Dorchester Minerals DMLP Form 10-Q filing Q2 FY2026

PART I – FINANCIAL INFORMATION

FILINGSOURCEITEMBOUNDARYBEGIN Item 1. FINANCIAL STATEMENTS (UNAUDITED) FILINGSOURCEITEMBOUNDARYENDITEM 1. FINANCIAL STATEMENTS

See attached financial statements on the following pages.

DORCHESTER MINERALS, L.P.

(A Delaware Limited Partnership)

CONDENSED CONSOLIDATED BALANCE SHEETS

(In Thousands)

(Unaudited)

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

DORCHESTER MINERALS, L.P.

(A Delaware Limited Partnership)

CONDENSED CONSOLIDATED INCOME STATEMENTS

(In Thousands, except per unit amounts)

(Unaudited)

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

DORCHESTER MINERALS, L.P.

(A Delaware Limited Partnership)

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN PARTNERSHIP CAPITAL

(In Thousands)

(Unaudited)

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

DORCHESTER MINERALS, L.P.

(A Delaware Limited Partnership)

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In Thousands)

(Unaudited)

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

DORCHESTER MINERALS, L.P.

(A Delaware Limited Partnership)

NOTES TO THE CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. 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 business may be described as the acquisition, ownership and administration of Royalty Properties (which consist of producing and nonproducing mineral, royalty, overriding royalty, net profits, and leasehold interests located in 593 counties and parishes in 28 states (“Royalty Properties”)) and net profits overriding royalty interests (referred to as the “Net Profits Interest”, or “NPI”).

Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of the Partnership have been prepared in accordance with generally accepted accounting principles in the United States (“U.S. GAAP”) and pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”). The unaudited condensed consolidated financial statements do not include all of the disclosures required for complete annual financial statements prepared in conformity with U.S. GAAP. Therefore, the accompanying unaudited condensed consolidated financial statements and related notes should be read in conjunction with the consolidated financial statements and notes thereto included in the Partnership’s Annual Report. The accompanying unaudited condensed consolidated financial statements reflect all adjustments (consisting only of normal and recurring adjustments unless indicated otherwise) that are, in the opinion of management, necessary for the fair presentation of our financial position and operating results for the interim period. Interim period results are not necessarily indicative of the results for the calendar year. Per unit information is calculated by dividing the income or loss applicable to holders of the Partnership’s common units by the weighted average number of units outstanding. The Partnership has no potentially dilutive securities and, consequently, basic and diluted income per unit do not differ.

The unaudited condensed consolidated financial statements include the accounts of the Partnership and its wholly-owned subsidiaries Dorchester Minerals Oklahoma LP, Dorchester Minerals Oklahoma GP, Inc., Maecenas Minerals LLP, Dorchester-Maecenas GP LLC, The Buffalo Co., A Limited Partnership, DMLPTBC GP LLC, and DMLP Terra Firma LLC. All significant intercompany balances and transactions have been eliminated in consolidation.

Certain amounts in the prior‑period condensed 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.

2. Summary of Significant Accounting Policies

The Partnership’s significant accounting policies are described in Note 2 of the consolidated financial statements included in the Partnership’s Annual Report on Form 10‑K for the year ended December 31, 2025. There have been no changes in such policies or the application of such policies during the six months ended June 30, 2026.

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.

Receivables — The following table presents the Partnership’s receivables as of the dates indicated:

Revenues — The following table disaggregates the Partnership’s oil and natural gas revenues from production on the Royalty Properties for the three and six months ended June 30, 2026 and 2025:

(1) Includes natural gas liquids sales.

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Recent Accounting Pronouncements

Recently Adopted Pronouncements

In July 2025, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2025-05, “Financial Instruments—Credit Losses (Topic 326): Measurement of Credit Losses for Accounts Receivable and Contract Assets” (“ASU 2025-05”), which provides a practical expedient for calculating current expected credit losses on accounts receivable and current contract assets. This practical expedient permits a reporting entity to assume that current conditions as of the balance sheet date remain unchanged over the remaining life of the assets. This ASU was effective for the Partnership beginning January 1, 2026, under a prospective approach. The adoption of this ASU did not have a material effect on the Partnership’s financial statements.

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 disclose 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

3. Acquisitions for Common Units

On July 31, 2026, pursuant to a non-taxable contribution and exchange agreement with multiple unrelated third parties, the Partnership acquired mineral and royalty interests totaling approximately 3,100 net royalty acres located in five counties across the Williston Basin in North Dakota in exchange for 835,958 common units representing limited partnership interests in the Partnership valued at $23.1 million and issued pursuant to the Partnership’s registration statement on Form S-4. At closing, in addition to conveying mineral and royalty interests to the Partnership, the contributors delivered funds to the Partnership in an amount equal to their cash receipts during the period from April 1, 2026 through June 30, 2026 of $3.6 million, which will be included in the calculation of the Partnership’s third quarter 2026 cash distribution to unitholders.

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. 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. Final settlement net cash received of $4.0 million is included in net cash contributed in acquisitions on the condensed consolidated statement of cash flows for the six months ended June 30, 2026.

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. Final settlement net cash received, net of capitalized transaction costs paid, of $2.0 million is included in net cash contributed in acquisitions on the condensed consolidated statement of cash flows for the six months ended June 30, 2025.

4. Commitments and Contingencies

Our Partnership and Dorchester Minerals Operating LP, a Delaware limited partnership owned directly and indirectly by our General Partner (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. During the first quarter of 2026, our Partnership and the Operating Partnership entered into a settlement and mutual release agreement with unrelated third parties resolving ordinary course litigation affecting certain leasehold in Midland County, Texas, which is owned by the Operating Partnership and subject to the NPI. The Operating Partnership received proceeds of $15.5 million, which were included in the calculation of the April 2026 NPI payment.

5. Distributions to Holders of Common Units

On July 23, 2026, the Partnership announced its cash distribution for the second quarter of 2026 of $1.272943 per common unit, representing activity for the three-month period ended June 30, 2026, payable to common unitholders of record as of August 3, 2026. This distribution will be paid on August 13, 2026. The partnership agreement requires the next cash distribution to be paid by November 14, 2026.

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6. Segment Reporting

The Partnership operates in a single operating and reportable segment. The Partnership’s Chief Executive Officer (“CEO”) has been determined to be the chief operating decision maker of the Partnership. The CEO uses net income 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. Disaggregated operating revenues of the Partnership’s single segment and all significant segment expenses are presented separately on the Partnership’s condensed consolidated income statements. There are no other significant segment expenses or other segment items that would require disclosure.

7. Leases

The Partnership leases its office space at 3838 Oak Lawn Avenue, Suite 300, Dallas, Texas (the “Office Lease”). The third amendment to the Office Lease was executed in April 2017 for a term of 129 months, beginning June 1, 2018 and expiring February 28, 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 approximately $25,000 to $30,000.

In May 2026, the Partnership executed the fourth amendment to the Office Lease, extending the lease term for an additional 86 months, beginning March 1, 2029 and expiring April 30, 2036. Monthly rental payments under the fourth amendment range from approximately $45,000 to $52,000.

Upon commencement of the fourth amendment, the Partnership concluded that the amendment constituted a lease modification and did not represent a separate contract under ASC 842 as the amendment did not grant the Partnership additional right of use not included in the existing Office Lease. As the fourth amendment did not represent a separate contract and extended the contractual term of the existing Office Lease, the Partnership reassessed the classification of the Office Lease and concluded that it continues to be an operating lease. Therefore, upon the effective date of the modification, the Partnership remeasured the operating lease liability using a discount rate of 7% and recognized a corresponding adjustment to the operating lease right-of-use asset. As the Office 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. The modification was accounted for as a non-cash exchange in which the Partnership obtained additional operating lease right-of-use asset in exchange for the remeasured operating lease liability. The non-cash exchange resulted in an increase of $2.8 million to both the operating lease right-of-use asset and operating lease liability on the condensed consolidated balance sheet.

Maturities of lease liabilities under the fourth amendment to the Office Lease are as follows:

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FILINGSOURCEITEMBOUNDARYBEGIN Item 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS FILINGSOURCEITEMBOUNDARYENDITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion contains forward-looking statements. For a description of limitations inherent in forward-looking statements, see page 1 of this Quarterly Report.

Objective

This discussion, which presents our results of operations for the three and six months ended June 30, 2026 and 2025, should be read in conjunction with our unaudited condensed consolidated financial statements and the accompanying notes. We intend for this discussion to provide the reader with information that will assist in understanding our financial statements, the changes in certain key items in those financial statements from period to period, and the primary factors that accounted for those changes.

Overview

We own producing and nonproducing mineral, royalty, overriding royalty, net profits and leasehold interests. We refer to these interests as the Royalty Properties. We currently own Royalty Properties in 593 counties and parishes in 28 states.

As of June 30, 2026, we own a net profits overriding royalty interest (referred to as the “Net Profits Interest”, or “NPI”) in various properties owned by Dorchester Minerals Operating LP (the “Operating Partnership”), a Delaware limited partnership owned directly and indirectly by our General Partner. We receive a monthly payment from the NPI equaling 96.97% of the net profits actually realized by the Operating Partnership from these properties in the preceding month. In the event that costs, including budgeted capital expenditures, exceed revenues on a cash basis in a given month for properties subject to the Net Profits Interest, no payment is made, and any deficit is accumulated and reflected in the following month's calculation of net profit.

In the event the NPI has a deficit of cumulative revenue versus cumulative costs, the deficit will be borne solely by the Operating Partnership.

From a cash perspective, as of June 30, 2026, the NPI was in a surplus position and had outstanding capital commitments, primarily in the Bakken region, of $10.4 million.

Commodity Price Risks

The pricing of oil and natural gas sales is primarily determined by supply and demand in the global marketplace and can fluctuate considerably. As a royalty owner and non-operator, we have extremely limited access to timely information and no operational control over the volumes of oil and natural gas produced and sold or the terms and conditions on which such volumes are marketed and sold.

Our profitability is affected by oil and natural gas market prices. Oil and natural gas market prices have fluctuated significantly in recent years in response to factors outside of our control, including the war in Ukraine, conflicts in the Middle East, including the ongoing military conflict in Iran, fluctuations in interest rates, global supply chain disruptions, political uncertainty in Venezuela, and actions taken by OPEC+. It is not possible for us to predict or determine how these factors might affect oil and natural gas market prices in the future. We continue to monitor factors impacting commodity supply and demand situations, including changes to tariff and import/export regulations by the United States or other countries, and assess their impact on our business.

Tariffs and Trading Relationships

The U.S. government has announced, adjusted and rescinded multiple tariffs on many foreign jurisdictions, which has increased uncertainty regarding the ultimate effect of the tariffs on economic conditions. Continued uncertainties about tariffs and their effects on trading relationships may affect costs for and availability of raw materials or contribute to inflation in the markets in which we own properties. Although we are continuing to monitor the economic effects of such announcements and adjustments, as well as opportunities to mitigate their related impacts, costs and other effects associated with the tariffs remain uncertain.

Global oil markets are contending with tariff impacts, geopolitical tensions, including the recent military conflict in Iran, and oil supply dynamics, including the evolving OPEC+ production strategy, potential constraints on Iranian, Russian, and Venezuelan oil exports, disruptions to the flow of oil through the Strait of Hormuz, and the withdrawal of the United Arab Emirates from OPEC and OPEC+. It is unclear how recent volatility in commodity prices will affect changes in North American production activity and oil producers are evaluating a range of scenarios in anticipation of oil price pressure in light of the foregoing. Gas producers could prove to be beneficiaries of potentially lower associated gas production in oil-weighted basins if oil production is curtailed. Larger, well-capitalized producers that comprise a greater portion of present North American shale production, are better able to withstand a broader range of commodity prices.

Results of Operations

Acquisitions for Common Units

On July 31, 2026, pursuant to a non-taxable contribution and exchange agreement with multiple unrelated third parties, the Partnership acquired mineral and royalty interests totaling approximately 3,100 net royalty acres located in five counties across the Williston Basin in North Dakota in exchange for 835,958 common units representing limited partnership interests in the Partnership valued at $23.1 million and issued pursuant to the Partnership’s registration statement on Form S-4. At closing, in addition to conveying mineral and royalty interests to the Partnership, the contributors delivered funds to the Partnership in an amount equal to their cash receipts during the period from April 1, 2026 through June 30, 2026 of $3.6 million, which will be included in the calculation of the Partnership’s third quarter 2026 cash distribution to unitholders.

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. Final settlement net cash received of $4.0 million is included in net cash contributed in acquisitions on the condensed consolidated statement of cash flows for the six months ended June 30, 2026.

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 (collectively, the “Contributors”), 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. Final settlement net cash received, net of capitalized transaction costs paid, of $2.0 million is included in the net cash contributed in acquisitions on the condensed consolidated statement of cash flows for the three months ended June 30, 2025.

Three and Six Months Ended June 30, 2026 as compared to Three and Six Months Ended June 30, 2025

Our period-to-period changes in net income and cash flows from operating activities are principally determined by changes in oil and natural gas sales volumes and prices, and to a lesser extent, by capital expenditures deducted under the NPI calculation. Our portion of oil and natural gas sales volumes and average sales prices are shown in the following table. Oil sales volumes include volumes attributable to natural gas liquids and oil sales prices include natural gas liquids prices combined by volumetric proportions.

Both oil and natural gas sales price changes reflected in the table above resulted from changing market conditions.

The increase in oil sales volumes attributable to our Royalty Properties from the second quarter of 2025 to the same period of 2026 is primarily a result of higher suspense releases on new wells on legacy acreage in the Permian Basin, increased baseline production from legacy wells in the Permian Basin, and Rockies wells acquired in the third quarter of 2025. The increase in oil sales volumes attributable to our Royalty Properties from the first six months of 2025 to the same period of 2026 is primarily a result of higher suspense releases on new wells on legacy acreage in the Permian Basin, and suspense releases on first time payments and increased baseline production from Rockies wells acquired in the third quarter of 2025, partially offset by decreased baseline production in the Permian Basin, particularly in the first quarter of 2026 compared to the same period of 2025, and lower suspense releases on new wells on legacy acreage in the Rockies in the first quarter of 2026 compared to the same period of 2025. The increase in natural gas sales volumes attributable to our Royalty Properties from the second quarter and first six months of 2025 to the same periods of 2026 is primarily a result of higher suspense releases on new wells on legacy acreage in the Permian Basin, and suspense releases on first time payments and increased baseline production from Rockies wells acquired in the third quarter of 2025, partially offset by decreased baseline production in the Permian Basin and lower suspense releases on new wells on legacy acreage in the Rockies in the first quarter of 2026 compared to the same period of 2025.

The increase in oil sales volumes attributable to our NPI properties from the second quarter of 2025 to the same period of 2026 is primarily a result of higher suspense releases on new wells in the Permian Basin and increased baseline production in the Bakken region and Rockies, partially offset by decreased baseline production on legacy wells in the Permian Basin. The increase in oil sales volumes attributable to our NPI properties from the first six months of 2025 to the same period of 2026 is primarily a result of higher suspense releases on new wells in the Permian Basin and Bakken region, increased baseline production in the Bakken region and Rockies, and the recognition of sales volumes from July 2021 through May 2025 associated with the $15.5 million of legal settlement proceeds received by the Operating Partnership in the first quarter of 2026 from resolution of ordinary course litigation affecting certain leasehold in Midland County, Texas, which is owned by the Operating Partnership and subject to the NPI. This increase was partially offset by decreased baseline production on legacy wells in the Permian Basin. The increase in natural gas sales volumes attributable to our NPI properties from the second quarter of 2025 to the same period of 2026 is primarily a result of increased baseline production in the Permian Basin, Bakken region, and Mid-Continent. The increase in natural gas sales volumes attributable to our NPI properties from the first six months of 2025 to the same period of 2026 is primarily due to the recognition of sales volumes from July 2021 through May 2025 associated with legal settlement proceeds noted above and increased baseline production in the Bakken region and Mid-Continent in the second quarter of 2026 compared to the same period of 2025, partially offset by decreased baseline production on legacy wells in the Permian Basin, particularly in the first quarter of 2026 compared to the same period of 2025.

Operating costs, including production taxes, attributable to our Royalty Properties increased 123% from the second quarter of 2025 to the same period of 2026 and 46% from the first six months of 2025 to the same period of 2026. This is primarily a result of higher proportionate oil production taxes due to higher oil sales revenue, higher post-production costs, such as compression, transportation, processing, and marketing, due to higher oil and natural gas sales volumes, and higher ad valorem taxes, partially offset by lower proportionate natural gas production taxes due to lower natural gas sales revenue.

Depreciation, depletion and amortization increased 8% from the second quarter of 2025 to the same period of 2026 and 17% from the first six months of 2025 to the same period of 2026. Depletion is the amount of cost basis of oil and natural gas properties at the beginning of a period attributable to the volume of reserves extracted during such period, calculated on a units-of-production basis. Estimates of proved developed producing reserves are a major component in the calculation of depletion. We adjust our depletion rate each quarter for significant changes in our estimates of oil and natural gas reserves, including recent acquisitions and suspense releases on new wells.

General and administrative expenses increased 33% from the second quarter of 2025 to the same period of 2026. The increase is primarily attributable to higher professional services fees and increased compensation expenses, including an expanded Operating Partnership equity program designed for employee retention. General and administrative expenses increased 12% from the first six months of 2025 to the same period of 2026. The increase is primarily attributable to higher professional services fees and increased compensation expenses, including an expanded Operating Partnership equity program designed for employee retention, partially offset by lower regulatory fees due to the Partnership’s S-4 filing in the first quarter of 2025.

Net cash provided by operating activities increased 38% from the first six months of 2025 to the same period of 2026 primarily due to higher revenue receipts attributable to our Royalty Properties and higher NPI payment receipts, partially offset by lower lease bonus receipts and higher general and administrative expense payments.

In an effort to provide the reader with information concerning prices of oil and natural gas sales that correspond to our quarterly distributions, management calculates the average price by dividing gross revenues received by the net volumes of the corresponding product without regard to the timing of the production to which such sales may be attributable. This “realized price” does not necessarily reflect the contract terms for such sales and may be affected by transportation costs, location differentials, and quality and gravity adjustments. While the relationship between our cash receipts and the timing of the production of oil and natural gas may be described generally, actual cash receipts may be materially impacted by purchasers’ release of suspended funds and by purchasers’ prior period adjustments.

Cash receipts attributable to our Royalty Properties during the second quarter of 2026 totaled $50.4 million. Approximately 66% of these receipts reflect oil sales during March 2026 through May 2026 and natural gas sales during February 2026 through April 2026, and approximately 34% from prior sales periods. The average realized prices for oil and natural gas sales cash receipts attributable to the Royalty Properties during the second quarter of 2026 were $70.37/bbl and $1.68/mcf, respectively.

Cash receipts attributable to the Partnership's NPI during the second quarter of 2026 totaled $16.6 million. Approximately 21% of these receipts reflect oil and natural gas sales during February 2026 through April 2026, and approximately 79% from prior sales periods including $15.5 million of proceeds from the previously announced settlement and mutual release agreement affecting certain leasehold in Midland County, Texas. The average realized prices for oil and natural gas sales cash receipts attributable to the NPI properties during the second quarter of 2026 were $67.87/bbl and $3.56/mcf, respectively.

Liquidity and Capital Resources

Capital Resources

Our primary sources of capital, on both a short-term and long-term basis, are our cash flows from the Royalty Properties and the NPI. Our partnership agreement requires that we distribute quarterly an amount equal to all funds that we receive from Royalty Properties and NPIs (other than cash proceeds received by the Partnership from a public or private offering of securities of the Partnership) less certain expenses and reasonable reserves. Additional cash requirements include the payment of oil and natural gas production and property taxes not otherwise deducted from gross production revenues and general and administrative expenses incurred on our behalf and allocated to the Partnership in accordance with the partnership agreement. Because the distributions to our unitholders are, by definition, determined after the payment of all expenses actually paid by us, the only cash requirements that may create liquidity concerns for us are the payment of expenses. Because many of these expenses vary directly with oil and natural gas sales prices and volumes, we anticipate that sufficient funds will be available at all times for payment of these expenses. See Note 5 to the unaudited condensed consolidated financial statements included in “Item 1 – Financial Statements” of this Quarterly Report for additional information regarding cash distributions to unitholders.

Contractual Obligations

The Partnership leases its office space at 3838 Oak Lawn Avenue, Suite 300, Dallas, Texas, through an operating lease (the “Office Lease”). The third amendment to our Office Lease was executed in April 2017 for a term of 129 months, beginning June 1, 2018 and expiring February 28, 2029. The fourth amendment to our Office Lease was executed in May 2026 for a term of 86 months, beginning March 1, 2029 and expiring April 30, 2036. Under the third and fourth amendments to the Office Lease, monthly rental payments range from $25,000 to $52,000. Future maturities of Office Lease liabilities representing monthly cash rental payment obligations are summarized in Note 7 to the unaudited condensed consolidated financial statements included in “Item 1 – Financial Statements” of this Quarterly Report.

We are not directly liable for the payment of any exploration, development or production costs. We do not have any transactions, arrangements or other relationships that could materially affect our liquidity or the availability of capital resources. We have not guaranteed the debt of any other party, nor do we have any other arrangements or relationships with other entities that could potentially result in unconsolidated debt.

To the extent necessary to avoid unrelated business taxable income, our partnership agreement prohibits us from incurring indebtedness, excluding trade payables, in excess of $50,000 in the aggregate at any given time or which would constitute “acquisition indebtedness” (as defined in Section 514 of the Internal Revenue Code of 1986, as amended).

We currently expect to have sufficient liquidity to fund our distributions to unitholders and operations. However, our liquidity and ability to fund future distributions may be affected by material uncertainties arising from factors beyond our control, including: ongoing global military conflicts such as those in Ukraine and the Middle East, including the conflict in Iran; current inflation and interest rates; political uncertainty in Venezuela; changes to tariff and import/export regulations by the United States or other countries; and prevailing economic conditions in the oil and natural gas market and other financial and business factors. We cannot predict events that may lead to future oil and natural gas price volatility. If market conditions were to change due to declines in oil prices, uncertainty created by military conflicts, or changes in trade policy, and our revenues were reduced significantly or our operating costs were to increase significantly, our cash flows and liquidity could be reduced. The current economic environment is volatile, and we cannot predict the ultimate long-term impact on our liquidity or cash flows from these factors.

Liquidity and Working Capital

Cash and cash equivalents totaled $72.5 million at June 30, 2026 and $41.9 million at December 31, 2025.

Critical Accounting Policies and Estimates

As of June 30, 2026, there have been no significant changes to our critical accounting policies and related estimates previously disclosed in our Annual Report.

FILINGSOURCEITEMBOUNDARYBEGIN Item 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK FILINGSOURCEITEMBOUNDARYENDITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

There have been no significant changes in our exposure to market risk during the three months ended June 30, 2026. For a discussion of our exposure to market risk, refer to Item 7A of Part II of the Partnership’s Annual Report.

FILINGSOURCEITEMBOUNDARYBEGIN Item 4. CONTROLS AND PROCEDURES FILINGSOURCEITEMBOUNDARYENDITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

As of the end of the period covered by this Quarterly Report, our principal executive officer and principal financial officer carried out an evaluation of the effectiveness of our disclosure controls and procedures. Based on their evaluation, they have concluded that our disclosure controls and procedures were effective.

Changes in Internal Control

There were no changes in our internal control over financial reporting (as defined in Rule 13a-15(f) of the Securities Exchange Act of 1934) during the quarter ended June 30, 2026 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II – OTHER INFORMATION

FILINGSOURCEITEMBOUNDARYBEGIN Item 1. LEGAL PROCEEDINGS FILINGSOURCEITEMBOUNDARYENDITEM 1. LEGAL PROCEEDINGS

The 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 material effect on consolidated financial position, cash flows, or operating results.

FILINGSOURCEITEMBOUNDARYBEGIN Item 1A. RISK FACTORS FILINGSOURCEITEMBOUNDARYENDITEM 1A. RISK FACTORS

There have been no material changes to the Partnership’s risk factors as disclosed under “Item 1A – Risk Factors” in the Partnership’s Annual Report other than as disclosed below.

The Partnership may be adversely affected by price volatility in the oil and natural gas markets.

Historically, there has been price volatility in the oil and natural gas markets, which have been impacted by a number of factors, including actions by oil producing nations. Global military conflicts and political uncertainty, fluctuating interest rates, changes in tariff rates, global supply chain disruptions, concerns about a potential economic downturn or recession, recent measures to combat persistent inflation, and actions taken by OPEC and its non-OPEC allies, collectively OPEC+, continued to contribute to economic and pricing volatility during 2025. More recently, military actions among the United States, Israel and Iran have occurred throughout 2026 with related disruptions to transit through the Strait of Hormuz. Additionally, Yemen has indicated a continued readiness to resume or escalate attacks on shipping and key waterways in the Red Sea corridor, particularly in response to further escalation of the conflict involving Iran. These hostilities have disrupted and may further disrupt the flow of oil, and have contributed to, and may continue to contribute to, price volatility. Although the length and impact of these ongoing and evolving conflicts are fluid and unpredictable, they have led and may continue to lead to market disruptions, including volatility in oil prices and disruptions to global trade flows. Furthermore, the withdrawal of the United Arab Emirates from OPEC and OPEC+ may further impact oil price volatility. Oil and natural gas market price volatility may have a material adverse effect on our cash distributions in periods of lower prices. During periods of substantial declines in prices, oil and natural gas operators on our properties may suspend drilling programs, which would impact our revenues and operating income. In the event that any wells on our properties are shut-in, restarting wells may require significant costs from our operators, and we cannot guarantee that they would be able to restart at the same level. Moreover, due to the extremely volatile market conditions, we are unable to predict the degree or duration of any adverse impact on our operations and financial condition and other risks in our industry may be enhanced by such conditions.

FILINGSOURCEITEMBOUNDARYBEGIN Item 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS FILINGSOURCEITEMBOUNDARYENDITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS

Issuer Purchases of Equity Securities

(1) The number of common units that our General Partner may grant under the Dorchester Minerals Management LP Equity Incentive Program, originally adopted on May 20, 2015, by Dorchester Minerals Operating LP, the Partnership’s sole limited partner, as amended and restated and adopted by the Partnership on October 20, 2022, and, subsequently, as amended and restated as of October 4, 2023, which was approved by our common unitholders on October 4, 2023 (the “Equity Incentive Program”), each fiscal year may not exceed 0.333% of the number of common units outstanding at the beginning of the fiscal year. In 2026, the maximum number of common units that could be purchased under the Equity Incentive Program is 160,691 common units.

(2) Open-market purchases by the Operating Partnership, an affiliate of the Partnership, pursuant to a Rule 10b5-1 plan adopted on November 12, 2025 for the purpose of satisfying equity awards to be granted pursuant to the Equity Incentive Program.

FILINGSOURCEITEMBOUNDARYBEGIN Item 5. OTHER INFORMATION FILINGSOURCEITEMBOUNDARYENDITEM 5. OTHER INFORMATION

Rule 10b5-1 Trading Plans

During the second quarter and six months ended June 30, 2026, none of our executive officers or directors adopted or terminated any contract, instruction or written plan for the purchase or sale of our securities that was intended to satisfy the affirmative defense conditions of Rule 10b5-1(c) under the Exchange Act (a “Rule 10b5-1 trading arrangement”) or any “Non-Rule 10b5-1 trading arrangement” (as defined in Item 408(c) of Regulation S-K).

FILINGSOURCEITEMBOUNDARYBEGIN Item 6. EXHIBITS FILINGSOURCEITEMBOUNDARYENDITEM 6. EXHIBITS

SIGNATURES

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