0001437749-26-005376 | 10-K | XBRL Viewer

Acquisition of Producing and Nonproducing Royalty and Mineral Rights [Text Block]

Acquisitions for Units

On August 29, 2025, pursuant to a non-taxable contribution and exchange agreement with multiple unrelated third parties, the Partnership acquired mineral interests totaling approximately 3,050 net royalty acres located in Adams County, Colorado in exchange for 915,694 common units representing limited partnership interests in the Partnership valued at $23.0 million and issued pursuant to the Partnership’s registration statement on Form S-4. We believe that the acquisition is considered complementary to our business. The transaction was accounted for as an acquisition of assets under U.S. GAAP. Accordingly, the cost of the acquisition was allocated on a relative fair value basis and transaction costs were capitalized as a component of the cost of the assets acquired. Contributed cash delivered at closing and final settlement net cash received, net of capitalized transaction costs paid, of $1.8 million is included in net cash contributed in acquisitions on the consolidated statement of cash flows for the year ended December 31, 2025. Oil and natural gas properties, at cost, on the consolidated balance sheet as of December 31, 2025 includes $19.7 million of net capitalized costs attributable to proved oil and natural gas properties acquired in the transaction.

On September 30, 2024, pursuant to a non-taxable contribution and exchange agreement with West Texas Minerals LLC, a Delaware limited liability company, Carrollton Mineral Partners, LP, a Texas limited partnership, Carrollton Mineral Partners Fund II, LP, a Texas limited partnership, Carrollton Mineral Partners III, LP, a Texas limited partnership, Carrollton Mineral Partners III-B, LP, a Texas limited partnership, Carrollton Mineral Partners IV, LP, a Texas limited partnership, CMP Permian, LP, a Texas limited partnership, CMP Glasscock, LP, a Texas limited partnership, and Carrollton Royalty, LP, a Texas limited partnership, the Partnership acquired mineral, royalty, and overriding royalty interests in producing and non-producing oil and natural gas properties representing approximately 14,225 net mineral acres located in 14 counties across New Mexico and Texas in exchange for 6,721,144 common units representing limited partnership interests in the Partnership valued at $202.6 million and issued pursuant to the Partnership’s registration statements on Form S-4. We believe that the acquisition is considered complementary to our business. The transaction was accounted for as an acquisition of assets under U.S. GAAP. Accordingly, the cost of the acquisition was allocated on a relative fair value basis and transaction costs were capitalized as a component of the cost of the assets acquired. Contributed cash delivered at closing and final settlement net cash received, net of capitalized transaction costs paid, of $8.8 million is included in net cash contributed in acquisitions on the consolidated statement of cash flows for the year ended December 31, 2024. Oil and natural gas properties, at cost, on the consolidated balance sheet as of December 31, 2024 includes $193.7 million of net capitalized costs attributable to proved oil and natural gas properties acquired in the transaction. Final settlement net cash received, net of capitalized transaction costs paid, of $1.9 million is included in net cash contributed in acquisitions on the consolidated statement of cash flows for the year ended December 31, 2025.

On September 30, 2024, pursuant to a non-taxable contribution and exchange agreement with an unrelated third party, the Partnership acquired overriding royalty interests totaling approximately 1,204 net royalty acres located in Weld County, Colorado in exchange for 530,000 common units representing limited partnership interests in the Partnership valued at $16.0 million and issued pursuant to the Partnership’s registration statement on Form S-4. We believe that the acquisition is considered complementary to our business. The transaction was accounted for as an acquisition of assets under U.S. GAAP. Accordingly, the cost of the acquisition was allocated on a relative fair value basis and transaction costs were capitalized as a component of the cost of the assets acquired. Contributed cash delivered at closing and final settlement net cash received, net of capitalized transaction costs paid, of $1.4 million is included in net cash contributed in acquisitions on the consolidated statement of cash flows for the year ended December 31, 2024. Oil and natural gas properties, at cost, on the consolidated balance sheet as of December 31, 2024 includes $14.6 million of net capitalized costs attributable to proved oil and natural gas properties acquired in the transaction.

On March 28, 2024, pursuant to a non-taxable contribution and exchange agreement with multiple unrelated third parties, the Partnership acquired mineral interests totaling approximately 1,485 net royalty acres located in two counties in Colorado in exchange for 505,369 common units representing limited partnership interests in the Partnership valued at $17.0 million and issued pursuant to the Partnership’s registration statement on Form S-4. We believe that the acquisition is considered complementary to our business. The transaction was accounted for as an acquisition of assets under U.S. GAAP. Accordingly, the cost of the acquisition was allocated on a relative fair value basis and transaction costs were capitalized as a component of the cost of the assets acquired. Contributed cash delivered at closing and final settlement net cash received, net of capitalized transaction costs paid, of $4.4 million is included in net cash contributed in acquisitions on the consolidated statement of cash flows for the year ended December 31, 2024. Oil and natural gas properties, at cost, on the consolidated balance sheet as of December 31, 2024 includes $12.3 million of net capitalized costs attributable to proved oil and natural gas properties acquired in the transaction.

Final settlement net cash received, net of capitalized transaction costs paid, of $0.2 million is included in net cash contributed in acquisitions on the consolidated statement of cash flows for the year ended December 31, 2025.

Note 1 - Business and Basis of Presentation (Details Textual)	Dec. 31, 2025
Number Of Counties In Which Entity Operates	594
Number of States in which Entity Operates	28

Note 1 - Business and Basis of Presentation

12 Months Ended

Dec. 31, 2025

Business Description and Basis of Presentation [Text Block]

Business and Basis of Presentation

Description of the Business

Dorchester Minerals, L.P. (the “Partnership”) is a publicly traded Delaware limited partnership that commenced operations on January 31, 2003. Our Partnership is based in Dallas, Texas and our business may be described as the acquisition, ownership and administration of Royalty Properties (which consists of producing and nonproducing mineral, royalty, overriding royalty, net profits, and leasehold interests located in 594 counties and parishes in 28 states (“Royalty Properties”)) and net profits overriding royalty interests (referred to as the “Net Profits Interest”, or “NPI”). In these Notes, the term “Partnership,” as well as the terms “us,” “our,” “we,” and “its” are sometimes used as abbreviated references to Dorchester Minerals, L.P. itself or Dorchester Minerals, L.P. and its related entities.

Basis of Presentation

The consolidated financial statements herein have been prepared in accordance with accounting principles generally accepted in the United States (“U.S. GAAP”). The consolidated financial statements include the accounts of Dorchester Minerals, L.P., Dorchester Minerals Oklahoma, LP, Dorchester Minerals Oklahoma GP, Inc., Maecenas Minerals LLP, Dorchester-Maecenas GP LLC, The Buffalo Co., A Limited Partnership, and DMLPTBC GP LLC, and DMLP Terra Firma LLC. All intercompany balances and transactions have been eliminated in consolidation.

Certain amounts in the prior‑period consolidated financial statements have been reclassified to conform to the current‑period presentation. Management believes these reclassifications enhance the clarity and consistency of the financial statement presentation. These are presentation only reclassifications and had no effect on total assets, total liabilities, shareholders’ equity, net income, or cash flows for any periods presented.

Note 8 - Segment Reporting (Details Textual)	12 Months Ended
Note 8 - Segment Reporting (Details Textual)	Dec. 31, 2025
Number of Operating Segments	1
Number of Reportable Segments	1
Segment Reporting, CODM, Individual Title and Position or Group Name [Extensible Enumeration]	Chief Executive Officer [Member]

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Cash flows from operating activities:
Net income	$ 57,352	$ 92,449	$ 114,117
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization	66,300	42,588	26,307
Amortization of operating lease right-of-use asset	163	179	194
Changes in operating assets and liabilities:
Accounts receivable	6,024	(4,646)	(467)
Net profits interest receivable - related party	3,031	2,731	(1,105)
Prepaid expenses and other current assets	(13)	(133)	(25)
Accounts payable and other current liabilities	(135)	(522)	1,052
Operating lease liability	(263)	(273)	(281)
Net cash provided by operating activities	132,485	132,639	139,842
Cash flows provided by investing activities:
Net cash contributed in acquisitions of oil and natural gas properties	3,888	14,725	2,284
Cash flows used in financing activities:
Distributions paid to General Partner and unitholders	(136,944)	(151,881)	(135,855)
(Decrease) Increase in cash and cash equivalents	(571)	(4,517)	6,271
Cash and cash equivalents at beginning of period	42,508	47,025	40,754
Cash and cash equivalents at end of period	41,937	42,508	47,025
Non-cash investing and financing activities:
Fair value of common units issued for acquisitions of oil and natural gas properties	$ 23,043	$ 235,663	$ 35,777

Note 7 - Leases - Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Operating cash flows from operating leases	$ 362	$ 356	$ 350

Consolidated Statements of Changes in Partnership Capital - USD ($) shares in Thousands, $ in Thousands	General Partner [Member]	Limited Partner [Member]	Total
Balance at Dec. 31, 2022	$ 676	$ 170,842	$ 171,518
Balance (in shares) at Dec. 31, 2022		38,372
Net income	3,728	$ 110,389	114,117
Acquisitions of oil and natural gas properties for common units	0	$ 35,777	35,777
Acquisitions of oil and natural gas properties for common units (in shares)		1,211
Distributions	(4,291)	$ (131,564)	(135,855)
Balance at Dec. 31, 2023	113	$ 185,444	185,557
Balance (in shares) at Dec. 31, 2023		39,583
Net income	3,249	$ 89,200	92,449
Acquisitions of oil and natural gas properties for common units	0	$ 235,663	235,663
Acquisitions of oil and natural gas properties for common units (in shares)		7,757
Distributions	(5,359)	$ (146,522)	(151,881)
Balance at Dec. 31, 2024	(1,997)	$ 363,785	361,788
Balance (in shares) at Dec. 31, 2024		47,340
Net income	2,100	$ 55,252	57,352
Acquisitions of oil and natural gas properties for common units	0	$ 23,043	23,043
Acquisitions of oil and natural gas properties for common units (in shares)		916
Distributions	(4,928)	$ (132,016)	(136,944)
Balance at Dec. 31, 2025	$ (4,825)	$ 310,064	$ 305,239
Balance (in shares) at Dec. 31, 2025		48,256

The portion of profit or loss for the period, net of income taxes, which is attributable to the parent.

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Note 7 - Leases - Lease Cost (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
General and Administrative Expense [Member]
Operating lease expense	$ 262	$ 262	$ 262

Note 7 - Leases

12 Months Ended

Dec. 31, 2025

Lessee, Operating Leases [Text Block]

Leases

The third amendment to our Office Lease was executed in April 2017 for a term of 129 months, beginning June 1, 2018 and expiring in 2029. At lease commencement, the Partnership concluded the Office Lease was an operating lease. Under the third amendment to the Office Lease, monthly rental payments range from $25,000 to $30,000 and the Partnership received lease incentives of $0.7 million.

Lease expense for the years ended December 31, 2025, 2024 and 2023 was as follows:

	*In Thousands*
	*2025*		*2024*		*2023*
Operating lease expense	$	262	$	262	$	262

Supplemental cash flow information related to leases was as follows:

	*In Thousands*
	*2025*		*2024*		*2023*
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	362	$	356	$	350

Supplemental balance sheet information related to leases was as follows:

	*2025*			*2024*			*2023*

Weighted-Average Remaining Lease Term (months)
Operating lease		38			50			62
Weighted-Average Discount Rate
Operating lease		5	%		5	%		5	%

Maturities of lease liabilities are as follows:

	*In Thousands*
	*2025*
2026	$	368
2027		374
2028		380
2029		63
Total lease payments		1,185
Less amount representing interest		(408	)
Total lease obligation	$	777

Consolidated Balance Sheets (Parentheticals) - shares shares in Thousands	Dec. 31, 2025	Dec. 31, 2024
Common units (in shares)	48,256	47,340

Note 8 - Segment Reporting

12 Months Ended

Dec. 31, 2025

Segment Reporting Disclosure [Text Block]

Segment Reporting

The Partnership manages its business activities on a consolidated basis and operates in a single operating and reportable segment. Operating segments are defined as components of a public entity that engages in business activities and for which discrete financial information and operating results are available and regularly reviewed by the chief operating decision maker in deciding how to allocate resources and assess performance. As disclosed in Note 1 – Business and Basis of Presentation, our business may be described as the acquisition, ownership and administration of Royalty Properties and the NPI. See Note 2 – Summary of Significant Accounting Policies for a summarization of the Partnerships revenue recognition policy.

The Partnership’s CEO has been determined to be the chief operating decision maker of the Partnership. The CEO uses Net income, as reported on our Consolidated Income Statements, to assess financial performance and allocate resources on a consolidated basis. The CEO manages and evaluates the results of the Partnership on a consolidated basis, and Net income is used to evaluate key operating decisions, such as making strategic acquisitions, determining transaction structures to capitalize on the development of the properties underlying our mineral interests, and allocating resources for general and administrative expenditures. The CEO does not review consolidated balance sheet assets when assessing segment performance and deciding how to allocate resources. Disaggregated operating revenues of the Partnership’s single segment and all significant segment expenses are presented separately on the Partnership’s Consolidated Income Statements. There are no other significant segment expenses or other segment items that would require disclosure.

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

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Note 4 - Related Party Transaction (Details Textual)	12 Months Ended
Note 4 - Related Party Transaction (Details Textual)	Dec. 31, 2025
General and Administrative Reimbursement, Maximum Percentage	5.00%

Note 2 - Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2025

Significant Accounting Policies [Text Block]

Summary of Significant Accounting Policies

Basic and Diluted Earnings Per Unit — Per-unit information is calculated by dividing the net income applicable to holders of our Partnership’s common units by the weighted average number of units outstanding. The Partnership has no potentially dilutive securities and, accordingly, basic and dilutive net income per unit do not differ.

Use of Estimates — The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Partnership evaluates these estimates on an ongoing basis, using historical experience, consultation with experts and other methods the Partnership considers reasonable in each circumstance. Any effects on the Partnership’s business, financial position, or results of operations resulting from revisions to these estimates are recorded in the period in which the facts that give rise to the revision become known. Although the Partnership believes these estimates are reasonable, actual results could differ from those estimates.

General Partner — Our general partner is Dorchester Minerals Management LP, referred to in these Notes as “our General Partner.” Our General Partner owns all of the partnership interests in Dorchester Minerals Operating LP, the Operating Partnership. See Note 4 —Related Party Transactions. The General Partner is allocated 4% and 1% of our Royalty Properties’ net revenues and Net Profits Interest (“NPI”) proceeds received by the Operating Partnership, respectively.

Cash and Cash Equivalents — Our principal banking relationships are with major financial institutions. Cash balances in these accounts may, at times, exceed federally insured limits. We have not experienced any losses in such cash accounts and do not believe we are exposed to any significant risk on cash and cash equivalents. Short term investments with an original maturity of three months or less are considered to be cash equivalents and are carried at cost, which approximates fair value.

Concentration of Credit Risks and Significant Customers — Our Partnership, as a royalty owner, has no control over the volumes or method of sale of oil and natural gas produced and sold from the Royalty Properties and NPI. Royalties operating revenues from properties operated by Exxon Mobil Corporation and its subsidiaries and Chevron Corporation and its subsidiaries represented approximately 15% and 10% of total operating revenues for the year ended December 31, 2025, respectively. Royalties operating revenues from properties operated by Exxon Mobil Corporation and its subsidiaries and Diamondback Energy, Inc. represented approximately 16% and 15% of total operating revenues for the year ended December 31, 2024, respectively. Royalties operating revenues from properties operated by Pioneer Natural Resources Company represented approximately 11% of total operating revenues for the year ended December 31, 2023. If we were to lose a significant customer, such loss could impact revenue. The loss of any single customer is mitigated by our diversified customer base, and we do not believe that the loss of any single customer would have a long-term material adverse effect on our financial position or the results of operations.

Fair Value of Financial Instruments — The carrying amount of cash and cash equivalents, trade and other receivables, net profits interest receivable - related party, and accounts payables and other current liabilities approximates fair value because of the short maturity of those instruments. These estimated fair values may not be representative of actual values of the financial instruments that could have been realized as of year-end or that will be realized in the future.

Receivables — Our Partnership’s accounts receivable and net profits interest receivable consist primarily of Royalty Properties payments receivable and NPI payments receivable, respectively. Most payments are received two to three months after the production date. No reserve for current expected credit losses on accounts receivable is deemed necessary based upon our lack of historical write offs and review of current receivables. The Partnership’s receivables as of the years ended December 31, 2025, 2024 and 2023 consists of the following:

	*In Thousands*
	*2025*		*2024*		*2023*
Royalty Properties receivable	$	13,810	$	19,120	$	13,556
Other		158		121		179
Accounts receivable		13,968		19,241		13,735
Net profits interest receivable - related party		2,513		5,544		8,275
Total Receivables	$	16,481	$	24,785	$	22,010

Oil and Natural Gas Properties — We utilize the full cost method of accounting for costs related to our oil and natural gas properties. Under this method, all such costs are capitalized and amortized on an aggregate basis over the estimated lives of the properties using the unit-of-production method. These capitalized costs are subject to a ceiling test, which limits such pooled costs to the aggregate of the present value of future net revenues attributable to proved oil and natural gas reserves discounted at 10% plus the lower of cost or market value of unproved properties. For the purposes of determining the capitalized costs ceiling, our Partnership only assigned value to proved developed producing oil and natural gas reserves as of December 31, 2025. The full cost ceiling is evaluated at the end of each quarter and when events indicate possible impairment. There have been no impairments for the years ended December 31, 2025, 2024 and 2023 as a result of the full cost ceiling test.

The discounted present value of our proved oil and natural gas reserves is a major component of the ceiling test calculation and requires many subjective judgments. Estimates of reserves are forecasts based on engineering and geological analyses. Different reserve engineers could reach different conclusions as to estimated quantities of oil and natural gas reserves based on the same information. The passage of time provides more qualitative and quantitative information regarding reserve estimates, and revisions are made to prior estimates based on updated information. However, there can be no assurance that more significant revisions will not be necessary in the future. Significant downward revisions could result in an impairment representing a non-cash charge to income. In addition to the impact on the calculation of the ceiling test, estimates of proved reserves are also a major component of the calculation of depletion.

While the quantities of proved reserves require substantial judgment, the associated prices of oil and natural gas reserves that are included in the discounted present value of our reserves are objectively determined. The ceiling test calculation requires use of the unweighted arithmetic average of the first day of the month price during the 12-month period ending on the balance sheet date and costs in effect as of the last day of the accounting period, which are generally held constant for the life of the oil and natural gas properties. As a result, the present value is not necessarily an indication of the fair value of the reserves. Oil and natural gas prices have historically been volatile, and the prevailing prices at any given time may not reflect our Partnership’s or the industry’s forecast of future prices.

Gains and losses are recognized upon the disposition of oil and natural gas properties involving a significant portion (greater than 25%) of our Partnership’s reserves. Proceeds from other dispositions of oil and natural gas properties are credited to the full cost pool.

Leasehold Improvements — Leasehold improvements are amortized over the shorter of their estimated useful lives or the related life of the lease.

Leases — The Partnership determines if an arrangement is a lease at inception. The Partnership leases its office space at 3838 Oak Lawn Avenue, Suite 300, Dallas, Texas, through an operating lease (the “Office Lease”). The operating lease is included in operating lease right-of-use (“ROU”) asset and operating lease liability in our consolidated balance sheets. Operating lease expense is included in general and administrative expenses in the consolidated income statements.

Operating lease ROU assets and operating lease liabilities are recognized based on the present value of lease payments over the lease term at commencement date. As the Partnership’s lease does not provide an implicit rate of return and as the Partnership is precluded from incurring any borrowings above a nominal amount under its partnership agreement, the Partnership used a discount rate commensurate with the incremental borrowing rate of a group of peers based on information available at the application date in determining the present value of lease payments. Lease expense for minimum lease payments is recognized on a straight-line basis over the lease term.

Asset Retirement Obligations — Based on the nature of our property ownership, we have no material obligations to record.

Revenue Recognition — The pricing of oil and natural gas sales from the Royalty Properties and NPI is primarily determined by supply and demand in the marketplace and can fluctuate considerably. As a royalty owner, we have no operational control over the volumes and method of sale of oil and natural gas produced and sold from the Royalty Properties and NPI.

Revenues from Royalty Properties and NPI are recorded under the cash receipts approach as directly received from the remitters’ statement accompanying the revenue check. Since the revenue checks are generally received two to three months after the production month, the Partnership accrues for revenue earned but not received by estimating production volumes and product prices. Identified differences between our accrued revenue estimates and actual revenue received historically have not been significant.

The Partnership does not record revenue for unsatisfied or partially unsatisfied performance obligations. The Partnership’s right to revenues from Royalty Properties and NPI occurs at the time of production, at which point, payment is unconditional, and no remaining performance obligation exists for the Partnership. Accordingly, the Partnership’s revenue contracts for Royalty Properties and NPI do not generate contract assets or liabilities.

The following table disaggregates the Partnership’s oil and natural gas revenues from production on the Royalty Properties for the years ended December 31, 2025, 2024 and 2023:

	*In Thousands*
	*2025*		*2024*		*2023*
Oil sales (1)	$	114,116	$	129,693	$	102,323
Natural gas sales		13,707		7,772		12,208
Total Royalties operating revenue	$	127,823	$	137,465	$	114,531

(1)	Includes natural gas liquids sales.

Revenues from lease bonus payments are recorded upon receipt. The lease bonus is separate from the lease itself and is recognized as revenue to the Partnership upon receipt of payment. The Partnership generates lease bonus revenue by leasing its mineral interests to exploration and production companies and includes proceeds from assignments of leasehold interests where the Partnership retains an interest. A lease agreement represents the Partnership’s contract with a lessee and generally transfers the rights to develop oil or natural gas, grants the Partnership a right to a specified royalty interest, and requires that drilling and completion operations commence within a specified time period. Upon signing a lease agreement, no further performance obligation exists for the Partnership, and therefore, no contract assets or contract liabilities are generated.

Income Taxes — We are treated as a partnership for income tax purposes and, as a result, our income or loss is includable in the tax returns of the individual unitholders. Depletion of oil and natural gas properties is an expense allowable to each individual partner, and the depletion expense as reported on the consolidated financial statements will not be indicative of the depletion expense an individual partner or unitholder may be able to deduct for income tax purposes.

Texas imposes a franchise tax (commonly referred to as the Texas margin tax) at a rate of 0.75% on gross revenues less certain deductions, as specifically set forth in the Texas margin tax statute. The Texas margin tax applies to corporations and limited liability companies, general and limited partnerships (unless otherwise exempt), limited liability partnerships, trusts (unless otherwise exempt), business trusts, business associations, professional associations, joint stock companies, holding companies, joint ventures, and certain other business entities having limited liability protection.

Limited partnerships that receive at least 90% of their gross income from designated passive sources, including royalties from mineral properties and other non-operated mineral interest income, and do not receive more than 10% of their income from operating an active trade or business, are generally exempt from the Texas margin tax as “passive entities.” We believe our Partnership meets the requirements for being considered a “passive entity” for Texas margin tax purposes and, therefore, it is exempt from the Texas margin tax. If the Partnership is exempt from Texas margin tax as a passive entity, each unitholder that is considered a taxable entity under the Texas margin tax would generally be required to include its portion of Partnership revenues in its own Texas margin tax computation. The Texas Administrative Code provides that such income is sourced according to the principal place of business of the Partnership, which would be the state of Texas.

Recent Accounting Pronouncements

Accounting Pronouncements Not Yet Adopted

In November 2024, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2024-03, “Income Statement—Reporting Comprehensive Income—Expense Disaggregation Disclosures (Subtopic 220-40): Disaggregation of Income Statement Expenses” (“ASU 2024-03”), which requires public entities to disclosure additional information about certain costs and expenses included in relevant expense captions presented on the income statement. ASU 2024-03 is effective for annual periods beginning after December 15, 2026, and for interim periods within annual reporting periods beginning after December 15, 2027, with early adoption permitted. Management is evaluating ASU 2024-03 to determine its impact on the Partnership’s disclosures.

In December 2025, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2025-11, “Interim Reporting (Topic 270): Narrow-Scope Improvements” (“ASU 2025-11”), which improves the guidance in Topic 270 by improving the navigability of the required interim disclosures and clarifying when that guidance is applicable. The ASU includes a comprehensive list of required interim disclosures and adds a principle that requires entities to disclose events since the end of the last annual reporting period that have a material impact on the entity. ASU 2025-11 is effective for interim reporting periods within annual reporting periods beginning after December 15, 2027, with early adoption permitted. Management is evaluating ASU 2025-11 to determine its impact on the Partnership’s disclosures.

The Partnership considers the applicability and impact of all ASUs. There are no other recent accounting pronouncements not yet adopted that are expected to have a material effect on the Partnership upon adoption.

Note 7 - Leases (Tables)

12 Months Ended

Dec. 31, 2025

Notes Tables

Lease, Cost [Table Text Block]

	*In Thousands*
	*2025*		*2024*		*2023*
Operating lease expense	$	262	$	262	$	262

Lessee, Operating Lease, Cash Flow [Table Text Block]

	*In Thousands*
	*2025*		*2024*		*2023*
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases	$	362	$	356	$	350

Lessee, Operating Lease, Balance Sheet [Table Text Block]

	*2025*			*2024*			*2023*

Weighted-Average Remaining Lease Term (months)
Operating lease		38			50			62
Weighted-Average Discount Rate
Operating lease		5	%		5	%		5	%

Lessee, Operating Lease, Liability, to be Paid, Maturity [Table Text Block]

	*In Thousands*
	*2025*
2026	$	368
2027		374
2028		380
2029		63
Total lease payments		1,185
Less amount representing interest		(408	)
Total lease obligation	$	777

Note 5 - Commitments and Contingencies

12 Months Ended

Dec. 31, 2025

Commitments and Contingencies Disclosure [Text Block]

Commitments and Contingencies

Our Partnership and the Operating Partnership are involved in legal and/or administrative proceedings arising in the ordinary course of their businesses, none of which have predictable outcomes and none of which are believed to have any significant effect on consolidated financial position, cash flows, or operating results.

Note 6 - Distributions to Holders of Common Units

12 Months Ended

Dec. 31, 2025

Partners' Capital Notes Disclosure [Text Block]

Distribution To Holders of Common Units

On January 22, 2026, the Partnership announced its cash distribution for the fourth quarter of 2025 of $0.755712 per common unit, representing activity for the three-month period ended December 31, 2025, payable to common unitholders on record as of February 2, 2026. This distribution was paid on February 12, 2026. The partnership agreement requires the next cash distribution to be paid by May 15, 2026.

Significant Accounting Policies (Policies)

12 Months Ended

Dec. 31, 2025

Accounting Policies [Abstract]

Earnings Per Share, Policy [Policy Text Block]

Use of Estimates, Policy [Policy Text Block]

Incentive Distribution Policy, Managing Member or General Partner, Description [Policy Text Block]

Cash and Cash Equivalents, Policy [Policy Text Block]

Concentration Risk, Credit Risk, Policy [Policy Text Block]

Fair Value of Financial Instruments, Policy [Policy Text Block]

Accounts Receivable [Policy Text Block]

	*In Thousands*
	*2025*		*2024*		*2023*
Royalty Properties receivable	$	13,810	$	19,120	$	13,556
Other		158		121		179
Accounts receivable		13,968		19,241		13,735
Net profits interest receivable - related party		2,513		5,544		8,275
Total Receivables	$	16,481	$	24,785	$	22,010

Oil and Gas, Accounting Method, Full Cost or Successful Efforts [Policy Text Block]

Property, Plant and Equipment, Policy [Policy Text Block]

Leasehold Improvements — Leasehold improvements are amortized over the shorter of their estimated useful lives or the related life of the lease.

Lessee, Leases [Policy Text Block]

Asset Retirement Obligation [Policy Text Block]

Asset Retirement Obligations — Based on the nature of our property ownership, we have no material obligations to record.

Revenue [Policy Text Block]

The following table disaggregates the Partnership’s oil and natural gas revenues from production on the Royalty Properties for the years ended December 31, 2025, 2024 and 2023:

	*In Thousands*
	*2025*		*2024*		*2023*
Oil sales (1)	$	114,116	$	129,693	$	102,323
Natural gas sales		13,707		7,772		12,208
Total Royalties operating revenue	$	127,823	$	137,465	$	114,531

(1)	Includes natural gas liquids sales.

Income Tax, Policy [Policy Text Block]

New Accounting Pronouncements, Policy [Policy Text Block]

Recent Accounting Pronouncements

Accounting Pronouncements Not Yet Adopted

Note 2 - Summary of Significant Accounting Policies - Schedule of Partnership's Receivables (Details) - USD ($) $ in Thousands	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Total Receivables	$ 16,481	$ 24,785	$ 22,010
Nonrelated Party [Member]
Accounts receivable	13,968	19,241	13,735
Related Party [Member]
Accounts receivable	2,513	5,544	8,275
Customer Contracts [Member]
Accounts receivable	13,810	19,120	13,556
Other Receivables [Member]
Accounts receivable	$ 158	$ 121	$ 179

Note 3 - Acquisitions for Units (Details Textual) $ in Thousands				12 Months Ended
	Aug. 29, 2025 USD ($) a shares	Sep. 30, 2024 USD ($) a shares	Mar. 28, 2024 USD ($) a shares	Dec. 31, 2025 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)
Asset Acquisition Consideration Transferred Royalty and Mineral Revenue Received				$ 3,888	$ 14,725	$ 2,284
Oil and Gas, Full Cost Method, Property and Equipment, after Accumulated Depletion				$ 249,896	298,011
Number Of Counties In Which Entity Operates				594
Multiple Unrelated Third Party [Member] \| Mineral and Royalty Interest in Adams County, Colorado [Member]
Area of Real Estate Property (Acre) \| a	3,050
Asset Acquisition, Consideration Transferred, Equity Interest Issued and Issuable, Number of Shares (in shares) \| shares	915,694
Asset Acquisition, Consideration Transferred, Equity Interest Issued and Issuable	$ 23,000
Asset Acquisition Consideration Transferred Royalty and Mineral Revenue Received				$ 1,800
Oil and Gas, Full Cost Method, Property and Equipment, after Accumulated Depletion				19,700
Multiple Unrelated Third Party [Member] \| Mineral and Royalty Interest in New Mexico and Texas [Member]
Area of Real Estate Property (Acre) \| a		14,225
Asset Acquisition, Consideration Transferred, Equity Interest Issued and Issuable, Number of Shares (in shares) \| shares		6,721,144
Asset Acquisition, Consideration Transferred, Equity Interest Issued and Issuable		$ 202,600
Asset Acquisition Consideration Transferred Royalty and Mineral Revenue Received				1,900	8,800
Oil and Gas, Full Cost Method, Property and Equipment, after Accumulated Depletion					193,700
Number Of Counties In Which Entity Operates		14
Multiple Unrelated Third Party [Member] \| Mineral and Royalty Interest in Weld County, Colorado [Member]
Area of Real Estate Property (Acre) \| a		1,204
Asset Acquisition, Consideration Transferred, Equity Interest Issued and Issuable, Number of Shares (in shares) \| shares		530,000
Asset Acquisition, Consideration Transferred, Equity Interest Issued and Issuable		$ 16,000
Asset Acquisition Consideration Transferred Royalty and Mineral Revenue Received					1,400
Oil and Gas, Full Cost Method, Property and Equipment, after Accumulated Depletion					14,600
Multiple Unrelated Third Party [Member] \| Mineral and Royalty Interest in Colorado [Member]
Area of Real Estate Property (Acre) \| a			1,485
Asset Acquisition, Consideration Transferred, Equity Interest Issued and Issuable, Number of Shares (in shares) \| shares			505,369
Asset Acquisition, Consideration Transferred, Equity Interest Issued and Issuable			$ 17,000
Asset Acquisition Consideration Transferred Royalty and Mineral Revenue Received				$ 200	4,400
Oil and Gas, Full Cost Method, Property and Equipment, after Accumulated Depletion					$ 12,300
Number Of Counties In Which Entity Operates			2

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2025	Dec. 31, 2024
Current assets:
Cash and cash equivalents	$ 41,937	$ 42,508
Prepaid expenses and other current assets	526	539
Total current assets	58,944	67,832
Oil and natural gas properties (full cost method)	745,539	727,446
Accumulated full cost depletion	(495,643)	(429,435)
Total	249,896	298,011
Operating lease right-of-use asset	423	586
Total assets	309,554	366,812
Current liabilities:
Accounts payable and other current liabilities	3,538	3,984
Operating lease liability	256	263
Total current liabilities	3,794	4,247
Operating lease liability	521	777
Total liabilities	4,315	5,024
Commitments and contingencies (Note 5)
Partnership capital:
General Partner	(4,825)	(1,997)
Unitholders (48,256 and 47,340 common units issued and outstanding as of December 31, 2025 and 2024, respectively)	310,064	363,785
Total partnership capital	305,239	361,788
Total liabilities and partnership capital	309,554	366,812
Leasehold Improvements [Member]
Current assets:
Leasehold improvements	989	989
Accumulated amortization	(698)	(606)
Total	291	383
Nonrelated Party [Member]
Current assets:
Accounts receivable	13,968	19,241
Related Party [Member]
Current assets:
Accounts receivable	$ 2,513	$ 5,544

Note 7 - Leases (Details Textual)	Jun. 01, 2018 USD ($)
Lessee, Operating Lease, Term of Contract (Month)	129 months
Deferred Rent Credit	$ 700,000
Minimum [Member]
Operating Leases, Monthly Payments	25,000
Maximum [Member]
Operating Leases, Monthly Payments	$ 30,000

Cybersecurity Risk Management and Strategy Disclosure	12 Months Ended
Cybersecurity Risk Management and Strategy Disclosure	Dec. 31, 2025
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	*ITEM 1C.* CYBERSECURITY** We and our operators increasingly rely on information technology systems to operate our respective businesses, and the oil and natural gas industry depends on digital technologies in exploration, development, production, and processing activities. We depend on digital technology in many areas of our business and operations, including, but not limited to, estimating quantities of oil and natural gas reserves, processing and recording financial and operating data, oversight and analysis of drilling, completion and production operations and communications with the employees of the Operating Partnership and third party customers and services providers. We recognize the importance of assessing, identifying, and managing material risks associated with cybersecurity threats, as defined in Item 106(a) of Regulation S-K. These risks include, among other things: operational risks, gathering, misuse, loss or destruction of proprietary and other information, fraud, extortion, harm to employees or customers, violation of data privacy or security laws and disruption of other business activities. In addition, the rapid evolution and increased adoption of artificial intelligence tools and similar machine learning technologies may intensify our cybersecurity risks. We maintain a comprehensive process for identifying, assessing, and managing material risks from cybersecurity threats as part of our broader risk management process. Our executive officers, along with input from our outsourced IT managed services provider, other external experts, and department managers, are responsible for our overall enterprise risk assessment and management process and regularly consider cybersecurity risks in the context of other material risks to the Partnership. We obtain input on the security industry and threat trends for our cybersecurity risk management processes from external experts, as appropriate. Our outsourced IT managed services provider has expertise in areas including, but not limited to, information technology and infrastructure, network and communications architecture, information systems and database management, back up management, and cybersecurity. Our risk management process also assesses third party risks. We perform assessments to identify and mitigate risks from third parties such as vendors and other business partners associated with our use of third party service providers. Cybersecurity risks are evaluated when determining the selection and oversight of applicable third party service providers and potential fourth party risks when handling and/or processing employee, business, or customer data. To protect our information systems from cybersecurity threats, we, among other things: (i) conduct regular reviews of information systems security programs and policies, (ii) perform penetration testing using external third party tools and techniques to test security controls, (iii) provide employee training, (iv) monitor emerging trends, laws, and regulations related to data protection and information security, and (v) use various security tools that help monitor, prevent, identify, escalate, investigate, resolve, and recover from identified vulnerabilities and security incidents in a timely manner, including, but not limited to, monitoring and detection tools managed by external experts and internal reporting. We, in coordination with external experts, have implemented a cyber and data security incident response plan that has four overarching and interconnected stages: (i) preparation for a cybersecurity incident, (ii) identification, analysis, and notification of a security incident by external experts, as applicable, (iii) containment, eradication, and recovery, and (iv) post-incident analysis and learnings for future preparedness. Such incident responses are managed by our outsourced IT managed services provider, Chief Financial Officer (“CFO”), and department managers, who, together, comprise our primary incident response team. As part of our cybersecurity risk management process, our incident response team logs and tracks privacy and security incidents across the Partnership, vendors, third party service providers, and other business partners. Cyber and data security incidents are evaluated to determine materiality, as well as operational, business, and privacy impact, ranked by severity, and prioritized for response and remediation. Significant incidents are evaluated by the primary incident response team to determine whether further escalation is appropriate, and any incident assessed as potentially being or potentially becoming material is immediately escalated for further assessment and reported to the Chief Executive Officer (“CEO”). We consult with outside counsel and other subject matter experts regarding materiality analysis, disclosure, and other compliance matters, as appropriate, and our executive officers, with input from the Board of Managers, as appropriate, make the final materiality determinations and disclosure and other compliance decisions. Our management apprises the Partnership’s independent public accounting firm of matters and any relevant developments. The Advisory Committee of the Board of Managers of the general partner of our General Partner has oversight responsibility for risks and incidents relating to cybersecurity threats, including compliance with disclosure requirements, cooperation with law enforcement, and related effects on financial and other risks, and it reports any findings and recommendations, as appropriate, to the full Board of Managers for consideration. Reports are periodically provided to the Advisory Committee during our board meetings by the individuals who oversee risk management in cybersecurity. This includes existing and new cybersecurity risks, including artificial intelligence, status on how management is addressing and/or mitigating those risks, cybersecurity and data privacy incidents (if any), and status on key information security initiatives. Members of the Board of Managers also engage in ad hoc conversations with management on cybersecurity-related news events and discuss any updates to our cybersecurity risk management and strategy programs. As of the date of this filing, our business strategy, results of operations, and financial condition have not been materially affected by risks from cybersecurity threats, including as a result of previously identified cybersecurity incidents, but we cannot provide assurance that they will not be materially affected in the future by such risks or any future material incidents. For more information on our cybersecurity related risks, see "Item 1A – Risk Factors".
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	We maintain a comprehensive process for identifying, assessing, and managing material risks from cybersecurity threats as part of our broader risk management process. Our executive officers, along with input from our outsourced IT managed services provider, other external experts, and department managers, are responsible for our overall enterprise risk assessment and management process and regularly consider cybersecurity risks in the context of other material risks to the Partnership. We obtain input on the security industry and threat trends for our cybersecurity risk management processes from external experts, as appropriate. Our outsourced IT managed services provider has expertise in areas including, but not limited to, information technology and infrastructure, network and communications architecture, information systems and database management, back up management, and cybersecurity.
Cybersecurity Risk Management Third Party Engaged [Flag]	true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag]	false
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Text Block]	The Advisory Committee of the Board of Managers of the general partner of our General Partner has oversight responsibility for risks and incidents relating to cybersecurity threats, including compliance with disclosure requirements, cooperation with law enforcement, and related effects on financial and other risks, and it reports any findings and recommendations, as appropriate, to the full Board of Managers for consideration. Reports are periodically provided to the Advisory Committee during our board meetings by the individuals who oversee risk management in cybersecurity. This includes existing and new cybersecurity risks, including artificial intelligence, status on how management is addressing and/or mitigating those risks, cybersecurity and data privacy incidents (if any), and status on key information security initiatives. Members of the Board of Managers also engage in ad hoc conversations with management on cybersecurity-related news events and discuss any updates to our cybersecurity risk management and strategy programs.
Cybersecurity Risk Role of Management [Text Block]	We, in coordination with external experts, have implemented a cyber and data security incident response plan that has four overarching and interconnected stages: (i) preparation for a cybersecurity incident, (ii) identification, analysis, and notification of a security incident by external experts, as applicable, (iii) containment, eradication, and recovery, and (iv) post-incident analysis and learnings for future preparedness. Such incident responses are managed by our outsourced IT managed services provider, Chief Financial Officer (“CFO”), and department managers, who, together, comprise our primary incident response team. As part of our cybersecurity risk management process, our incident response team logs and tracks privacy and security incidents across the Partnership, vendors, third party service providers, and other business partners. Cyber and data security incidents are evaluated to determine materiality, as well as operational, business, and privacy impact, ranked by severity, and prioritized for response and remediation. Significant incidents are evaluated by the primary incident response team to determine whether further escalation is appropriate, and any incident assessed as potentially being or potentially becoming material is immediately escalated for further assessment and reported to the Chief Executive Officer (“CEO”). We consult with outside counsel and other subject matter experts regarding materiality analysis, disclosure, and other compliance matters, as appropriate, and our executive officers, with input from the Board of Managers, as appropriate, make the final materiality determinations and disclosure and other compliance decisions. Our management apprises the Partnership’s independent public accounting firm of matters and any relevant developments.
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

Note 2 - Summary of Significant Accounting Policies (Tables)

12 Months Ended

Dec. 31, 2025

Notes Tables

Schedule of Partneship's Receivables [Table Text Block]

	*In Thousands*
	*2025*		*2024*		*2023*
Royalty Properties receivable	$	13,810	$	19,120	$	13,556
Other		158		121		179
Accounts receivable		13,968		19,241		13,735
Net profits interest receivable - related party		2,513		5,544		8,275
Total Receivables	$	16,481	$	24,785	$	22,010

Disaggregation of Revenue [Table Text Block]

	*In Thousands*
	*2025*		*2024*		*2023*
Oil sales (1)	$	114,116	$	129,693	$	102,323
Natural gas sales		13,707		7,772		12,208
Total Royalties operating revenue	$	127,823	$	137,465	$	114,531

Note 7 - Leases - Maturities of Lease Liabilities (Details) $ in Thousands	Dec. 31, 2025 USD ($)
2026	$ 368
2027	374
2028	380
2029	63
Total lease payments	1,185
Less amount representing interest	(408)
Total lease obligation	$ 777

Note 4 - Related Party Transaction

12 Months Ended

Dec. 31, 2025

Related Party Transactions

Our General Partner owns all of the partnership interests in the Operating Partnership. The Operating Partnership is the employer of all personnel, owns the working interests and other properties underlying our NPI, and provides day-to-day operational and administrative services to us and the General Partner. In accordance with our partnership agreement, we reimburse the General Partner for certain allocable general and administrative costs, including rent, salaries, and employee equity and benefit plans that are not direct expenses. These types of reimbursements are limited to 5% of distributions, plus certain costs previously paid. All such costs have been below the annual 5% limit amount, including the allowable surplus carryforward, for the years ended December 31, 2025, 2024 and 2023. Additionally, certain reimbursable direct expenses such as professional and regulatory fees, as well as certain general and administrative costs that are related to regulatory matters, are not limited. The Partnership reimburses the Operating Partnership an estimated monthly fee for these expenses and in the month following will settle any payable or receivable remaining for actual expenses paid on behalf of the Partnership. All significant related party transactions with the Operating Partnership have been stated on the face of the consolidated financial statements for the years ended December 31, 2025, 2024 and 2023.

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

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Consolidated Income Statements - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Operating revenues:
Operating revenues	$ 152,832	$ 161,523	$ 163,799
Operating revenues	152,832	161,523	163,799
Costs and expenses:
Production taxes	5,834	6,884	5,776
Operating expenses	10,022	7,671	6,435
Depreciation, depletion and amortization	66,300	42,588	26,307
Total costs and expenses	95,480	69,074	49,682
Net income	57,352	92,449	114,117
Allocation of net income:
General Partner	2,100	3,249	3,728
Unitholders	$ 55,252	$ 89,200	$ 110,389
Net income per common unit (basic and diluted) (in dollars per share)	$ 1.16	$ 2.13	$ 2.85
Weighted average basic and diluted common units outstanding (in shares)	47,654	41,811	38,783
Nonrelated Party [Member]
Costs and expenses:
General and administrative expenses	$ 2,179	$ 1,980	$ 3,350
Related Party [Member]
Costs and expenses:
General and administrative expenses	11,145	9,951	7,814
Royalties [Member]
Operating revenues:
Operating revenues	127,823	137,465	114,531
Operating revenues	127,823	137,465	114,531
Net Profit Interests [Member]
Operating revenues:
Operating revenues	13,928	21,856	34,338
Operating revenues	13,928	21,856	34,338
Lease Bonus [Member]
Operating revenues:
Operating revenues	9,400	314	12,668
Operating revenues	9,400	314	12,668
Other Revenue [Member]
Operating revenues:
Operating revenues	1,681	1,888	2,262
Operating revenues	$ 1,681	$ 1,888	$ 2,262

Note 6 - Distributions to Holders of Common Units (Details Textual)	3 Months Ended
	Dec. 31, 2025 $ / shares
Distribution Made to Limited Partner, Distributions Paid, Per Unit (in dollars per share)	$ 0.755712

Note 2 - Summary of Significant Accounting Policies - Disaggregation of Partnership's Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2025	Dec. 31, 2024	Dec. 31, 2023
Revenue	$ 152,832	$ 161,523	$ 163,799
Royalties, Oil [Member]
Revenue	114,116	129,693	102,323
Royalties, Natural Gas [Member]
Revenue	13,707	7,772	12,208
Royalties [Member]
Revenue	$ 127,823	$ 137,465	$ 114,531

Amount, including tax collected from customer, of revenue from satisfaction of performance obligation by transferring promised good or service to customer. Tax collected from customer is tax assessed by governmental authority that is both imposed on and concurrent with specific revenue-producing transaction, including, but not limited to, sales, use, value-added and excise.

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