10-Q 1 tm2516763d1_10q.htm FORM 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2025

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

For the transition period from                  to

Commission File Number: 001-35333

PERMIANVILLE ROYALTY TRUST

(Exact name of registrant as specified in its charter)

Delaware		45-6259461
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

The Bank of New York Mellon Trust Company, N.A., Trustee 601 Travis Street 16^th Floor Houston, Texas		77002
(Address of principal executive offices)		(Zip Code)

1-512-236-6555

(Registrant’s telephone number, including area code)

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		PVL		The 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 x 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, a 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.

Large accelerated filer ¨		Accelerated filer ¨
Non-accelerated filer x		Smaller reporting company x
		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 x

As of August 14, 2025, 33,000,000 units of beneficial interest in Permianville Royalty Trust were outstanding.

TABLE OF CONTENTS

	Glossary of Certain Oil and Natural Gas Terms	1

	PART I — FINANCIAL INFORMATION
Item 1.	Financial Statements	2
	Statements of Assets, Liabilities and Trust Corpus as of June 30, 2025 (unaudited) and December 31, 2024	2
	Statements of Distributable Income for the three and six months ended June 30, 2025 and 2024 (unaudited)	3
	Statements of Changes in Trust Corpus for the three and six months ended June 30, 2025 and 2024 (unaudited)	4
	Notes to Financial Statements	5
Item 2.	Trustee’s Discussion and Analysis of Financial Condition and Results of Operations	10
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	19
Item 4.	Controls and Procedures	20

	PART II — OTHER INFORMATION
Item 1A.	Risk Factors	21
Item 5.	Other Information	21
Item 6.	Exhibits	21
	Signatures	22

GLOSSARY OF CERTAIN OIL AND NATURAL GAS TERMS

The following are definitions of significant terms used in this report.

Bbl—One barrel of 42 U.S. gallons liquid volume, used herein in reference to crude oil and other liquid hydrocarbons.

Boe—One barrel of oil equivalent, computed on an approximate energy equivalent basis that one Bbl of crude oil equals approximately six Mcf of natural gas.

Btu—A British Thermal Unit, a common unit of energy measurement.

Completion—The installation of permanent equipment for the production of oil or natural gas, or in the case of a dry hole, the reporting of abandonment to the appropriate agency.

Differential—The difference between a benchmark price of oil and natural gas, such as the NYMEX crude oil spot, and the wellhead price received.

Field—An area consisting of either a single reservoir or multiple reservoirs, all grouped on or related to the same individual geological structural feature and/or stratigraphic condition.

GAAP—Accounting principles generally accepted in the United States of America.

Gross acres or gross wells—The total acres or wells, as the case may be, in which a working interest is owned.

MBbl—One thousand barrels of crude oil or condensate.

Mboe—One thousand barrels of oil equivalent.

Mcf—One thousand cubic feet of natural gas.

MMBoe—One million barrels of oil equivalent.

MMBtu—One million British Thermal Units.

MMcf—One million cubic feet of natural gas.

Net acres or net wells—The sum of the fractional working interests owned in gross acres or wells, as the case may be.

Net profits interest—A nonoperating interest that creates a share in gross production from an operating or working interest in oil and natural gas properties. The share is measured by net profits from the sale of production after deducting costs associated with that production.

NYMEX—New York Mercantile Exchange.

NYSE—New York Stock Exchange.

Plugging and abandonment—Activities to remove production equipment and seal off a well at the end of a well’s economic life.

Reservoir—A porous and permeable underground formation containing a natural accumulation of producible oil and/or natural gas that is confined by impermeable rock or water barriers and is individual and separate from other reservoirs.

Working interest—The right granted to the lessee of a property to explore for and to produce and own oil, natural gas, or other minerals. The working interest owners bear the exploration, development, and operating costs on either a cash, penalty, or carried basis.

PART I—FINANCIAL INFORMATION

Item 1.

Financial Statements.

PERMIANVILLE ROYALTY TRUST

Statements of Assets, Liabilities and Trust Corpus

	June 30,		December 31,
	2025		2024
	(unaudited)
ASSETS
Cash and cash equivalents	$	2,239,884	$	2,193,787
Net profits interest in oil and natural gas properties, net		39,429,178		41,892,402
Total assets	$	41,669,062	$	44,086,189
LIABILITIES AND TRUST CORPUS
Advances from Sponsor	$	550,323	$	150,000
Total liabilities		550,323		150,000
Trust corpus (33,000,000 units issued and outstanding)		41,118,739		43,936,189
Total liabilities and Trust corpus	$	41,669,062	$	44,086,189

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

PERMIANVILLE ROYALTY TRUST

Statements of Distributable Income

(unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2025			2024			2025			2024
Income from net profits interest		$419,589		$	–		$	419,589		$	169,372
Interest and investment income		23,097			18,332			46,097			36,635
General and administrative expenses		(289,272	)		(416,976	)		(537,828	)		(608,104	)
Cash reserves used for Trust expenses		128,670			398,644			354,226			402,097
Distributable income	$	282,084		$	–		$	282,084		$	–

Distributable income per unit (33,000,000 units)	$	0.008548		$	–		$	0.008548		$	–

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

PERMIANVILLE ROYALTY TRUST

Statements of Changes in Trust Corpus

(unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	2025			2024			2025			2024
Trust corpus, beginning of period	$	42,509,676		$	50,142,008		$	43,936,189		$	51,628,130
Cash reserves used for Trust expenses		(128,670	)		(398,644	)		(354,226	)		(402,097	)
Distributable income		282,084			–			282,084			–
Distributions to unitholders		(282,084	)		–			(282,084	)		–
Amortization of net profits interest		(1,262,267	)		(1,933,769	)		(2,463,224	)		(3,416,438	)
Trust corpus, end of period	$	41,118,739		$	47,809,595		$	41,118,739		$	47,809,595

Distributions per unit (33,000,000 units)	$	0.008548		$	–		$	0.008548		$	–

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

PERMIANVILLE ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS

(unaudited)

1.	TRUST ORGANIZATION AND PROVISIONS

Permianville Royalty Trust (the “Trust”), previously known as Enduro Royalty Trust, is a Delaware statutory trust formed in May 2011 pursuant to a trust agreement (as subsequently amended and restated, the “Trust Agreement”) among Enduro Resource Partners LLC (“Enduro”), as trustor, The Bank of New York Mellon Trust Company, N.A. (the “Trustee”), as trustee, and Wilmington Trust Company (the “Delaware Trustee”), as Delaware Trustee.

The Trust was created to acquire and hold for the benefit of the Trust unitholders a net profits interest representing the right to receive 80% of the net profits from the sale of oil and natural gas production from certain properties in the states of Texas, Louisiana and New Mexico held by Enduro as of the date of the conveyance of the net profits interest to the Trust (the “Net Profits Interest”). The properties in which the Trust holds the Net Profits Interest are referred to as the “Underlying Properties.”

In connection with the closing of the initial public offering in November 2011, Enduro contributed the Net Profits Interest to the Trust in exchange for 33,000,000 units of beneficial interest in the Trust (the “Trust Units”). On August 31, 2018, COERT Holdings 1 LLC (“COERT” or the “Sponsor”) acquired from Enduro the Underlying Properties and all of the outstanding Trust Units owned by Enduro (the “Sale Transaction”). In connection with the Sale Transaction, COERT assumed all of Enduro’s obligations under the Trust Agreement and other instruments to which Enduro and the Trustee were parties. As of June 30, 2025, the Sponsor owned 7,363,961 Trust Units, or 22% of the issued and outstanding Trust Units.

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 Agreement provides, among other provisions, that:

the Trust’s business activities are limited to owning the Net Profits Interest and any activity reasonably related to such ownership, including activities required or permitted by the terms of the Conveyance of Net Profits Interest, dated effective as of July 1, 2011 (as supplemented and amended to date, the “Conveyance”). As a result, the Trust is not permitted to acquire other oil and natural gas properties or net profits interests or otherwise to engage in activities beyond those necessary for the conservation and protection of the Net Profits Interest;

the Trust may dispose of all or any material part of the assets of the Trust (including the sale of the Net Profits Interest) if approved by at least 75% of the outstanding Trust Units;

the Sponsor may sell a divided or undivided portion of its interests in the Underlying Properties, free from and unburdened by the Net Profits Interest, if approved by at least 50% of the outstanding Trust Units at a meeting of Trust unitholders;

the Trustee will make monthly cash distributions to unitholders (Note 5);

the Trustee may create a cash reserve to pay for future liabilities of the Trust;

the Trustee may authorize the Trust to borrow money to pay administrative or incidental expenses of the Trust that exceed its cash on hand and available reserves. No further distributions will be made to Trust unitholders until such amounts borrowed are repaid; and

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; however, the Trust will dissolve upon the earliest to occur of the following:

the Trust, upon approval of the holders of at least 75% of the outstanding Trust Units, sells the Net Profits Interest; the annual cash proceeds received by the Trust attributable to the Net Profits Interest are less than $2 million for each of any two consecutive years;

the holders of at least 75% of the outstanding Trust Units vote in favor of dissolution; or

the Trust is judicially dissolved.

2.	BASIS OF PRESENTATION

The Statement of Assets, Liabilities and Trust Corpus as of December 31, 2024, which has been derived from audited financial statements, and the unaudited interim financial statements as of June 30, 2025 and for the three and six months ended June 30, 2025 and 2024 have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, certain information and disclosures normally included in annual financial statements have been condensed or omitted pursuant to those rules and regulations. Therefore, these financial statements should be read in conjunction with the financial statements and notes thereto included in the Trust’s Annual Report on Form 10-K for the fiscal year ended December 31, 2024 (the “2024 Annual Report on Form 10-K”).

In the opinion of the Trustee, the accompanying unaudited financial statements reflect all adjustments, consisting only of normal adjustments that are necessary for a fair presentation of the interim periods presented and include all the disclosures necessary to make the information presented not misleading. These interim results are not necessarily indicative of results for a full year.

The preparation of financial statements requires the Trustee to make estimates and assumptions that affect reported amounts of assets and liabilities and the reported amounts of revenues and expenses during the reporting period. Although the Trustee believes that these estimates are reasonable, actual results could differ from those estimates.

The Trust uses the modified cash basis of accounting to report Trust receipts of income from the Net Profits Interest and payments of expenses incurred. The Net Profits Interest represents the right to receive revenues (oil and natural gas sales), less direct operating expenses (lease operating expenses and production and property 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.

Under the terms of the Conveyance, the monthly Net Profits Interest calculation includes oil and natural gas revenues received during the relevant month. Monthly operating expenses and capital expenditures represent estimated incurred expenses and, as a result, represent accrued expenses as well as expenses paid during the period.

The financial statements of the Trust are prepared on the following basis:

(a)

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

(b)

Distributions to Trust unitholders are recorded when paid by the Trust;

(c)

Trust general and administrative expenses (which includes the Trustee’s fees as well as accounting, engineering, legal, and other professional fees) are recorded when paid;

(d)

Cash reserves for Trust expenses may be established by the Trustee for certain future expenditures that would not be recorded as contingent liabilities under accounting principles generally accepted in the United States of America (“GAAP”);

(e)

Amortization of the Net Profits Interest in oil and natural gas properties is calculated on a unit-of-production basis and is charged directly to the Trust corpus; and

(f)

The Net Profits Interest in oil and natural gas properties is periodically assessed whenever events or circumstances indicate that the aggregate value may have been impaired below its total capitalized cost based on the Underlying Properties. If an impairment loss is indicated by the carrying amount of the assets exceeding the sum of the undiscounted expected future net cash flows of the Net Profits Interest, then an impairment loss is recognized for the amount by which the carrying amount of the asset exceeds its estimated fair value determined using discounted cash flows. Any impairment is a direct charge to the Trust Corpus.

The financial statements of the Trust differ from financial statements prepared in accordance with GAAP because revenues are not accrued; certain cash reserves may be established for contingencies which would not be accrued in financial statements prepared in accordance with GAAP; general and administrative expenses are recorded when paid instead of when incurred; amortization of the net profits interest calculated on a unit-of-production basis is charged directly to trust corpus instead of as an expense; the Trust does not record a liability or repay any overpayment received as these will be deducted from future payments; and impairment is charged directly to the trust corpus. While these statements differ from financial statements prepared in accordance with GAAP, the modified cash basis of reporting is considered to be the most meaningful because monthly distributions to the Trust unitholders are based on net cash receipts.

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.

3.	NET PROFITS INTEREST IN OIL AND NATURAL GAS PROPERTIES

The Net Profits Interest in oil and natural gas properties was recorded at its fair value on the date of conveyance. Amortization of the Net Profits Interest in oil and natural gas properties is calculated on a unit-of-production basis based on the Underlying Properties’ production and reserves. The reserves upon which the amortization rate is based are quantity estimates that are subject to numerous uncertainties inherent in the estimation of proved reserves. The volumes considered to be commercially recoverable fluctuate with changes in commodity prices and operating costs. These estimates are expected to change as additional information becomes available in the future. Downward revisions in proved reserves may result in an increased rate of amortization. Amortization is charged directly to the Trust corpus balance and does not affect the distributable income of the Trust. Accumulated amortization as of June 30, 2025 and December 31, 2024 was $313,498,129 and $311,034,905, respectively.

The Net Profits Interest is periodically assessed for impairment whenever events or circumstances indicate that the current fair value based on expected future cash flows of the Underlying Properties may be less than the carrying value of the Net Profits Interest. While the Trust did not record an impairment during the three and six months ended June 30, 2025 or 2024, future downward revisions in actual production volumes relative to current forecasts, higher than expected operating costs, or lower than anticipated commodity prices could result in recognition of impairment in future periods.

4.	INCOME TAXES

Federal Income Taxes

For federal income tax purposes, the Trust is a grantor trust and therefore is not subject to tax at the trust level. Trust unitholders are treated as owning a direct interest in the assets of the Trust, and each Trust unitholder is taxed directly on his or her pro rata share of the income and gain attributable to the assets of the Trust and entitled to claim his or her pro rata share of the deductions and expenses attributable to the assets of the Trust. The income of the Trust is deemed to have been received or accrued by each unitholder at the time such income is received or accrued by the Trust rather than when distributed by the Trust.

The deductions of the Trust consist of severance taxes and administrative expenses. In addition, each unitholder is entitled to depletion deductions because the Net Profits Interest constitutes “economic interests” in oil and natural gas properties for federal income tax purposes. Each unitholder is entitled to amortize the cost of the Trust Units through cost depletion over the life of the Net Profits Interest or, if greater, through percentage depletion. Unlike cost depletion, percentage depletion is not limited to a unitholder’s depletable tax basis in the Trust Units. Rather, a unitholder could be entitled to percentage depletion as long as the applicable Underlying Properties generate gross income.

Some Trust Units are held by a middleman, as such term is broadly defined in U.S. Treasury Regulations (and includes custodians, nominees, certain joint owners, and brokers holding an interest for a custodian in street name). Therefore, the Trustee considers the Trust to be a non-mortgage widely held fixed investment trust (“WHFIT”) for U.S. federal income tax purposes. The Bank of New York Mellon Trust Company, N.A., 601 Travis, 16^th Floor, Houston, Texas 77002, telephone number (512) 236-6545, is the representative of the Trust that will provide tax information in accordance with applicable U.S. Treasury Regulations governing the information reporting requirements of the Trust as a WHFIT. Tax information is also posted by the Trustee at www.permianvilleroyaltytrust.com. Notwithstanding the foregoing, the middlemen holding units on behalf of unitholders, and not the Trustee of the Trust, are solely responsible for complying with the information reporting requirements under the U.S. Treasury Regulations with respect to such units, including the issuance of IRS Forms 1099 and certain written tax statements. Unitholders whose units are held by middlemen should consult with such middlemen regarding the information that will be reported to them by the middlemen with respect to the Trust Units.

The tax consequences to a unitholder of ownership of Trust Units will depend in part on the unitholder’s tax circumstances. Unitholders should consult their tax advisors about the federal tax consequences relating to owning the Trust Units.

State Taxes

The Trust’s revenues are from sources in the states of Louisiana, New Mexico, and Texas. Because it distributes all of its net income to unitholders, the Trust is not taxed at the trust level in Louisiana or New Mexico. Although the Trust does not owe tax, the Trustee is required to file a return with Louisiana reflecting the income and deductions of the Trust attributable to properties located in that state. Presently, Louisiana and New Mexico tax nonresident income from real property located within that state. Louisiana and New Mexico impose a corporate income tax which may apply to unitholders organized as corporations.

Texas does not impose a state income tax, so the Trust’s income is not subject to income tax at the trust level in Texas. Texas imposes a franchise tax at a rate of 0.75% on gross revenues less certain deductions for returns originally due on or after January 1, 2016, as specifically set forth in the Texas franchise tax statutes. Entities subject to tax generally include trusts unless otherwise exempt. Trusts that receive at least 90% of their federal gross income from designated passive sources, including royalties from mineral properties and other income from other non-operating mineral interests, and do not receive more than 10% of their income from operating an active trade or business, generally are exempt from the Texas franchise tax as “passive entities.” Although the Trust is intended to be exempt from Texas franchise tax at the trust level as a passive entity, each unitholder that is considered a taxable entity under the Texas franchise tax would generally be required to include its portion of Trust net income in its own Texas franchise tax computation.

Each unitholder should consult his or her own tax advisor regarding state tax requirements, if any, applicable to such person’s ownership of Trust Units.

5.	DISTRIBUTIONS TO UNITHOLDERS

Each month, the Trustee determines the amount of funds available for distribution to the Trust unitholders. Available funds are the excess cash, if any, received by the Trust from the Net Profits Interest and other sources (such as interest earned on any amounts reserved by the Trustee) that month, over the Trust’s liabilities for that month, subject to adjustments for changes made by the Trustee during the month in any cash reserves established for future liabilities of the Trust. No distributions will be made to Trust unitholders until the indebtedness created by such amounts drawn or borrowed as advances to the Trust have been repaid in full. Distributions are made to the holders of Trust Units as of the applicable record date (generally the last business day of each calendar month) and are payable on or before the 10th business day after the record date.

The following table provides information regarding the Trust’s distributions per unit paid during the periods indicated:

			Distribution
Declaration Date	Record Date	Payment Date	per Unit
Six Months Ended June 30, 2025:
March 17, 2025 (Special Distribution)	March 31, 2025	April 14, 2025	$	0.008548
Year to Date – 2025			$	0.008548

Six Months Ended June 30, 2024:
Year to Date – 2024			$	0.000000

During the three months ended June 30, 2025, the Net Profits Interest generated positive income, which eliminated the cumulative Net Profits Interest shortfall of $1.4 million that existed as of March 31, 2025; however, no distributions were made to Trust unitholders because of outstanding advances from the Sponsor to the Trust for the payment of administrative expenses, which totaled $0.6 million as of June 30, 2025. The Trust is not permitted to make distributions to Trust unitholders until any Net Profits Interest shortfall has been recouped and outstanding advances from the Sponsor have been repaid.

During the six months ended June 30, 2024, the Net Profits Interest generated positive income for several of the months in the period, which reduced the cumulative Net Profits Interest shortfall of $1.2 million that existed as of December 31, 2023. In March and April 2024, however, direct operating and development expenses exceeded revenues, thereby causing net profits attributable to the Underlying Properties to be negative and resulting in an approximately $3.9 million Net Profits Interest shortfall as of June 30, 2024, which was carried forward to be deducted from future net profits generated by the Underlying Properties. As a result, there were no net profits reported or distributed in the first six months of 2024.

On March 17, 2025, the Trustee declared a special cash distribution of $0.008548 per Trust Unit, which was paid on April 14, 2025 to Trust unitholders of record on March 31, 2025. The special cash distribution reflected the release of the $250,000 withheld from the net proceeds allocable to the Trust from the August 2023 sale by the Sponsor of certain oil and natural gas properties in the Permian Basin, which amount was intended to cover possible indemnification obligations arising during the indemnification period following the closing of the sale. Together with interest, the amount distributed equated to $282,072.

6.	TRUSTEE FEES

Under the terms of the Trust Agreement, the Trust pays an administrative fee of $200,000 per year to the Trustee and an annual fee of $2,000 to the Delaware Trustee. During the three- and six-month periods ended June 30, 2025 and 2024, the Trust paid $50,000 and $100,000, respectively, to the Trustee and $0 and $2,010, respectively, to the Delaware Trustee pursuant to the terms of the Trust Agreement.

Item 2.

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

References to the “Trust” in this document refer to Permianville Royalty Trust, previously known as Enduro Royalty Trust, while references to “COERT” or the “Sponsor” in this document refer to COERT Holdings 1 LLC. References to “Enduro” in this document refer to Enduro Resource Partners LLC, the original sponsor of the Trust. The following review of the Trust’s financial condition and results of operations should be read in conjunction with the financial statements and notes thereto, as well as Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in the Trust’s Annual Report on Form 10-K for the year ended December 31, 2024 (the “2024 Annual Report on Form 10-K”). The Trust’s annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all other filings with the SEC are available on the SEC’s website at www.sec.gov.

Forward-Looking Statements

This Quarterly Report on Form 10-Q (this “Form 10-Q”) includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical fact included in this Form 10-Q, including without limitation the statements under this “Trustee’s Discussion and Analysis of Financial Condition and Results of Operations,” are forward-looking statements. Such statements may be influenced by factors that could cause actual outcomes and results to differ materially from those projected. Such expectations may not prove to have been correct. When used in this document, the words “believes,” “expects,” “anticipates,” “intends” or similar expressions are intended to identify such forward-looking statements. The following important factors, in addition to those discussed elsewhere in this Form 10-Q, in the Trust’s 2024 Annual Report on Form 10-K and the Trust’s other filings with the SEC could affect the future results of the energy industry in general, and COERT and the Trust in particular, and could cause actual results to differ materially from those expressed in such forward-looking statements:

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

the amount of future direct operating expenses and development expenses;

the occurrence or threat of epidemic or pandemic diseases or other public health event or any government response to such occurrence or threat;

the impact of geopolitical developments and tensions, war and uncertainty involving or in the geographical region of oil producing countries (including the ongoing armed conflicts between Russia and Ukraine and between Israel and Iran and its proxies and any related political or economic responses and counter-responses or otherwise by various global actors or the general effect on the global economy);

global economic conditions, such as a general slowdown in the global economy, trade barriers and tariffs, supply chain disruptions, inflationary pressures, currency fluctuations, changes in interest rates, and instability of financial institutions;

the effects of actions by, or disputes among or between members of the Organization of Petroleum Exporting Countries (“OPEC”) and other oil-exporting nations with respect to production levels or other matters related to the prices of oil and natural gas;

the effect of existing and future laws and regulatory actions;

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

the prohibition on the Trust’s entry into any new hedging arrangements under the terms of the Conveyance;

conditions in the capital markets;

competition from others in the energy industry;

uncertainty of estimates of oil and natural gas reserves and production;

potential impacts on the Sponsor’s business resulting from climate change, greenhouse gas regulations, and the impact of climate change related changes in the frequency and severity of weather patterns; and

other risks described under the caption “Risk Factors” in Part I, Item 1A of the 2024 Annual Report on Form 10-K.

You should not place undue reliance on these forward-looking statements. All forward-looking statements speak only as of the date of this Form 10-Q. 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 Form 10-Q or to reflect the occurrence of unanticipated events, unless the securities laws require the Trust to do so.

This Form 10-Q describes other important factors that could cause actual results to differ materially from expectations of the Sponsor and the Trust. All forward-looking statements in this report and all subsequent written and oral forward-looking statements attributable to the Sponsor or the Trust or persons acting on behalf of the Sponsor or the Trust are expressly qualified in their entirety by such factors. The Trust assumes no obligation, and disclaims any duty, to update these forward-looking statements.

Overview

Permianville Royalty Trust, a statutory trust created in May 2011, completed its initial public offering in November 2011. The Trust’s only asset and source of income is the net profits interest representing the right to receive 80% of the net profits from the sale of oil and natural gas production from certain properties in the states of Texas, Louisiana and New Mexico held by Enduro as of the date of the conveyance of the net profits interest to the Trust (the “Net Profits Interest”). The properties in which the Trust holds the Net Profits Interest are referred to as 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. Additionally, third parties operate substantially all of the wells on the Underlying Properties and, therefore, the Sponsor is not in a position to control the timing of development efforts, associated costs, or the rate of production of the reserves.

On August 31, 2018, COERT completed the acquisition from Enduro of the Underlying Properties and all of the outstanding Trust Units owned by Enduro (the “Sale Transaction”). In connection with the Sale Transaction, COERT assumed all of Enduro’s obligations under the Amended and Restated Trust Agreement of the Trust (the “Trust Agreement”) and other instruments to which Enduro and the Trustee were parties.

The Trust is required to make monthly cash distributions of substantially all of its monthly cash receipts, after deducting the Trust’s administrative expenses, to the holders of Trust Units as of the applicable record date (generally the last business day of each calendar month) on or before the 10^th business day after the record date. The Net Profits Interest is entitled to a share of the profits from and after July 1, 2011 attributable to production occurring on or after June 1, 2011. The amount of Trust revenues and cash distributions to Trust unitholders depends on, among other things:

oil and natural gas sales prices;

volumes of oil and natural gas produced and sold attributable to the Underlying Properties;

production and development costs;

price differentials;

potential reductions or suspensions of production;

the amount and timing of Trust administrative expenses; and

the establishment, increase, or decrease of reserves for approved development expenses or future liabilities of the Trust.

Generally, the Sponsor receives cash 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.

Outlook

The Sponsor has indicated to the Trustee that development activity on the Underlying Properties remained elevated through the first six months of 2025 compared to prior years, although activity in the first half of 2025 declined from the comparable period in 2024, which included a material amount of prior period production from certain Permian wells that had been delayed due to pending title work completed during the 2024 period. The Sponsor reports that most of the continued capital expenditures were associated with work undertaken by a super major oil conglomerate and the completion of three wells in the Haynesville region. Subsequent to June 30, 2025, the Sponsor indicates that it has received from the operator the initial revenues from these wells, which will be reflected in the net profits interest calculations in the third quarter. Otherwise, the Sponsor believes the remaining capital expenditure outlook for the operators of the Underlying Properties remains highly uncertain given current macroeconomic conditions. Nevertheless, although commodity prices remain volatile, the majority of the capital expenditures for the Underlying Properties are associated with large cap, investment-grade oil and gas operators that tend to spend through periods of volatility. Directionally, the Sponsor continues to expect oil-directed capital expenditures in the Permian basin to decline and gas-directed capital expenditures in the Haynesville region to remain stable or perhaps even slightly increase, consistent with the first six months of 2025. Specifically, the same operator that recently completed the three Haynesville wells described above has recently proposed three more Haynesville wells for 2026, fairly similar in size and profile to the prior three wells. Future capital expenditure expectations remain subject to revision from the operators of the Underlying Properties. With the revenue recently received from the new Haynesville wells, the Sponsor expects the net profits interest to return to positive monthly payments in calendar year 2025.

The Sponsor believes that the outlook for the oil and gas industry remains increasingly complicated since the start of 2025, albeit somewhat relatively more stable at the end of the quarter ended June 30, 2025 compared to the beginning of the quarter. OPEC continues to indicate increasing oil production and supply, which has weighed on oil prices, although these price impacts are somewhat offset by elevated geopolitical uncertainty. Oil prices have ranged from just over $80 per Bbl to as low as $57 per Bbl between December 2024 and August 2025, with several public oil and gas companies indicating that the volatility has affected their budget planning for the remainder of 2025. Natural gas prices have experienced similar volatility, ranging from a low of $2.93 per MMBtu to a high of $4.49 per MMBtu over the same period, as previous forecasts of increasing demand for U.S. liquified natural gas exports have been called into question given the uncertain global trade environment. Meanwhile, mergers and acquisitions continue to change the makeup of companies in the sector, including one of the operators on the Underlying Properties. The Sponsor continues to believe that consolidation within the oil and gas sector could lead to lower operating costs given economies of scale, but could also lead to more binary swings in capital spending, as more assets and capital budgets are set by fewer operators than in years past.

Despite this volatility, given the continued elevated capital expenditures during the first six months of 2025, the Sponsor is now guiding to the high end of its previously revised 2025 capital spending outlook of $10.0 million to $15.0 million, or $8.0 million to $12.0 million net to the Trust’s Net Profits Interest, as detailed in the prior Form 10-Q for the quarter ended March 31, 2025. The Sponsor expects a majority of the remaining anticipated capital expenditures in 2025 to be focused in the Haynesville area, given relatively higher industry rig counts compared to last year, versus the declining Permian rig count thus far in 2025. As in prior periods, the outlook for capital expenditures remains subject to change, as operators are expected to continue to reevaluate their planned capital expenditures, particularly given volatile capital markets and an uncertain geopolitical situation.

Over the first six months of 2025, the Sponsor continued to see a reduction in operating costs that had been affecting the Underlying Properties in prior periods on an aggregate basis, as seen in the continued decline in lease operating expenditures per barrel of oil equivalent for the six months ended June 30, 2025 compared to the same period in 2024. The Sponsor indicates that this decline continues to reflect the increased production from newer wells that feature lower operating costs than some of the legacy wells on the Underlying Properties. Nevertheless, the Sponsor indicates that some legacy producing properties of the Underlying Properties continue to experience operating cost and production issues consistent with late-life oil and gas properties, and currently it is unclear if some of these properties will be able to realize a return to prior period operating costs and cash flow profile. While the markets remain volatile and there remains an inherent delay in cash flows given the non-operated nature of the Underlying Properties, the Sponsor indicates that it continues to have access to adequate capital and liquidity to fund such operating and capital expenditures as they come due.

The Sponsor believes there could be further opportunity in the coming quarters for potential divestitures and/or leasing of some or all of the Underlying Properties, subject to the Trust’s Net Profits Interest, as certain operators of the Underlying Properties look to acquire assets, particularly in the Permian and Haynesville regions.

Capex Drilling Activity Update

Presented below is a summary of the current status of certain notable capital projects recently undertaken on the Underlying Properties pursuant to the capital expenditure program described above. All information has been provided by the Sponsor.

The following table is not intended to be a comprehensive list reflecting all capital expenditures to date. In addition, there can often be a several-month delay from the time of capital expenditures to the time of production and cash flows attributable to the Underlying Properties, especially given the non-operated nature of the Underlying Properties.

Operator

Region

Number
of Wells

Underlying
Properties
W/I

Project

Capex
Cumulative
Total
(in thousands)

Status

Large Cap E&P 1

Delaware

5.0

D&C New Drills

–

3 Pre Drills

Large Cap E&P 2

Midland

3.4

D&C New Drills

1,062

4 Drilling In-Process

Large Cap E&P 3

Delaware

1.0

D&C New Drills

–

19 Pre Drills

Large Major Cap E&P 1

Haynesville

8.9

D&C New Drills

–

3 Pre Drills

PE-Backed Private 1

Delaware

4.6

D&C New Drills

–

2 Pre Drills

PE-Backed Private 2

Delaware

0.7

D&C New Drills

–

4 Drilling in-Process

The projects identified above are still in process or awaiting first revenues, and the Sponsor expects a majority of those projects to be completed and to begin producing during 2025.

Results of Operations

Three Months Ended June 30, 2025 Compared to Three Months Ended June 30, 2024

The Trust’s net profits income consists of monthly net profits attributable to the Net Profits Interest, which was determined as shown in the following table:

	Three Months Ended June 30,
	2025			2024			Increase (Decrease)
Gross profits:
Oil sales	$	7,978,067		$	15,754,950			(49	)%
Natural gas sales		3,240,447			2,690,578			20	%
Total		11,218,514			18,445,528			(39	)%

Costs:
Direct operating expenses:
Lease operating expenses		4,787,000			8,408,000			(43	)%
Compression, gathering and transportation		968,000			898,000			8	%
Production, ad valorem and other taxes		720,000			1,273,000			(43	)%
Development expenses		2,798,000			12,895,000			(78	)%
Total		9,273,000			23,474,000			(60	)%
Gross proceeds from sale of assets		–			146,400			(100	)%
Net profits		1,945,514			(4,882,072	)		140	%
Percentage allocable to Net Profits Interest		80	%		80	%
Net profits allocable to Net Profits Interest		1,556,412			(3,905,657	)		140	%
Negative Net Profits Carryforward		(1,418,895	)		–			(100	)%
Less: Repayment of Sponsor Loan		(137,517	)		–			(100	)%
Plus: Release of Escrow		282,072			–			100	%
Plus: Net profits allocable to Net Profits Interest shortfall		–			3,905,657			(100	)%
Distributable income	$	282,072		$	–			100	%

During the three months ended June 30, 2024, direct operating and development expenses exceeded revenues, thereby causing net profits attributable to the Underlying Properties to be negative and resulting in an approximately $3.9 million Net Profits Interest shortfall as of June 30, 2024, which was carried forward to be deducted from future net profits generated by the Underlying Properties. As a result, there were no net profits reported or distributed in the second quarter of 2024.

On March 17, 2025, the Trustee declared a special cash distribution of $0.008548 per Trust Unit, which was paid on April 14, 2025 to Trust unitholders of record on March 31, 2025. The special cash distribution reflected the release of the $250,000 withheld from the net proceeds allocable to the Trust from the August 2023 sale by the Sponsor of certain oil and gas properties in the Permian Basin, which amount was intended to cover possible indemnification obligations arising during the indemnification period following the closing of the sale. Together with interest, the amount distributed equated to $282,072.

The following table displays reported oil and natural gas sales volumes and average prices from the Underlying Properties, representing the amounts included in the net profits calculation for distributions paid or payable during the three months ended June 30, 2025 and 2024:

	Three Months Ended June 30,
	2025			2024			Increase (Decrease)
Underlying Properties Production Volumes:
Oil (Bbls)		108,972			205,150			(47	)%
Natural Gas (Mcf)		1,308,205			1,050,147			25	%
Combined (Boe)		327,006			380,175			(14	)%

Average Prices:
Oil - NYMEX (applicable NPI period) ($/Bbl)	$	72.00		$	74.99			(4	)%
Differential	$	1.21		$	1.81			(33	)%
Oil prices realized ($/Bbl)	$	73.21		$	76.80			(5	)%

Natural gas - NYMEX (applicable NPI period) ($/Mcf)	$	3.09		$	2.85			8	%
Differential	$	(0.61	)	$	(0.29	)		(112	)%
Natural gas prices realized ($/Mcf)	$	2.48		$	2.56			(3	)%

Net profits attributable to the Underlying Properties for the three months ended June 30, 2025 were $1.9 million compared to $(4.9) million for the three months ended June 30, 2024. The $6.8 million increase in net profits attributable to the Underlying Properties from the 2024 period to the 2025 period was primarily due to the following items:

Oil sales decreased $7.8 million due to lower produced volumes and lower realized prices. The 47% reduction in produced volumes decreased revenues by $7.4 million. This decrease was primarily due to the 15 new Permian wells that either turned to sales or completed title work in the 2024 period, thereby allowing production attributable to prior periods to be released by the operators of the Underlying Properties. Realized oil sales prices decreased 5% in the 2025 period compared to the 2024 period, which decreased revenues by $0.4 million.

Natural gas sales increased $0.5 million compared to the 2024 period, reflecting a $0.6 million increase due to higher produced volumes, partially offset by a $0.1 million decrease due to lower realized prices. The average natural gas price received decreased 3% primarily due to the decrease in the average realized natural gas price for the relevant production months.

Lease operating expenses during the three months ended June 30, 2025 decreased $3.6 million compared to the three months ended June 30, 2024.

Compression, gathering and transportation costs increased $0.1 million, primarily due to the increase in natural gas production during the three months ended June 30, 2025.

Production, ad valorem and other taxes decreased $0.6 million during the three months ended June 30, 2025 compared to the three months ended June 30, 2024.

Development expenses decreased $10.1 million during the three months ended June 30, 2025 compared to the same period in 2024, due to a decrease in drilling and completion costs incurred.

For the three months ended June 30, 2025, the Trust withheld $0.0 million and paid $0.3 million for general and administrative expenses. Expenses paid during the period primarily consisted of fees for the preparation of the Trust’s monthly press releases, insurance expense, Trustee fees, and New York Stock Exchange listing fees. For the three months ended June 30, 2024, the Trust withheld $0.0 million and paid $0.4 million for general and administrative expenses.

Six Months Ended June 30, 2025 Compared to Six Months Ended June 30, 2024

The Trust’s net profits income consists of monthly net profits attributable to the Net Profits Interest, which was determined as shown in the following table:

	Six Months Ended June 30,
	2025			2024			Increase (Decrease)
Gross profits:
Oil sales	$	16,508,772		$	25,460,484			(35	)%
Natural gas sales		5,282,124			4,378,759			21	%
Total		21,790,896			29,839,243			(27	)%

Costs:
Direct operating expenses:
Lease operating expenses		9,516,000			15,016,000			(37	)%
Compression, gathering and transportation		1,970,000			1,497,000			32	%
Production, ad valorem and other taxes		1,428,000			2,175,000			(34	)%
Development expenses		9,955,000			15,968,000			(38	)%
Total		22,869,000			34,656,000			(34	)%
Gross proceeds from sale of assets		–			146,400			(100	)%
Net profits		(1,078,104	)		(4,670,357	)		77	%
Percentage allocable to Net Profits Interest		80	%		80	%
Net profits allocable to Net Profits Interest		(862,483	)		(3,736,285	)		77	%
Plus: Sponsor reserve release for capital expenditures		1,000,000			–			(100	)%
Less: Repayment of Sponsor Loan		(137,517	)		–			(100	)%
Plus: Release of Escrow		282,072			–			100	%
Plus: Net profits allocable to Net Profits Interest shortfall		–			3,905,657			(100	)%
Less: Trust general and administrative expenses and cash withheld for expenses net of interest income		–			(169,372	)		100	%
Distributable income	$	282,072		$	–			100	%

During the six months ended June 30, 2025, although the Net Profits Interest shortfall that existed throughout the first five months of the period was eliminated by the end of the period, no distributions were made to Trust unitholders because of outstanding advances from the Sponsor to the Trust for the payment of administrative expenses, which totaled $0.6 million as of June 30, 2025. The Trust is not permitted to make distributions to Trust unitholders until any Net Profits Interest shortfall has been recouped and outstanding advances from the Sponsor have been repaid.

During the six months ended June 30, 2024, the Net Profits Interest generated positive income for the first two months in the period, which eliminated the cumulative Net Profits Interest shortfall of $1.2 million that existed as of December 31, 2023. In March 2024, however, direct operating and development expenses exceeded revenues, thereby causing net profits attributable to the Underlying Properties to be negative and resulting in an approximately $3.9 million Net Profits Interest shortfall as of June 30, 2024, which was carried forward to be deducted from future net profits generated by the Underlying Properties. As a result, there were no net profits reported or distributed in the first six months of 2024.

	Six Months Ended June 30,
	2025		2024			Increase (Decrease)
Underlying Properties Production Volumes:
Oil (Bbls)		223,352		320,493			(30	)%
Natural Gas (Mcf)		2,488,665		1,761,271			41	%
Combined (Boe)		638,130		614,038			4	%

Average Prices:
Oil - NYMEX (applicable NPI period) ($/Bbl)	$	73.86	$	79.54			(7	)%
Differential	$	0.06	$	(0.10	)		158	%
Oil prices realized ($/Bbl)	$	73.92	$	79.44			(7	)%

Natural gas - NYMEX (applicable NPI period) ($/Mcf)	$	2.11	$	2.46			(14	)%
Differential	$	0.01	$	0.03			(65	)%
Natural gas prices realized ($/Mcf)	$	2.12	$	2.49			(15	)%

Net profits attributable to the Underlying Properties for the six months ended June 30, 2025 were $(1.1) million compared to $(4.7) million for the six months ended June 30, 2024. The $3.6 million increase in net profits attributable to the Underlying Properties from the 2024 period to the 2025 period was primarily due to the following items:

Oil sales decreased $8.9 million due to lower produced volumes and lower realized prices. The 30% decrease in produced volumes decreased revenues by $7.7 million. This decrease was primarily due to the 15 new Permian wells that either turned to sales or completed title work in the 2024 period, thereby allowing production attributable to prior periods to be released by the operators of the Underlying Properties. Realized oil sales prices decreased 7% in the 2025 period compared to the 2024 period, which increased revenues by $1.2 million.

Natural gas sales increased $0.9 million compared to the 2024 period, reflecting a $1.8 million increase due to higher produced volumes, offset by a $0.9 million decrease due to lower realized prices. The average natural gas price received decreased 15% primarily due to the decrease in the average realized natural gas price for the relevant production months.

Lease operating expenses during the six months ended June 30, 2025 decreased $5.5 million compared to the six months ended June 30, 2024.

Compression, gathering and transportation costs increased $0.5 million, primarily due to the increase in natural gas production during the six months ended June 30, 2025.

Production, ad valorem and other taxes decreased $0.7 million during the six months ended June 30, 2025 compared to the six months ended June 30, 2024.

Development expenses decreased $6.0 million during the six months ended June 30, 2025 compared to the same period in 2024, due to a decrease in drilling and completion costs incurred.

For the six months ended June 30, 2025, the Trust withheld $0.0 million and paid $0.5 million for general and administrative expenses. Expenses paid during the period primarily consisted of fees for the preparation of the Trust’s monthly press releases, insurance expense, Trustee fees, and New York Stock Exchange listing fees. For the six months ended June 30, 2024, the Trust withheld $0.2 million and paid $0.6 million for general and administrative expenses.

Liquidity and Capital Resources

The Trust’s principal sources of liquidity are cash flow generated from the Net Profits Interest and borrowing capacity under the letter of credit described below. Other than Trust administrative expenses, including any reserves established by the Trustee for future liabilities, the Trust’s only use of cash is for distributions to Trust unitholders. Available funds are the excess cash, if any, received by the Trust from the Net Profits Interest and other sources (such as interest earned on any amounts reserved by the Trustee) in any given month, over the Trust’s expenses paid for that month. Available funds are reduced by any cash the Trustee determines to hold as a reserve against future expenses.

The Trustee may create a cash reserve to pay for future liabilities of the Trust. In February 2022, the Trustee began withholding $37,833 from the funds otherwise available for distribution each month to gradually build a cash reserve of approximately $2.3 million for the payment of future known, anticipated or contingent expenses or liabilities of the Trust. Commencing with the distribution to Trust unitholders payable in April 2023, the Trustee has been withholding, and in the future intends to withhold, $50,000 from the funds otherwise available for distribution each month to gradually build the reserve. The Trustee may increase or decrease the targeted cash reserve amount at any time, and may increase or decrease the rate at which it is withholding funds to build the cash reserve at any time, without advance notice to the Trust unitholders. Cash held in reserve will be invested as required by the Trust Agreement. Any cash reserved in excess of the amount necessary to pay or provide for the payment of future known, anticipated or contingent expenses or liabilities eventually will be distributed to Trust unitholders, together with interest earned on the funds. As of June 30, 2025, the Trustee has withheld $1,241,386 toward this cash reserve. Due to the cumulative Net Profits Interest shortfall, no amounts were withheld toward this cash reserve during the six months ended June 30, 2025.

If the Trustee determines that the cash on hand and the cash to be received are, or will be, insufficient to cover the Trust’s liabilities, the Trustee may authorize the Trust to borrow money to pay administrative or incidental expenses of the Trust that exceed cash held by the Trust. The Trustee may authorize the Trust to borrow from any person, including the Trustee or the Delaware Trustee or an affiliate thereof, although none of the Trustee, the Delaware Trustee or any affiliate thereof intends to lend funds to the Trust. The Trustee may also cause the Trust to mortgage its assets to secure payment of the indebtedness. The terms of such indebtedness and security interest, if funds were to be loaned by the entity serving as Trustee or Delaware Trustee or an affiliate thereof, would be similar to the terms which such entity would grant to a similarly situated commercial customer with whom it did not have a fiduciary relationship. In addition, COERT has provided the Trust with a $1.2 million letter of credit to be used by the Trust if its cash on hand (including available cash reserves) is insufficient to pay ordinary course administrative expenses. Further, if the Trust requires more than the $1.2 million under the letter of credit to pay administrative expenses, COERT has agreed to loan funds to the Trust necessary to pay such expenses. Any loan made by COERT to the Trust would be evidenced by a written promissory note, be on an unsecured basis, and have terms that are no less favorable to COERT than those that would be obtained in an arm’s length transaction between COERT and an unaffiliated third party. If the Trust borrows funds or draws on the letter of credit, no further distributions will be made to Trust unitholders until such amounts borrowed or drawn are repaid. Except for the foregoing, the Trust has no source of liquidity or capital resources. The Trustee has no current plans to authorize the Trust to borrow any funds. As of June 30, 2025 and December 31, 2024, including the aggregate amounts withheld as of such dates toward the approximately $2.3 million cash reserve discussed above, the Trust had cash of $2,239,884 and $2,193,787, respectively, to be used towards future Trust expenses. Since its formation, the Trust has not borrowed any funds and no amounts have been drawn on the letter of credit.

From time to time, if the Trust’s cash on hand (including available cash reserves, if any) is not sufficient to pay the Trust’s ordinary course administrative expenses that are due prior to the monthly payment to the Trust of proceeds from the Net Profits Interest, COERT may advance funds to the Trust to pay such expenses. At June 30, 2025 and December 31, 2024, there were outstanding advances of $550,323 and $150,000, respectively. Any advances to the Trust will be carried forward to be repaid out of future net profits generated by the Underlying Properties.

Cash held by the Trustee as a reserve against future liabilities or for distribution at the next distribution date may be held in a noninterest-bearing account or may be invested in:

interest-bearing obligations of the United States government;

money market funds that invest only in United States government securities;

repurchase agreements secured by interest-bearing obligations of the United States government; or

bank certificates of deposit.

The Trust pays the Trustee an annual administrative fee of $200,000 and the Delaware Trustee an annual fee of $2,000. The Trust also incurs, either directly or as a reimbursement to the Trustee, legal, accounting, tax and engineering fees, printing costs and other expenses that are deducted by the Trust before distributions are made to Trust unitholders. The Trust also is responsible for paying other expenses incurred as a result of being a publicly traded entity, including costs associated with annual and quarterly reports to Trust unitholders, tax return and Form 1099 preparation and distribution, NYSE listing fees, independent auditor fees and registrar and transfer agent fees.

The Trust does not have any transactions, arrangements or other relationships with unconsolidated entities or persons that could materially affect the Trust’s liquidity or the availability of capital resources.

Off-Balance Sheet Arrangements

The Trust has no off-balance sheet arrangements. The Trust has not guaranteed the debt of any other party, nor does the Trust have any other arrangements or relationships with other entities that could potentially result in unconsolidated debt, losses or contingent obligations.

Critical Accounting Policies and Estimates

Please read “Item 7. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Policies and Estimates” of the Trust’s 2024 Annual Report on Form 10-K for additional information regarding the Trust’s critical accounting policies and estimates. There were no material changes to the Trust’s critical accounting policies or estimates during the three months ended June 30, 2025.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk.

As a “smaller reporting company” as defined in Item 10(f)(1) of Regulation S-K, the Trust is not required to provide information required by this Item.

Item 4.

Controls and Procedures.

Evaluation of Disclosure Controls and Procedures

The Trustee conducted an evaluation of the Trust’s disclosure controls and procedures (as defined in Rules 13a-15 and 15d-15 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)). Based on this evaluation, the Trustee has concluded that the disclosure controls and procedures of the Trust were effective, as of the end of the period covered by this report, in ensuring that information required to be disclosed by the Trust in the reports that it files or submits under the Exchange Act is accumulated and communicated to the Trustee to allow timely decisions regarding required disclosure.

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 (i) the Trust Agreement and (ii) the Conveyance, the Trustee’s disclosure controls and procedures related to the Trust necessarily rely on (A) information provided by the Sponsor, including information relating to results of operations, the costs and revenues attributable to the Trust’s interest 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 the Net Profits Interest, and (B) conclusions and reports regarding reserves by the Trust’s independent reserve engineers.

Changes in Internal Control over Financial Reporting

During the quarter ended June 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 Trust’s internal control over financial reporting. The Trustee notes for purposes of clarification that it has no authority over, and makes no statement concerning, the internal control over financial reporting of the Sponsor.

PART II—OTHER INFORMATION

Item 1A. Risk Factors.

There have been no material changes to the risk factors contained in Item 1A of the Trust’s 2024 Annual Report on Form 10-K.

Item 5.

Other Information.

Rule 10b5-1 Trading Plans. During the three months ended June 30, 2025, no officer or employee of the Trustee who performs policy-making functions for the Trust adopted, modified, or terminated any Rule 10b5-1 trading arrangement or non-Rule 10b5-1 trading arrangement, as such terms are defined in Item 408(a) of Regulation S-K, with respect to the Trust Units.

Item 6.

Exhibits.

The exhibits listed in the following index to exhibits are filed or furnished as part of this Form 10-Q.

INDEX TO EXHIBITS


Exhibit Number		Description
2.1		Agreement and Plan of Merger of Enduro Royalty Trust and Enduro Texas LLC, dated as of November 3, 2011, by and between the Bank of New York Mellon Trust Company, N.A., as Trustee of Enduro Royalty Trust, and Enduro Texas LLC. (Incorporated herein by reference to Exhibit 1.2 to our Current Report on Form 8-K filed on November 8, 2011 (File No. 1-35333))

3.1		Certificate of Trust of Enduro Royalty Trust. (Incorporated herein by reference to Exhibit 3.3 to the Registration Statement on Form S-1, filed on May 16, 2011 (Registration No. 333-174225))

3.2		Certificate of Amendment to Certificate of Trust. (Incorporated herein by reference to Exhibit 3.1 to the Current Report on Form 8-K filed on September 5, 2018 (File No. 1-35333))

3.3		Amended and Restated Trust Agreement of Enduro Royalty Trust, dated November 3, 2011, among Enduro Resource Partners LLC, The Bank of New York Mellon Trust Company, N.A., as Trustee of Enduro Royalty Trust, and Wilmington Trust Company, as Delaware Trustee of Enduro Royalty Trust. (Incorporated herein by reference to Exhibit 3.1 to our Current Report on Form 8-K filed on November 8, 2011 (File No. 1-35333))

3.4		Second Amendment to Amended and Restated Trust Agreement of Enduro Royalty Trust, dated September 14, 2018, among COERT Holdings 1 LLC, Wilmington Trust Company, as Delaware trustee, and The Bank of New York Mellon Trust Company, N.A., as trustee. (Incorporated herein by reference to Exhibit 3.1 to the Current Report on Form 8-K filed on September 14, 2018 (File No. 1-35333))

31.1*		Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

32.1**		Certification pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

Filed herewith.

Furnished herewith.

SIGNATUREs

Pursuant to the requirements of Section 13 or 15(d) 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.


	PERMIANVILLE ROYALTY TRUST

	By:	THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.

	By:	/s/ SARAH NEWELL
		Sarah Newell
		Vice President and Trust Officer

Date: August 14, 2025

The Registrant, Permianville 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 such function exists pursuant to the terms of the Trust.

SEC Form 10-Q filed by Permianville Royalty Trust