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 March 31, 2025

or

¨        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)

1-512-236-6555 

(Registrant’s telephone number, including area code)

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

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.

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 May 15, 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

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

PERMIANVILLE ROYALTY TRUST

Statements of Assets, Liabilities and Trust Corpus

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

PERMIANVILLE ROYALTY TRUST

Statements of Distributable Income

(unaudited)

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

PERMIANVILLE ROYALTY TRUST

Statements of Changes in Trust Corpus

(unaudited)

 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 March 31, 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:

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 March 31, 2025 and for the three months ended March 31, 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:

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 March 31, 2025 and December 31, 2024 was $312,235,862 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 months ended March 31, 2025, 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 Trust did not make any regular monthly distributions to Trust unitholders during the three months ended March 31, 2025 or 2024 due to the existence of a Net Profits Interest shortfall during each period.

During the three months ended March 31, 2025, direct operating and development expenses exceeded cash receipts, leading to a shortfall of approximately $1.4 million as of March 31, 2025, which will be 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 three months of 2025.

During the three months ended March 31, 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 $1.2 million Net Profits Interest shortfall as of March 31, 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 three months of 2024.

On March 17, 2025, the Trustee declared a special cash distribution of $0.008548 per Trust Unit, payable 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.

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-month periods ended March 31, 2025 and 2024, the Trust paid $50,000 to the Trustee and $2,010 and $0, respectively, to the Delaware Trustee pursuant to the terms of the Trust Agreement.

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:

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:

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 three months of 2025, increasing over 130% from the same period in 2024. Most of the increase reflected continued capital expenditures by a super major oil conglomerate associated with Haynesville wells that are expected to come online in the coming months. Otherwise, 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 expects oil-directed capital expenditures in the Permian basin to decline and gas-directed capital expenditures in the Haynesville to remain stable or perhaps even slightly increase, consistent with the first quarter of 2025. These indications remain subject to revision from the operators of the Underlying Properties; however, in light of the current expectations, the Sponsor continues to maintain its previously established cash reserve for approved, future development expenses expected in the near-term.

The Sponsor believes that the outlook for the oil and gas industry has become increasingly complicated since the start of 2025, especially with the development of trade disputes and indications that OPEC may increase oil production. Oil prices have ranged from just over $80 per Bbl to as low as $57 per Bbl between December 2024 and May 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 believes 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 significant increase in capital expenditures during the first three months of 2025, the Sponsor is revising its 2025 capital spending outlook from the prior range of $7.0 million to $13.0 million, or $5.6 million to $10.4 million net to the Trust’s Net Profits Interest, as detailed in the Trust’s 2024 Annual Report on Form 10-K, to $10.0 million to $15.0 million, or $8.0 million to $12.0 million net to the Trust’s Net Profits Interest. The Sponsor expects the remaining anticipated capital expenditures in 2025 to be focused in the Haynesville area, given relatively strong natural gas prices and ongoing capital expenditure projects in that region which began during 2024. 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 three months of 2025, the Sponsor continued to see a stabilization of inflationary pressures and 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 three months ended March 31, 2025 compared to the same period in 2024. The Sponsor indicates that this decline also benefited from 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.

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

During the three months ended March 31, 2025, direct operating and development expenses exceeded cash receipts, leading to a shortfall of approximately $1.4 million as of March 31, 2025, which will be 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 three months of 2025.

During the three months ended March 31, 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, direct operating and development expenses exceeded revenues, thereby causing net profits attributable to the Underlying Properties to be negative and resulting in an approximately $1.2 million Net Profits Interest shortfall as of March 31, 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 three months of 2024.

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 March 31, 2025 and 2024:

Net (loss) profits attributable to the Underlying Properties for the three months ended March 31, 2025 were $(3.0) million compared to $0.2 million for the three months ended March 31, 2024. The $3.2 million decrease in net profits attributable to the Underlying Properties from the 2024 period to the 2025 period was primarily due to the following items:

For the three months ended March 31, 2025, the Trust withheld $0.0 million and paid $0.2 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 March 31, 2024, the Trust withheld $0.2 million and paid $0.2 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 March 31, 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 three months ended March 31, 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 March 31, 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 $2,216,799 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 March 31, 2025 and December 31, 2024, there were outstanding advances of $398,568 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:

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 March 31, 2025.

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.

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 March 31, 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

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.

Rule 10b5-1 Trading Plans.   During the three months ended March 31, 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.

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

INDEX TO EXHIBITS

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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.

Date: May 15, 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.