PermRock Royalty Trust (PRT) sees lower 2026 payouts as net profits income falls

Rhea-AI Filing Summary

PermRock Royalty Trust reported lower distributable income for the quarter and six months ended June 30, 2026, as weaker production and gas pricing outweighed higher oil prices. For the quarter, net profits income was $697,904 versus $1,545,465 a year earlier, leading to distributable income of $409,050, or $0.033622 per unit. For the first half of 2026, net profits income was $1,345,337 compared with $3,256,228 in the prior-year period, and distributable income was $813,117, or $0.066834 per unit.

Oil and gas sales volumes from the Underlying Properties fell, while the average realized oil price rose and the average realized natural gas price declined. As of June 30, 2026, the Trust held $1.0 million in administrative cash reserves and $150,000 was reserved by T2S for future capital obligations, with the Net Profits Interest carried at $26.05 million. A subsequent distribution of $274,696.04, or $0.022579 per unit, was declared based on May 2026 production.

Positive

• None.

Negative

• Net profits income decreased to $697,904 for Q2 2026 and $1,345,337 for the first half of 2026, down from $1,545,465 and $3,256,228 in the prior-year periods, significantly reducing cash available for distributions.
• Distributable income per unit fell to $0.033622 for Q2 2026 and $0.066834 for the first half, compared with $0.098679 and $0.219196 a year earlier, indicating materially lower unitholder cash returns.

Filing Explained

As of August 14, 2026, a T2S affiliate held trust units while the Trust remained dependent on operator-reported net profits.

The August 14, 2026 Form 10-Q is an unaudited interim report for the period ended June 30, 2026; it leaves PermRock Royalty Trust dependent on T2S-operated properties for receipts, with distributions made after expenses and reserves.

The Trust holds a passive 80% Net Profits Interest in the properties, while neither the Trust nor its Trustee controls operating costs.

This means operating performance, prices, and T2S’s cost and reserve decisions affect cash available for unitholder distributions.

T2S reported an estimated $0.7 million 2026 workover budget covering 22 shut-in wells and one plugging-and-abandonment operation; approximately $0.4 million had been spent by June 30, 2026, and the budget remains subject to change.

The statements use a modified cash basis rather than GAAP: income is recorded when received, distributions when declared, and certain reserves and expenses are handled differently from GAAP reporting.

The next quarterly disclosure is the specific checkpoint for the remaining 2026 workover program and any resulting effect on the Net Profits Interest; the filing does not commit the full budget to be spent.

Key Figures

Net profits income Q2 2026: $697,904 Net profits income Q2 2025: $1,545,465 Distributable income per unit Q2 2026: $0.033622 +5 more

8 metrics

Net profits income Q2 2026 $697,904 Three months ended June 30, 2026

Net profits income Q2 2025 $1,545,465 Three months ended June 30, 2025

Distributable income per unit Q2 2026 $0.033622 Three months ended June 30, 2026

Distributable income per unit H1 2026 $0.066834 Six months ended June 30, 2026

Oil sales volume Q2 2026 46,379 Bbl Underlying Properties sales volumes, three months ended June 30, 2026

Average realized oil price Q2 2026 $81.09 per Bbl Three months ended June 30, 2026

Cash reserves held by Trustee $1,000,000 Administrative cash reserves as of June 30, 2026

Net Profits Interest carrying value $26,050,564 Net Profits Interest asset as of June 30, 2026

Key Terms

Net Profits Interest, modified cash basis of accounting, severance and ad valorem taxes, workover, +2 more

6 terms

Net Profits Interest financial

"The Net Profits Interest entitles the Trust to receive 80% of the net profits"

A net profits interest (NPI) is a contractual right to receive a fixed percentage of a project’s or asset’s profits after allowable costs are paid, rather than a share of gross revenue or ownership. For investors, it matters because it gives upside tied to actual profitability while shielding the holder from direct operating expenses and capital calls, similar to getting a portion of the leftover profits from a business after the bills are settled.

modified cash basis of accounting financial

"The Trust uses the modified cash basis of accounting to report Trust receipts"

severance and ad valorem taxes financial

"Severance and ad valorem taxes decreased for the three and six months ended"

Severance and ad valorem taxes are two types of government charges that companies pay: severance taxes are levied when natural resources (like oil, gas, coal, or minerals) are removed from the ground, like a fee for taking something valuable out of the earth; ad valorem taxes are charged based on the assessed value of an asset, similar to a property tax that rises with the asset’s worth. For investors they matter because these taxes reduce project revenue and cash flow, change operating costs and asset valuations, and can alter the expected return on resource or real-estate investments.

workover technical

"This budget includes workovers on twenty-two (22) wells that are shut-in"

A workover is a targeted maintenance or repair operation on an oil or gas well to restore, improve, or change its production—like giving a car a tune-up or replacing parts so it runs better. Investors care because workovers can increase or prolong revenue by boosting output or recovering trapped reserves, but they also involve upfront costs and temporary downtime that affect short-term cash flow and the long-term value of the asset.

Waha Hub technical

"a negative pricing differential at the Waha Hub in the Permian Basin"

Waha Hub is a regional oil and gas collection, processing and export facility that gathers production from surrounding fields, stores or conditions the hydrocarbons as needed, and sends them on to pipelines or shipping points. Investors care because changes in the hub’s operating status or throughput can quickly alter production volumes, company revenues and local supply — like a busy harbor where goods must flow smoothly for sellers to get paid and markets to stay stable.

Level 3 measurements financial

"fair value estimates utilized in the impairment assessment are generally Level 3"

Earnings Snapshot

Net profits income Q2 2026: $697,904

Three and six months ended June 30, 2026

Net profits income Q2 2026 $697,904 Decreased versus $1,545,465 in Q2 2025

Distributable income per unit Q2 2026 $0.033622 Decreased versus $0.098679 in Q2 2025

Net profits income H1 2026 $1,345,337 Decreased versus $3,256,228 in H1 2025

Distributable income per unit H1 2026 $0.066834 Decreased versus $0.219196 in H1 2025

FAQ

How did PermRock Royalty Trust (PRT) perform in Q2 2026 versus Q2 2025?

Distributable income in Q2 2026 was $409,050, or $0.033622 per unit, compared with $1,200,518, or $0.098679 per unit in Q2 2025, mainly due to lower oil and gas sales volumes and weaker gas prices.

What were PermRock Royalty Trust (PRT)’s results for the first half of 2026?

For the six months ended June 30, 2026, PermRock generated net profits income of $1,345,337 and distributable income of $813,117, or $0.066834 per unit, versus $3,256,228 and $2,666,713, or $0.219196 per unit, in the prior-year period.

How did production volumes and prices change for PRT’s underlying properties?

For Q2 2026, oil sales volumes were 46,379 Bbl versus 64,816 Bbl a year earlier, and natural gas volumes were 46,482 Mcf versus 85,631 Mcf. The average realized oil price rose to $81.09/Bbl, while gas fell to $1.89/Mcf.

What cash reserves does PermRock Royalty Trust (PRT) hold as of June 30, 2026?

As of June 30, 2026, the Trustee held $1,000,000 in cash reserves for administrative expenses. T2S also held $150,000 net to the Trust as a capital reserve for future ad valorem taxes and workovers.

What distribution did PRT declare after quarter-end based on May 2026 production?

On July 21, 2026, the Trust declared a cash distribution of $274,696.04, or $0.022579 per unit, to holders of record on July 31, 2026, payable August 14, 2026, based on May 2026 production volumes and prices.

What is the status and value of PRT’s Net Profits Interest at June 30, 2026?

At June 30, 2026, the Net Profits Interest was carried at $26,050,564. It entitles the Trust to receive 80% of net profits from oil and natural gas production from the Underlying Properties in the Permian Basin.

How much has T2S budgeted for 2026 workovers on PRT’s underlying properties?

T2S set an estimated 2026 workover budget of approximately $0.7 million for the Underlying Properties, including workovers on 22 shut-in wells and one plugging and abandonment. About $0.4 million had been spent as of June 30, 2026.

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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 June 30, 2026

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:

		Trading Symbol(s)		Name of each exchange on which registered
Title of each class
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 August 14, 2026, 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.

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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 2025 Annual Report on Form 10-K (“2025 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 June 30, 2026, and the distributable income and changes in Trust corpus for the three and six month periods ended June 30, 2026, and June 30, 2025, have been included. Distributable income for such interim periods is not necessarily indicative of distributable income for the full year.

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PERMROCK ROYALTY TRUST

CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS

		June 30, 2026 (unaudited)				December 31, 2025
ASSETS
Cash and short-term investments		$	1,370,880			$	1,199,573
Net Profits Interest (1)			26,050,564				26,595,875
TOTAL ASSETS		$	27,421,444			$	27,795,448
LIABILITIES AND TRUST CORPUS
Distribution payable to unitholders		$	370,880			$	199,573
Cash reserves (2)			1,000,000				1,000,000
Trust corpus			26,050,564				26,595,875
TOTAL LIABILITIES AND TRUST CORPUS		$	27,421,444			$	27,795,448

(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.

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PERMROCK ROYALTY TRUST

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)

		Three Months Ended June 30,							Six Months Ended June 30,
		2026				2025			2026				2025
Net profits income		$	697,904			$	1,545,465		$	1,345,337			$	3,256,228
Interest income			8,768				12,137			18,303				24,677
Total revenue			706,672				1,557,602			1,363,640				3,280,905
Expenditures – general and administrative			(297,622	)			(357,084	)		(550,523	)			(614,192	)
Cash reserves (1)			—				—			—				—
Distributable income		$	409,050			$	1,200,518		$	813,117			$	2,666,713
Distributable income per unit (2)		$	0.033622			$	0.098679		$	0.066834			$	0.219196

(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 August 14, 2026.

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

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PERMROCK ROYALTY TRUST

CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)

			Three Months Ended June 30,								Six Months Ended June 30,
			2026				2025				2026				2025
Trust corpus, beginning of period			$	26,272,950			$	71,286,955			$	26,595,875			$	72,379,939
Amortization of Net Profits Interest				(222,386	)			(1,067,269	)			(545,311	)			(2,160,253	)
Distributable income				409,050				1,200,518				813,117				2,666,713
Distributions declared				(409,050	)			(1,200,518	)			(813,117	)			(2,666,713	)
Trust corpus, end of period			$	26,050,564			$	70,219,686			$	26,050,564			$	70,219,686
Distributions declared per unit (12,165,732 Units outstanding)			$	0.033622			$	0.098679			$	0.066834			$	0.219196

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

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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, 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” or "Buyer"), 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 the Buyer, 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. As of March 31, 2025, Boaz Energy transferred 4,884,861 Trust units to Ustx LLC, a wholly-owned subsidiary of T2S. As of August 14, 2026, Ustx LLC owned 4,884,861 Trust units of the 12,165,732 Trust units issued and outstanding.

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.

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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.

•Fair value accounting guidance includes a hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 inputs) and the lowest priority to unobservable inputs (Level 3). When indicators of impairment are present and it is determined that the carrying value of the Trust’s Net Profits Interest in the subject interests exceeds the estimated undiscounted cash flows of the subject interest, fair value estimates utilized in the impairment assessment are generally determined based on inputs not observable in the market and thus represent Level 3 measurements.

•Significantly, in 2025, the Trustee determined that an impairment in the amount of $39.9 million occurred for the year ended December 31, 2025, after reviewing the undiscounted and discounted reserves cash flow that had been revised to reflect future crude oil and natural gas commodity prices published by third-party industry experts (adjusted for base differentials) and a risk-adjusted discount rate. The Net Profits Interest was written down to its fair value of $26.6 million and the impairment was charged directly to the Trust corpus, which did not affect distributable income. Impairments recorded for book purposes will not result in a loss for tax purposes for the unitholders until the loss is recognized.

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 2025 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.

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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.

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 June 30, 2026.

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, 2025, the balance of funds held by T2S to cover certain future capital expenses was $74,933 net to the Trust. In March 2026, a scrivener's error by the operator caused an additional $10,000 net to the Trust to be distributed to the Trust, which was reversed from the April 2026 net profits income paid to the Trust, resulting in a corresponding reduction in funds payable to the Trust in April 2026. As of June 30, 2026, $150,000 in funds net to the Trust was held by T2S to cover future capital obligations.

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 June 30, 2026, were as follows:

Record Date		Payment Date		Distribution per Unit
April 30, 2026		May 14, 2026		$	0.000473
May 29, 2026		June 12, 2026			0.002664
June 30, 2026		July 15, 2026			0.030485
				$	0.033622

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 2026, the Trustee’s annual administrative fee is $209,152, 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 2022 and 2023. The Trustee’s annual administrative fee increased at a rate of 1% in 2026, and will continue to increase at a rate of 1% per year until the 20th anniversary of

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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 May 14, 2026, Ustx LLC, owned 4,884,861 Trust units of the 12,165,732 Trust units issued and outstanding.

7.Development Costs

T2S has an estimated workover budget for 2026 for the Underlying Properties of approximately $0.7 million. This budget includes workovers on twenty-two (22) wells that are shut-in and includes one (1) plugging and abandonment operation. These workovers and plugging and abandonment operations are expected to be completed during the second and third quarters of 2026. T2S reports that approximately $0.4 million of the approximately $0.7 million budget has been spent as of June 30, 2026. T2S has advised the Trust that the expenditures on development are subject to change based on, among other things, changes in the price of oil and natural gas, actual capital requirements, the pace of regulatory approvals and the mix of projects, if any occur.

8.Settlements and Litigation

None.

9.Subsequent Events

On July 21, 2026, the Trust declared a cash distribution of $274,696.04, or $0.022579 per Trust unit, to holders of record as of July 31, 2026, payable on August 14, 2026, based upon production during the month of May 2026.

Production Month		Underlying Sales Volumes								Average Price
		Oil (Bbls)				Gas (Mcf)				Oil (per Bbl)				Gas (per Mcf)
May			15,086				19,692			$	104.89			$	0.71

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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 2025 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;

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•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 2025 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, 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 Terry Counties, Texas. The Permian Abo area consists of 1,667 net acres on the Central Basin Platform of the Permian Basin in Terry

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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 has an estimated workover budget for 2026 for the Underlying Properties of approximately $0.7 million. This budget includes workovers on twenty-two (22) wells that are shut-in and includes one (1) plugging and abandonment operation. These workovers and plugging and abandonment operations are expected to be completed during the second and third quarters of 2026. T2S reports that approximately $0.4 million of the approximately $0.7 million budget has been spent as of June 30, 2026. T2S has advised the Trust that the expenditures on development are subject to change based on, among other things, changes in the price of oil and natural gas, actual capital requirements, the pace of regulatory approvals and the mix of projects, if any occur.

RESULTS OF OPERATIONS

Distributable Income

Three Months Ended June 30, 2026

For the three months ended June 30, 2026, net profits income received by the Trust was $697,904 compared to $1,545,465 for the same period of the prior year. This decrease in net profits income was primarily due to decreases in oil and gas sales volumes and lower gas sales prices, partially offset by higher oil prices. See “Computation of Income from the Net Profits Interest Received by the Trust” below.

After considering interest income of $8,768 and general and administrative expenditures of $297,622, distributable income for the three months ended June 30, 2026, was $409,050, or $0.033622 per Trust unit.

Interest income for the quarter ended June 30, 2026, decreased $3,369 as compared to the same period in the prior year, primarily due to lower interest rates. General and administrative expenditures decreased by $59,462 for the three months ended June 30, 2026, as compared to the prior year, primarily due to the timing of payments.

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 June 30, 2026, or June 30, 2025. Total cash reserves were $1,000,000 as of June 30, 2026, and June 30, 2025.

Based on 12,165,732 Trust units outstanding at each date listed below, the per unit distributions during the quarter ended June 30, 2026, were as follows:

Record Date		Payment Date		Distribution per Unit
April 30, 2026		May 14, 2026		$	0.000473
May 29, 2026		June 12, 2026			0.002664
June 30, 2026		July 15, 2026			0.030485
				$	0.033622

Six Months Ended June 30, 2026

For the six months ended June 30, 2026, net profits income received by the Trust was $1,345,337 compared to $3,256,228 for the same period of the prior year. This decrease in net profits income was primarily due to decreases in oil and gas sales volumes and lower gas sales prices, partially offset by higher oil prices. See "Computation of Income from the Net Profits Interest Received by the Trust" below.

After considering interest income of $18,303 and general and administrative expenditures of $550,523, distributable income for the six months ended June 30, 2026, was $813,117, or $0.066834 per Trust unit. For the six months ended June 30, 2025 total distributable income was $2,666,713, or $0.219196 per Trust unit.

Interest income decreased for the six months ended June 30, 2026, as compared to the prior year, primarily due to lower interest rates. General and administrative expenditures decreased by $63,669 for the six months ended June 30, 2026, as compared to the prior year, primarily due to timing of payments.

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Pursuant to 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 six months ended June 30, 2026. Total cash reserves were $1,000,000 as of June 30, 2026 and June 30, 2025.

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 June 30, 2026, was based on production during the months of February 2026 through April 2026.

		Three Months Ended June 30, 2026				Three Months Ended June 30, 2025				Six Months Ended June 30, 2026				Six Months Ended June 30, 2025
Underlying Properties sales volumes(1):
Oil (Bbl)			46,379				64,816				90,951				134,445
Natural gas (Mcf)(2)			46,482				85,631				108,331				164,793
Total sales (Boe)			54,126				79,088				109,006				161,911
Average realized sales price:
Oil (per Bbl)		$	81.09			$	66.36			$	69.37			$	67.91
Natural gas (per Mcf)		$	1.89			$	3.24			$	1.66			$	3.21
Calculation of net profits:
Gross profits:
Oil sales		$	3,761,006			$	4,301,269			$	6,309,401			$	9,130,923
Natural gas sales			87,668				277,564				180,552				529,721
Other revenue			—				21,687				—				57,207
Total gross profits		$	3,848,674			$	4,600,520			$	6,489,953			$	9,717,851
Costs:
Direct operating expenses:		$	494,694			$	220,660			$	564,205			$	686,598
Lease operating expenses			1,464,170				1,348,400				2,619,703				3,264,960
Severance and ad valorem taxes			309,217				417,592				506,009				733,727
Development expenses			(3,119	)			77,395				1,868				212,358
Other expenses			511,332				544,643				1,022,664				1,009,923
Total costs		$	(2,776,294	)		$	(2,608,690	)		$	(4,714,449	)		$	(5,907,566	)
Net profits		$	1,072,380			$	1,991,830			$	1,775,504			$	3,810,285
Percentage allocable to Net Profits Interest			80	%			80	%			80	%			80	%
Net profits income (before capital reserve)		$	857,904			$	1,593,464			$	1,420,403			$	3,048,228
Capital reserve activity (3)			(160,000	)			(48,000	)			(75,066	)			208,000
Net profits income received by the Trust		$	697,904			$	1,545,464			$	1,345,337			$	3,256,228

(1)Quarterly sales volumes are typically reported for a three-month period, and therefore sales volumes for the three months ended June 30, 2026, reflect production volumes for February 2026 through April 2026.

(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. Capital reserve activity for the quarter ended June 30, 2026, included the withholding of $150,000 net to the Trust of funds plus the recovery of $10,000 net to the Trust as a result of a scrivener's error in the first quarter of 2026. As of June 30, 2026, $150,000, net to the Trust, was held by T2S to cover future capital obligations.

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.

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Sales Volumes

Oil

Oil sales volumes decreased by 18,437 Bbls (28.4%) for the three months ended June 30, 2026, as compared to the same period in 2025. T2S reports that the decline in oil sales volumes was primarily attributable to the natural decline of the producing properties, in addition to the shut-in of certain wells during winter storms during January and February 2026, which wells were not returned to production until later in the second quarter of 2026 as part of the development plan. T2S reports that weather related shut-ins from the January and February 2026 winter storms in Texas had been substantially restored by June 30, 2026.

Natural Gas

Natural gas sales volumes decreased by 39,149 Mcf (45.7%) for the three months ended June 30, 2026, as compared to the same period in 2025. T2S reports that the decrease in natural gas sales volumes was primarily attributable to the natural decline of the producing properties and a decrease in deliveries during the current period. T2S reports that weather related shut-ins from the January and February 2026 winter storms in Texas had been substantially restored by June 30, 2026.

Sales Prices

Oil

The average realized oil price per Bbl increased for the three and six months ended June 30, 2026, as compared to the same period in 2025. T2S reports this increase was primarily due to an increase in the WTI benchmark oil price during the current period and improved regional pricing differentials, partially offset by the lingering effects of the January and February 2026 winter weather in Texas, which temporarily disrupted production, transportation and certain downstream operations.

Natural Gas

The average realized natural gas price per Mcf decreased for the three and six months ended June 30, 2026, as compared to the same period in 2025. T2S reports this decrease was primarily due to a negative pricing differential at the Waha Hub in the Permian Basin, where natural gas from the Underlying Properties is sold, as distinguished from Henry Hub pricing. The Waha Hub pricing weakness was primarily driven by decreased pipeline takeaway capacity for natural gas that resulted from periods of pipeline maintenance and weather-related shut-ins, as well as oil-directed drilling activity that exceeded available pipeline takeaway capacity. In early 2026, some operators were required to pay to transport natural gas out of the Permian Basin.

Costs

Direct Operating Expenses

Direct operating expenses increased for the three months ended June 30, 2026, as compared to the prior year period. T2S reports this increase was primarily because of higher workover activity on the Underlying Properties during the current period. Direct operating expenses decreased for the six months ended June 30, 2026, as compared to the prior year period. T2S reports this decrease was primarily due to fewer projects to return wells to production.

Lease Operating Expenses

Lease operating expenses increased for the three months ended June 30, 2026, as compared to the same quarter in 2025. T2S reports this increase was primarily due to increased routine lease operating and third-party service activity on the Underlying Properties during the current period. Lease operating expenses decreased for the six months ended June 30, 2026, as compared to the same prior year period. T2S reports this decrease is primarily due to lower workover activity, reduced third-party service costs, and the deferral of certain non-essential maintenance projects.

Severance and Ad Valorem Taxes

Severance and ad valorem taxes decreased for the three and six months ended June 30, 2026, as compared to the prior year periods. T2S reports these decreases were primarily due to lower oil and natural gas sales volumes and lower property valuations, partially offset by higher realized oil prices during the current period.

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Development Expenses Related to the Underlying Properties

Development expenses related to the Underlying Properties decreased for the three months ended June 30, 2026, as compared to the prior year period as a result of fewer capital projects.

Other Expenses

Other expenses decreased for the three months ended June 30, 2026, as compared to the same quarter in 2025. T2S reports this decrease was primarily because of lower overhead allocations during the current period. Other expenses increased for the six months ended June 30, 2026, as compared to the same prior year period. T2S reports this increase was due to adjustments to overhead.

Capital Reserve

As of June 30, 2026, $150,000 net to the Trust was held by T2S to cover future ad valorem taxes and workovers budgeted for the third quarter of 2026.

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 June 30, 2026.

T2S's Capital Expenditure Budget

T2S has an estimated workover budget for 2026 for the Underlying Properties of approximately $0.7 million. This budget includes workovers on twenty-two (22) wells that are shut-in and includes one (1) plugging and abandonment operation. These workovers and plugging and abandonment operations are expected to be completed during the second and third quarters of 2026. T2S reports that approximately $0.4 million of the approximately $0.7 million budget has been spent as of June 30, 2026. T2S has advised the Trust that the expenditures on development are subject to change based on, among other things, changes in the price of oil and natural gas, actual capital requirements, the pace of regulatory approvals and the mix of projects, if any occur.

Distributions Declared After Quarter End

On July 21, 2026, the Trust declared a cash distribution of $274,696.04, or $0.022579 per Trust unit, to holders of record as of July 31, 2026, payable on August 14, 2026, based upon production during the month of May 2026.

Production Month		Underlying Sales Volumes								Average Price
		Oil (Bbls)				Gas (Mcf)				Oil (per Bbl)				Gas (per Mcf)
May			15,086				19,692			$	104.89			$	0.71

Off-Balance Sheet Arrangements

As of June 30, 2026, the Trust had no off-balance sheet arrangements.

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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 2025 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 June 30, 2026, 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.

There were no changes in the Trust's internal control over financial reporting during the quarter ended June 30, 2026, that have materially affected, or are reasonably likely to materially affect, the Trust'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.

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PART II. OTHER INFORMATION

ITEM 1. Legal Proceedings

None.

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, 2025.

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.

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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: August 14, 2026

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.

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