574   32,253   99,134 65,039
Sisecam Wyoming [Member]            
Beginning Balance 295,361 306,470 280,156 276,004 306,470 276,004
Income allocation to NRP’s equity interests (1) [4] 28,212   15,804   48,576 31,869
Amortization of basis difference (1,234)   (1,161)   (2,344) (2,389)
Other comprehensive income (loss) 911   (4,013)   (18,672) (1,468)
Distribution (32,350)   (10,486)   (43,130) (23,716)
Ending Balance $ 290,900 $ 295,361 $ 280,300 $ 280,156 $ 290,900 $ 280,300
[1] Net income includes $5.0 million of income attributable to preferred unitholders that accumulated during the period, of which $4.9 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.
[2] Net income includes $6.7 million of income attributable to preferred unitholders that accumulated during the period, of which $6.5 million is allocated to the common unitholders and $0.1 million is allocated to the general partner.
[3] Net income includes $7.5 million of income attributable to preferred unitholders that accumulated during the period, of which $7.4 million is allocated to the common unitholders and $0.2 million is allocated to the general partner.
[4] Amounts reclassified into income out of accumulated other comprehensive loss were $2.3 million and $(3.0) million for the three months ended June 30, 2023 and 2022, respectively, and $(18.3) million and $(4.7) million for the six months ended June 30, 2023 and 2022, respectively.
v3.23.2
Note 8 - Mineral Rights, Net (Details Textual) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Depreciation, Depletion and Amortization $ 3,792 $ 5,847 $ 7,875 $ 9,715
Mineral Rights Segment [Member]        
Depreciation, Depletion and Amortization $ 3,600 $ 5,400 $ 7,500 $ 9,100
v3.23.2
Note 8 - Mineral Rights, Net - Composition of Mineral Rights (Details) - USD ($)
$ in Thousands
Jun. 30, 2023
Dec. 31, 2022
Mineral Properties, carrying value $ 695,897 $ 695,971
Mineral Properties, accumulated depletion (291,156) (283,659)
Mineral Properties, net book value 404,741 412,312
Coal Properties [Member]    
Mineral Properties, carrying value 661,743 661,812
Mineral Properties, accumulated depletion (276,085) (269,037)
Mineral Properties, net book value 385,658 392,775
Aggregates Properties [Member]    
Mineral Properties, carrying value 8,655 8,655
Mineral Properties, accumulated depletion (3,618) (3,410)
Mineral Properties, net book value 5,037 5,245
Oil and Gas Royalty Properties [Member]    
Mineral Properties, carrying value 12,354 12,354
Mineral Properties, accumulated depletion (9,841) (9,600)
Mineral Properties, net book value 2,513 2,754
Other [Member]    
Mineral Properties, carrying value 13,145 13,150
Mineral Properties, accumulated depletion (1,612) (1,612)
Mineral Properties, net book value $ 11,533 $ 11,538
v3.23.2
Note 9 - Debt, Net (Details Textual)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
USD ($)
Jun. 30, 2023
USD ($)
Jun. 30, 2022
USD ($)
May 31, 2023
USD ($)
Dec. 31, 2022
USD ($)
Aug. 30, 2022
USD ($)
Long-Term Debt, Gross $ 183,059 $ 183,059     $ 169,087  
Opco [Member] | Floating Rate Revolving Credit Facility Due August 2027 [Member]            
Line of Credit Facility, Remaining Borrowing Capacity 52,000 52,000   $ 155,000 60,000 $ 130,000
Line of Credit Facility, Maximum Borrowing Capacity, Addition of Future Commitments       $ 200,000    
Ratio of EBITDA To Consolidated Fixed Charges       3.5    
Long-Term Line of Credit $ 103,000 103,000     70,000  
Proceeds from Lines of Credit   165,000        
Repayments of Lines of Credit   $ 132,000        
Long-Term Debt, Weighted Average Interest Rate, over Time 8.61% 8.44%        
Long-Term Debt, Gross $ 103,034 $ 103,034     70,000  
Opco [Member] | Floating Rate Revolving Credit Facility Due August 2027 [Member] | Other Noncurrent Assets [Member]            
Debt Instrument, Collateral Amount 320,000 320,000     326,400  
Opco [Member] | Senior Notes [Member]            
Long-Term Debt, Gross $ 80,000 80,000     $ 99,100  
Repayments of Debt   $ 19,100 $ 19,100      
Opco [Member] | The Eight Point Nine Two Senior Notes Due March Two Zero Two Four [Member]            
Debt Instrument, Interest Rate, Stated Percentage 8.92% 8.92%        
Partnership Leverage Ratio, Maximum 3.75 3.75        
Debt Instrument, Additional Variable Interest Rate 2.00% 2.00%        
v3.23.2
Note 9 - Debt, Net - Schedule of Long-term Debt (Details) - USD ($)
$ in Thousands
Jun. 30, 2023
Dec. 31, 2022
Debt instrument, carrying value $ 183,059 $ 169,087
Net unamortized debt issuance costs (623) (806)
Total debt, net 182,436 168,281
Less: current portion of long-term debt (36,743) (39,076)
Total long-term debt, net 145,693 129,205
Opco Senior Notes [Member]    
Debt instrument, carrying value 80,025 99,087
Opco Senior Notes [Member] | Five Point Five Five Percent Senior Note Due June Two Zero Two Three [Member]    
Debt instrument, carrying value 0 2,366
Opco Senior Notes [Member] | Four Point Seven Three Percent Senior Note Due December Two Zero Two Three [Member]    
Debt instrument, carrying value 6,004 6,004
Opco Senior Notes [Member] | Five Point Eight Two Percent Senior Note Due March Two Zero Two Four [Member]    
Debt instrument, carrying value 12,684 25,368
Opco Senior Notes [Member] | Eight Point Nine Two Percent Senior Note Due March Two Zero Two Four [Member]    
Debt instrument, carrying value 4,011 8,023
Opco Senior Notes [Member] | Five Point Zero Three Percent Senior Note Due December Two Zero Two Six [Member]    
Debt instrument, carrying value 45,683 45,683
Opco Senior Notes [Member] | Five Point One Eight Percent Senior Note Due December Two Zero Two Six [Member]    
Debt instrument, carrying value 11,643 11,643
Opco [Member] | Floating Rate Revolving Credit Facility Due August 2027 [Member]    
Debt instrument, carrying value $ 103,034 $ 70,000
v3.23.2
Note 9 - Debt, Net - Schedule of Long-term Debt (Details) (Parentheticals) - Opco Senior Notes [Member]
Jun. 30, 2023
Dec. 31, 2022
Five Point Five Five Percent Senior Note Due June Two Zero Two Three [Member]    
Debt instrument, interest rate   5.55%
Four Point Seven Three Percent Senior Note Due December Two Zero Two Three [Member]    
Debt instrument, interest rate 4.73% 4.73%
Five Point Eight Two Percent Senior Note Due March Two Zero Two Four [Member]    
Debt instrument, interest rate 5.82% 5.82%
Eight Point Nine Two Percent Senior Note Due March Two Zero Two Four [Member]    
Debt instrument, interest rate 8.92% 8.92%
Five Point Zero Three Percent Senior Note Due December Two Zero Two Six [Member]    
Debt instrument, interest rate 5.03% 5.03%
Five Point One Eight Percent Senior Note Due December Two Zero Two Six [Member]    
Debt instrument, interest rate 5.18% 5.18%
v3.23.2
Note 10 - Fair Value Measurements (Details Textual) - USD ($)
$ in Thousands
Jun. 30, 2023
Dec. 31, 2022
Discount Rate 15.00% 15.00%
Embedded Derivative, Fair Value of Embedded Derivative Liability $ 0 $ 0
v3.23.2
Note 10 - Fair Value Measurements - Fair Value of Financial Assets and Liabilities (Details) - Fair Value, Inputs, Level 3 [Member] - USD ($)
$ in Thousands
Jun. 30, 2023
Dec. 31, 2022
Reported Value Measurement [Member]    
Contract receivable, net (current and long-term) [1] $ 30,182 $ 31,371
Estimate of Fair Value Measurement [Member]    
Contract receivable, net (current and long-term) [1] 25,254 24,833
Opco Senior Notes [Member] | Reported Value Measurement [Member]    
Long term debt, fair value [2] 79,402 98,281
Opco Senior Notes [Member] | Estimate of Fair Value Measurement [Member]    
Long term debt, fair value [2] 75,848 96,060
Floating Rate Revolving Credit Facility Due August 2027 [Member] | Reported Value Measurement [Member]    
Long term debt, fair value [3] 103,034 70,000
Floating Rate Revolving Credit Facility Due August 2027 [Member] | Estimate of Fair Value Measurement [Member]    
Long term debt, fair value [3] $ 103,034 $ 70,000
[1] The fair value of the Partnership's contract receivable is determined based on the present value of future cash flow projections related to the underlying asset at a discount rate of 15% at June 30, 2023 and December 31, 2022.
[2] The fair value of the Opco Senior Notes at June 30, 2023 and December 31, 2022 were estimated by management utilizing the present value replacement method incorporating the interest rate of the Opco Credit facility at June 30, 2023 and December 31, 2022, respectively.
[3] The fair value of the Opco Credit Facility approximates the outstanding borrowing amount because the interest rates are variable and reflective of market rates and the terms of the credit facility allow the Partnership to repay the debt at any time without penalty.
v3.23.2
Note 11 - Related Party Transactions (Details Textual) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Dec. 31, 2022
Accounts Payable, Current $ 1,524   $ 1,524   $ 1,992
Operating Costs and Expenses 7,930 $ 10,015 15,093 $ 18,091  
Quintana Minerals Corp [Member] | Affiliated Entity [Member]          
Accounts Payable, Current 400   400   400
Western Pocahontas Properties Limited Partnership [Member] | Affiliated Entity [Member]          
Accounts Payable, Current 800   800   $ 1,000
Operating Costs and Expenses $ 2,000 $ 2,700 $ 4,000 $ 4,300  
v3.23.2
Note 11 - Related Party Transactions - General Partner Affiliates (Details) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Operating Costs and Expenses $ 7,930 $ 10,015 $ 15,093 $ 18,091
QMC and WPPLP and QID [Member] | Affiliated Entity [Member]        
Operating Costs and Expenses 1,712 1,698 3,431 3,357
General and administrative expenses $ 1,253 $ 1,225 $ 2,573 $ 2,465
v3.23.2
Note 12 - Major Customers - Concentration Risk (Details) - USD ($)
$ in Thousands
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Alpha Metallurgical Resources [Member]        
Net sales [1] $ 19,685 $ 32,895 $ 43,903 $ 60,638
Alpha Metallurgical Resources [Member] | Revenue Benchmark [Member] | Customer Concentration Risk [Member]        
Revenue, percent (1) [1] 22.00% 33.00% 23.00% 32.00%
Foresight Energy Resources [Member]        
Net sales [1] $ 12,324 $ 16,497 $ 24,853 $ 27,747
Foresight Energy Resources [Member] | Revenue Benchmark [Member] | Customer Concentration Risk [Member]        
Revenue, percent (1) [1] 14.00% 17.00% 13.00% 15.00%
[1] Revenues from Alpha Metallurgical Resources, Inc. and Foresight are included within the Partnership's Mineral Rights segment.
v3.23.2
Note 14 - Unit-Based Compensation (Details Textual) - USD ($)
$ in Millions
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Fair Value $ 0.1   $ 16.0 $ 7.9  
Share-Based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Amount 18.2   $ 18.2   $ 6.3
Share-Based Payment Arrangement, Nonvested Award, Cost Not yet Recognized, Period for Recognition (Year)     2 years 3 months 18 days    
General and Administrative Expenses and Operating and Maintenance Expense [Member]          
Share-Based Payment Arrangement, Expense $ 2.6 $ 1.3 $ 5.1 $ 2.8  
v3.23.2
Note 14 - Unit-Based Compensation - Share-based Compensation Activity (Details)
shares in Thousands
6 Months Ended
Jun. 30, 2023
$ / shares
shares
Outstanding (in shares) | shares 386
Outstanding (in dollars per share) | $ / shares $ 28.96
Granted (in shares) | shares 281
Granted (in dollars per share) | $ / shares $ 56.84
Fully vested and issued (in shares) | shares (184)
Fully vested and issued (in dollars per share) | $ / shares $ 26.30
Outstanding (in shares) | shares 483
Outstanding (in dollars per share) | $ / shares $ 46.21
v3.23.2
Note 15 - Financing Transaction (Details Textual) - Sugar Camp Mine [Member] - USD ($)
6 Months Ended 12 Months Ended
Jun. 30, 2023
Dec. 31, 2032
Lessor, Operating Lease, Renewal Term (Year) 80 years  
Proceeds from Annual Minimum Lease Payments $ 5,000,000.0  
Forecast [Member]    
Operating Lease, Lease Income   $ 10,000
v3.23.2
Note 16 - Credit Losses (Details Textual) - USD ($)
$ in Millions
3 Months Ended 6 Months Ended
Jun. 30, 2023
Jun. 30, 2022
Jun. 30, 2023
Jun. 30, 2022
Financing Receivable, Credit Loss, Expense (Reversal) $ (0.2) $ (0.4) $ (0.8) $ 0.6
v3.23.2
Note 16 - Credit Losses - Allowance for Credit Losses (Details) - USD ($)
$ in Thousands
Jun. 30, 2023
Dec. 31, 2022
Receivables $ 42,974 $ 47,237
Receivables (3,699) (4,461)
Receivables 39,275 42,776
Long-term contract receivable 28,652 29,984
Long-term contract receivable (993) (1,038)
Long-term contract receivable 27,659 28,946
Total 71,626 77,221
Total (4,692) (5,499)
Total $ 66,934 $ 71,722
v3.23.2
Note 17 - Subsequent Events (Details Textual) - Subsequent Event [Member]
$ / shares in Units, $ in Millions
1 Months Ended
Aug. 31, 2023
USD ($)
$ / shares
Distribution Made to Limited Partner, Distributions Paid, Per Unit (in dollars per share) | $ / shares $ 0.75
Dividends, Preferred Stock, Cash | $ $ 3.7

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