UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

(Mark One)


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

For the quarterly period ended March 31, 2026


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

For the transition period to________

Commission File Number: 001-08033

PERMIAN BASIN ROYALTY TRUST

(Exact name of registrant as Specified in the Permian Basin Trust Indenture)


Texas	75-6280532
( State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
Argent Trust Company 3838 Oak Lawn Ave, Suite 1720 Dallas, Texas 75219
(Address of Principal Executive Offices; Zip Code)

(855) 588-7839

(Registrant’s telephone number, including area code)

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


	Trading Symbol(s)	Name of each exchange on which registered
Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Units of Beneficial Interest	PBT	New York Stock Exchange

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):


Large accelerated filer	☐	Accelerated filer	☐
Non-accelerated filer	☒	Smaller reporting company	☒
		Emerging growth company	☐

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

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

Number of units of beneficial interest outstanding at May 14, 2026: 46,608,796

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PERMIAN BASIN ROYALTY TRUST

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

The condensed interim financial statements included herein have been prepared by Argent Trust Company as Trustee for the Permian Basin Royalty Trust (the “Trust”), without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in annual financial statements have been condensed or omitted pursuant to such rules and regulations, although the Trustee believes that the disclosures are adequate to make the information presented not misleading. It is suggested that these condensed interim financial statements and notes thereto be read in conjunction with the financial statements and the notes thereto included in the Trust’s latest annual report on Form 10-K. In the opinion of the Trustee, all adjustments, consisting only of normal recurring adjustments, necessary to present fairly the assets, liabilities and trust corpus of the Trust as of March 31, 2026, and the distributable income and the changes in trust corpus for the three months ended March 31, 2026 and 2025, have been included. The distributable income for such interim periods is not necessarily indicative of the distributable income for the full year. Unless specified otherwise, all amounts included herein are presented in US dollars.


		Page
Condensed Interim Statements of Assets, Liabilities and Trust Corpus		3
Condensed Interim Statements of Distributable Income (Unaudited)		4
Condensed Interim Statements of Changes in Trust Corpus (Unaudited)		5

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PERMIAN BASIN ROYALTY TRUST

CONDENSED INTERIM STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS


	March 31, 2026 (Unaudited)		December 31, 2025
ASSETS
Cash and short-term investments	$	1,596,941	$	1,715,167
Net overriding royalty interests in producing oil and gas properties (net of accumulated amortization of $10,813,082 and $10,812,650 at March 31, 2026 and December 31, 2025, respectively)		162,134		162,566
TOTAL ASSETS	$	1,759,075	$	1,877,733
LIABILITIES AND TRUST CORPUS
Distribution payable to Unitholders	$	496,941	$	615,167
Commitments and reserves for contingencies (Note 7)		1,100,000		1,100,000
Total Liabilities	$	1,596,941	$	1,715,167
Trust corpus – 46,608,796 Units of beneficial interest authorized and outstanding		162,134		162,566
TOTAL LIABILITIES AND TRUST CORPUS	$	1,759,075	$	1,877,733

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

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PERMIAN BASIN ROYALTY TRUST

CONDENSED INTERIM STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)


	Three Months Ended March 31, 2026			Three Months Ended March 31, 2025
Royalty income	$	3,551,082		$	3,054,697
Interest income		16,876			16,523
Total Income		3,567,958			3,071,220
General and administrative expenditures		(541,157	)		(475,008	)
Distributable income	$	3,026,801		$	2,596,212
Distributable income per Unit (46,608,796 Units outstanding)	$	0.06		$	0.06

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

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PERMIAN BASIN ROYALTY TRUST

CONDENSED INTERIM STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)


	Three Months Ended March 31, 2026			Three Months Ended March 31, 2025
Trust corpus, beginning of period	$	162,566		$	164,407
Amortization of net overriding royalty interests		(432	)		(642	)
Distributable income		3,026,802			2,596,212
Distributions declared		(3,026,802	)		(2,596,212	)
Total Trust Corpus, end of period	$	162,134		$	163,765
Distributions per Unit (46,608,796 Units outstanding)	$	0.06		$	0.06

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

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PERMIAN BASIN ROYALTY TRUST

NOTES TO CONDENSED INTERIM FINANCIAL STATEMENTS (UNAUDITED)

TRUST ORGANIZATION AND PROVISIONS

The Permian Basin Royalty Trust (“Trust”) was established as of November 1, 1980. Argent Trust Company, a Tennessee chartered trust company (“Argent”) is Trustee for the Trust. The net overriding royalties conveyed to the Trust include (1) a 75% net overriding royalty in Southland Royalty Company’s fee mineral interest in the Waddell Ranch in Crane County, Texas (the “Waddell Ranch properties”) and (2) a 95% net overriding royalty carved out of Southland Royalty Company’s major producing royalty properties in Texas (the “Texas Royalty properties”). The net overriding royalty for the Texas Royalty properties is subject to the provisions of the lease agreements under which such royalties were created. The net overriding royalties above are collectively referred to as the “Royalties.”

On November 3, 1980, Units of Beneficial Interest (“Units”) in the Trust were distributed to the Trustee for the benefit of Southland Royalty Company’s shareholders of record as of November 3, 1980, who received one Unit in the Trust for each share of Southland Royalty Company common stock held. The Units are traded on the New York Stock Exchange.

Burlington Resources Oil & Gas Company LP (“BROG”), a subsidiary of ConocoPhillips, was the interest owner for the Waddell Ranch properties and Riverhill Energy Corporation (“Riverhill Energy”), formerly a wholly owned subsidiary of Riverhill Capital Corporation (“Riverhill Capital”) and formerly an affiliate of Coastal Management Corporation (“CMC”), was the interest owner for the Texas Royalty properties. In February 1997, BROG sold its interest in the Texas Royalty properties to Riverhill Energy. Riverhill Energy currently conducts all field, technical and accounting operations for the Texas Royalty properties. BROG notified the Trust that on November 1, 2019, the Waddell Ranch properties that are subject to the Net Overriding Royalty Conveyance (Permian Basin Royalty Trust-Waddell Ranch) dated November 1, 1980, were sold to Blackbeard Operating, LLC (“Blackbeard”) of Fort Worth, Texas. Blackbeard became the operator effective as of April 1, 2020.

The Trustee was advised that in the first quarter of 1998, Schlumberger Technology Corporation (“STC”) acquired all of the shares of stock of Riverhill Capital. Prior to such acquisition by STC, CMC and Riverhill Energy were wholly owned subsidiaries of Riverhill Capital. The Trustee was further advised that in connection with STC’s acquisition of Riverhill Capital, the shareholders of Riverhill Capital acquired ownership of all of the shares of stock of Riverhill Energy. Thus, the ownership in the Texas Royalty properties referenced above remained in Riverhill Energy, the stock ownership of which was acquired by the former shareholders of Riverhill Capital.

On January 9, 2014, Bank of America N.A. (as successor to The First National Bank of Fort Worth) gave notice to the holders of Units (the “Unitholders”) that it would be resigning as trustee of the Trust subject to certain conditions that included the appointment of Southwest Bank as successor trustee. At a Special Meeting of Trust Unitholders, the Unitholders approved the appointment of Southwest Bank as successor trustee of the Trust once the resignation of Bank of America N.A. took effect and also approved certain amendments to the Trust’s indenture (the “Trust Indenture”). The effective date of Bank of America N.A.’s resignation and the effective date of Southwest Bank’s appointment as successor trustee was August 29, 2014. Effective October 19, 2017, Simmons First National Corporation (“SFNC”) completed its acquisition of First Texas BHC, Inc., the parent company of Southwest Bank. SFNC is the parent company of Simmons Bank. SFNC merged Southwest Bank with Simmons Bank effective February 20, 2018.

On November 4, 2021, Simmons Bank announced that it had entered into an agreement with Argent, pursuant to which Simmons Bank would be resigning as trustee of the Trust and would nominate Argent as successor trustee of the Trust. The effective date of Simmons Bank’s resignation and Argent’s appointment as successor trustee was December 30, 2022. The defined term “Trustee” as used herein shall refer to Bank of America N.A. for periods prior to August 29, 2014, shall refer to Southwest Bank for periods from August 29, 2014 through February 19, 2018, shall refer to Simmons Bank for periods from February 20, 2018 through December 29, 2022, and shall refer to Argent for periods on and after December 30, 2022.

The terms of the Trust Indenture provide, among other things, that:

•

the Trust shall not engage in any business or commercial activity of any kind or acquire any assets other than those initially conveyed to the Trust;

•

the Trustee may not sell all or any part of the Royalties unless approved by holders of 75% of all Units outstanding in which case the sale must be for cash and the proceeds promptly distributed;

•

the Trustee may establish a cash reserve for the payment of any liability which is contingent or uncertain in amount;

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•

the Trustee is authorized to borrow funds to pay liabilities of the Trust; and

•

the Trustee will make monthly cash distributions to Unitholders (see Note 3).

The Trustee believes such information includes all the disclosures necessary to make the information presented not misleading. The information furnished reflects all adjustments which are, in the opinion of the Trustee, necessary for a fair presentation of the results for the interim periods presented. The financial information should be read in conjunction with the financial statements and notes thereto included in the Trust's Annual Report on Form 10-K for the year ended December 31, 2025. The Trust considers all highly liquid investments with a maturity of three months or less to be cash equivalents. Net overriding royalty interests are reviewed for impairment whenever events or changes in circumstances indicate that its carrying amount may not be recoverable. If circumstances require the net overriding royalty interests to be tested for possible impairment, the Trust first compares undiscounted cash flows expected to be generated by the net overriding royalty interests to its carrying value. If the carrying value of the net overriding royalty interests is not recoverable on an undiscounted cash flow basis, an impairment is recognized to the extent that the carrying value exceeds its fair value. The fair value of the net overriding royalty interests is measured using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount.

ACCOUNTING POLICIES

Basis of Accounting

The condensed interim financial statements of the Trust are prepared on the following modified cash basis of accounting and are not intended to present financial position and results of operations in conformity with accounting principles generally accepted in the United States of America (“GAAP”):

•

Royalty income recorded for a month is the amount computed and paid to the Trustee on behalf of the Trust by the interest owners. Royalty income consists of the amounts received and available for distribution by the owners of the interest burdened by the Royalties from the sale of production less accrued production costs, development and drilling costs, applicable taxes, operating charges and other costs and deductions multiplied by 75% in the case of the Waddell Ranch properties and 95% in the case of the Texas Royalty properties. Royalty income for the Waddell Ranch properties was not received for the quarter ended March 31, 2026.

•

Trust expenses, consisting principally of routine general and administrative costs, as recorded are based on liabilities paid and cash reserves established out of cash received or borrowed funds for liabilities and contingencies.

•

Distributions to Unitholders are recorded when declared by the Trustee.

•

Royalty income is computed separately for each of the conveyances under which the Royalties were conveyed to the Trust. If monthly costs exceed revenues for any conveyance (“excess costs”), such excess costs cannot reduce royalty income from other conveyances, but are carried forward with accrued interest to be recovered from future net proceeds of that conveyance.

The condensed interim financial statements of the Trust differ from financial statements prepared in accordance with accounting principles generally accepted in GAAP because revenues are not accrued in the month of production, expenses are recorded when paid and certain cash reserves may be established for contingencies which would not be accrued in financial statements prepared in accordance with GAAP. Amortization of the Royalties calculated on a unit-of-production basis is charged directly to trust corpus. This comprehensive basis of accounting other than GAAP corresponds to the accounting permitted for royalty trusts by the U.S. Securities and Exchange Commission as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts.

Use of Estimates

The preparation of financial statements in conformity with the basis of accounting described above requires management to make estimates and assumptions that affect reported amounts of certain assets, liabilities, income and expenses as of and for the reporting periods. Actual results may differ from such estimates.

Contingencies

Contingencies related to the underlying properties from which the royalties are carved (the “Underlying Properties”) that are unfavorably resolved would generally be reflected by the Trust as reductions to future royalty income payments to the Trust with corresponding reductions to cash distributions to Unitholders.

Distributable Income Per Unit

Basic distributable income per Unit is computed by dividing distributable income by the weighted average of Units outstanding. Distributable income per Unit assuming dilution is computed by dividing distributable income by the weighted average number of Units and equivalent Units outstanding. The Trust had no equivalent Units outstanding for any period presented. Therefore, basic distributable income per Unit and distributable income per Unit assuming dilution are the same.

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New Accounting Pronouncements

There are no new accounting pronouncements that are expected to have significant impact on the Trust’s financial statements.

NET OVERRIDING ROYALTY INTERESTS AND DISTRIBUTION TO UNITHOLDERS

The amounts to be distributed to Unitholders (“Monthly Distribution Amounts”) are determined on a monthly basis. The Monthly Distribution Amount is an amount equal to the sum of cash received by the Trustee during a calendar month attributable to the Royalties, any reduction in cash reserves and any other cash receipts of the Trust, including interest, reduced by the sum of liabilities paid and any increase in cash reserves. If the Monthly Distribution Amount for any monthly period is a negative number, then the distribution will be zero for such month. To the extent the distribution amount is a negative number, that amount will be carried forward and deducted from future monthly distributions until the cumulative distribution calculation becomes a positive number, at which time a distribution will be made. Unitholders of record will be entitled to receive the calculated Monthly Distribution Amount for each month on or before 10 business days after the monthly record date, which is generally the last business day of each calendar month.

The cash received by the Trustee consists of the amounts received by owners of the interest burdened by the Royalties from the sale of production less the sum of applicable taxes, accrued production costs, development and drilling costs, operating charges and other costs and deductions, multiplied by 75% in the case of the Waddell Ranch properties and 95% in the case of the Texas Royalty properties.

As of May 2024, Blackbeard, the operator of the Waddell Ranch properties, provides the Trustee information necessary to calculate the net proceeds during the last week of the month. In accordance with the Trust Indenture, if royalty income is received on or prior to the record date, it will be included in the following month’s distribution, rather than the current month’s distribution. As such, royalty income reporting for the Waddell Ranch properties is one month in arrears.

As a result of excess costs, there was no royalty income received from Blackbeard for the three months ended March 31, 2026, with the exception of the $1.1 million partial settlement included in the distribution declared in January 2026 that was paid on February 13, 2026. The $1.1 million partial payment is included in “Royalty Income” on the “Condensed Interim Statements of Distributable Income for the three months ended March 31, 2026” (See Note 7).

EXCESS COSTS

If monthly costs exceed revenues for the Waddell Ranch properties or Texas Royalty properties, such excess costs must be recovered, with accrued interest, from future net proceeds and cannot reduce net proceeds from the other conveyance. The Waddell Ranch properties did not contribute to royalty income for the months of October 2024 through February 2026, respectively such that the Waddell Ranch properties remain in a deficit position as of March 31, 2026.

The following table summarizes excess costs activity, cumulative excess costs balance, and accrued interest to be recovered as calculated by Blackbeard.


	Underlying Properties			Net to the Trust
Cumulative excess costs remaining at 12/31/2025	$	63,867,613		$	47,900,709
Net excess costs (recovery) for the quarter ended 3/31/26	$	(5,229,920	)	$	(3,922,440	)
Cumulative excess costs remaining at 3/31/2026	$	58,637,693		$	43,978,269
Accrued interest at 3/31/26	$	4,192,476		$	3,144,357
Total remaining to be recovered at 3/31/26	$	62,830,169		$	47,122,626

FEDERAL INCOME TAXES

For federal income tax purposes, the Trust constitutes a fixed investment trust that is taxed as a grantor trust. A grantor trust is not subject to federal income tax at the trust level. The Unitholders are considered for federal income tax purposes to own the Trust’s income and principal as though no trust were in existence. The income of the Trust is deemed to have been received or accrued by each Unitholder at the time such income is received or accrued by the Trust and not when distributed by the Trust. If the Trust borrows funds to pay liabilities of the Trust, as contemplated in the Trust Indenture, tax-exempt Unitholders could be required to recognize unrelated business taxable income.

STATE TAX CONSIDERATIONS

All revenues from the Trust are from sources within Texas, which does not impose an individual income tax. Texas imposes a franchise tax at a rate of 0.75% on gross revenues less certain deductions, as specifically set forth in the Texas franchise tax statutes. Entities subject to the Texas franchise tax generally include trusts and most other types of entities that provide limited liability protection, unless otherwise exempt. Trusts that receive at least 90% of their federal gross income from certain 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, generally are exempt from the Texas franchise tax as “passive

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entities.” The Trust has been and expects to continue to be exempt from Texas franchise tax as a passive entity. Because the Trust should be exempt from Texas franchise tax at the Trust level as a passive entity, each Unitholder that is a taxable entity under the Texas franchise tax generally will be required to include its portion of Trust revenues in its own Texas franchise tax computation. This revenue is sourced to Texas under provisions of the Texas Administrative Code providing that such income is sourced according to the principal place of business of the Trust, which is Texas.

Unitholders should consult their tax advisors regarding state tax requirements, if any, applicable to such Unitholder’s ownership of Units.

COMMITMENTS AND CONTINGENCIES

Blackbeard Settlement

On August 19, 2025, the Trustee on behalf of the Trust, entered into a settlement agreement and release (the “Settlement Agreement”) in connection with its lawsuit against Blackbeard. Pursuant to the lawsuit, the Trustee had sought to recover more than $9 million in damages it alleged resulted from Blackbeard’s failure to properly calculate and pay royalties due and owing to the Trust.

Pursuant to the Settlement Agreement, Blackbeard has agreed to pay the Trust $9,000,000, of which $4,500,000 was paid in September 2025, $1,125,000 was paid in January 2026, and the remainder of which will be paid in three equal installments of $1,125,000 quarterly during the next three quarters of the 2026 calendar year.

Additionally, the Settlement Agreement established the overhead rate that may be charged to the Trust and permits Blackbeard to pass through third-party charges for saltwater disposal and gathering and transportation, and charge technical labor on reservoir engineers using an agreed allocation methodology against the net overriding royalty. The parties also agreed that the Trust would not make future claims for lost volumes in the case of ordinary line loss (as defined by third party purchase agreements with purchasers). The Trust will have the option to conduct annual site audits, at its expense. The Settlement Agreement also set forth agreed reporting that Blackbeard will provide the Trustee going forward.

Contingencies

Contingencies related to the Underlying Properties that are unfavorably resolved would generally be reflected by the Trust as reductions to future royalty income payments to the Trust with corresponding reductions to cash distributions to Unitholders. The Trustee maintains an expense reserve, which is currently $1,100,000, that allows the Trustee to pay obligations of the Trust in the event there is not sufficient royalty income to pay such expenses.

8. TRUSTEE FEES

Trustee fees for the period ending March 31, 2026, were $18,644. For the period ending March 31, 2025, Trustee fees were $31,365.

9. SUBSEQUENT EVENTS

Subsequent events were evaluated through the issuance date of the condensed interim financial statements. Subsequent to March 31, 2026, the Trust declared a distribution on April 20, 2026 of $0.038014 per Unit outstanding payable on May 14, 2026 to Unitholders of record on April 30, 2026. The April 2026 distribution included $1.125 million, the third partial installment of the settlement with Blackbeard.

On March 30, 2026, Blackbeard informed the Trust that after further reviewing the Trust Conveyance (Sections 1.07, 1.10, and 1.15) for the Waddell Ranch properties, it has initiated a change in the computation of net proceeds. Beginning with the activity month of January 2026, production costs will be reported in the month incurred (activity month) rather than in the month in which revenue is recognized (generally the subsequent month). To bring the quarterly reporting into compliance with this timing change in the calculation of net proceeds, the March reporting period, which will be disclosed in the Trust’s quarterly report on Form 10-Q for the second quarter of 2026, will include production costs for both January and February while reflecting one month (January) of gross proceeds.

On May 8, 2026, a hearing (the “Hearing”) was held before the 96th District Court of Tarrant County, Texas (the “Court”) in connection with the Original Petition for Modification of Trust (the “Petition”) filed by SoftVest, L.P. (“SoftVest”), a Unitholder of the Trust , seeking judicial modification of the Trust Indenture. At the Hearing, the Court approved SoftVest’s requested modifications which (1) amended Section 8.03 of the Trust Indenture to eliminate the requirement that certain amendments require approval by 75% of the outstanding Units of the Trust, and (2) deleted Section 10.01 of the Trust Indenture that sets forth certain prohibited amendments and replaced Article X of the Trust Indenture with a provision permitting amendment of any provision of the Trust Indenture by a vote of Unitholders in accordance with Article VIII (which, as amended, will permit amendment by a majority in interest of Unitholders constituting a quorum at a meeting of Unitholders where a quorum is present). As a result of the Court’s order, the Trustee entered into Amendment No. 2 to the Amended and Restated Trust Indenture of Permian Basin Royalty Trust dated May 8, 2026 implementing the modifications approved by the Court.

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* * * * *

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Item 2. Trustee’s Discussion and Analysis

Forward Looking Information

Certain information included in this report contains, and other materials filed or to be filed by the Trust with the Securities and Exchange Commission (as well as information included in oral statements or other written statements made or to be made by the Trust) may contain or include, forward looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended, and Section 27A of the Securities Act of 1933, as amended. Such forward looking statements may be or may concern, among other things, capital expenditures, drilling activity, development activities, production efforts and volumes, hydrocarbon prices and the results thereof, litigation, information to be received by operators of the Waddell Ranch properties or Texas Royalty properties, and regulatory matters. Although the Trustee believes that the expectations reflected in such forward-looking statements are reasonable, such expectations are subject to numerous risks and uncertainties and the Trustee can give no assurance that they will prove correct. There are many factors, none of which are within the Trustee’s control, that may cause such expectations not to be realized, including, among other things, factors such as actual oil and gas prices and the recoverability of reserves, capital expenditures, general economic conditions, actions and policies of petroleum-producing nations and other changes in the domestic and international energy markets. Such forward looking statements generally are accompanied by words such as “estimate,” “expect,” “predict,” “anticipate,” “goal,” “should,” “assume,” “believe,” or other words that convey the uncertainty of future events or outcomes.

Commodity Prices

The Trust’s income and monthly distributions are heavily influenced by commodity prices. Commodity prices may fluctuate widely in response to (i) relatively minor changes in the supply of and demand for oil and natural gas, (ii) market uncertainty and (iii) a variety of additional factors that are beyond the Trustee’s control. Recently, there has been volatility in oil and natural gas prices due in part to geopolitical conditions in Eastern Europe and the Middle East. During 2025, oil hit a high price of $79.28 per barrel on January 17, 2025 and steadily decreased throughout the year due to production outpacing demand and slower economic growth. In early 2026 oil prices remained well below $70 per barrel. Oil prices began to spike sharply in March and April, reaching a high price of $114.58 on April 7, 2026, due to the war in Iran. As of May 4, 2026 the price of oil was $109.76 per barrel. Factors that may impact future commodity prices, including the price of oil and natural gas, include but are not limited to:

•

political conditions in major oil producing regions, including the conflicts in Eastern Europe, and the Middle East;

•

worldwide economic and geopolitical conditions;

•

weather conditions;

•

trade barriers and tariffs;

•

public health concerns;

•

the supply and price of domestic and foreign crude oil or natural gas;

•

the level of consumer demand;

•

the price and availability of alternative fuels;

•

the proximity to, and capacity of, transportation facilities;

•

the effect of worldwide energy conservation measures and governmental policies and regulatory incentives for investment in non-fossil fuel energy sources; and

•

the nature and extent of governmental regulation and taxation.

Although the Trustee cannot predict the occurrence of events that may affect future commodity prices or the degree to which these prices will be affected, gas royalty income for a given period generally relates to production three months prior to the period and crude oil royalty income for a given period generally relates to production two months prior to the period and will generally approximate current market prices in the geographic region of the production at the time of production. When crude oil and natural gas prices decline, the Trust is affected in two ways. First, distributable income from the Royalty properties is reduced. Second, exploration and development activity by operators on the Royalty properties may decline as some projects may become uneconomic and are either delayed or eliminated. It is impossible to predict future crude oil and natural gas price movements, and this reduces the predictability of future cash distributions to Unitholders.

Liquidity and Capital Resources

As stipulated in the Trust Indenture, the Trust is intended to be passive in nature, and the Trustee does not have any control over or any responsibility relating to the operation of the Underlying Properties. The Trustee has powers to collect and distribute proceeds

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received by the Trust and pay Trust liabilities and expenses and its actions have been limited to those activities. The Trust is a passive entity and other than the Trust’s ability to periodically borrow money as necessary to pay expenses, liabilities and obligations of the Trust that cannot be paid out of cash held by the Trust, the Trust is prohibited from engaging in borrowing transactions. As a result, other than such borrowings, if any, the Trust has no source of liquidity or capital resources other than the Royalties.

Recent Developments

SoftVest Special Meeting and Petition

On December 16, 2025, the Trust held a special meeting of its Unitholders (the “Special Meeting”). The Special Meeting was called by the Trustee as required by Section 8.02 of the Trust Indenture at the request of SoftVest Advisors, LLC (“SoftVest Advisors”) and other Unitholders of the Trust collectively owning not less than 15% of the Trust’s outstanding Units. At the Special Meeting, Unitholders approved a non-binding proposal for SoftVest Advisors or another appropriate party to take appropriate actions as beneficiaries of the Trust to effect the judicial reformation or modification of the Trust Indenture, to allow for the approval of any amendment to the Trust Indenture by a simple majority of votes cast by Unitholders at a special meeting at which a quorum is present.

On or about February 10, 2026, SoftVest, L.P. (“SoftVest”), a Unitholder of the Trust, mailed documents to the other Unitholders, which included a cover letter, a Citation in the District Court of Tarrant County, Texas (“Citation”), the Original Petition for Modification of Trust (the “Petition”) in the District Court of Tarrant County, Texas (Cause No. 96-373245-25) seeking judicial modification of the Trust’s Indenture, and the Petitioner SoftVest, L.P.’s Notice of Bench Trial on Petitioner’s Original Petition for Modification of Trust (“Notice of Bench Trial”), also collectively known as the “Unitholder Mailing”. The Unitholder Mailing advised Unitholders of a hearing to be scheduled Friday, May 8, 2026, at 10:30 a.m. before the 96th District Court of Tarrant County, Texas (the “Court”), Tom Vandergriff Civil Courts Building, 4th Floor, 100 North Calhoun Street, Fort Worth, Texas 76196, on the merits of SoftVest’s Petition pursuant to which it sought to (1) amend Section 8.03 of the Trust Indenture to eliminate the requirement that certain amendments require approval by 75% of the outstanding Units of the Trust, and (2) delete Section 10.01 of the Trust Indenture that sets forth certain prohibited amendments and replace Article X of the Trust Indenture with a provision permitting amendment of any provision of the Trust Indenture by a vote of Unitholders in accordance with Article VIII (which, as amended, would permit amendment by a majority in interest of Unitholders constituting a quorum at a meeting of Unitholders where a quorum is present).

On May 8, 2026, a hearing (the “Hearing”) was held before the Court in connection with the Petition. At the Hearing, the Court approved SoftVest’s requested modifications. As a result of the Court’s order, the Trustee entered into Amendment No. 2 to the Amended and Restated Trust Indenture of Permian Basin Royalty Trust dated May 8, 2026 implementing the modifications approved by the Court.

Blackbeard Settlement

On August 19, 2025, the Trustee entered into the “Settlement Agreement” in connection with its lawsuit against Blackbeard, as operator of the properties in the Waddell Ranch, in Crane County, Texas, in which the Trust holds a 75% net overriding royalty. Pursuant to the lawsuit, the Trustee had sought to recover more than $9 million in damages it alleged resulted from Blackbeard’s failure to properly calculate and pay royalties due and owing to the Trust.

Pursuant to the Settlement Agreement, Blackbeard agreed to pay the Trust $9,000,000, of which $4,500,000 was paid to the Trust on September 18, 2025, $1,125,000 was paid in January 2026, and the remainder of which will be paid in three equal installments of $1,125,000 quarterly during the 2026 calendar year.

Additionally, the Settlement Agreement established the overhead rate that may be charged to the Trust and permits Blackbeard to pass through third-party charges for salt water disposal, gathering and transportation, and charge technical labor on reservoir engineers using an agreed allocation methodology against the net overriding royalty. The parties also agreed that the Trust would not make future claims for lost volumes in the case of ordinary line loss (as defined by third party purchase agreements with purchasers). The Trust will have the option to conduct annual site audits, at its expense. The Settlement Agreement also set forth agreed reporting that Blackbeard will provide the Trustee going forward.

Change in timing of Computation of Net Proceeds

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Results of Operations

Three Months Ended March 31, 2026 Compared to Three Months Ended March 31, 2025

For the quarter ended March 31, 2026, royalty income received by the Trust amounted to $3,551,082 compared to royalty income of $3,054,697 during the first quarter of 2025. The royalty income for the three months ended March 31, 2026 includes the $1,125,000 partial settlement payment from Blackbeard. Pricing information for the Waddell Ranch properties is for December 2025, January and February 2026 (reflecting the period for which proceeds would have been distributed to Unitholders in the first quarter of 2026). For the Waddell Ranch properties, the average realized oil and gas prices were $59.19 per barrel (Bbl) and $0.92 per thousand cubic feet (Mcf), respectively for the three months ended March 31, 2026, compared to $68.83 per barrel (Bbl) and $1.66 per Mcf for the three months ended March 31, 2025. For the Texas Royalty properties, the average realized oil and gas prices were $57.58 per Bbl and $6.70 per Mcf, respectively for the quarter ended March 31, 2026, compared to $68.96 per Bbl and $8.61 per Mcf, respectively for the quarter ended March 31, 2025. The higher royalty income reported in the three months ended March 31, 2026, compared to the same time period in 2025 is attributable to a $1,125,000 partial settlement payment from Blackbeard in the first quarter of 2026.

Interest income for the quarter ended March 31, 2026 was $16,876 compared to $16,523 during the first quarter of 2025. The slight increase in interest income is primarily attributable to a small increase in the amount of funds available for investment. Total expenses during the first quarter of 2026 amounted to $541,157 compared to $475,008 during the first quarter of 2025. The increase in total expenses can be primarily attributed to the timing of payment of expenses.

These transactions resulted in distributable income for the quarter ended March 31, 2026 of $3,026,801 or $0.06 per Unit outstanding of beneficial interest. Distributions of $0.040056, $0.014221, and $0.010662 per Unit were made to Unitholders of record as of January 30, 2026, February 27, 2026, and March 31, 2026, respectively. The January distribution includes the second installment, in the amount of $1,125,000 of the Settlement Agreement. For the first quarter of 2025, distributable income was $2,596,212 or $0.06 per Unit outstanding of beneficial interest.

From and after May 2024, Blackbeard has provided, and will continue to provide, information to calculate net proceeds during the last week of the month. In accordance with the Trust Indenture, if royalty income is received on or just prior to the record date, it will be included in the following month's distribution, rather than the current month's distribution. As such, royalty income reporting for the Waddell Ranch properties is one month in arrears. Royalty income for the Trust for the first quarter of the calendar year is associated with actual oil and gas production for October, November, and December 2025 for the Waddell Ranch properties from which “Royalties” were carved. Royalty income for the Trust for the first quarter of the calendar year for the Texas Royalty properties is associated with actual oil and gas production from November of 2025, December of 2025 and January of 2026.

Beginning in May 2024, Blackbeard has provided production, product sales, capital expenditure, and development information for the Waddell Ranch properties from which the Trust's Royalties are carved for each distribution month on a quarterly basis, as required in the conveyance, approximately 30 days after the end of each fiscal quarter. On April 30, 2026, Blackbeard provided the Trustee with a quarterly statement showing the production volumes and computation of net proceeds to the Trust for each month of the quarter ended March 31, 2026. Oil and gas sales attributable to the Royalties and the properties from which the Royalties were carved are as follows:



	Waddell Ranch Properties
	2025 - 2026								2024 - 2025
	December		January		February		Total		December		January		February		Total
Royalties
Oil sales (Bbls)		338,471		393,189		419,195		1,150,855		200,636		193,737		233,428		627,801
Gas sales (Mcf)		1,493,371		1,807,337		1,865,916		5,166,624		1,220,898		1,031,786		1,153,901		3,406,586
Properties From Which the Royalties Were Carved:
Oil:
Total oil sales (Bbls)		451,294		524,252		558,926		1,534,472		267,515		258,316		311,237		837,068
Average per day (Bbls)		14,558		16,911		19,962		17,050		8,630		8,333		11,116		9,301
Average realized price per Bbl	$	59.36	$	58.55	$	59.64		59.19	$	71.04	$	67.81	$	67.64	$	68.83
Gas:
Total gas sales (Mcf)		1,991,161		2,409,783		2,487,888		6,888,832		1,627,864		1,375,715		1,538,535		4,542,114
Average per day (Mcf)		64,231		77,735		88,853		76,543		52,512		44,378		54,948		50,468
Average realized price per Mcf	$	0.29	$	1.07	$	1.28	$	0.92	$	1.89	$	0.77	$	2.31	$	1.66

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	Texas Royalty Properties
	2026								2025
	January		February		March		Total		January		February		March		Total
Royalties
Oil sales (Bbls)		15,285		13,325		13,047		41,657		14,914		13,469		14,957		43,340
Gas sales (Mcf)		7,401		8,573		8,518		24,492		8,213		8,774		9,462		26,449
Properties From Which the Royalties Were Carved:
Oil:
Total oil sales (Bbls)		17,309		15,292		15,009		47,610		16,839		15,307		16,839		48,985
Average per day (Bbls)		558		546		484		529		543		547		543		544
Average realized price per Bbl	$	59.18	$	56.78	$	56.56		57.58	$	67.69	$	68.37	$	70.81		68.96
Gas:
Total gas sales (Mcf)		8,378		9,841		9,793		28,012		9,283		9,971		10,659		29,913
Average per day (Mcf)		270		351		316		311		299		356		344		332
Average realized price per Mcf	$	8.49	$	5.85	$	6.02	$	6.70	$	9.56	$	8.38	$	7.88	$	8.61

Pricing and Production Discussion

For the Waddell Ranch properties, the average realized price of oil decreased to $59.19 per Bbl for the period December 2025 through February 2026 compared to $68.83 per Bbl for the period December 2024 through February 2025 due to worldwide market variables. The average realized price of gas decreased to $0.92 per Mcf for the period December 2025 through February 2026 from $1.66 per Mcf for the period December 2024 through February 2025.

For the Texas Royalty properties, the average realized price of oil decreased to $57.58 per Bbl in the first quarter of 2026, compared to $68.96 per Bbl in the first quarter of 2025 due to worldwide market variables. The average realized price of gas (including natural gas liquids) for the Texas Royalty properties decreased from $8.61 per Mcf in the first quarter of 2025 to $6.70 per Mcf in the first quarter of 2026 in part due to change in overall market variables.

Since the oil and gas sales attributable to the Royalties are based on an allocation formula that is dependent on such factors as price and cost (including capital expenditures), the production amounts in the Royalties section of the above table do not always provide a meaningful comparison. However, for the Texas Royalty properties, oil and gas volumes decreased from the Underlying Properties for the applicable period in 2026 compared to 2025, while for the Waddell Ranch properties, oil volumes and natural gas volumes (including plant products) increased for the applicable period in 2026 compared to 2025.

Blackbeard Capital Expense Discussion

Blackbeard advised the Trustee that capital expenditures for drilling, remedial and maintenance activities on the Waddell Ranch properties during the first quarter of 2026 totaled $48.8 million (gross) as compared to $47.9 million (gross) for the first quarter of 2025. Blackbeard does not provide capital expenditures budget information or development information for the Waddell Ranch properties such as well completions, workovers, remedial activities, and plugging and abandonment.

Blackbeard advised the Trustee that lease operating expenses and property taxes totaled $30.7 million (gross) for the first quarter of 2026, compared to $21.4 million (gross) for the same period in 2025 on the Waddell Ranch properties.

Calculation of Royalty Income

The Trust’s royalty income is computed as a percentage of the net profit from the operation of the properties in which the Trust owns net overriding royalty interests. The royalty income received and recorded by the Trust was determined by the operator as noted below. These percentages of net profits are 75% and 95% in the case of the Waddell Ranch properties and the Texas Royalty properties, respectively. Royalty income received and available for distribution by the Trust for the three months ended March 31, 2026 and 2025, respectively, was computed as shown in the table below:

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	Three Months Ended March 31,
	2026						2025
	WADDELL RANCH PROPERTIES (1)			TEXAS ROYALTY PROPERTIES			WADDELL RANCH PROPERTIES			TEXAS ROYALTY PROPERTIES
Gross proceeds of sales from the Underlying Properties
Oil proceeds	$	90,819,305		$	2,741,568		$	57,571,976		$	3,378,836
Gas proceeds		6,340,865			187,634			7,687,489			256,333
Other (adjustment)(1)		(1,037,442	)		—			14,483,131			—
Total		96,122,728			2,929,202			79,742,596			3,635,169
Less:
Severance tax:
Oil		4,179,667			106,597			2,945,725			129,325
Gas		33,794			6,884			76,852			11,688
Gathering and Transportation Costs		12,739,395			39,950			7,368,268			38,685
Lease operating expense and property tax:
Oil and gas		30,680,638			222,000			21,417,188			240,000
Capital expenditures		48,489,234			—			47,934,563			—
Total		96,122,728			375,431			79,742,596			419,698
Net profits(2)		—			2,553,771			—			3,215,471
Net overriding royalty interests		75	%		95	%		75	%		95	%
Royalty income(2)(3)	$	—			2,426,082		$	—			3,054,697

(1) Due to an NPI deficit, the Waddell Ranch properties did not contribute to royalty income from November 2024 through March 2026.

(2) The 2025 Net profits and Royalty income for the Waddell Ranch properties have been adjusted to reflect the amount received rather than reflecting Excess Costs for the quarter. Excess Costs can be reviewed in Note 4 of the Condensed Interim Financial Statements.

(3) Royalty income for the Waddell Ranch properties does not include the $1.1 million partial settlement payment received in January of 2026.

Critical Accounting Policies and Estimates

A disclosure of critical accounting policies and the more significant judgments and estimates used in the preparation of the Trust’s financial statements is included in Item 7 of the Trust’s Annual Report on Form 10-K for the year ended December 31, 2025. There have been no significant changes to the critical accounting policies during the three months ended March 31, 2026.

Distributable Income Per Unit

New Accounting Pronouncements

There are no new accounting pronouncements that are expected to have significant impact on the Trust’s financial statements.

Item 3. Qualitative and Quantitative Disclosures About Market Risk

The Trust is a passive entity and other than the Trust’s ability to periodically borrow money as necessary to pay expenses, liabilities and obligations of the Trust that cannot be paid out of cash held by the Trust, the Trust is prohibited from engaging in borrowing transactions. The amount of any such borrowings is unlikely to be material to the Trust. The Trust periodically holds short-term investments acquired with funds held by the Trust pending distribution to Unitholders and funds held in reserve for the payment of Trust expenses and liabilities. Because of the short-term nature of these borrowings and investments and certain limitations upon the types of such investments which may be held by the Trust, the Trustee believes that the Trust is not subject to any material interest rate risk. The Trust does not engage in transactions in foreign currencies which could expose the Trust or Unitholders to any foreign currency related market risk. The Trust invests in no derivative financial instruments and has no foreign operations or long- term debt instruments.

Item 4. Controls and Procedures

On May 14, 2013, the Committee of Sponsoring Organizations of the Treadway Commission issued an updated version of its Internal Control – Integrated Framework (the “2013 Framework”) which helps organizations design, implement and evaluate the effectiveness of internal control concepts and simplify their use and application. As of the end of the period covered by this report, the Trustee carried out an evaluation of the effectiveness of the design and operation of the Trust’s disclosure controls and procedures pursuant to Exchange Act Rules 13a-15 and 15d-15 based on the criteria established in the 2013 Framework. Based upon that evaluation,

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the Trustee concluded that the Trust’s disclosure controls and procedures are effective in recording, processing, summarizing and reporting, on a timely basis, information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 and are effective in ensuring that information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 is accumulated and communicated to the Trustee to allow timely decisions regarding required disclosure. In its evaluation of disclosure controls and procedures, the Trustee has relied, to the extent considered reasonable, on information provided by Blackbeard, the owner of the Waddell Ranch properties, and Riverhill Energy Corporation, the owner of the Texas Royalty properties.

There has not been any change in the Trust’s internal control over financial reporting during the period covered by this report that has materially affected, or is reasonably likely to materially affect, the Trust’s internal control over financial reporting.

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PART II - OTHER INFORMATION

Item 1. Legal Proceedings

SoftVest Petition

On May 8, 2026, a hearing (the “Hearing”) was held before the 96th District Court of Tarrant County, Texas (the “Court”) in connection with the Original Petition for Modification of Trust (the “Petition”) filed by SoftVest, L.P. (“SoftVest”), a Unitholder of the Trust, seeking judicial modification of the Trust Indenture. At the Hearing, the Court approved SoftVest's requested modifications which (1) amended Section 8.03 of the Trust Indenture to eliminate the requirement that certain amendments require approval by 75% of the outstanding Units of the Trust, and (2) deleted Section 10.01 of the Trust Indenture that sets forth certain prohibited amendments and replaced Article X of the Trust Indenture with a provision permitting amendment of any provision of the Trust Indenture by a vote of Unitholders in accordance with Article VIII (which, as amended, will permit amendment by a majority in interest of Unitholders constituting a quorum at a meeting of Unitholders where a quorum is present). As a result of the Court’s order, the Trustee entered into Amendment No. 2 to the Amended and Restated Trust Indenture of Permian Basin Royalty Trust dated May 8, 2026 implementing the modifications approved by the Court.

Blackbeard Settlement

On August 19, 2025, the Trustee entered into a settlement agreement and release (the “Settlement Agreement”) in connection with its lawsuit against Blackbeard, as operator of the properties in the Waddell Ranch, in Crane County, Texas, in which the Trust holds a 75% net overriding royalty. Pursuant to the lawsuit, the Trustee had sought to recover more than $9 million in damages it alleged resulted from Blackbeard’s failure to properly calculate and pay royalties due and owing to the Trust.

Additionally, the Settlement Agreement established the overhead rate that may be charged to the Trust and permits Blackbeard to pass through third-party charges for salt water disposal, gathering and transportation, and charge technical labor on reservoir engineers using an agreed allocation methodology against the net overriding royalty. The parties also agreed that the Trust would not make future claims for lost volumes in the case of ordinary line loss (as defined by third party purchase agreements with purchasers). The Trust will have the option to conduct annual site audits, at its expense. The Settlement Agreement also set forth agreed reporting that Blackbeard will provide the Trustee going forward.

There are no material pending legal proceedings to which the Trust is a party or of which any of its property is the subject.

Item 1A. Risk Factors

Risk factors relating to the Trust are contained in Item 1A of the Trust's Annual Report on Form 10-K for the fiscal year ended December 31, 2025. Except as set forth in such filing, no material change to such risk factors has occurred during the three months ended March 31, 2026.

Items 2 through 4

Not applicable.

Item 5. Other Information

The Trust does not have any directors or officers, and as a result, no such persons adopted or terminated any Rule 10b5-1 trading arrangement or any non-Rule 10b5-1 trading arrangement, as defined in Item 408(a) of Regulation S-K.

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Item 6. Exhibits


4.1	Permian Basin Amended and Restated Royalty Trust Indenture dated June 20, 2014, between Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) and The First National Bank of Fort Worth (now Argent Trust Company), as Trustee, heretofore filed as Exhibit 4.1 to the Trust’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarterly period ended June 30, 2014, is incorporated herein by reference. *

4.2	Amendment No. 1 to the Amended and Restated Royalty Trust Indenture of Permian Basin Royalty Trust, dated May 4, 2022, heretofore filed as Exhibit 4.1 to the Trust’s Form 8-K to the Securities and Exchange Commission filed on May 6, 2022, is incorporated herein by reference. *

4.3	Net Overriding Royalty Conveyance (Permian Basin Royalty Trust) from Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Argent Trust Company), as Trustee, dated November 3, 1980 (without Schedules), heretofore filed as Exhibit (4)(b) to the Trust’s Annual Report on Form 10-K to the Securities and Exchange Commission for the fiscal year ended December 31, 1980, is incorporated herein by reference. * (P)

4.4	Net Overriding Royalty Conveyance (Permian Basin Royalty Trust) from Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Argent Trust Company), as Trustee, dated November 3, 1980 (without Schedules), heretofore filed as Exhibit (4)(b) to the Trust’s Annual Report on Form 10-K to the Securities and Exchange Commission for the fiscal year ended December 31, 1980, is incorporated herein by reference. * (P)

4.5	Amendment No. 2 to the Amended and Restated Royalty Trust Indenture of Permian Basin Royalty Trust, dated May 8, 2026, heretofore filed as Exhibit 4.1 to the Trust’s Form 8-K to the Securities and Exchange Commission filed on May 8, 2026, is incorporated herein by reference.*

31.1	Certification by Nancy Willis, Director of Royalty Trust Services of Argent Trust Company, Trustee of Permian Basin Royalty Trust, dated May 14, 2026, and submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1	Certificate by Argent Trust Company, Trustee of Permian Basin Royalty Trust, dated May 14, 2026, and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350).

99.1	Item 1A and 7 to the Annual Report on Form 10-K for Permian Basin Royalty Trust filed with the Securities and Exchange Commission on March 27, 2026 (incorporated herein by reference).

* A copy of this Exhibit is available to any Unitholder, at the actual cost of reproduction, upon written request to the Trustee, Argent Trust Company, 3838 Oak Lawn Avenue, Suite 1720, Dallas, Texas 75219.

(P)

Paper exhibits.

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SIGNATURES

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


	ARGENT TRUST COMPANY, TRUSTEE FOR THE PERMIAN BASIN ROYALTY TRUST

Date: May 14, 2026	By:	/s/ NANCY WILLIS
		Nancy Willis
		Director of Royalty Trust Services

(The Trust has no directors or executive officers.)

PERMIAN BASIN ROYALTY TRUST 10-Q