NATURAL RESOURCE PARTNERS LP 10-Q

nrp20230630_10q.htm   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       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 (Registrant ’ s 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.       Table of Contents     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. Management ’ s 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   i Table of Contents       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.   1 Table of Contents     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.   2 Table of Contents     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.   3 Table of Contents     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.   4 Table of Contents     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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents 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 Table of Contents     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.    17 Table of Contents   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.   18 Table of Contents   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 m onths 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:   19 Table of Contents   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 )%   20 Table of Contents   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 mi llion 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.   21 Table of Contents   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 )   22 Table of Contents   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:   23 Table of Contents   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 )%   24 Table of Contents   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 mi llion p rimarily 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.   25 Table of Contents   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 )   26 Table of Contents   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     27 Table of Contents   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.   28 Table of Contents   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 Partnership ’ s 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.   29 Table of Contents   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   30 Table of Contents   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