[10-Q] PermRock Royalty Trust Quarterly Earnings Report

Rhea-AI Filing Summary

PermRock Royalty Trust reported lower quarterly cash flow as oil volumes and prices declined. For Q3 2025, net profits income was $1,246,690 and distributable income was $1,111,576, or $0.091367 per unit, compared with $1,340,784 and $0.110208 per unit a year ago. Nine-month distributable income was $3,778,289 ($0.310563 per unit) versus $3,813,324 last year.

Oil sales volumes were 59,142 Bbl in Q3 2025 vs 70,584 Bbl in Q3 2024, with average realized oil price at $63.58/Bbl vs $78.07/Bbl. Natural gas volumes were 89,599 Mcf vs 90,213 Mcf, at $1.88/Mcf vs $2.07/Mcf. Lower operating and development costs partially offset revenue declines. Cash reserves remained at $1,000,000.

T2S, which assumed operations on March 31, 2025, revised the 2025 capital and workover plan from $4.0 million to $1.0 million (about $0.2 million spent as of September 30) and deferred two planned wells. On October 21, 2025, the Trust declared a $0.031565 per-unit distribution based on August 2025 production. Trust units outstanding were 12,165,732 as of November 13, 2025.

Insights

Energy royalty trust analyst

Q3 cash flow dipped on lower oil volumes and prices; costs eased.

PRT derives cash from an 80% net profits interest. Q3 2025 net profits income was $1.25M with distributable income of $1.11M ($0.091367 per unit). Oil volumes fell to 59,142 Bbl and realized oil price dropped to $63.58/Bbl, pressuring revenue. Lower lease operating and development expenses cushioned the decline.

T2S cut the 2025 capital plan from $4.0M to $1.0M, deferring two Crane County wells while completing one non-operated well. This prioritizes near-term distributions but may temper production support until spending resumes. Cash reserves held by the Trust remained $1,000,000.

The Trust declared a $0.031565 October distribution based on August production. Actual outcomes hinge on commodity pricing, T2S cost discipline, and execution of workovers; subsequent filings may detail any plan updates.

Table of Contents

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 September 30, 2025

OR

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

For the transition period to

Commission File Number: 001-38472

PERMROCK ROYALTY TRUST

(Exact name of registrant as specified in its charter)

Delaware	82-6725102
( State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
Argent Trust Company Trustee 3838 Oak Lawn Ave, Suite 1720 Dallas, Texas 75219-4518
(Address of principal executive offices) (Zip Code)

Registrant’s telephone number, including area code: (855) 588-7839

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

Title of each class		Trading Symbol(s)		Name of each exchange on which registered
Units of Beneficial Interest		PRT		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  ☒

As of November 13, 2025, 12,165,732 trust units representing beneficial interests in PermRock Royalty Trust were outstanding.

Table of Contents

TABLE OF CONTENTS

Glossary of Terms	1
PART I. FINANCIAL INFORMATION
ITEM 1. Financial Statements	2
CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS	3
CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)	4
CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)	5
NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)	6
ITEM 2. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations	10
ITEM 3. Quantitative and Qualitative Disclosures about Market Risk	16
ITEM 4. Controls and Procedures	16
PART II. OTHER INFORMATION
ITEM 1. Legal Proceedings	17
ITEM 1A. Risk Factors	17
ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds	17
ITEM 3. Defaults Upon Senior Securities	17
ITEM 4. Mine Safety Disclosures	17
ITEM 5. Other Information	17
ITEM 6. Exhibits.	17
SIGNATURE	18

Table of Contents

Glossary of Terms

Bbl	Barrel (of oil).
Boe	One barrel of crude oil equivalent.
differential	The difference between a benchmark price of oil and natural gas, such as the NYMEX crude oil spot, and the wellhead price received.
distributable income	An amount paid to Trust unitholders equal to the net profits income received by the Trust during a given period plus interest, less the expenses and payment of liabilities of the Trust, adjusted by any changes in cash reserves.
GAAP	United States generally accepted accounting principles.
MBbl	One thousand barrels of crude oil or condensate.
MBoe	One thousand barrels of crude oil equivalent.
Mcf	One thousand cubic feet (of natural gas).
MMcf	One million cubic feet (of natural gas).
natural gas liquids (NGL)	Those hydrocarbons that are separated from the gas as liquids through the process of absorption, condensation, or other methods in gas processing or cycling plants.
net acres	The sum of the fractional working interests owned by a given operator in gross acres.
net profits	Gross profits received by T2S from the sale of production from the Underlying Properties, less applicable costs, as provided in the Conveyance.
net profits income	Net profits multiplied by the net profits percentage of 80%, which is paid to the Trust by T2S. “Net profits income” is referred to as “royalty income” for tax reporting purposes.
Net Profits Interest	An interest in an oil and natural gas property measured by net profits from the sale of production, rather than a specific portion of production. An 80% net profits interest was conveyed to the Trust entitling the Trust to receive 80% of the net profits from the Underlying Properties.
NYMEX	The New York Mercantile Exchange is a commodity futures exchange that quotes prices for transactions which are the prices paid for various commodities, including oil and natural gas, throughout the world.
Trust units	Trust units representing beneficial interests in the Trust.
Underlying Properties	The interest in certain oil and natural gas properties from which the Net Profits Interest was conveyed by Boaz Energy. The Underlying Properties include working interests in oil and natural gas producing properties located in the Permian Basin in Texas.
working interest	An operating interest in an oil and natural gas property that provides the owner a specified share of production that is subject to all production expense and development costs.

1

Table of Contents

PART I. FINANCIAL INFORMATION

ITEM 1. Financial Statements

The condensed financial statements included herein are presented without audit, pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (the “SEC”). Certain information and footnote disclosures normally included in annual financial statements have been condensed or omitted pursuant to such rules and regulations, and Argent Trust Company, as Trustee (the “Trustee”), believes that the disclosures are adequate to make the information presented not misleading. These condensed interim financial statements and notes thereto should be read in conjunction with the audited financial statements and notes thereto included in the Trust’s 2024 Annual Report on Form 10-K (“2024 Annual Report”). In the opinion of the Trustee, all adjustments, consisting only of normal recurring adjustments, necessary for a fair statement of the assets, liabilities and Trust corpus of PermRock Royalty Trust at September 30, 2025 and December 31, 2024, and the distributable income and changes in Trust corpus for the three and nine months ended September 30, 2025 and 2024, have been included. Distributable income for such interim periods is not necessarily indicative of distributable income for the full year.

2

Table of Contents

PERMROCK ROYALTY TRUST

CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS

		September 30, 2025 (unaudited)				December 31, 2024
ASSETS
Cash and short-term investments		$	1,378,835			$	1,612,261
Net Profits Interest (1)			69,293,250				72,379,939
TOTAL ASSETS		$	70,672,085			$	73,992,200
LIABILITIES AND TRUST CORPUS
Distribution payable to unitholders		$	378,835			$	612,261
Cash reserves (2)			1,000,000				1,000,000
Trust corpus			69,293,250				72,379,939
TOTAL LIABILITIES AND TRUST CORPUS		$	70,672,085			$	73,992,200

(1)See Note 2 to condensed financial statements for further discussion of the Net Profits Interest.

(2)The Trustee is authorized to retain cash from distributions received by the Trust in an amount not to exceed $1.0 million to be used in the event that cash on hand is not sufficient to pay ordinary course administrative expenses and to provide for future liabilities of the Trust.

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

3

Table of Contents

PERMROCK ROYALTY TRUST

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)

		Three Months Ended September 30,								Nine Months Ended September 30,
		2025				2024				2025				2024
Net profits income		$	1,246,690			$	1,548,855			$	4,502,918			$	4,503,683
Interest income			12,105				15,485				36,782				45,056
Total revenue			1,258,795				1,564,340				4,539,700				4,548,739
Expenditures – general and administrative			(147,219	)			(223,556	)			(761,411	)			(735,415	)
Cash reserves (1)			—				—				—				—
Distributable income		$	1,111,576			$	1,340,784			$	3,778,289			$	3,813,324
Distributable income per unit (2)		$	0.091367			$	0.110208			$	0.310563			$	0.313443

(1)The Trustee is authorized to retain cash from distributions received by the Trust in an amount not to exceed $1.0 million to be used in the event that cash on hand is not sufficient to pay ordinary course administrative expenses and to provide for future liabilities of the Trust.

(2)Based on 12,165,732 Trust units issued and outstanding as of November 13, 2025.

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

4

Table of Contents

PERMROCK ROYALTY TRUST

CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)

			Three Months Ended September 30,								Nine Months Ended September 30,
			2025				2024				2025				2024
Trust corpus, beginning of period			$	70,219,686			$	74,117,597			$	72,379,939			$	75,876,170
Amortization of Net Profits Interest				(926,436	)			(943,931	)			(3,086,689	)			(2,702,504	)
Distributable income			$	1,111,576			$	1,340,784			$	3,778,289			$	3,813,324
Distributions declared				(1,111,576	)			(1,340,784	)			(3,778,289	)			(3,813,324	)
Trust corpus, end of period			$	69,293,250			$	73,173,666			$	69,293,250			$	73,173,666

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

5

Table of Contents

PERMROCK ROYALTY TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS
(Unaudited)

1.Organization of Trust

PermRock Royalty Trust (the “Trust”) is a Delaware statutory trust formed on November 22, 2017 under the Delaware Statutory Trust Act pursuant to a trust agreement dated November 22, 2017, as amended and restated on May 4, 2018, by and among Boaz Energy II, LLC (“Boaz Energy”), as trustor, Simmons Bank, as trustee, and Wilmington Trust, National Association, as Delaware Trustee (the “Delaware Trustee”) (such amended and restated trust agreement, as amended to date, the “Trust Agreement”).

In accordance with the successor trustee provisions of the Trust Agreement, Argent Trust Company, as successor trustee of the Trust, is subject to all terms and conditions of the Trust Agreement. The defined term “Trustee” as used herein shall refer to Simmons Bank (which maintains its offices at 2200 West 7th Street, Suite 210, P.O. Box 470727, Fort Worth, Texas 76147) for periods prior to December 30, 2022, and shall refer to Argent Trust Company (which maintains its offices at 3838 Oak Lawn Ave., Suite 1720, Dallas, Texas 75219) for periods on and after December 30, 2022.

The Trust was created to acquire and hold the Net Profits Interest for the benefit of the Trust unitholders. In connection with the closing of the initial public offering of Trust units, on May 4, 2018, Boaz Energy conveyed the Net Profits Interest to the Trust in exchange for Trust units pursuant to a conveyance agreement between Boaz Energy, the Trustee and the Delaware Trustee (the “Conveyance”). The Net Profits Interest represents an interest in the Underlying Properties.

On January 13, 2025, the Trust announced that Boaz Energy, the owner and operator of the oil and gas properties underlying the Trust (the “Underlying Properties”), informed the Trust that Boaz Energy and its affiliate, Boaz Energy II Royalty, LLC (“Boaz Royalty” and, together with Boaz Energy, the “Grantors”), entered into a Purchase and Sale Agreement on January 10, 2025 (the “Purchase and Sale Agreement”) with T2S Permian Acquisition II LLC, a Delaware limited liability company (“T2S”), with respect to the Underlying Properties. The Underlying Properties are subject to the Net Profits Interests conveyed to the Trust pursuant to the Conveyance. The transaction between the Grantors and T2S closed on March 31, 2025. Boaz Energy also sold and conveyed to Ustx LLC, a Delaware limited liability company and a wholly-owned subsidiary of T2S, Boaz Energy’s 4,884,861 Trust units representing beneficial interests in the Trust. At closing, T2S assumed operations of the Underlying Properties. T2S assumed all obligations and privileges of Boaz Energy under each of the Conveyance and the Trust Agreement. The Trustee continues to administer the Trust in the ordinary course of business

The Net Profits Interest entitles the Trust to receive 80% of the net profits from the sale of oil and natural gas production from the Underlying Properties. The Net Profits Interest is passive in nature and neither the Trust nor the Trustee has any control over, or responsibility for, costs relating to the operation of the Underlying Properties. The Trust has and will continue to make monthly cash distributions of all of its monthly cash receipts, after deduction of fees and expenses for the administration of the Trust and any cash reserves, to holders of its Trust units as of the applicable record date on or before the 10th business day after the record date. Distributions generally relate to sales from a one-month period.

The Trustee may deposit funds awaiting distribution in an account with an FDIC-insured or national bank, including the Trustee, if the interest paid to the Trust at least equals amounts paid by the Trustee on similar deposits, and make other short-term investments with the funds distributed to the Trust.

In May 2018, Boaz Energy completed an initial public offering of 6,250,000 of the 12,165,732 total Trust units outstanding, retaining ownership of 5,915,732 Trust units. Pursuant to the Purchase and Sale Agreement, Boaz Energy conveyed all of its remaining 4,884,861 Trust units to Ustx, LLC, a wholly owned subsidiary of T2S, on March 31, 2025. As of November 13, 2025, Ustx, LLC owned 4,884,861 Trust units.

2.Trust Significant Accounting Policies

a.Basis of Accounting

The Trust uses the modified cash basis of accounting to report Trust receipts of the Net Profits Interest and payments of expenses incurred. The Net Profits Interest represents the right to receive revenues (primarily oil and natural gas sales), less direct operating expenses, overhead expenses, lease operating expenses, severance and ad valorem taxes and development expenses of the Underlying Properties, multiplied by 80%. Cash distributions of the Trust are made based on the amount of cash received by the Trust pursuant to terms of the Conveyance creating the Net Profits Interest.

6

Table of Contents

The financial statements of the Trust, as prepared on a modified cash basis, reflect the Trust’s assets, liabilities, Trust corpus, earnings and distributions as follows:

•Income from the Net Profits Interest is recorded when distributions are received by the Trust;

•Distributions to Trust unitholders are recorded when declared by the Trust;

•Trust general and administrative expenses (which includes the Trustee’s fees as well as accounting, printing, engineering, legal, tax advisory and other professional fees) are recorded when paid; cash reserves for Trust expenses may be established by the Trustee for certain expenditures that would not be recorded as contingent liabilities under United States generally accepted accounting principles (“GAAP”);

•Amortization of the investment in the Net Profits Interest is calculated on a unit-of-production basis and is charged directly to Trust corpus, and such amortization does not affect distributions from the Trust; and

•The Trust’s investment in the Net Profits Interest is periodically assessed to determine whether its aggregate value has been impaired below its total capitalized cost basis. In general, neither the Trustee nor T2S view temporarily low prices as an indication of impairment. The markets for crude oil and natural gas have a history of significant price volatility and though prices will occasionally drop significantly, industry prices over the long term will continue to be driven by market supply and demand. If events and circumstances indicate the carrying value may not be recoverable, the Trustee would use the estimated undiscounted future net cash flows from the Net Profits Interest to evaluate the recoverability of the Trust assets. If the undiscounted future net cash flows from the Net Profits Interest are less than the Net Profits Interest carrying value, the Trust would recognize an impairment loss for the difference between the Net Profits Interest carrying value and the estimated fair value of the Net Profits Interest. The determination as to whether the Net Profits Interest is impaired is based on the best information available to the Trustee at the time of the evaluation, including information provided by T2S such as estimates of future production and development and operating expenses. Any impairment would be charged directly to the Trust corpus.

The financial statements of the Trust are prepared on a modified cash basis of accounting, which is considered to be the most meaningful basis of preparation for a royalty trust because monthly distributions to the Trust unitholders are based on net cash receipts. Although this basis of accounting is permitted for royalty trusts by the SEC, the financial statements of the Trust differ from financial statements prepared in accordance with GAAP because net profits income is not accrued in the month of production, expenses are not recognized when incurred, cash reserves may be established for certain contingencies, and overpayments received do not need to be paid back and are instead taken from future payments that would not be recorded in GAAP financial statements. This comprehensive basis of accounting other than GAAP corresponds to the accounting permitted for royalty trusts by the SEC as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts.

b.Interim Financial Statements.

The accompanying unaudited financial statements have been prepared by the Trust in accordance with the accounting policies stated in the audited financial statements and notes of the Trust thereto included in the Trust’s 2024 Annual Report and reflect all adjustments that are, in the opinion of the Trustee, necessary to state fairly the information in the Trust’s unaudited interim financial statements.

c.Use of Estimates.

The preparation of financial statements requires the Trust to make estimates and assumptions that affect the reported amounts of assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Estimated future cash flows used to determine amortization and potential impairment of the investment in the Net Profits Interest are subject to change.

d.Risks and Uncertainties.

The Trust’s revenue and distributions are substantially dependent upon the prevailing and future prices for oil and natural gas, each of which depends on numerous factors beyond the Trust’s control such as economic conditions, the global political environment, regulatory developments and competition from other energy sources. Oil and natural gas prices historically have been volatile and may be subject to significant fluctuations in the future.

e.Contingencies.

Contingencies related to the Underlying Properties that are unfavorably resolved would generally be expected to result in reductions to cash receipts to the Trust in respect of the Net Profits Interest with corresponding reductions to cash distributions to Trust unitholders. Please see the discussion of litigation in Note 8 to condensed financial statements.

7

Table of Contents

3.Income Taxes

Tax counsel advised the Trust at the time of formation that for U.S. federal income tax purposes, the Trust is treated as a grantor trust and will not be subject to federal income tax at the trust level. Trust unitholders will be treated for such purposes as owning a direct interest in the assets of the Trust, and each Trust unitholder is taxed directly on its pro rata share of the income and any gain, if sold, attributable to the assets of the Trust and is entitled to claim its pro rata share of deductions and expenses attributable to the assets of the Trust. Each Trust unitholder should consult his or her own tax advisor regarding income tax requirements, if any, applicable to such unitholder’s ownership of Trust units.

4.Cash Reserves

Pursuant to the Trust Agreement, as of May 31, 2019, the Trustee began retaining cash from the distributions the Trust receives to be used by the Trust in the event that its cash on hand (including available cash reserves) is not sufficient to pay ordinary course administrative expenses as they become due. The Trustee is authorized to retain cash reserves (i) in an amount not to exceed $1,000,000 at any one time and (ii) in such amounts as the Trustee in its discretion deems appropriate to pay for future liabilities of the Trust, but not less than $25,000 per month or more than $100,000 per month. Cash reserves held by the Trustee for administrative expenses totaled $1,000,000 as of September 30, 2025.

T2S is entitled under the Conveyance to reserve up to $3.0 million from the net profits for certain future taxes and development or operating expenses. As of December 31, 2024, the balance of funds held by Boaz Energy to cover certain future capital expenses was $526,174 net to the Trust. As of September 30, 2025, the balance of funds held by T2S to cover future capital expenses was $224,933 net to the Trust.

5.Distributions to Unitholders

The Trust makes monthly cash distributions of the net amount, if any, of its monthly cash receipts, after deduction of fees and expenses for the administration of the Trust and cash reserves to holders of its Trust units as of the applicable record date on or before the 10th business day after the record date.

Based on 12,165,732 Trust units outstanding at each date listed below, the per unit distributions during the quarter ended September 30, 2025, were as follows:

Record Date		Payment Date		Distribution per Unit
July 31, 2025		August 14, 2025		$	0.032491
August 29, 2025		September 15, 2025			0.027737
September 30, 2025		October 15, 2025			0.031139
				$	0.091367

6.Related Party Transactions

Trustee Administrative Fee. Under the terms of the Trust Agreement, the Trust pays an annual administrative fee to the Trustee and the Delaware Trustee. The Delaware Trustee’s annual fee is $4,000. For 2025, the Trustee’s annual administrative fee is $205,031, which is divided into twelve equal monthly payments throughout the year. The Trustee’s annual administrative fee increased at a rate of 3% per year for the first three years of the Trust’s existence, and increased at a rate of 2% in 2023 and 2024. The Trustee’s annual administrative fee increased at a rate of 1% in 2025, and will continue to increase at a rate of 1% per year until the 20th anniversary of the Trust’s formation and then will remain flat thereafter. These costs of the Trust, which are included in administration expenses, are deducted by the Trust before distributions are made to Trust unitholders.

Agreements with T2S as successor-in-interest to Boaz Energy. On May 4, 2018, the Trust entered into a registration rights agreement for the benefit of Boaz Energy and certain of its affiliates and transferees, pursuant to which the Trust agreed to register the offering of the Trust units held by Boaz Energy and certain of its affiliates and permitted transferees upon request by Boaz Energy. The Trust filed a Registration Statement on Form S-3 on April 28, 2022 (the “Registration Statement”) seeking the registration of 5,801,675 Trust units held by Boaz Energy. The SEC confirmed the effectiveness of the Registration Statement on May 9, 2022. On March 31, 2025, Ustx LLC, a Delaware limited liability company and a wholly-owned subsidiary of T2S, acquired from Boaz Energy 4,884,861 Trust units representing beneficial interests in the Trust. As of November 13, 2025, Ustx, LLC, owned 4,884,861 Trust units of the 12,165,732 Trust units issued and outstanding.

7.Development Costs

T2S and its predecessor, Boaz Energy, initially established a $4.0 million capital and workover budget for 2025 for the Underlying Properties (the "Plan"), of which approximately $0.2 million had been spent as of September 30, 2025. In response to the current

8

Table of Contents

market environment and economic pressures affecting the oil and gas sector, including continued commodity price volatility, increased service and labor costs, and tightening capital markets, T2S revised the Plan downward to approximately $1.0 million. This reduction was made to preserve liquidity, maintain financial flexibility, and align spending levels with prevailing industry and macroeconomic conditions.

T2S has advised the Trustee the decrease in planned expenditures primarily relates to the deferral of two wells originally scheduled for drilling in Crane County, Texas—one injector well and one producer well—which have been postponed to a future date to be determined based on improved market visibility and commodity price stability. The revised Plan includes T2S’s participation in a non-operated well in the Permian Shelf Area, which was successfully drilled and completed during the third quarter of 2025, as well as ongoing investment in workovers, waterflood pattern optimization, and the reactivation of certain shut-in wells to sustain production levels.

T2S has advised the Trustee that it believes this revision provides an appropriate balance between near-term cash preservation and the continued development of the Underlying Properties. T2S has advised the Trustee that the revised Plan reflects T2S’s ongoing evaluation of project economics, commodity price forecasts, and regulatory timing, and may be further adjusted based on changes in market conditions, operating performance, and capital requirements.

8.Settlements and Litigation

On October 1, 2018, a lawsuit styled Thaleia L. Marston, Trustee of the Marston Trust v. Blackbeard Operating, LLC, et.al, No. 18-10-24761 – CVW in the 143rd District Court in Ward County, Texas (the “2018 Litigation”) was filed, naming, among others, Boaz Energy and the Trust as defendants. The plaintiff is a lessor under two leases operated by Blackbeard Operating LLC. The Underlying Properties include the interests of Boaz Energy in some of the minerals covered by those leases. The litigation sought surface use damages and alleged violations of the terms of the leases, among other things. The court had set a two-day bench trial to commence May 18, 2022, but on May 10, 2022, the court granted motions for summary judgment effectively disposing of the plaintiff’s claims. At a status conference conducted on May 12, 2022, the plaintiff confirmed the court’s rulings disposed of all the plaintiff’s claims. The court held a hearing regarding attorneys’ fees in June 2022. On May 12, 2023, the court entered its final judgment, incorporating its prior order granting the defendants’ motion for summary judgment and granting defendants’ motion for attorneys’ fees, but the plaintiff then filed a notice of appeal to the Eighth Court of Appeals in El Paso County, Texas. By order dated February 5, 2025, the Court of Appeals affirmed the trial court's judgment in favor of the defendant appellees and therefore, this case concluded.

9.Subsequent Events

On October 21, 2025, the Trust declared a cash distribution of $0.031565 per Trust unit based upon production during the month of August 2025.

Production Month		Underlying Sales Volumes								Average Price
		Oil (Bbls)				Gas (Mcf)				Oil (per Bbl)				Gas (per Mcf)
August			22,490				25,914			$	58.06			$	2.31

9

Table of Contents

ITEM 2. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations

Introduction

The following discussion and analysis is intended to help the reader understand the Trust’s financial condition, results of operations, liquidity and capital resources. This discussion and analysis should be read in conjunction with the Trust’s unaudited condensed financial statements and the accompanying notes included in this Quarterly Report on Form 10-Q (“Quarterly Report”) and the Trust’s audited financial statements and the accompanying notes included in the Trust’s 2024 Annual Report.

Cautionary Statement Regarding Forward Looking Statements

Certain information included in this Quarterly Report contains, and other materials filed or to be filed by the Trust with the SEC (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 Exchange Act and Section 27A of the Securities Act of 1933, as amended (the “Securities Act”). Such forward-looking statements generally are accompanied by words such as “may,” “will,” “estimate,” “expect,” “predict,” “project,” “anticipate,” “goal,” “should,” “assume,” “believe,” “plan,” “intend,” or other words that convey the uncertainty of future events or outcomes. All statements other than statements of historical fact included in this Quarterly Report are forward-looking statements, including without limitation statements under this “Trustee’s Discussion and Analysis of Financial Conditions and Results of Operations” and all statements regarding T2S and Argent Trust Company’s (as Trustee of the Trust) expectations, beliefs and plans regarding the following: (i) T2S’s capital projects, timing and estimated costs, and the resulting impact of those activities on the computation of the Net Profits Interest; (ii) outside operators’ capital projects and the resulting impact of those activities on the Net Profits Interest; (iii) implementation or continued use of waterflood projects and workovers and the location of waterflood projects and workovers; (iv) T2S’s estimated capital expenditures; (v) the timing of capital expenditures and capital reserve amounts; (vi) the expected timing of litigation proceedings; (vii) the impact of current litigation matters on the Trust; (viii) T2S’s staffing levels or future reductions in staffing on the Underlying Properties; and (ix) distributions to Trust unitholders. Such statements are based on certain assumptions of the Trustee, and certain assumptions of information provided to the Trust by T2S, the owner of the Underlying Properties; are based on an assessment of, and are subject to, a variety of factors deemed relevant by the Trustee and T2S; and involve risks and uncertainties. Certain factors could affect the future results of the energy industry in general, and T2S and the Trust in particular, and could cause actual results to differ materially from those projected in such forward-looking statements. Those factors include, without limitation, the following:

•the effect of changes in commodity prices or alternative fuel prices;

•the effects of armed conflict throughout the world on global oil and gas producing regions, countries, thoroughfares and the oil and gas markets;

•political and economic conditions in or affecting other oil and natural gas producing regions or countries;

•uncertainties in estimating production and oil and natural gas reserves of the Underlying Properties;

•risks associated with the drilling and operation of oil and natural gas wells;

•the cost of developing the Underlying Properties;

•the ability to maintain anticipated production levels;

•the amount of future direct operating expenses, development expenses and other capital expenditures;

•availability and terms of capital to fund capital expenditures;

•risks associated with T2S and its ability to transfer operation of the Underlying Properties to third parties without the approval of Trust unitholders;

•the performance of such third parties contracted by T2S and their ability or willingness to provide sufficient facilities and services to T2S on commercially reasonable terms;

•the effect of existing and future laws and regulatory actions;

•the actions of the Organizations of Petroleum Exporting Countries (“OPEC”);

•conditions in the capital markets;

•competition from others in the energy industry;

•uncertainty in whether development projects will be pursued;

•severe or unseasonable weather that may adversely affect production;

10

Table of Contents

•adequacy of T2S’s insurance coverage;

•costs to comply with current and future governmental regulation of the oil and natural gas industry, including environmental, health and safety laws and regulations, and regulations with respect to hydraulic fracturing and the disposal of produced water;

•the effect of existing and future laws and regulatory actions, including real estate, bankruptcy and tax legislation and the ability to accurately interpret the impact of such laws;

•general economic conditions affecting the Permian Basin;

•risks associated with title deficiencies that may arise with respect to the Underlying Properties and T2S’s ability to cure any such defects;

•actions by T2S, including such that result in conflicts of interest, that adversely affect the Trust;

•the ability to successfully estimate the impact of litigation matters, and certain accounting and tax matters;

•the cost of inflation; and

•the risk factors discussed in Part I, Item 1A of the Trust’s 2024 Annual Report.

You should not place undue reliance on any forward-looking statements. All forward-looking statements speak as of the date of this Quarterly Report. The Trust does not undertake any obligation to release publicly any revisions to the forward-looking statements to reflect events or circumstances after the date of this Quarterly Report or to reflect the occurrence of unanticipated events, unless required by applicable law.

T2S Information

As a holder of a net profits interest, the Trust relies on T2S for information regarding T2S and its affiliates; the Underlying Properties, including the operations, acreage, well and completion count, working interests, production volumes, sales revenues, capital expenditures, operating expenses, reserves, drilling plans, drilling results and leasehold terms related to the Underlying Properties; and factors and circumstances that have or may affect the foregoing.

Overview

PermRock Royalty Trust, a Delaware statutory trust formed in November 2017 by Boaz Energy, completed its initial public offering in May 2018. The Trust’s main asset and source of income is the Net Profits Interest, which entitles the Trust to receive 80% of the net profits from oil and natural gas production from the Underlying Properties. The Net Profits Interest is passive in nature and neither the Trust nor the Trustee has any management control over or responsibility for costs relating to the operation of the Underlying Properties.

The Trust is required to make monthly cash distributions of substantially all of its monthly cash receipts, after deduction of fees and expenses for the administration of the Trust and any cash reserves, to holders of its Trust units as of the applicable record date on or before the 10th business day after the record date. The Net Profits Interest is entitled to a share of the profits from and after January 1, 2018 attributable to production occurring on or after such date. The Trust is not subject to any pre-set termination provisions based on a maximum volume of oil or natural gas to be produced or the passage of time. The amount of Trust revenues and cash distributions to Trust unitholders depends on, among other things:

•volumes produced;

•wellhead prices;

•price differentials;

•production and development costs;

•potential reductions or suspensions of production; and

•the amount and timing of Trust administrative expenses.

T2S, as the operator of the Underlying Properties, typically receives payment for oil production 30 to 60 days after it is produced and for natural gas production 60 to 90 days after it is produced.

Properties. The Underlying Properties consist of four operating areas in the Permian Basin in Texas, aggregating 31,354 gross (22,394 net) acres. The Permian Clearfork area consists of 2,434 net acres on the Central Basin Platform of the Permian Basin in Hockley and

11

Table of Contents

Terry Counties, Texas. The Permian Abo area consists of 1,667 net acres on the Central Basin Platform of the Permian Basin in Terry and Cochran Counties, Texas. The Permian Shelf area consists of 14,390 net acres on the Eastern Shelf of the Permian Basin in Glasscock, Schleicher, Stonewall and Coke Counties, Texas. The Permian Platform area consists of 3,903 net acres on the Central Basin Platform of the Permian Basin in Ward, Crane, Terry and Ector Counties, Texas.

Outlook

T2S and its predecessor, Boaz Energy, initially established a $4.0 million capital and workover budget for 2025 for the Underlying Properties (the "Plan"), of which approximately $0.2 million had been expended as of September 30, 2025. In response to the current market environment and economic pressures affecting the oil and gas sector, including continued commodity price volatility, increased service and labor costs, and tightening capital markets, T2S revised the Plan downward to approximately $1.0 million. This reduction was made to preserve liquidity, maintain financial flexibility, and align spending levels with prevailing industry and macroeconomic conditions.

T2S has advised the Trustee the decrease in planned expenditures primarily relates to the deferral of two wells originally scheduled for drilling in Crane County, Texas—one injector well and one producer well—which have been postponed to a future date to be determined based on improved market visibility and commodity price stability. The revised Plan includes T2S’s participation in a non-operated well in the Permian Shelf Area, which was successfully drilled and completed during the third quarter of 2025, as well as ongoing investment in workovers, waterflood pattern optimization, and the reactivation of certain shut-in wells to sustain production levels.

T2S has advised the Trustee that it believes this revision provides an appropriate balance between near-term cash preservation and the continued development of the Underlying Properties. T2S has advised the Trustee that the revised Plan reflects T2S’s ongoing evaluation of project economics, commodity price forecasts, and regulatory timing, and may be further adjusted based on changes in market conditions, operating performance, and capital requirements.

RESULTS OF OPERATIONS

Distributable Income

Three Months Ended September 30, 2025

For the three months ended September 30, 2025, net profits income received by the Trust was $1,246,690 compared to $1,548,855 for the same period of the prior year. This decrease in net profits income was primarily due to decreased oil and gas production and lower oil and gas prices, partially offset by lower production costs. See “Computation of Income from the Net Profits Interest Received by the Trust” below.

After considering interest income of $12,105 and general and administrative expenditures of $147,219, distributable income for the three months ended September 30, 2025, was $1,111,576, or $0.091367 per Trust unit.

Interest income was lower for the quarter ended September 30, 2025, as compared to the prior year, due primarily to lower interest rates. General and administrative expenditures decreased by $76,337 for the three months ended September 30, 2025, as compared to the prior year, primarily due to the timing of payments for expenses.

Pursuant to the Trust Agreement, as of May 31, 2019, the Trustee is authorized to retain cash reserves for administrative expenses. The Trustee did not retain any cash reserves during the three months ended September 30, 2025, or September 30, 2024. Total cash reserves were $1,000,000 as of September 30, 2025, and September 30, 2024.

Based on 12,165,732 Trust units outstanding at each date listed below, the per unit distributions during the quarter ended September 30, 2025, were as follows:

Record Date		Payment Date		Distribution per Unit
July 31, 2025		August 14, 2025		$	0.032491
August 29, 2025		September 15, 2025			0.027737
September 30, 2025		October 15, 2025			0.031139
				$	0.091367

12

Table of Contents

Nine Months Ended September 30, 2025

For the nine months ended September 30, 2025, net profits income received by the Trust was $4,502,918, essentially unchanged from the $4,503,683 received for the same period of the prior year. T2S has advised the Trustee that the stable Trust distribution level reflects the benefit of cost containment and the modest recovery in natural gas pricing, offsetting lower crude oil revenues. See “Computation of Income from the Net Profits Interest Received by the Trust” below.

After considering interest income of $36,782 and general and administrative expenditures of $761,411, distributable income for the nine months ended September 30, 2025, was $3,778,289, or $0.310563 per Trust unit. For the nine months ended September 30, 2024, total distributable income was $3,813,324, or $0.313443 per Trust unit.

Interest income decreased for the nine months ended September 30, 2025, as compared to the prior year, due to lower interest rates. General and administrative expenditures increased by $25,996 for the nine months ended September 30, 2025, as compared to the prior year, primarily due to timing of payments and an increase in professional expenses.

Pursuant the terms of the Trust Agreement, the Trustee was authorized to begin retaining cash reserves for administrative expenses in May of 2019. The Trustee did not retain any cash reserves during the nine months ended September 30, 2025, or September 30, 2024. Total cash reserves were $1,000,000 as of September 30, 2025, and September 30, 2024.

Computation of Income from the Net Profits Interest Received by the Trust

The Net Profits Interest entitles the Trust to receive 80% of the net profits attributable to T2S's interest from the sale of oil and natural gas production from the Underlying Properties. The Trust’s income from the Net Profits Interest consists of monthly net profits attributable to income from the Underlying Properties. Because of the interval between the time of production and receipt of net profits income by the Trust, the Trust recognizes production during the month in which the related net profits income is paid to the Trust. Net profits income for the three months ended September 30, 2025, was based on production during the months of May 2025 through July 2025. Net profits income for the nine months ended September 30, 2025, was based on production during the months of November 2024 through July 2025. The table below outlines the computation of income from the Net Profits Interest received by the Trust for the three and nine months ended September 30, 2025 and 2024.

		Three Months Ended September 30, 2025				Three Months Ended September 30, 2024				Nine Months Ended September 30, 2025				Nine Months Ended September 30, 2024
Underlying Properties sales volumes(1):
Oil (Bbl)			59,142				70,584				193,587				217,572
Natural gas (Mcf)(2)			89,599				90,213				254,392				255,462
Total sales (Boe)			74,075				85,620				235,986				260,149
Average realized sales price:
Oil (per Bbl)		$	63.58			$	78.07			$	66.59			$	76.63
Natural gas (per Mcf)		$	1.88			$	2.07			$	2.74			$	2.71
Calculation of net profits:
Gross profits:
Oil sales		$	3,760,286			$	5,510,827			$	12,891,209			$	16,672,061
Natural gas sales			168,048				186,659				697,769				692,626
Other revenue			—				42,409				57,207				116,954
Total gross profits		$	3,928,334			$	5,739,895			$	13,646,185			$	17,481,641
Costs:
Direct operating expenses:		$	227,809			$	519,461			$	914,406			$	1,465,890
Lease operating expenses			1,122,041				1,660,728				4,387,001				5,131,318
Severance and ad valorem taxes			389,475				433,070				1,123,201				1,148,229
Development expenses			266,552				1,058,132				478,910				2,576,684
Other expenses			480,648				473,935				1,490,571				1,308,977
Total costs		$	(2,486,525	)		$	(4,145,326	)		$	(8,394,089	)		$	(11,631,098	)
Net profits		$	1,441,809			$	1,594,569			$	5,252,096			$	5,850,543
Percentage allocable to Net Profits Interest			80	%			80	%			80	%			80	%
Net profits income (before capital reserve)		$	1,153,448			$	1,275,655			$	4,201,677			$	4,680,435
Capital reserve activity (3)			93,242				273,200				301,241				(176,752	)
Net profits income received by the Trust		$	1,246,690			$	1,548,855			$	4,502,918			$	4,503,683

13

Table of Contents

(1)Quarterly sales volumes are typically reported for a three-month period, and therefore sales volumes for the three months ended September 30, 2025, reflect production volumes for May 2025 through July 2025. Sales volumes for the nine months ended September 30, 2025, reflect production volumes for November 2024 through July 2025.

(2)Sales volumes for natural gas include NGLs.

(3)The operator of the Underlying Properties is entitled under the Conveyance to reserve up to $3.0 million from the net profits for certain future taxes and expenses. As of September 30, 2025, T2S, as successor to Boaz Energy, held $224,933 net to the Trust of funds previously reserved for future capital expenses.

Important factors used in calculating the Trust’s net profits income include the volumes of oil and natural gas produced from the Underlying Properties and the realized prices received for the sale of those minerals, including oil and natural gas liquids, as well as direct operating expenses, lease operating expenses, severance and ad valorem taxes, development and other expenses and capital reserves.

Sales Volumes

Oil

Oil sales volumes decreased by 11,442 Bbls (16.2%) for the three months ended September 30, 2025, as compared to the same period in 2024, and 23,985 Bbls (11.0%) for the nine months ended September 30, 2025, as compared to the same period in 2024. T2S reports these decreases were primarily due to a natural decline in the producing properties, as well as lower production volumes due to reduced operations and a reduction in the number of workover projects amid the sales and transition process between Boaz Energy and T2S that continued throughout the third quarter of 2025, as well as the continued commodity price volatility, increased service and labor costs, and tightening capital markets

Natural Gas

Natural gas sales volumes decreased slightly by 614 Mcf for the three months ended September 30, 2025, as compared to the same period in 2024, and 1,070 Mcf for the nine months ended September 30, 2025, as compared to the same period in 2024. T2S reports these decreases in natural gas sales volumes were primarily related to natural decline, as well as to unfavorable market conditions that delayed the timing for bringing wells back online until at least late 2025 or 2026.

Sales Prices

Oil

The average realized oil price per Bbl decreased for the three and nine months ended September 30, 2025, as compared to the same periods in 2024. T2S reports this decrease was primarily due to a decrease in the WTI benchmark oil price.

Natural Gas

The average realized natural gas price per Mcf decreased for the three months ended September 30, 2025, as compared to the same period in 2024. T2S reports this decrease was primarily due to the lower sales price of the natural gas liquids in the natural gas, which is tied to lower oil prices as compared to oil prices in 2024. The average realized natural gas price per Mcf increased for the nine months ended September 30, 2025. T2S reports this increase was primarily due to an increase in the Henry Hub benchmark price for natural gas.

Costs

Direct Operating Expenses

Direct operating expenses decreased for the three and nine months ended September 30, 2025, as compared to the same periods in 2024. T2S reports these decreases are primarily due to lower workover activity, reduced third-party service costs, and the deferral of certain non-essential maintenance projects.

Lease Operating Expenses

Lease operating expenses decreased for the three and nine months ended September 30, 2025, as compared to the same periods in 2024, T2S reports these decreases are; primarily due to T2S implementing cost-reduction initiatives aimed at minimizing lease operating expenses in response to weaker oil prices and lower production levels.

14

Table of Contents

Severance and Ad Valorem Taxes

Severance and ad valorem taxes decreased for the three and nine months ended September 30, 2025, as compared to the same periods in 2024, primarily because of lower revenues and decreased valuations of properties resulting from decreased industry prices.

Development Expenses Related to the Underlying Properties

T2S reports that development expenses related to the Underlying Properties decreased for the three and nine months ended September 30, 2025, as compared to the same periods in 2024. This is because in 2025, T2S has participated in drilling only one non-operated well, which was completed during the third quarter 2025, as compared to stimulating and upgrading several wells in the Permian Platform in the prior year.

Other Expenses

Other expenses increased for the three and nine months ended September 30, 2025, as compared to the same periods in 2024, primarily due to adjustments to overhead, as reported by T2S.

Capital Reserve

As of September 30, 2025, T2S held $224,933 net to the Trust of funds previously reserved to cover future capital expenses.

LIQUIDITY AND CAPITAL RESOURCES

The Trust’s principal sources of liquidity and capital are cash flow generated from the Net Profits Interest, the amounts held by the Trustee as cash reserves to pay future liabilities, and borrowings, if any to fund administrative expenses. The Trust’s primary uses of cash are distributions to Trust unitholders, payment of Trust administrative expenses, including, if applicable, any reserves established by the Trustee for future liabilities.

Administrative expenses include the Trustee and Delaware Trustee fees, accounting, engineering, legal, tax advisory and other professional fees, and tax reporting and distribution expenses. The Trust is also responsible for paying other expenses incurred as a result of being a publicly traded entity, including costs associated with annual, quarterly and current reports to the SEC, New York Stock Exchange listing fees, independent auditor fees and registrar and transfer agent fees. If the Trustee determines that cash on hand and cash to be received in respect of the Net Profits Interest are, or will be, insufficient to cover the Trust’s liabilities and expenses, the Trustee may cause the Trust to borrow funds to pay liabilities of the Trust.

As authorized under the Trust Agreement, the Trustee is authorized to retain cash from the distributions the Trust receives (i) in an amount not to exceed $1.0 million at any one time to be used by the Trust in the event that its cash on hand (including available cash reserves) is not sufficient to pay ordinary course administrative expenses as they become due and (ii) in such amounts as the Trustee in its discretion deems appropriate to pay for future liabilities of the Trust, but not less than $25,000 or more than $100,000 per month. Cash reserves previously retained and currently held by the Trustee for future administrative expenses total $1,000,000 as of November 13, 2025.

T2S's Capital Expenditure Budget

T2S and its predecessor, Boaz Energy, initially established a $4.0 million capital and workover budget for 2025 for the Underlying Properties (the "Plan"), of which approximately $0.2 million had been expended as of September 30, 2025. In response to the current market environment and economic pressures affecting the oil and gas sector, including continued commodity price volatility, increased service and labor costs, and tightening capital markets, T2S revised the Plan downward to approximately $1.0 million. This reduction was made to preserve liquidity, maintain financial flexibility, and align spending levels with prevailing industry and macroeconomic conditions.

T2S has advised the Trustee the decrease in planned expenditures primarily relates to the deferral of two wells originally scheduled for drilling in Crane County, Texas—one injector well and one producer well—which have been postponed to a future date to be determined based on improved market visibility and commodity price stability. The revised Plan includes T2S’s participation in a non-operated well in the Permian Shelf Area, which was successfully drilled and completed during the third quarter of 2025, as well as ongoing investment in workovers, waterflood pattern optimization, and the reactivation of certain shut-in wells to sustain production levels.

T2S has advised the Trustee that it believes this revision provides an appropriate balance between near-term cash preservation and the continued development of the Underlying Properties. T2S has advised the Trustee that the revised Plan reflects T2S's ongoing

15

Table of Contents

evaluation of project economics, commodity price forecasts, and regulatory timing, and may be further adjusted based on changes in market conditions, operating performance, and capital requirements.

Distributions Declared After Quarter End

On October 21, 2025, the Trust declared a cash distribution of $0.031565 per Trust unit based upon production during the month of August 2025.

Production Month		Underlying Sales Volumes								Average Price
		Oil (Bbls)				Gas (Mcf)				Oil (per Bbl)				Gas (per Mcf)
August			22,490				25,914			$	58.06			$	2.31

Off-Balance Sheet Arrangements

As of September 30, 2025, the Trust had no off-balance sheet arrangements.

New Accounting Pronouncements

As the Trust’s financial statements are prepared on the modified cash basis, most accounting pronouncements are not applicable to the Trust’s financial statements. No new accounting pronouncements have been adopted or issued that would impact the financial statements of the Trust.

Critical Accounting Policies and Estimates

Refer to Note 2 to the unaudited condensed financial statements contained in this Quarterly Report and the Trust’s 2024 Annual Report on Form 10-K, including the audited financial statements of the Trust and notes thereto included therein, for a description of the Trust’s accounting policies and use of estimates.

ITEM 3. Quantitative and Qualitative Disclosures about Market Risk

The Trust is a smaller reporting company as defined by Rule 12b-2 of the Exchange Act and is not required to provide the information required under this Item.

ITEM 4. Controls and Procedures

The Trustee conducted an evaluation of the effectiveness of the Trust’s disclosure controls and procedures pursuant to Exchange Act Rules 13a-15(a) and 15d-15(a) as of the end of the period covered by this Quarterly Report. Based on this evaluation, the Trustee has concluded that the disclosure controls and procedures of the Trust are effective as of September 30, 2025, that the information required to be disclosed by the Trust in its reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC, and such information is accumulated and communicated, as appropriate 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 T2S.

Due to the nature of the Trust as a passive entity and in light of the contractual arrangements pursuant to which the Trust was created, including the provisions of the Trust Agreement and the Conveyance, the Trustee’s disclosure controls and procedures related to the Trust necessarily rely on (A) information provided by T2S, including information relating to results of operations, the costs and revenues attributable to the Trust’s interests under the Conveyance and other operating and historical data, plans for future operating and capital expenditures, reserve information, information relating to projected production, and other information relating to the status and results of operations of the Underlying Properties, and (B) conclusions and reports regarding reserves by the Trust’s independent reserve engineers.

During the quarter ended September 30, 2025, there were no changes in the Trust’s internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the Trustee’s internal control over financial reporting. The Trustee notes for purposes of clarification that it has no authority over, has not evaluated and makes no statement concerning, the internal control over financial reporting of T2S.

16

Table of Contents

PART II. OTHER INFORMATION

ITEM 1. Legal Proceedings

On October 1, 2018, a lawsuit styled Thaleia L. Marston, Trustee of the Marston Trust v. Blackbeard Operating, LLC, et.al, No. 18-10-24761 – CVW in the 143rd District Court in Ward County, Texas (the “2018 Litigation”) was filed, naming, among others, Boaz Energy and the Trust as defendants. The plaintiff is a lessor under two leases operated by Blackbeard Operating LLC. The Underlying Properties include the interests of Boaz Energy in some of the minerals covered by those leases. The litigation sought surface use damages and alleged violations of the terms of the leases, among other things. The court had set a two-day bench trial to commence May 18, 2022, but on May 10, 2022, the court granted motions for summary judgment effectively disposing of the plaintiff’s claims. At a status conference conducted on May 12, 2022, the plaintiff confirmed the court’s rulings disposed of all the plaintiff’s claims. The court held a hearing regarding attorneys’ fees in June 2022. On May 12, 2023, the court entered its final judgment, incorporating its prior order granting the defendants’ motion for summary judgment and granting defendants’ motion for attorneys’ fees, but the plaintiff then filed a notice of appeal to the Eighth Court of Appeals in El Paso County, Texas. By order dated February 5, 2025, the Court of Appeals affirmed the trial court's judgment in favor of the defendant appellees and therefore, this case concluded.

Item 1A. Risk Factors

There have been no material changes in the risk factors disclosed under Part I, Item 1A of the Trust’s Annual Report on Form 10-K for the year ended December 31, 2024.

ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds

Not applicable.

ITEM 3. Defaults Upon Senior Securities

Not applicable.

ITEM 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

The Trust does not have any directors or officers, and as a result, no such person adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K, during the most recent fiscal quarter. Because the Trust does not have officers, directors, or employees, it has not adopted insider trading policies and procedures governing the purchase, sale, or other disposition of Trust securities by such persons.

ITEM 6. Exhibits.

Exhibit No.	Description
3.1	Certificate of Trust of PermRock Royalty Trust (incorporated by reference to Exhibit 3.3 to Registration Statement on Form S-1 (SEC File No. 333-224191) filed on April 6, 2018).
3.2	Amended and Restated Trust Agreement of PermRock Royalty Trust, dated May 4, 2018, among Boaz Energy II, LLC, Wilmington Trust, National Association, as Delaware Trustee of PermRock Royalty Trust, and Argent Trust Company, as Trustee of PermRock Royalty Trust (incorporated by reference to Exhibit 3.1 to Current Report on Form 8-K (SEC File No. 001-38472) filed on May 8, 2018).
3.3	Amendment No. 1 to the Amended and Restated Trust Agreement of PermRock Royalty Trust, dated May 4, 2022 (incorporated by reference to Exhibit 4.1 to Current Report on form 8-K (SEC File No 001-38472) filed on May 6, 2022).
31.1	Section 302 Certification.*
32.1	Section 906 Certification.*

The exhibits marked with the asterisk symbol (*) are filed or furnished with this Quarterly Report on Form 10-Q.

17

Table of Contents

SIGNATURE

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.

PERMROCK ROYALTY TRUST
By:		Argent Trust Company, as Trustee
By:		/s/ Nancy Willis
		Nancy Willis
		Director of Royalty Trust Services

Date: November 13, 2025

The registrant, PermRock Royalty Trust, has no principal executive officer, principal financial officer, board of directors or persons performing similar functions. Accordingly, no additional signatures are available, and none have been provided. In signing the report above, the Trustee does not imply that it has performed any such function or that any such function exists pursuant to the terms of the Trust Agreement under which it serves.

18

FAQ

What was PermRock Royalty Trust (PRT) Q3 2025 distributable income and per-unit amount?

Distributable income was $1,111,576, or $0.091367 per unit.

How did PRT’s Q3 2025 oil volumes and realized prices compare to last year?

Oil volumes were 59,142 Bbl vs 70,584 Bbl and realized oil price was $63.58/Bbl vs $78.07/Bbl.

What is PRT’s year-to-date 2025 distributable income?

For the nine months ended September 30, 2025, distributable income was $3,778,289 ($0.310563 per unit).

Did PRT change its 2025 capital plan for the Underlying Properties?

Yes. T2S revised the plan from $4.0 million to approximately $1.0 million, deferring two wells.

What cash reserves does PRT hold for administrative expenses?

The Trust held $1,000,000 in cash reserves as of September 30, 2025.

What distribution did PRT declare after quarter end?

On October 21, 2025, it declared $0.031565 per unit based on August 2025 production.

How many PRT units were outstanding?

There were 12,165,732 Trust units outstanding as of November 13, 2025.