NATURAL RESOURCE PARTNERS LP 10-Q

nrp20260630_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, 2026 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 15 Item 3. Quantitative and Qualitative Disclosures About Market Risk 28 Item 4. Controls and Procedures 28 Part II. Other Information Item 1. Legal Proceedings 29 Item 1A. Risk Factors 29 Item 2. Unregistered Sales of Equity Securities and Use of Proceeds 29 Item 3. Defaults Upon Senior Securities 29 Item 4. Mine Safety Disclosures 29 Item 5. Other Information 29 Item 6. Exhibits 29 Signatures 30 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, 2026 2025 (In thousands, except unit data) (Unaudited) ASSETS Current assets Cash and cash equivalents $ 30,132 $ 30,141 Accounts receivable, net 30,640 28,666 Other current assets, net 934 2,105 Total current assets $ 61,706 $ 60,912 Land 24,007 24,008 Mineral rights, net 351,503 366,987 Intangible assets, net 8,655 11,908 Equity in unconsolidated investment 277,475 250,244 Long-term contract receivable, net 18,775 20,406 Other long-term assets, net 15,414 13,900 Total assets $ 757,535 $ 748,365 LIABILITIES AND CAPITAL Current liabilities Accounts payable $ 989 $ 1,159 Accrued liabilities 7,127 10,897 Accrued interest 63 69 Current portion of deferred revenue 6,705 6,663 Current portion of debt, net 14,271 14,198 Total current liabilities $ 29,155 $ 32,986 Deferred revenue 59,744 58,067 Long-term debt, net 13,084 18,884 Other non-current liabilities 5,496 5,909 Total liabilities $ 107,479 $ 115,846 Commitments and contingencies (see Note 12) Partners’ capital Common unitholders’ interest ( 13,250,412 and 13,138,097 units issued and outstanding at June 30, 2026 and December 31, 2025, respectively) $ 641,221 $ 625,188 General partner’s interest 12,072 11,332 Accumulated other comprehensive loss ( 3,237 ) ( 4,001 ) Total partners’ capital $ 650,056 $ 632,519 Total liabilities and partners' capital $ 757,535 $ 748,365 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) 2026 2025 2026 2025 Revenues and other income Royalty and other mineral rights $ 49,119 $ 44,295 $ 92,416 $ 95,555 Transportation and processing services 3,851 2,551 7,736 6,972 Equity in earnings (loss) of Sisecam Wyoming ( 4,905 ) 2,526 ( 12,733 ) 7,136 Gain on asset sales and disposals 45 729 44 976 Total revenues and other income $ 48,110 $ 50,101 $ 87,463 $ 110,639 Operating expenses Operating and maintenance expenses $ 5,731 $ 4,159 $ 11,844 $ 10,935 Depreciation, depletion and amortization 11,131 3,754 18,745 7,743 General and administrative expenses 5,020 5,597 10,054 12,429 Asset impairments — — — 20 Total operating expenses $ 21,882 $ 13,510 $ 40,643 $ 31,127 Income from operations $ 26,228 $ 36,591 $ 46,820 $ 79,512 Interest expense, net $ ( 1,052 ) $ ( 2,380 ) $ ( 2,025 ) $ ( 5,048 ) Net income $ 25,176 $ 34,211 $ 44,795 $ 74,464 Net income attributable to common unitholders $ 24,672 $ 33,527 $ 43,899 $ 72,975 Net income attributable to the general partner 504 684 896 1,489 Net income per common unit (see Note 4) Basic $ 1.86 $ 2.55 $ 3.32 $ 5.56 Diluted 1.85 2.52 3.29 5.49 Net income $ 25,176 $ 34,211 $ 44,795 $ 74,464 Comprehensive income (loss) from unconsolidated investment and other 904 ( 414 ) 764 1,846 Comprehensive income $ 26,080 $ 33,797 $ 45,559 $ 76,310 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 Comprehensive Partners' (In thousands) Units Amounts Partner Loss Capital Balance at December 31, 2025 13,138 $ 625,188 $ 11,332 $ ( 4,001 ) $ 632,519 Net income — 19,227 392 — 19,619 Distributions to common unitholders and the general partner — ( 11,528 ) ( 235 ) — ( 11,763 ) Issuance of unit-based awards 112 — — — — Unit-based awards amortization and vesting, net — ( 7,985 ) — — ( 7,985 ) Capital contribution — — 282 — 282 Comprehensive loss from unconsolidated investment and other — — — ( 140 ) ( 140 ) Balance at March 31, 2026 13,250 $ 624,902 $ 11,771 $ ( 4,141 ) $ 632,532 Net income — 24,672 504 — 25,176 Distributions to common unitholders and the general partner — ( 9,938 ) ( 203 ) — ( 10,141 ) Unit-based awards amortization — 1,585 — — 1,585 Comprehensive income from unconsolidated investment and other — — — 904 904 Balance at June 30, 2026 13,250 $ 641,221 $ 12,072 $ ( 3,237 ) $ 650,056 Accumulated Other Total Common Unitholders General Comprehensive Partners' (In thousands) Units Amounts Partner Income (Loss) Capital Balance at December 31, 2024 13,049 $ 543,231 $ 9,547 $ ( 1,670 ) $ 551,108 Net income — 39,448 805 — 40,253 Distributions to common unitholders and the general partner — ( 25,750 ) ( 526 ) — ( 26,276 ) Issuance of unit-based awards 89 — — — — Unit-based awards amortization and vesting, net — ( 3,175 ) — — ( 3,175 ) Capital contribution — — 187 — 187 Comprehensive income from unconsolidated investment and other — — — 2,260 2,260 Balance at March 31, 2025 13,138 $ 553,754 $ 10,013 $ 590 $ 564,357 Net income — 33,527 684 — 34,211 Distributions to common unitholders and the general partner — ( 9,854 ) ( 201 ) — ( 10,055 ) Unit-based awards amortization — 2,346 — — 2,346 Comprehensive loss from unconsolidated investment and other — — — ( 414 ) ( 414 ) Balance at June 30, 2025 13,138 $ 579,773 $ 10,496 $ 176 $ 590,445 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) 2026 2025 Cash flows from operating activities Net income $ 44,795 $ 74,464 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion and amortization 18,745 7,743 Distributions from unconsolidated investment — 7,840 Equity in (earnings) loss from unconsolidated investment 12,733 ( 7,136 ) Gain on asset sales and disposals ( 44 ) ( 976 ) Asset impairments — 20 Bad debt expense ( 743 ) ( 869 ) Unit-based compensation expense 2,835 5,379 Amortization of debt issuance costs and other 889 ( 449 ) Change in operating assets and liabilities: Accounts receivable ( 3,211 ) 3,461 Accounts payable ( 170 ) 20 Accrued liabilities ( 4,795 ) ( 5,694 ) Accrued interest ( 6 ) ( 134 ) Deferred revenue 1,719 ( 4,213 ) Other items, net 1,217 547 Net cash provided by operating activities $ 73,964 $ 80,003 Cash flows from investing activities Proceeds from asset sales and disposals $ 46 $ 977 Capital to unconsolidated investment ( 39,200 ) — Return of long-term contract receivable 1,531 1,414 Net cash provided by (used in) investing activities $ ( 37,623 ) $ 2,391 Cash flows from financing activities Debt borrowings $ 67,200 $ 33,700 Debt repayments ( 73,000 ) ( 74,500 ) Distributions to common unitholders and the general partner ( 21,904 ) ( 36,331 ) Other items, net ( 8,646 ) ( 5,363 ) Net cash used in financing activities $ ( 36,350 ) $ ( 82,494 ) Net decrease in cash and cash equivalents $ ( 9 ) $ ( 100 ) Cash and cash equivalents at beginning of period 30,141 30,444 Cash and cash equivalents at end of period $ 30,132 $ 30,344 Supplemental cash flow information: Cash paid for interest $ 1,888 $ 5,096 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 reportable segments further described in Note 5. 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, 2025 , and notes thereto included in the Partnership's Annual Report on Form 10 -K, which was filed with the SEC on February 27, 2026. 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 Issued Accounting Standard In November 2024, the FASB issued ASU 2024 - 03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures ("ASU 2024 - 03" ). ASU 2024 - 03 is intended to improve disclosures about a public business entity's expenses and provide more detailed information to investors about the types of expenses in commonly presented expense captions. The guidance is effective for annual periods beginning after December 15, 2026, and quarterly periods beginning after December 31, 2027, and can be adopted prospectively to financial statements issued for reporting periods after the effective date or retrospectively to all prior periods presented in the financial statements. NRP does not expect the adoption of this guidance to have a material impact on its Consolidated Financial Statements. 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 from contracts with customers by major source: For the Three Months Ended June 30, For the Six Months Ended June 30, (In thousands) 2026 2025 2026 2025 Coal royalty revenues $ 34,793 $ 31,543 $ 64,367 $ 67,041 Production lease minimum revenues 251 123 809 2,848 Minimum lease straight-line revenues 4,019 4,050 8,038 8,100 Oil and gas royalty revenues 2,447 1,981 3,833 4,425 Carbon neutral revenues 94 290 279 885 Property tax revenues 1,710 1,519 3,421 3,156 Wheelage revenues 1,959 2,543 3,949 4,281 Coal overriding royalty revenues 1,040 456 2,426 1,336 Lease amendment revenues 1,242 656 2,442 1,311 Aggregates royalty revenues 1,246 906 2,364 1,759 Other revenues 318 228 488 413 Royalty and other mineral rights revenues $ 49,119 $ 44,295 $ 92,416 $ 95,555 Transportation and processing services revenues 3,389 2,029 6,797 5,914 Total Mineral Rights segment revenues from contracts with customers $ 52,508 $ 46,324 $ 99,213 $ 101,469 The following table details the Partnership's Mineral Rights segment contract assets and liabilities resulting from contracts with customers: June 30, December 31, (In thousands) 2026 2025 Contract assets Accounts receivable, net $ 26,228 $ 24,372 Other current assets, net — 84 Other long-term assets, net 7,353 5,281 Contract liabilities Accounts payable $ 125 $ 211 Current portion of deferred revenue 6,705 6,663 Deferred revenue 59,744 58,067 The following table shows the activity related to the Partnership's Mineral Rights segment deferred revenue resulting from contracts with customers: For the Six Months Ended June 30, (In thousands) 2026 2025 Balance at beginning of period (current and non-current) $ 64,730 $ 60,155 Increase due to minimums and lease amendment fees 15,793 7,836 Recognition of previously deferred revenue ( 14,074 ) ( 12,049 ) Balance at end of period (current and non-current) $ 66,449 $ 55,942 The Partnership's non-cancellable annual minimum payments due under the lease terms of its coal and aggregates royalty contracts with customers are as follows as of June 30, 2026 (in thousands): Lease Term (1) Weighted Average Remaining Years Annual Minimum Payments 0 - 5 years 1.9 $ 13,216 5 - 10 years 6.0 15,392 10+ years 9.8 26,309 Total 6.8 $ 54,917 ( 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. Common Unit Distributions The Partnership makes cash distributions to common 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 common 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. The following table shows the cash distributions declared and paid to common unitholders during the six months ended June 30, 2026 and 2025 , respectively: Month Paid Period Covered by Distribution Distribution per Unit Total Distribution (1) (In thousands) 2026 February October 1 - December 31, 2025 $ 0.75 $ 10,141 March (2) Special Distribution 0.12 1,622 May January 1 - March 31, 2026 0.75 10,141 2025 February October 1 - December 31, 2024 $ 0.75 $ 10,055 March (3) Special Distribution 1.21 16,221 May January 1 - March 31, 2025 0.75 10,055 ( 1 ) Totals include the amount paid to NRP's general partner in accordance with the general partner's 2% general partner interest. ( 2 ) Special distribution was made to help cover unitholder tax liabilities associated with owning NRP's common units during 2025. ( 3 ) Special distribution was made to help cover unitholder tax liabilities associated with owning NRP's common units during 2024. 4. Net Income Per Common Unit Basic net income per common unit is computed by dividing net income, after considering 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 unvested unit-based awards if the inclusion of these items is dilutive. The dilutive effect of the unvested unit-based awards is calculated using the treasury stock method, which assumes that the proceeds from the vesting of the unvested unit-based awards 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, 2026 and 2025 included the impact of the vesting of the unvested unit-based awards. 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) 2026 2025 2026 2025 Basic net income per common unit Net income attributable to common unitholders $ 24,672 $ 33,527 $ 43,899 $ 72,975 Weighted average common units—basic 13,250 13,138 13,225 13,118 Basic net income per common unit $ 1.86 $ 2.55 $ 3.32 $ 5.56 Diluted net income per common unit Weighted average common units—basic 13,250 13,138 13,225 13,118 Plus: dilutive effect of unvested unit-based awards 84 153 117 180 Weighted average common units—diluted 13,334 13,291 13,342 13,298 Diluted net income attributable to common unitholders and the general partner $ 25,176 $ 34,211 $ 44,795 $ 74,464 Less: diluted net income attributable to the general partner ( 504 ) ( 684 ) ( 896 ) ( 1,489 ) Diluted net income attributable to common unitholders $ 24,672 $ 33,527 $ 43,899 $ 72,975 Diluted net income per common unit $ 1.85 $ 2.52 $ 3.29 $ 5.49 7 Table of Contents NATURAL RESOURCE PARTNERS L.P. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (Unaudited) 5. Segment Information The Partnership's reportable 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 reportable 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. Soda Ash —consists of the Partnership's 49 % non-controlling equity interest in Sisecam Wyoming, one of the world's lowest-cost producers of soda ash, an essential ingredient for the manufacturing of glass, detergents, solar panels, and batteries for electric vehicles. Operations are managed by NRP's partner, Sisecam Chemicals Wyoming, LLC, and NRP realizes cash flow when distributions are paid to it. Direct segment costs and certain other costs incurred at the corporate level that are identifiable and that benefit the Partnership's reportable segments are allocated to the reportable 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 reportable segment and are included in general and administrative expenses on the Partnership's Consolidated Statements of Comprehensive Income. NRP’s Chief Operating Decision Makers (“CODMs”) are its Chief Executive Officer and President and Chief Operating Officer. They evaluate the Partnership’s performance through a review of the reportable segments’ net income and free cash flow as compared to budget and utilize this information to assess the reportable segments’ performance and allocate resources. NRP does not conduct operations on any of its assets or directly engage in any type of industrial activity. Instead, it leases its mineral and other rights to companies that conduct operations on its properties in exchange for paying royalties and other fees to the Partnership. Operating expenses, capital costs and other liabilities arising out of production activities are borne entirely by NRP's lessees. In the case of its soda ash investment, operations are managed by NRP's partner, Sisecam Chemicals Wyoming LLC. NRP has determined its significant segment expenses to be its employee related expenses, including compensation (salaries, benefits and bonus) and property tax expense. The Partnership is responsible for paying property taxes on the properties it owns. Typically, NRP's lessees are contractually responsible for reimbursing the Partnership for property taxes on the leased properties and this reimbursement amount is included within the Mineral Rights reportable segment revenues. 8 Table of Contents NATURAL RESOURCE PARTNERS L.P. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (Unaudited) The following tables summarize certain financial information for each of the Partnership's reportable segments: Reportable Segments (In thousands) Mineral Rights Soda Ash Total Reportable Segments Corporate and Financing Total For the Three Months Ended June 30, 2026 Revenues $ 52,970 $ — $ 52,970 $ — $ 52,970 Equity in loss of Sisecam Wyoming — ( 4,905 ) ( 4,905 ) — ( 4,905 ) Gain on asset sales and disposals 45 — 45 — 45 Total revenues and other income $ 53,015 $ ( 4,905 ) $ 48,110 $ — $ 48,110 Less: Compensation (salaries, benefits and bonus) $ 1,808 $ — $ 1,808 $ 1,988 $ 3,796 Property taxes 1,876 — 1,876 — 1,876 Depreciation, depletion and amortization 11,126 — 11,126 5 11,131 Other items (1) 1,968 79 2,047 4,084 6,131 Net income (loss) $ 36,237 $ ( 4,984 ) $ 31,253 $ ( 6,077 ) $ 25,176 For the Three Months Ended June 30, 2025 Revenues $ 46,846 $ — $ 46,846 $ — $ 46,846 Equity in earnings of Sisecam Wyoming — 2,526 2,526 — 2,526 Gain on asset sales and disposals 729 — 729 — 729 Total revenues and other income $ 47,575 $ 2,526 $ 50,101 $ — $ 50,101 Less: Compensation (salaries, benefits and bonus) $ 1,683 $ — $ 1,683 $ 1,847 $ 3,530 Property taxes 1,767 — 1,767 — 1,767 Depreciation, depletion and amortization 3,748 — 3,748 6 3,754 Other items (1) 686 24 710 6,129 6,839 Net income (loss) $ 39,691 $ 2,502 $ 42,193 $ ( 7,982 ) $ 34,211 For the Six Months Ended June 30, 2026 Revenues $ 100,152 $ — $ 100,152 $ — $ 100,152 Equity in loss of Sisecam Wyoming — ( 12,733 ) ( 12,733 ) — ( 12,733 ) Gain on asset sales and disposals 44 — 44 — 44 Total revenues and other income $ 100,196 $ ( 12,733 ) $ 87,463 $ — $ 87,463 Less: Compensation (salaries, benefits and bonus) $ 3,605 $ — $ 3,605 $ 4,052 $ 7,657 Property taxes 3,755 — 3,755 — 3,755 Depreciation, depletion and amortization 18,736 — 18,736 9 18,745 Other items (1) 4,333 151 4,484 8,027 12,511 Net income (loss) $ 69,767 $ ( 12,884 ) $ 56,883 $ ( 12,088 ) $ 44,795 As of June 30, 2026 Total assets $ 475,312 $ 277,475 $ 752,787 $ 4,748 $ 757,535 For the Six Months Ended June 30, 2025 Revenues $ 102,527 $ — $ 102,527 $ — $ 102,527 Equity in earnings of Sisecam Wyoming — 7,136 7,136 — 7,136 Gain on asset sales and disposals 976 — 976 — 976 Total revenues and other income $ 103,503 $ 7,136 $ 110,639 $ — $ 110,639 Less: — — Compensation (salaries, benefits and bonus) $ 3,621 $ — $ 3,621 $ 3,956 $ 7,577 Property taxes 3,559 — 3,559 — 3,559 Depreciation, depletion and amortization 7,733 — 7,733 10 7,743 Asset impairments 20 — 20 — 20 Other items (1) 3,671 84 3,755 13,521 17,276 Net income (loss) $ 84,899 $ 7,052 $ 91,951 $ ( 17,487 ) $ 74,464 As of December 31, 2025 Total assets $ 492,672 $ 250,244 $ 742,916 $ 5,449 $ 748,365 ( 1 ) Other items in the Mineral Rights reportable segment primarily include: insurance, legal, overriding royalty expense, processing and transportation expense, information technology, shared facility services, rent, professional fees, long-term incentive compensation expense and bad debt expense. Other items in the Soda Ash reportable segment primarily include professional fees. Other items in Corporate and Financing primarily include: interest expense, net, long-term incentive compensation expense, insurance, legal, information technology, shared facility services, rent and professional fees. 9 Table of Contents NATURAL RESOURCE PARTNERS L.P. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (Unaudited) 6. 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) 2026 2025 2026 2025 Balance at beginning of period $ 281,477 $ 261,286 $ 250,244 $ 257,355 Income (loss) allocation to NRP’s equity interests (1) ( 3,821 ) 3,652 ( 10,518 ) 9,416 Amortization of basis difference ( 1,085 ) ( 1,126 ) ( 2,215 ) ( 2,279 ) Capital investment — — 39,200 — Other comprehensive income (loss) 904 ( 414 ) 764 1,846 Distributions — ( 4,900 ) — ( 7,840 ) Balance at end of period $ 277,475 $ 258,498 $ 277,475 $ 258,498 ( 1 ) Amounts reclassified into income (loss) out of accumulated other comprehensive loss were $ 1.5 million and $ 0.0 million for the three months ended June 30, 2026 and 2025 , respectively, and $ 3.1 million and $ 1.3 million for the six months ended June 30, 2026 and 2025 , respectively. During the six months ended June 30, 2026, NRP and Sisecam Wyoming's managing partner made a capital investment into Sisecam Wyoming ($ 39.2 million for NRP's 49 %) to reduce outstanding amounts under Sisecam Wyoming's bank credit facility. 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, 2026 and 2025 : For the Three Months Ended June 30, For the Six Months Ended June 30, (In thousands) 2026 2025 2026 2025 Net sales $ 132,798 $ 136,598 $ 260,133 $ 289,907 Gross profit (loss) 782 15,170 ( 3,949 ) 34,203 Net income (loss) ( 7,798 ) 7,452 ( 21,465 ) 19,216 7. Mineral Rights, Net The Partnership’s mineral rights consist of the following: June 30, 2026 December 31, 2025 (In thousands) Carrying Value Accumulated Depletion Net Book Value Carrying Value Accumulated Depletion Net Book Value Coal properties $ 653,808 $ ( 319,665 ) $ 334,143 $ 653,808 $ ( 304,412 ) $ 349,396 Aggregates properties 8,655 ( 4,520 ) 4,135 8,655 ( 4,364 ) 4,291 Oil and gas royalty properties 12,354 ( 10,658 ) 1,696 12,354 ( 10,584 ) 1,770 Other 13,141 ( 1,612 ) 11,529 13,142 ( 1,612 ) 11,530 Total mineral rights, net $ 687,958 $ ( 336,455 ) $ 351,503 $ 687,959 $ ( 320,972 ) $ 366,987 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 $ 9.4 million and $ 3.5 million for the three months ended June 30, 2026 and 2025 , respectively, and $ 15.5 million and $ 7.2 million for the six months ended June 30, 2026 and 2025 , 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 minerals 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 Partnership's analysis, NRP recorded an immaterial impairment expense during the six months ended June 30, 2025. 10 Table of Contents NATURAL RESOURCE PARTNERS L.P. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (Unaudited) 8. Debt, Net The Partnership's debt consists of the following: June 30, December 31, (In thousands) 2026 2025 Opco Credit Facility $ 13,084 $ 18,884 Opco Senior Notes 5.03% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026 $ 11,420 $ 11,420 5.18% with semi-annual interest payments in June and December, with annual principal payments in December, due December 2026 2,911 2,911 Total Opco Senior Notes $ 14,331 $ 14,331 Total debt at face value $ 27,415 $ 33,215 Net unamortized debt issuance costs ( 60 ) ( 133 ) Total debt, net $ 27,355 $ 33,082 Less: current portion of debt ( 14,271 ) ( 14,198 ) Total long-term debt, net $ 13,084 $ 18,884 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, 2026 and December 31, 2025 , Opco was in compliance with the terms of the financial covenants contained in its debt agreements. Opco Credit Facility As of December 31, 2025 , the Partnership had $ 18.9 million in borrowings outstanding under the Opco Credit Facility and $ 181.1 million of available borrowing capacity. During the six months ended June 30, 2026 , the Partnership borrowed $ 67.2 million and repaid $ 73.0 million, resulting in $ 13.1 million in borrowings outstanding under the Opco Credit Facility and $ 186.9 million of available borrowing capacity as of June 30, 2026 . During the six months ended June 30, 2025 , the Partnership borrowed $ 33.7 million and repaid $ 74.5 million on the Opco Credit Facility. The weighted average interest rate for the borrowings outstanding under the Opco Credit Facility for the three months ended June 30, 2026 and 2025 were 7.25 % and 7.93 %, respectively. The weighted average interest rate for the borrowings outstanding under the Opco Credit Facility for the six months ended June 30, 2026 and 2025 were 7.26 % and 7.93 %, million for the respectively. The Opco Credit Facility is collateralized and secured by liens on certain of Opco’s assets with carrying values of $ 276.0 million an d $ 290.6 million classified as mineral rights, net and $ 18.8 million and $ 20.4 million classified as long-term contract receivable, net on the Partnership’s Consolidated Balance Sheets as of June 30, 2026 and December 31, 2025 , respectively. 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. As of June 30, 2026 , this rati o was 0.2x; 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 June 30, 2026 , this ratio was 25.7x. Opco Senior Notes Opco issued several series of private placement senior notes (the "Opco Senior Notes") with various interest rates and principal due dates. As of June 30, 2026 , the 5.03% and 5.18% Opco Senior Notes remain outstanding. These Opco Senior Notes have principal due annually in December and interest due semi-annually in June and December. As of both June 30, 2026 and December 31, 2025 , the Opco Senior Notes had cumulative principal balances of $ 14.3 million. These Opco Senior Notes will fully mature in December 2026. 11 Table of Contents NATURAL RESOURCE PARTNERS L.P. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (Unaudited) 9. Fair Value Measurements Fair Value of Financial Assets and Liabilities The Partnership’s financial assets and liabilities consist of cash and cash equivalents, accounts receivables, a contract receivable, accounts payables and debt. The carrying amounts reported on the Consolidated Balance Sheets for cash and cash equivalents, accounts receivables and accounts payables 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 contract receivable and debt. The following table shows the carrying value and estimated fair value of the Partnership's contract receivable and debt: June 30, 2026 December 31, 2025 Fair Value Carrying Estimated Carrying Estimated (In thousands) Hierarchy Level Value Fair Value Value Fair Value Assets: Contract receivable, net (current and long-term) (1) 3 $ 21,973 $ 19,679 $ 23,480 $ 20,792 Debt: Opco Senior Notes (2) 3 $ 14,271 $ 14,180 $ 14,198 $ 14,018 Opco Credit Facility (3) 3 13,084 13,084 18,884 18,884 ( 1 ) The fair value of the Partnership's contract receivable is determined based on the present value of future cash flow projections related to the underlying asset at a discount rate of 15 % at June 30, 2026 and December 31, 2025 . ( 2 ) The fair value of the Opco Senior Notes was estimated by management utilizing the present value replacement method incorporating the interest rate of the Opco Credit Facility. ( 3 ) The fair value of the Opco Credit Facility approximates the outstanding borrowing amount because the interest rates are variable and reflective of market rates and the terms of the credit facility allow the Partnership to repay the debt at any time without penalty. 10. 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, and other related parties, 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. Related party general and administrative expenses included on the Partnership's Consolidated Statement of Comprehensive Income are as follows: For the Three Months Ended June 30, For the Six Months Ended June 30, (In thousands) 2026 2025 2026 2025 Operating and maintenance expenses $ 1,629 $ 1,515 $ 3,251 $ 3,308 General and administrative expenses 1,353 1,313 2,919 2,882 The Partnership had accounts payable to related parties of $ 0.6 million and $ 0.7 million on its Consolidated Balance Sheets as of June 30, 2026 and December 31, 2025, respectively. As of June 30, 2026 and December 31, 2025, the Partnership had $ 0.1 million a nd $ 0.2 million, respectively, of prepaid expenses included in other current assets, net on its Consolidated Balance Sheets. As a result of its office lease with WPPLP, the Partnership has a right-of-use asset and lease liability of $ 3.4 million included in other long-term assets, net and other non-current liabilities, respectively on its Consolidated Balance Sheets at both June 30, 2026 and December 31, 2025 . During the three months ended June 30, 2026 and 2025, the Partnership recognized less than $ 0.1 million and $ 0.1 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 $ 1.2 million and $ 0.2 million during the six months ended June 30, 2026 and 2025 , respectively. As of both June 30, 2026 and December 31, 2025, the Partnership had $ 0.1 million in accounts payable on its Consolidated Balance Sheets related to this agreement. As of both June 30, 2026 and December 31, 2025, the Partnership had $ 1.1 million of other long-term assets, net on its Consolidated Balance Sheets related to a prepaid royalty for this agreement. 12 Table of Contents NATURAL RESOURCE PARTNERS L.P. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (Unaudited) 11. 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, 2026 2025 2026 2025 (In thousands) Revenues Percent Revenues Percent Revenues Percent Revenues Percent Foresight Energy Resources LLC ("Foresight") (1) $ 13,830 26 % $ 9,796 21 % $ 27,327 27 % $ 26,256 26 % Alpha Metallurgical Resources, Inc. (1) $ 13,517 26 % $ 13,184 28 % $ 27,218 27 % $ 26,360 26 % Alabama Kanu Holdings, LLC (1) $ 5,856 11 % $ 5,284 11 % $ 10,586 11 % $ 8,543 8 % ( 1 ) Revenues from Foresight, Alpha Metallurgical Resources, Inc., and Alabama Kanu Holdings, LLC are generated in the United States of America and are included within the Partnership's Mineral Rights segment. 12. 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 as of and for the three and six months ended June 30, 2026. 13. Unit-Based Compensation During the six months ended June 30, 2026 and 2025 , the Partnership granted service, performance and market-based awards under its 2017 Long-Term Incentive Plan. 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 the awards granted during the six months ended June 30, 2026 and 2025 was $ 8.6 million and $ 6.8 million, respectively, which included a grant date fair value of $ 3.1 million and $ 2.5 million for the market-based awards valued using a Monte Carlo simulation during the six months ended June 30, 2026 and 2025 , respectively. Total unit-based compensation expense associated with service, performance and market-based awards was $ 1.7 million and $ 2.7 million for the three months ended June 30, 2026 and 2025 , respectively, and is included in general and administrative expenses and operating and maintenance expenses on the Partnership's Consolidated Statements of Comprehensive Income. Total unit-based compensation expense associated with service, performance and market-based awards was $ 2.8 million and $ 5.4 million for the six months ended June 30, 2026 and 2025 , respectively. The unamortized cost associated with unvested outstanding awards as of June 30, 2026 was $ 10.4 million, which will be recognized over a weighted average period of 2.1 years. The unamortized cost associated with unvested outstanding awards as of December 31, 2025 was $ 5.9 million. The Partnership paid $ 8.9 million and $ 5.5 million in cash during the six months ended June 30, 2026 and 2025 , respectively, for taxes on the unit-based award settlements during the respective years. These cash payments are included in other items, net under cash flows from financing activities on the Partnership's Consolidated Statements of Cash Flows. A summary of the unit activity in the outstanding grants during 2026 is as follows: (In thousands) Common Units Weighted Average Grant Date Fair Value per Common Unit Outstanding at January 1, 2026 266 $ 78.68 Granted 65 $ 132.29 Fully vested and issued ( 155 ) $ 65.19 Outstanding at June 30, 2026 176 $ 110.54 13 Table of Contents NATURAL RESOURCE PARTNERS L.P. NOTES TO CONSOLIDATED FINANCIAL STATEMENTS—CONTINUED (Unaudited) 14. 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, 2026 and December 31, 2025 , NRP had the following current expected credit loss (“CECL”) allowance related to its receivables and long-term contract receivable: June 30, 2026 December 31, 2025 (In thousands) Gross CECL Allowance Net Gross CECL Allowance Net Receivables $ 39,304 $ ( 3,595 ) $ 35,709 $ 36,178 $ ( 4,183 ) $ 31,995 Long-term contract receivable 19,449 ( 674 ) 18,775 21,138 ( 732 ) 20,406 Total $ 58,753 $ ( 4,269 ) $ 54,484 $ 57,316 $ ( 4,915 ) $ 52,401 NRP recorded an expense of less than $ 0.1 million and a reversal of $ 1.4 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, 2026 and 2025 , respectively, and reversals of $ 0.6 million and $ 1.7 million during the six months ended June 30, 2026 and 2025 , 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. 15. Subsequent Events The following represents material events that occurred after June 30, 2026 through the time of the Partnership’s filing of its Quarterly Report on Form 10 -Q with the SEC: Common Unit Distributions In August 2026, the Board of Directors declared a distribution of $ 0.75 per common unit with respect to the second quarter of 2026 . 14 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, 2026 and 2025 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, 2025. 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. 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: future distributions on our common 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 business; 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, 2025 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 in 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 8. 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, 2025. 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. 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 capital expenditures, cash flow used in acquisition costs classified as investing or financing activities and capital to unconsolidated investment. 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. 15 Table of Contents Introduction The following discussion and analysis present management's view of our business, financial condition and overall performance. Our discussion and analysis consist 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 reportable 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 assets provide critical inputs for the manufacturing of steel, electricity and building materials as well as opportunities for carbon sequestration and renewable energy. Soda Ash —consists of our 49% non-controlling equity interest in Sisecam Wyoming, one of the world's lowest-cost producers of soda ash, an essential ingredient for the manufacturing of glass, solar panels, detergents, and batteries for electric vehicles. Operations are managed by our partner, Sisecam Chemicals Wyoming LLC, and we realize cash flow when distributions are paid to us. 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 reportable segment. Our financial results for the six months ended June 30, 2026 are as follows: Reportable Segments (In thousands) Mineral Rights Soda Ash Corporate and Financing Total Revenues and other income $ 100,196 $ (12,733 ) $ — $ 87,463 Net income (loss) $ 69,767 $ (12,884 ) $ (12,088 ) $ 44,795 Adjusted EBITDA (1) $ 88,503 $ (151 ) $ (10,054 ) $ 78,298 Cash flow provided by (used in) continuing operations Operating activities $ 86,406 $ (151 ) $ (12,291 ) $ 73,964 Investing activities $ 1,577 $ (39,200 ) $ — $ (37,623 ) Financing activities $ (1,256 ) $ — $ (35,094 ) $ (36,350 ) Free cash flow (1) $ 87,937 $ (39,351 ) $ (12,291 ) $ 36,295 (1) See "Results of Operations" below for reconciliations to the most comparable GAAP financial measures. 16 Table of Contents Current Results/Market Commentary Financial Results and Quarterly Distributions We generated $74.0 million of operating cash flow and $36.3 million of free cash flow during the six months ended June 30, 2026, and ended the quarter with $217.0 million of liquidity consisting of $30.1 million of cash and cash equivalents and $186.9 million of available borrowing capacity under our Opco Credit Facility. As of June 30, 2026 our leverage ratio was 0.2 x. In February 2026, we paid a cash distribution of $0.75 per common unit of NRP with respect to the fourth quarter of 2025. In March 2026, we paid a special cash distribution of $0.12 per common unit of NRP to help cover unitholder tax liabilities associated with owning NRP's common units in 2025. In May 2026, we paid a cash distribution of $0.75 per common unit of NRP with respect to the first quarter of 2026. Future distributions on our common 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 of Directors determines is necessary for future operating and capital needs. Mineral Rights Reportable Segment Revenues and other income during the six months ended June 30, 2026 decreased $3.3 million, or 3% , as compared to the prior year period. Cash provided by operating activities and free cash flow during the six months ended June 30, 2026 decreased by $2.4 million and $2.3 million, respectively, as compared to the prior year period. These decreases are primarily due to lower metallurgical and thermal coal sales volumes at certain properties. Mineral Rights segment results continue to be impacted by low natural gas prices, ample coal stockpiles at power plants, and soft global steel demand. We have no meaningful developments to report on our carbon neutral initiatives, but continue to explore opportunities to create value through carbon sequestration and renewable energy production across our vast portfolio of mineral and surface assets. Soda Ash Reportable Segment Revenues and other income during the six months ended June 30, 2026 decreased $19.9 million, or 278%, as compared to the prior year period primarily due to lower sales prices in 2026. Cash provided by operating activities during the six months ended June 30, 2026 decreased $7.9 million as compared to the prior year period due primarily due to $7.8 million in distributions received from Sisecam Wyoming in 2025 and no distribution received from Sisecam Wyoming in 2026. Free cash flow decreased $47.1 million as compared to the prior year period primarily due to the $39.2 million capital investment made to Sisecam Wyoming in the first quarter of 2026 in addition to $7.8 million in distributions received from Sisecam Wyoming in 2025. The global soda ash market remains weak with international soda ash prices below the cost of production for many producers due to the increased natural soda ash supply from China, along with sluggish demand for flat glass due to slowing commercial and residential construction globally. We do not expect to receive distributions from Sisecam Wyoming for several years until the soda ash market returns to equilibrium through increased demand and/or capacity rationalization. 17 Table of Contents Results of Operations Second Quarter of 2026 and 2025 Compared Revenues and Other Income The following table includes our revenues and other income by reportable segment: For the Three Months Ended June 30, Increase Percentage Reportable Segment (In thousands) 2026 2025 (Decrease) Change Mineral Rights $ 53,015 $ 47,575 $ 5,440 11 % Soda Ash (4,905 ) 2,526 (7,431 ) (294 )% Total $ 48,110 $ 50,101 $ (1,991 ) (4 )% The changes in revenues and other income are discussed for each of the reportable segments below: 18 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) 2026 2025 (Decrease) Change Coal sales volumes (tons) Appalachia Northern 1,492 132 1,360 1030 % Central 3,371 3,195 176 6 % Southern 453 548 (95 ) (17 )% Total Appalachia 5,316 3,875 1,441 37 % Illinois Basin 2,416 1,637 779 48 % Northern Powder River Basin 309 426 (117 ) (27 )% Gulf Coast 198 176 22 13 % Total coal sales volumes 8,239 6,114 2,125 35 % Coal royalty revenue per ton Appalachia Northern $ 1.18 $ 1.91 $ (0.73 ) (38 )% Central 6.06 6.41 (0.35 ) (5 )% Southern 11.52 8.53 2.99 35 % Illinois Basin 2.45 2.21 0.24 11 % Northern Powder River Basin 4.86 5.73 (0.87 ) (15 )% Gulf Coast 0.82 0.80 0.02 2 % Combined average coal royalty revenue per ton 4.25 5.17 (0.92 ) (18 )% Coal royalty revenues Appalachia Northern $ 1,759 $ 252 $ 1,507 598 % Central 20,414 20,494 (80 ) (0 )% Southern 5,218 4,676 542 12 % Total Appalachia 27,391 25,422 1,969 8 % Illinois Basin 5,925 3,610 2,315 64 % Northern Powder River Basin 1,503 2,443 (940 ) (38 )% Gulf Coast 163 140 23 16 % Unadjusted coal royalty revenues 34,982 31,615 3,367 11 % Coal royalty adjustment for minimum leases (189 ) (72 ) (117 ) (163 )% Total coal royalty revenues $ 34,793 $ 31,543 $ 3,250 10 % Other revenues Production lease minimum revenues $ 251 $ 123 $ 128 104 % Minimum lease straight-line revenues 4,019 4,050 (31 ) (1 )% Oil and gas royalty revenues 2,447 1,981 466 24 % Carbon neutral revenues 94 290 (196 ) (68 )% Property tax revenues 1,710 1,519 191 13 % Wheelage revenues 1,959 2,543 (584 ) (23 )% Coal overriding royalty revenues 1,040 456 584 128 % Lease amendment revenues 1,242 656 586 89 % Aggregates royalty revenues 1,246 906 340 38 % Other revenues 318 228 90 39 % Total other revenues $ 14,326 $ 12,752 $ 1,574 12 % Royalty and other mineral rights $ 49,119 $ 44,295 $ 4,824 11 % Transportation and processing services revenues 3,851 2,551 1,300 51 % Gain on asset sales and disposals 45 729 (684 ) (94 )% Total Mineral Rights segment revenues and other income $ 53,015 $ 47,575 $ 5,440 11 % 19 Table of Contents Coal Royalty Revenues Approximately 70% of coal royalty revenues and approximately 45% of coal royalty sales volumes were derived from metallurgical coal during the three months ended June 30, 2026. Total coal royalty revenues increased $3.3 million primarily due to higher metallurgical and thermal coal sales volumes and higher prices at certain properties during the three months ended June 30, 2026, as compared to the prior year quarter. Soda Ash Revenues and other income related to our Soda Ash segment decreased $7.4 million as compared to the prior year quarter primarily due to lower sales prices in 2026. Total Operating Expenses, Net The following table presents the significant categories of our consolidated operating expenses: For the Three Months Ended June 30, Increase Percentage (In thousands) 2026 2025 (Decrease) Change Operating expenses Operating and maintenance expenses $ 5,731 $ 4,159 $ 1,572 38 % Depreciation, depletion and amortization 11,131 3,754 7,377 197 % General and administrative expenses 5,020 5,597 (577 ) (10 )% Total operating expenses $ 21,882 $ 13,510 $ 8,372 62 % Total operating expenses, net increased $8.4 million primarily due to a $7.4 million increase in depreciation, depletion and amortization expense in addition to a $1.6 million increase in operating and maintenance expenses. The increase in depreciation, depletion and amortization expense was primarily due to revised engineering and increased depletion rate at a thermal property. This property continues to hold significant economic tons and long-term mine life, and there has been no material change to our estimate of the segment's long-term earning power. The increase in operating and maintenance expenses was primarily due to the change in the current expected credit loss allowance as discussed in Note 14. Credit Losses in the Notes to Consolidated Financial Statements. Interest Expense, Net Interest expense, net, decreased $1.3 million due to less debt outstanding during the three months ended June 30, 2026 as compared to the prior year quarter. Adjusted EBITDA (Non-GAAP Financial Measure) The following table reconciles net income (loss) (the most comparable GAAP financial measure) to Adjusted EBITDA: Reportable Segments For the Three Months Ended (In thousands) Mineral Rights Soda Ash Corporate and Financing Total June 30, 2026 Net income (loss) $ 36,237 $ (4,984 ) $ (6,077 ) $ 25,176 Add (Less): equity in (earnings) loss from unconsolidated investment — 4,905 — 4,905 Add: interest expense, net — — 1,052 1,052 Add: depreciation, depletion and amortization 11,126 — 5 11,131 Adjusted EBITDA $ 47,363 $ (79 ) $ (5,020 ) $ 42,264 June 30, 2025 Net income (loss) $ 39,691 $ 2,502 $ (7,982 ) $ 34,211 Add (Less): equity in (earnings) loss from unconsolidated investment — (2,526 ) — (2,526 ) Add: total distributions from unconsolidated investment — 4,900 — 4,900 Add: interest expense, net — — 2,380 2,380 Add: depreciation, depletion and amortization 3,748 — 6 3,754 Adjusted EBITDA $ 43,439 $ 4,876 $ (5,596 ) $ 42,719 Net income decreased $9.0 million during the three months ended June 30, 2026 as compared to the prior year quarter primarily due to the decrease in revenues and other income within our Soda Ash segment and increase in total operating expenses as discussed above. These decreases were partially offset by higher revenues and other income within our Mineral Rights segment in addition to lower interest expense, net, all discussed above. Adjusted EBITDA decreased $0.5 million as compared to the prior year quarter primarily due to a $5.0 million decrease in Adjusted EBITDA within our Soda Ash segment driven by no distribution received from Sisecam Wyoming during the three months ended June 30, 2026. This decrease was partially offset by a $3.9 million increase in Adjusted EBITDA within our Mineral Rights segment primarily driven by the increase in revenues and other income as discussed above. 20 Table of Contents Free Cash Flow ("FCF") (Non-GAAP Financial Measure) The following table presents the three major categories of the statement of cash flows: Reportable Segments For the Three Months Ended (In thousands) Mineral Rights Soda Ash Corporate and Financing Total June 30, 2026 Cash flow provided by (used in) Operating activities $ 44,579 $ (79 ) $ (3,550 ) $ 40,950 Investing activities 819 — — 819 Financing activities — — (43,141 ) (43,141 ) June 30, 2025 Cash flow provided by (used in) Operating activities $ 45,576 $ 4,875 $ (4,872 ) $ 45,579 Investing activities 1,444 — — 1,444 Financing activities — — (47,555 ) (47,555 ) The following table reconciles net cash provided by (used in) operating activities (the most comparable GAAP financial measure) to FCF: Reportable Segments For the Three Months Ended (In thousands) Mineral Rights Soda Ash Corporate and Financing Total June 30, 2026 Net cash provided by (used in) operating activities $ 44,579 $ (79 ) $ (3,550 ) $ 40,950 Add: return of long-term contract receivable 773 — — 773 Free cash flow $ 45,352 $ (79 ) $ (3,550 ) $ 41,723 June 30, 2025 Net cash provided by (used in) operating activities $ 45,576 $ 4,875 $ (4,872 ) $ 45,579 Add: return of long-term contract receivable 714 — — 714 Free cash flow $ 46,290 $ 4,875 $ (4,872 ) $ 46,293 Operating cash flow and FCF each decreased $4.6 million, as compared to the prior year quarter due to the following: • Mineral Rights Segment ◦ Operating cash flow and FCF decreased $1.0 million and $0.9 million, respectively, primarily due to higher recoupments during the three months ended June 30, 2026, partially offset by increased cash from minimum payments during the same period. • Soda Ash Segment ◦ Operating cash flow and FCF each decreased by $5.0 million as compared to the prior year quarter primarily due to a $4.9 million distribution received from Sisecam Wyoming in the second quarter of 2025 and no distribution received from Sisecam Wyoming in the second quarter of 2026. • Corporate and Financing ◦ Operating cash flow and FCF each improved by $1.3 million as compared to the prior year quarter primarily due to lower cash paid for interest during the three months ended June 30, 2026 as a result of less debt outstanding. 21 Table of Contents First Six Months of 2026 and 2025 Compared Revenues and Other Income The following table includes our revenues and other income by reportable segment: For the Six Months Ended June 30, Percentage Reportable Segment (In thousands) 2026 2025 Decrease Change Mineral Rights $ 100,196 $ 103,503 $ (3,307 ) (3 )% Soda Ash (12,733 ) 7,136 (19,869 ) (278 )% Total $ 87,463 $ 110,639 $ (23,176 ) (21 )% The changes in revenues and other income are discussed for each of the reportable segments below: 22 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) 2026 2025 (Decrease) Change Coal sales volumes (tons) Appalachia Northern 1,964 256 1,708 667 % Central 6,338 6,501 (163 ) (3 )% Southern 782 844 (62 ) (7 )% Total Appalachia 9,084 7,601 1,483 20 % Illinois Basin 4,836 4,979 (143 ) (3 )% Northern Powder River Basin 484 1,342 (858 ) (64 )% Gulf Coast 360 413 (53 ) (13 )% Total coal sales volumes 14,764 14,335 429 3 % Coal royalty revenue per ton Appalachia Northern $ 1.24 $ 1.70 $ (0.46 ) (27 )% Central 6.11 6.29 (0.18 ) (3 )% Southern 11.47 8.76 2.71 31 % Illinois Basin 2.38 2.36 0.02 1 % Northern Powder River Basin 5.35 4.93 0.42 9 % Gulf Coast 0.83 0.78 0.05 6 % Combined average coal royalty revenue per ton 4.37 4.70 (0.33 ) (7 )% Coal royalty revenues Appalachia Northern $ 2,430 $ 435 $ 1,995 459 % Central 38,742 40,920 (2,178 ) (5 )% Southern 8,968 7,394 1,574 21 % Total Appalachia 50,140 48,749 1,391 3 % Illinois Basin 11,531 11,751 (220 ) (2 )% Northern Powder River Basin 2,587 6,612 (4,025 ) (61 )% Gulf Coast 298 324 (26 ) (8 )% Unadjusted coal royalty revenues 64,556 67,436 (2,880 ) (4 )% Coal royalty adjustment for minimum leases (189 ) (395 ) 206 52 % Total coal royalty revenues $ 64,367 $ 67,041 $ (2,674 ) (4 )% Other revenues Production lease minimum revenues $ 809 $ 2,848 $ (2,039 ) (72 )% Minimum lease straight-line revenues 8,038 8,100 (62 ) (1 )% Oil and gas royalty revenues 3,833 4,425 (592 ) (13 )% Carbon neutral revenues 279 885 (606 ) (68 )% Property tax revenues 3,421 3,156 265 8 % Wheelage revenues 3,949 4,281 (332 ) (8 )% Coal overriding royalty revenues 2,426 1,336 1,090 82 % Lease amendment revenues 2,442 1,311 1,131 86 % Aggregates royalty revenues 2,364 1,759 605 34 % Other revenues 488 413 75 18 % Total other revenues $ 28,049 $ 28,514 $ (465 ) (2 )% Royalty and other mineral rights $ 92,416 $ 95,555 $ (3,139 ) (3 )% Transportation and processing services revenues 7,736 6,972 764 11 % Gain on asset sales and disposals 44 976 (932 ) (95 )% Total Mineral Rights segment revenues and other income $ 100,196 $ 103,503 $ (3,307 ) (3 )% 23 Table of Contents Coal Royalty Revenues Approximately 65% of coal royalty revenues and approximately 45% of coal royalty sales volumes were derived from metallurgical coal during the six months ended June 30, 2026. Total coal royalty revenues decreased $2.7 million primarily due to lower metallurgical and thermal coal sales volumes at certain properties during the six months ended June 30, 2026 as compared to the prior year period. Soda Ash Revenues and other income related to our Soda Ash segment decreased $19.9 million as compared to the prior year period primarily due to lower sales prices in 2026. Total Operating Expenses, Net The following table presents the significant categories of our consolidated operating expenses: For the Six Months Ended June 30, Increase Percentage (In thousands) 2026 2025 (Decrease) Change Operating expenses Operating and maintenance expenses $ 11,844 $ 10,935 $ 909 8 % Depreciation, depletion and amortization 18,745 7,743 11,002 142 % General and administrative expenses 10,054 12,429 (2,375 ) (19 )% Asset impairments — 20 (20 ) (100 )% Total operating expenses $ 40,643 $ 31,127 $ 9,516 31 % Total operating expenses, net increased $9.5 million primarily due to an $11.0 million increase in depreciation, depletion and amortization expense, partially offset by a $2.4 million decrease in general and administrative expenses. The increase in depreciation, depletion and amortization expense was primarily due to increased depletion rates on certain thermal properties as discussed above. The decrease in general and administrative expenses was primarily due to lower long-term incentive expense as compared to the prior year period. Interest Expense, Net Interest expense, net, decreased $3.0 million due to less debt outstanding during the six months ended June 30, 2026 as compared to the prior year period. Adjusted EBITDA (Non-GAAP Financial Measure) The following table reconciles net income (loss) (the most comparable GAAP financial measure) to Adjusted EBITDA: Reportable Segments For the Six Months Ended (In thousands) Mineral Rights Soda Ash Corporate and Financing Total June 30, 2026 Net income (loss) $ 69,767 $ (12,884 ) $ (12,088 ) $ 44,795 Add (Less): equity in (earnings) loss from unconsolidated investment — 12,733 — 12,733 Add: interest expense, net — — 2,025 2,025 Add: depreciation, depletion and amortization 18,736 — 9 18,745 Adjusted EBITDA $ 88,503 $ (151 ) $ (10,054 ) $ 78,298 June 30, 2025 Net income (loss) $ 84,899 $ 7,052 $ (17,487 ) $ 74,464 Less: equity earnings from unconsolidated investment — (7,136 ) — (7,136 ) Add: total distributions from unconsolidated investment — 7,840 — 7,840 Add: interest expense, net — — 5,048 5,048 Add: depreciation, depletion and amortization 7,733 — 10 7,743 Add: asset impairments 20 — — 20 Adjusted EBITDA $ 92,652 $ 7,756 $ (12,429 ) $ 87,979 Net income during the six months ended June 30, 2026 decreased $29.7 million as compared to the prior year period primarily due to the decrease in total revenues and other income and increase in total operating expenses, partially offset by lower interest expense, all discussed above. Adjusted EBITDA decreased $9.7 million as compared to the prior year period primarily due to a $4.1 million decrease in Adjusted EBITDA within our Mineral Rights segment primarily driven by the decrease in revenues and other income as discussed above and a $7.9 million decrease in Adjusted EBITDA within our Soda Ash segment driven by no distribution received from Sisecam Wyoming during the six months ended June 30, 2026. 24 Table of Contents Free Cash Flow ("FCF") (Non-GAAP Financial Measure) The following table presents the three major categories of the statement of cash flows: Reportable Segments For the Six Months Ended (In thousands) Mineral Rights Soda Ash Corporate and Financing Total June 30, 2026 Cash flow provided by (used in) Operating activities $ 86,406 $ (151 ) $ (12,291 ) $ 73,964 Investing activities 1,577 (39,200 ) — (37,623 ) Financing activities (1,256 ) — (35,094 ) (36,350 ) June 30, 2025 Cash flow provided by (used in) Operating activities $ 88,799 $ 7,755 $ (16,551 ) $ 80,003 Investing activities 2,391 — — 2,391 Financing activities (841 ) — (81,653 ) (82,494 ) The following table reconciles net cash provided by (used in) operating activities (the most comparable GAAP financial measure) to FCF: Reportable Segments For the Six Months Ended (In thousands) Mineral Rights Soda Ash Corporate and Financing Total June 30, 2026 Net cash provided by (used in) operating activities $ 86,406 $ (151 ) $ (12,291 ) $ 73,964 Add: return of long-term contract receivable 1,531 — — 1,531 Less: capital contribution to unconsolidated investment — (39,200 ) — (39,200 ) Free cash flow $ 87,937 $ (39,351 ) $ (12,291 ) $ 36,295 June 30, 2025 Net cash provided by (used in) operating activities $ 88,799 $ 7,755 $ (16,551 ) $ 80,003 Add: return of long-term contract receivable 1,414 — — 1,414 Free cash flow $ 90,213 $ 7,755 $ (16,551 ) $ 81,417 Operating cash flow and FCF decreased $6.0 million and $45.1 million, respectively, as compared to the prior year period due to the following: • Mineral Rights Segment ◦ Operating cash flow and FCF decreased $2.4 million and $2.3 million, respectively, primarily due to lower metallurgical and thermal coal sales volumes at certain properties as compared to the prior year period. • Soda Ash Segment ◦ Operating cash flow decreased $7.9 million primarily due to $7.8 million in distributions received from Sisecam Wyoming in 2025 and no distribution received from Sisecam Wyoming in 2026. FCF decreased $47.1 million as compared to the prior year quarter primarily due to a $39.2 million capital investment made to Sisecam Wyoming in 2026 in addition to $7.8 million in distributions received from Sisecam in 2025. • Corporate and Financing ◦ Operating cash flow and FCF each improved by $4.3 million as compared to the prior year period primarily due to lower cash paid for interest during the six months ended June 30, 2026 as a result of less debt outstanding. 25 Table of Contents Liquidity and Capital Resources Current Liquidity As of June 30, 2026, we had total liquidity of $217.0 million, consisting of $30.1 million of cash and cash equivalents and $186.9 million of borrowing capacity under our Opco Credit Facility. We have debt service obligations, including $14.3 million of principal repayments on Opco’s senior notes, throughout the remainder of 2026. The following table calculates our leverage ratio as of June 30, 2026: For the Three Months Ended (In thousands) September 30, 2025 December 31, 2025 March 31, 2026 June 30, 2026 Last 12 Months Net income $ 30,905 $ 30,998 $ 19,619 $ 25,176 $ 106,698 Add (Less): equity in (earnings) loss from unconsolidated investment 2,390 1,686 7,828 4,905 16,809 Add: total distributions from unconsolidated investment — — — — — Add: interest expense, net 1,779 1,157 973 1,052 4,961 Add: depreciation, depletion and amortization 3,868 3,344 7,614 11,131 25,957 Add: asset impairments — — — — — Adjusted EBITDA $ 38,942 $ 37,185 $ 36,034 $ 42,264 $ 154,425 Debt—at June 30, 2026 $ 27,415 Leverage Ratio 0.2 x Cash Flows Cash flows provided by operating activities decreased $6.0 million, from $80.0 million during the six months ended June 30, 2025 to $74.0 million during the six months ended June 30, 2026, primarily due to decreased cash flow within our Mineral Rights and Soda Ash segments, partially offset by lower cash paid for interest, all discussed above. Cash flows used in investing activities increased $40.0 million, from $2.4 million provided by investing activities during the six months ended June 30, 2025 to $37.6 million used in investing activities during the six months ended June 30, 2026 primarily due to a $39.2 million capital investment made to Sisecam Wyoming in the first quarter of 2026. Cash flows used in financing activities decreased $46.1 million, from $82.5 million during the six months ended June 30, 2025 to $36.4 million during the six months ended June 30, 2026 due to the following: • $33.5 million increased debt borrowings during the six months ended June 30, 2026 as compared to the prior year period; • $14.4 million less cash used for common unit distributions primarily as a result of a lower special distribution paid during the six months ended June 30, 2026 as compared to the prior year period; and, • $1.5 million less cash used for debt repayments in 2026 as compared to 2025. These decreases in cash flow used were partially offset by $3.3 million of increased cash used for other items, net in 2026 as compared to 2025. 26 Table of Contents Capital Resources and Obligations Debt, Net We had the following debt outstanding as of June 30, 2026 and December 31, 2025: June 30, December 31, (In thousands) 2026 2025 Current portion of long-term debt, net $ 14,271 $ 14,198 Long-term debt, net 13,084 18,884 Total debt, net $ 27,355 $ 33,082 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 8. 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 is set forth under Note 10. Related Party Transactions to the Consolidated Financial Statements and 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, 2025. Recently Issued Accounting Standard In November 2024, the FASB issued ASU 2024-03, Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures ("ASU 2024-03"). ASU 2024-03 is intended to improve disclosures about a public business entity's expenses and provide more detailed information to investors about the types of expenses in commonly presented expense captions. The guidance is effective for annual periods beginning after December 15, 2026 and quarterly periods beginning after December 31, 2027 and can be adopted prospectively to financial statements issued for reporting periods after the effective date or retrospectively to all prior periods presented in the financial statements. We do not expect the adoption of this guidance to have a material impact on our Consolidated Financial Statements. 27 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 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 affect 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. Currently soda ash prices are severely declined and Sisecam Wyoming suspended distributions in the third quarter of 2025. We cannot predict whether or when soda ash prices will recover to a level at which Sisecam Wyoming with resume distributions. 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, 2026, we had $13.1 million in borrowings outstanding under the Opco Credit Facility. If interest rates were to increase by 1%, annual interest expense would increase approximately $0.1 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 2026 that materially affected, or were reasonably likely to materially affect, the Partnership’s internal control over financial reporting. 28 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, 2025. 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). 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 29 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 5, 2026 By: /s/ Corbin J. Robertson, Jr. Corbin J. Robertson, Jr. Chairman of the Board and Chief Executive Officer (Principal Executive Officer) Date: August 5, 2026 By: /s/ Christopher J. Zolas Christopher J. Zolas Chief Financial Officer (Principal Financial and Accounting Officer) 30