[10-Q] HUGOTON ROYALTY TRUST Quarterly Earnings Report

Rhea-AI Filing Summary

Hugoton Royalty Trust reported third‑quarter results showing continued suspension of payouts. Net profits income was $0, yielding distributable income of $0 and per‑unit distributions of $0.000000 for all three monthly record dates in the quarter.

The Trust highlighted substantial doubt about its ability to continue as a going concern. Underlying cumulative excess costs were $21.7 million as of September 30, 2025 ($17.4 million net to the Trust), including accrued interest of $1.7 million ($1.4 million net). Cash and short‑term investments stood at $360,188, held as an expense reserve.

Administrative expense was $107,037 in the quarter, offset by $4,628 of interest income and by using $102,409 from the reserve. The Trust owes $1,060,336 on two advance distributions (including interest) that are recoupable from future net proceeds, subject to a $250,000 minimum cash safeguard. Mach Natural Resources assumed operatorship on April 30, 2025. Units were re‑listed on the OTCQB after filing delays were resolved. Units outstanding were 40,000,000 as of November 13, 2025.

Insights

Distressed credit and royalty trust analyst

Going‑concern risk persists with rising excess costs and minimal cash.

Hugoton Royalty Trust posted $0 net profits income and continued $0 distributions. Excess costs across Kansas, Oklahoma, and Wyoming totaled $21.7 million underlying ($17.4 million net), including accrued interest of $1.7 million ($1.4 million net). With cash and short‑term investments of $360,188, the Trust is funding admin needs from its reserve.

The filing states substantial doubt about continuing as a going concern. Two recoupable advances total $1,060,336 (including interest) and must be repaid from future net proceeds while maintaining at least $250,000 cash. Whether net proceeds resume depends on future revenues versus costs and recovery of excess costs.

The operator changed to Mach Natural Resources on April 30, 2025. Actual impact will reflect future production, prices, and costs. The Trustee notes it is reviewing alternatives, which could include a sale or termination requiring at least 80% unitholder approval.

Table of Contents

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended September 30, 2025

OR

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

For the transition period from to .

HUGOTON ROYALTY TRUST

(Exact name of registrant as specified in its charter)

Texas	1-10476	58-6379215
(State or other jurisdiction of incorporation or organization)	(Commission File Number)	(I.R.S. Employer Identification No.)

c/o The Corporate Trustee:

Argent Trust Company

3838 Oak Lawn Ave, Suite 1720

Dallas, Texas 75219-4518

(Address of principal executive offices) (Zip Code)

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

(Former name, former address and former fiscal year, if change since last report)

Securities registered pursuant to Section 12(b) of the Act: None

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

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

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

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

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

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

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

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

Indicate the number of units of beneficial interest outstanding, as of the latest practicable date:

Outstanding as of November 13, 2025

40,000,000

Table of Contents

HUGOTON ROYALTY TRUST

FORM 10-Q FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2025

TABLE OF CONTENTS

Glossary of Terms		3
PART I ‑ FINANCIAL INFORMATION		4
Item 1.	Financial Statements (Unaudited)	4
	Condensed Statements of Assets, Liabilities and Trust Corpus at September 30, 2025 and December 31, 2024	5
	Condensed Statements of Distributable Income for the Three and Nine Months Ended September 30, 2025 and 2024	6
	Condensed Statements of Changes in Trust Corpus for the Three and Nine Months Ended September 30, 2025 and 2024	7
	Notes to Condensed Financial Statements	8
Item 2.	Trustee’s Discussion and Analysis	13
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	20
Item 4.	Controls and Procedures	20
PART II - OTHER INFORMATION		21
Item 1.	Legal Proceedings	21
Item 1A.	Risk Factors	21
Item 5.	Other Information	22
Item 6.	Exhibits	22
Signatures		23

Table of Contents

HUGOTON ROYALTY TRUST

GLOSSARY OF TERMS

The following are definitions of significant terms used in this Form 10-Q:

Bbl		Barrel (of oil)
Mcf		Thousand cubic feet (of natural gas)
MMBtu		One million British Thermal Units, a common energy measurement
net proceeds		Gross proceeds received by XTO Energy or its successor, Mach Natural Resources (“Mach”), from sale of production from the underlying properties, less applicable costs, as defined in the net profits interest conveyances.
net profits income		Net proceeds multiplied by the net profits percentage of 80%, which is paid to the Trust by Mach, successor to XTO Energy. “Net profits income” is referred to as “royalty income” for income tax purposes.
net profits interest		An interest in an oil and gas property measured by net profits from the sale of production, rather than a specific portion of production. The following defined net profits interests were conveyed to the Trust from the underlying properties:
		80% net profits interests- interests that entitle the Trust to receive 80% of the net proceeds from the underlying properties.
underlying properties		XTO Energy, succeeded by Mach’s interest in certain oil and gas properties from which the net profits interests were conveyed. The underlying properties include working interests in predominantly gas-producing properties located in Kansas, Oklahoma and Wyoming.
working interest		An operating interest in an oil and gas property that provides the owner a specified share of production that is subject to all production expense and development costs.

3

Table of Contents

HUGOTON ROYALTY TRUST

PART I ‑ FINANCIAL INFORMATION

Item 1. Financial Statements

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

4

Table of Contents

HUGOTON ROYALTY TRUST

Condensed Statements of Assets, Liabilities and Trust Corpus (Unaudited)

		September 30,				December 31,
		2025				2024
ASSETS
Cash and short-term investments		$	360,188			$	233,736
Net profits interests in oil and gas properties - net (Note 1)			—				—
		$	360,188			$	233,736
LIABILITIES AND TRUST CORPUS
Distribution payable to unitholders		$	—			$	—
Expense reserve (a)(b)			360,188				233,736
Trust corpus (40,000,000 units of beneficial interest authorized    and outstanding)			—				—
		$	360,188			$	233,736

(a)The expense reserve allows the Trustee to pay its obligations should it be unable to pay them out of the net profits income.

(b)Expense reserve partially replenished by advance distribution of $500,000 from XTO Energy that was part of the Settlement Agreement between the Trust and XTO Energy as well as the second advance distribution of $500,000 from XTO Energy that was disbursed to the Trust on April 30, 2025. See Note 5 to Condensed Financial Statements.

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

5

Table of Contents

HUGOTON ROYALTY TRUST

Condensed Statements of Distributable Income (Unaudited)

		Three Months Ended September 30								Nine Months Ended September 30,
		2025				2024				2025				2024
Net profits income		$	—			$	—			$	—			$	—
Interest income			4,628				4,710				9,499				11,220
Total income			4,628				4,710				9,499				11,220
Administration expense			107,037				171,655				383,046				513,801
Cash reserves withheld (used) for Trust expenses			(102,409	)			(166,945	)			(373,547	)			(502,581	)
Distributable income		$	—			$	—			$	—			$	—
Distributable income per unit (40,000,000 units)		$	0.000000			$	0.000000			$	0.000000			$	0.000000

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

6

Table of Contents

HUGOTON ROYALTY TRUST

Condensed Statements of Changes in Trust Corpus (Unaudited)

		Three Months Ended September 30								Nine Months Ended September 30,
		2025				2024				2025				2024
Trust corpus, beginning of period		$	—			$	—			$	—			$	—
Distributable income			—				—				—				—
Distributions declared			—				—				—				—
Trust corpus, end of period		$	—			$	—			$	—			$	—

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

7

Table of Contents

HUGOTON ROYALTY TRUST

Notes to Condensed Financial Statements (Unaudited)

1.Basis of Accounting

The financial statements of Hugoton Royalty Trust (the “Trust”) are prepared on the following basis and are not intended to present the financial position and results of operations in conformity with U.S. generally accepted accounting principles (“U.S. GAAP”):

-	Net profits income recorded for a month is the amount computed and paid by XTO Energy Inc. (“XTO Energy”) or Mach Natural Resources (“Mach”), as applicable, the owner of the underlying properties, to Argent Trust Company, as trustee (the “Trustee”) for the Trust. XTO Energy is a wholly owned subsidiary of Exxon Mobil Corporation. Net profits income consists of net proceeds received by XTO Energy or Mach, as applicable, from the underlying properties in the prior month, multiplied by a net profits percentage of 80%. The primary production month for XTO Energy is two months prior to the distribution month, and the primary production month for Mach is three months prior to the distribution month.
-	Costs deducted in the calculation of net proceeds for the 80% net profits interests generally include applicable taxes, transportation, marketing and legal costs, production expense, development costs, operating charges and other costs.
-	Net profits income is computed separately for each of the three conveyances under which the net profits interests were conveyed to the Trust. If monthly costs exceed revenues for any conveyance, such excess costs must be recovered, with accrued interest, from future net proceeds of that conveyance and cannot reduce net proceeds from the other conveyances.
-	Interest income and distribution payable to unitholders include interest earned on the previous month’s investment.
-	Trust expenses are recorded based on liabilities paid and cash reserves established by the Trustee for liabilities and contingencies.
-	Distributions to unitholders are recorded when declared by the Trustee.

The Trust’s financial statements differ from those prepared in conformity with U.S. GAAP because revenues are recognized when received rather than accrued in the month of production, expenses are recognized when paid rather than when incurred and certain cash reserves may be established by the Trustee for contingencies which would not be recorded under U.S. GAAP. This comprehensive basis of accounting other than U.S. GAAP corresponds to the accounting permitted for royalty trusts by the U.S. Securities and Exchange Commission, as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts.

Most accounting pronouncements apply to entities whose financial statements are prepared in accordance with U.S. GAAP, directing such entities to accrue or defer revenues and expenses in a period other than when such revenues were received or expenses were paid. Because the Trust’s financial statements are prepared on the modified cash basis, as described above, most accounting pronouncements are not applicable to the Trust’s financial statements.

Changes in Ownership of Underlying Properties

XTO Energy has informed the Trustee that it closed the divestment of XTO Energy’s interest in the assets underlying the Trust to Mach on April 30, 2025. Mach has assumed XTO Energy’s obligations under the Trust Indenture and operatorship of applicable properties.

Net profits interests in oil and gas properties

The initial carrying value of the net profits interests of $247,066,951 represents XTO Energy’s historical net book value for the interests on December 1, 1998, the date of the transfer to the Trust. During the second quarter 2016, the carrying

8

Table of Contents

value of the net profits interests was written down to its fair value of $28,801,000, resulting in an impairment of $57,306,527 charged directly to trust corpus. During the third quarter 2019, the carrying value of the net profits interests was written down to its fair value of zero, resulting in an impairment of $15,681,533 charged directly to trust corpus. Amortization of the net profits interests is calculated on a unit-of-production basis using proved reserves and is charged directly to trust corpus. Accumulated amortization was $174,078,891 as of September 30, 2019, when the net profits interests was written down to its fair value of zero.

Liquidity and Going Concern

The accompanying condensed financial statements have been prepared assuming that the Trust will continue as a going concern. Financial statements prepared on a going concern basis assume the realization of assets and the settlement of liabilities in the normal course of business. However, substantial doubt about the Trust's ability to continue as a going concern exists.

Accumulated excess costs for the Kansas, Oklahoma and Wyoming conveyances have resulted in insufficient net proceeds to the Trust which have resulted in no unitholder distributions since July 2023, and a reduction in the Trust’s expense reserve. As a result of these conditions the Trust may not have sufficient cash to meet its obligations during the one-year period after the financial statements are issued. Factors attributable to the cash shortage are primarily the previously disclosed development costs to drill four non-operated wells in Major County, Oklahoma, lower oil and natural gas prices, and excess cost positions on the Kansas, Oklahoma and Wyoming conveyances including accumulated interest.

The Trustee has prepared a preliminary budget estimating the administrative expenses for the year ending December 31, 2025, and through November 30, 2026, which assumes no cash inflow from either net profits income or from other sources other than the $500,000 advance distribution received in second quarter 2024 from the Settlement Agreement with XTO Energy and the $500,000 second advance distribution from XTO Energy received second quarter 2025, as described in Note 5 to Condensed Financial Statements. Based on the preliminary budget, the Trust’s cash reserves may be depleted during the one-year period after the financial statements are issued. Once the Trust's cash reserves are depleted, the Trust will likely be unable to continue to make SEC filings, provide reporting to unitholders or provide audited financial statements or third-party reserve reports. To help control costs, the Trustee has reviewed all administrative functions and has attempted to reduce or eliminate costs for functions other than those required to comply with SEC regulations or the Trust Indenture; however, there can be no assurance that there will be sufficient funds available to continue such functions in the future. To further reduce administrative costs to the Trust, the Trustee has deferred payment of its monthly fee of approximately $7,300 since April 2024, and approximately $8,000 since April 2025. Nothing in the Trust Indenture obligates the Trustee to pay for the Trust's expenses if the Trust's expense reserve were to be completely depleted, and the Trustee currently does not intend to advance funds to the Trust.

As previously disclosed, the Trustee has reviewed and may in the future review financing as an option to pay Trust obligations during the one-year period after the date the financial statements are issued; however, there can be no assurance that financing will be available on acceptable terms or at all. If financing became available to the Trust, it would have to be repaid, together with interest, and the Trust’s expense reserve would have to be replenished prior to any distributions to unitholders. The Trustee has sought sources of financing, but currently believes that financing in an amount sufficient to satisfy the Trust's long term liquidity needs is unlikely to be a viable option for the Trust moving forward. As a result, the Trustee has reviewed and intends to continue to review options for the Trust which may include alternatives to continuing as a going concern such as seeking to terminate the Trust or marketing the Trust's interest (which are net profits interests burdened by excess costs) for a potential sale. The Trustee has reached out to potential third parties regarding interest in the Trust's assets but no interest has resulted from such discussions. As a result, the Trustee believes a potential sale of the Trust's assets may be unlikely in the near term; however, it will continue to consider any and all viable options. Even if a sale of the Trust assets were to occur, there is no assurance that the proceeds would result in funds to distribute to unitholders after all financial obligations of the Trust are met. Any material sale of assets and/or termination of the Trust requires unitholder approval by at least 80 percent of all outstanding units.

On July 9, 2020, the Trustee notified XTO Energy of the Trustee’s claim to indemnification to the Trust Estate for all liability, expense, claims, damages or loss incurred by the Trustee in connection with the administration of the Trust.

9

Table of Contents

The Trustee stated it anticipates seeking reimbursement from XTO Energy upon depletion of the Trust’s cash reserve. XTO Energy responded that any indemnity claim to XTO Energy is premature before the Trust Estate is exhausted. XTO Energy's position remains unchanged. XTO Energy and Mach have informed the Trustee that they currently have no intention of providing any additional financing or extending any credit to the Trustee or the Trust Estate beyond the outstanding advance distributions made by XTO Energy in second quarter 2024 and second quarter 2025 that must be repaid from any future net proceeds. See Note 5 to the Condensed Financial Statements for further information on the advance distributions.

The Trust’s financial statements do not include any adjustments that might result from the outcome of these uncertainties.

2.Income Taxes

For federal income tax purposes, the Trust constitutes a fixed investment trust that is taxed as a grantor trust. A grantor trust is not subject to tax at the trust level. Accordingly, no provision for income taxes has been made in the financial statements. The unitholders are considered, for federal income tax purposes, to own the Trust’s income and principal as though no trust were in existence. The income of the Trust is deemed to have been received or accrued by each unitholder at the time such income is received or accrued by the Trust and not when distributed by the Trust. Impairments recorded for book purposes will not result in a loss for tax purposes for the unitholders until the loss is recognized.

On July 4, 2025, the One Big Beautiful Bill Act ("OBBBA") was signed into law. The OBBBA includes significant federal income tax provisions, such as the permanent extension of the income tax rates set by the Tax Cuts and Jobs Act, the continued suspension of miscellaneous itemized deductions and the restoration of favorable tax treatment for certain business provisions. The legislation has multiple effective dates, with certain provisions effective in 2025 and others implemented through 2027. Each unitholder should consult their own tax advisor regarding the potential tax consequences of the OBBBA and its impact on such person's ownership of Trust units.

All revenues from the Trust are from sources within Kansas, Oklahoma or Wyoming. Because the Trust distributes all of its net income to unitholders, the Trust has not been taxed at the trust level in Kansas or Oklahoma. While the Trust has not owed tax, the Trustee is generally required to file Kansas and Oklahoma income tax returns reflecting the income and deductions of the Trust attributable to properties located in each state, along with a schedule that includes information regarding distributions to unitholders. However, the Trust did not file Kansas and Oklahoma income tax returns for the 2024 tax year due to the fact that there were no revenues attributable to properties located in Kansas and Oklahoma in that time period.

Wyoming does not impose a state income tax.

Each unitholder should consult their own tax advisor regarding income tax requirements, if any, applicable to such person’s ownership of Trust units.

Unitholders should consult the Trust’s latest Annual Report on Form 10-K for a more detailed discussion of federal and state tax matters.

3.Contingencies

Litigation

Lawsuits and Governmental Proceedings

Certain of the underlying properties are involved in various lawsuits and governmental proceedings arising in the ordinary course of business. XTO Energy and Mach have advised the Trustee that, based on the information available at

10

Table of Contents

this stage of the various proceedings, it does not believe that the ultimate resolution of these claims will have a material effect on the financial position or liquidity of the Trust, but may have an effect on annual distributable income.

Other

Several states have enacted legislation requiring state income tax withholding from payments made to nonresident recipients of oil and gas proceeds. After consultation with its tax counsel, the Trustee believes that it is not required to withhold on payments made to the unitholders. However, regulations are subject to change by the various states, which could change this conclusion. Should amounts be withheld on payments made to the Trust or the unitholders, distributions to the unitholders would be reduced by the required amount, subject to the filing of a claim for refund by the Trust or unitholders for such amount.

11

Table of Contents

4.Excess Costs

If monthly costs exceed revenues for any of the three conveyances (one for each of the states of Kansas, Oklahoma and Wyoming), such excess costs must be recovered, with accrued interest, from future net proceeds of that conveyance and cannot reduce net proceeds from other conveyances.

The following summarizes excess costs activity, cumulative excess costs balances and accrued interest to be recovered by conveyance as calculated by XTO Energy and Mach:

		Underlying
		KS				OK				WY				Total
Cumulative excess costs remaining at 12/31/24		$	1,263,171			$	1,093,891			$	7,421,195			$	9,778,257
Net excess costs (recovery) for the quarter ended 3/31/25			345,989				719,354				232,001				1,297,344
Net excess costs (recovery) for the quarter ended 6/30/25			244,538				3,594,804				832,707				4,672,049
Net excess costs (recovery) for the quarter ended 9/30/25			481,351				2,489,021				1,286,935				4,257,307
Cumulative excess costs remaining at 9/30/25			2,335,049				7,897,070				9,772,838				20,004,957
Accrued interest at 9/30/25			219,821				632,633				873,033				1,725,487
Total remaining to be recovered at 9/30/25		$	2,554,870			$	8,529,703			$	10,645,871			$	21,730,444
		NPI
		KS				OK				WY				Total
Cumulative excess costs remaining at 12/31/24		$	1,010,537			$	875,113			$	5,936,955			$	7,822,605
Net excess costs (recovery) for the quarter ended 3/31/25			276,791				575,483				185,601				1,037,875
Net excess costs (recovery) for the quarter ended 6/30/25			195,630				2,875,843				666,166				3,737,639
Net excess costs (recovery) for the quarter ended 9/30/25			385,081				1,991,217				1,029,548				3,405,846
Cumulative excess costs remaining at 9/30/25			1,868,039				6,317,656				7,818,270				16,003,965
Accrued interest at 9/30/25			175,857				506,107				698,426				1,380,390
Total remaining to be recovered at 9/30/25		$	2,043,896			$	6,823,763			$	8,516,696			$	17,384,355

For the quarter ended September 30, 2025, excess costs were $481,351 ($385,081 net to the Trust) on properties underlying the Kansas net profits interests.

For the quarter ended September 30, 2025, excess costs were $2,489,021 ($1,991,217 net to the Trust) on properties underlying the Oklahoma net profits interests. The excess costs balance includes items from the Settlement Agreement that were recorded in third quarter 2024.

For the quarter ended September 30, 2025, excess costs were $1,286,935 ($1,029,548 net to the Trust) on properties underlying the Wyoming net profits interests.

Underlying cumulative excess costs for the Kansas, Oklahoma and Wyoming conveyances remaining as of September 30, 2025, totaled $21.7 million ($17.4 million net to the Trust), including accrued interest of $1.7 million ($1.4 million net to the Trust).

12

Table of Contents

5.Advance Distribution

In the second quarter of 2024, XTO Energy provided the Trust an advance distribution of $500,000 (net to the Trust) that was part of the Settlement Agreement between the Trust and XTO Energy, that can be treated as a production cost, except that it can be recouped, together with interest, from what would otherwise be distributable net profits under any of the three conveyances; provided, however that recoupment from net proceeds shall only be permitted to the extent that such recoupment does not leave the Trust with less than $250,000 of available cash. Mach has assumed the right to recoup this advance following the conveyance of XTO Energy's interest on April 30, 2025.

		NPI
		Total
Advance Distribution at 9/30/25		$	500,000
Accrued interest at 9/30/25			47,579
Total remaining to be recovered at 9/30/25		$	547,579

In the second quarter of 2025, XTO Energy provided the Trust a second advance distribution of $500,000 (net to the Trust) that was intended to provide the Trustee of the Trust with liquidity to meet current and near-term financial reporting obligations. The second advance distribution can be recouped, together with interest, from what would otherwise be distributable net profits under any of the three conveyances; provided, however that recoupment from net proceeds shall only be permitted to the extent that such recoupment does not leave the Trust with less than $250,000 of available cash. Mach has assumed the right to recoup this advance following the conveyance of XTO Energy's interest on April 30, 2025.

		NPI
		Total
Advance Distribution at 9/30/25			500,000
Accrued interest at 9/30/25			12,757
Total remaining to be recovered at 9/30/25		$	512,757

The total owed by Hugoton Royalty Trust for both advance distributions is $1,060,336, which includes accrued interest of $60,336.

6.Administration Expense

Administrative expenses are incurred so that the Trustee may meet its reporting obligations to the unitholders and regulatory entities and otherwise manage the administrative functions of the Trust. These obligations include, but are not limited to, all expenses, taxes, compensation to the Trustee for managing the Trust, fees to consultants, accountants, attorneys, transfer agents, other professional and expert persons, expenses for clerical and other administrative assistance, and fees and expenses for all other services.

Item 2. Trustee’s Discussion and Analysis

The following discussion should be read in conjunction with the Trustee’s discussion and analysis contained in the Trust’s 2024 Annual Report on Form 10-K, as well as the condensed financial statements and notes thereto included in this Quarterly Report on Form 10-Q. The Trust’s Annual Report on Form 10-K, Quarterly Reports on Form 10‑Q, Current Reports on Form 8-K and all amendments to those reports are available on the Trust’s website at www.hgt-hugoton.com.

13

Table of Contents

Recent Updates

Change In Trading Markets

In June 2025, due to the Trust's inability to file its quarterly report on Form 10-Q for the quarter ended March 31, 2025 and resulting non-compliance with SEC regulations, Trust units were de-listed from the OTCQB and began to be quoted on the OTC Pink Market (“OTC Pink”), which is maintained by the OTC Mark Group, Inc. Once the quarterly reports on Form 10-Q for both the first and second quarters were filed, the Trustee applied for and was granted the ability to re-list on the OTCQB. The units still trade under the symbol “HGTXU”.

14

Table of Contents

Results of Operations

Distributable Income

Quarter

For the quarter ended September 30, 2025, net profits income was $0 compared to $0 for third quarter 2024. This was primarily the result of decreased oil and gas production ($3.6 million), increased overhead ($0.7 million), lower oil prices ($.6 million) and increased taxes, transportation and other costs ($0.1 million), partially offset by lower production expense and development cost ($1.8 million), net excess costs activity ($1.5 million), higher gas prices ($1.6 million) and decreased development costs ($0.2 million). See “Net Profits Income” below.

After adding interest income of $4,628, deducting administration expense of $107,037, and utilizing $102,409 of the cash reserve for the payment of Trust expenses, distributable income for the quarter ended September 30, 2025, was $0 or $0.000000 per unit of beneficial interest. Administration expense for the quarter decreased $64,618 compared to the prior year quarter, primarily related to the timing of receipt and payment of Trust expenses and terms of professional services. Changes in interest income are attributable to fluctuations in net profits income, cash reserve and interest rates. For third quarter 2024, distributable income was $0 or $0.000000 per unit.

Distributions to unitholders for the quarter ended September 30, 2025, were:

Record Date		Payment Date		Distribution per Unit
July 31, 2025		August 14, 2025		$	0.000000
August 29, 2025		September 15, 2025			0.000000
September 30, 2025		October 15, 2025			0.000000
				$	0.000000

Nine Months

For the nine months ended September 30, 2025, net profits income was $0 compared with $0 for the same 2024 period primarily due to decreased oil and gas production ($3.1 million), increased development costs ($2.7 million), increased taxes, transportation, and other costs ($1.1 million), lower oil prices ($1.0 million), increased overhead ($0.9 million), partially offset by higher natural gas prices ($3.8 million), net excess costs activity ($3.2 million), and decreased production expense ($1.8 million). See “Net Profits Income” below.

After adding interest income of $9,499 and deducting administration expense of $383,046, and utilizing $373,547 of the cash reserve for the payment of Trust expenses, distributable income for the nine months ended September 30, 2025, was $0 or $0.000000 per unit of beneficial interest. Administration expense for the nine months ended September 30, 2025, decreased $130,755 as compared to the same 2024 period, primarily related to the timing of receipt and payment of Trust expenses and terms of professional services. Changes in interest income are attributable to fluctuations in net profits income, cash reserve and interest rates. For the nine months ended September 30, 2024, distributable income was $0 or $0.000000 per unit.

Based on current excess costs, the Trustee does not foresee any distributions in the near term.

15

Table of Contents

Net Profits Income

Net profits income is recorded when received by the Trust, which is the month following receipt by XTO Energy and Mach, and generally two months after oil and gas production for XTO Energy and three months after oil and gas production for Mach. Net profits income is generally affected by three major factors:

1.	oil and gas sales volumes,
2.	oil and gas sales prices, and
3.	costs deducted in the calculation of net profits income.

16

Table of Contents

The following is a summary of the calculation of net profits income received by the Trust:

		Three Months Ended								Nine Months
		September 30 (a)						Increase		September 30 (a)					Increase
			2025			2024		(Decrease)		2025			2024		(Decrease)
Sales Volumes
Gas (Mcf) (b)
Underlying properties			1,253,345			2,133,138		(41%)		5,310,839			6,103,166		(13%)
Average per day			14,083			23,186		(39%)		19,670			22,274		(12%)
Net profits interests			—			—		—		—			—		—
Oil (Bbls) (b)
Underlying properties			26,895			51,512		(48%)		125,025			140,314		(11%)
Average per day			302			560		(46%)		463			512		(10%)
Net profits interests			—			—		—		—			—		—
Average Sales Prices
Gas (per Mcf)		$	3.32		$	2.40		38%		$3.65			$2.87		27%
Oil (per Bbl)		$	61.99		$	75.84		(18%)		$65.53			$74.78		(12%)
Revenues
Gas sales		$	4,163,250		$	5,115,614		(19%)		$19,374,401			$17,499,744		11%
Oil sales			1,667,148			3,906,813		(57%)		8,192,491			10,492,601		(22%)
Total Revenues			5,830,398			9,022,427		(35%)		27,566,892			27,992,345		(2%)
Costs
Taxes, transportation and other			1,887,963			1,747,086		8%		7,271,502			5,902,701		23%
Production expense			4,210,368			6,233,224		(32%)		14,847,282			17,148,793		(13%)
Development costs			214,601			469,797		(54%)		5,095,716			1,749,709		191%
Overhead			3,774,773			2,929,000		29%		10,597,334			9,465,993		12%
Excess costs (c)			(4,257,307)			(2,331,003)		83%		(10,226,700)			(6,249,174)		64%
Total Costs			5,830,398			9,048,104		(36%)		27,585,134			28,018,022		(2%)
Other Proceeds			—			25,677		(100%)		18,242			25,677		(29%)
Net Proceeds			—			—		—		—			—		—
Net Profits Percentage			80%			80%				80%			80%
Net Profits Income		$	—		$	—		—	$	—		$	—		—

(a)Because of the two-month interval between time of production and receipt of net profits income by the Trust, (1) gas and oil sales for the quarter ended September 30, 2025, generally represent production for the period May and June, and for the quarter ended September 30, 2024, generally represent production for the period May through July, respectively, and (2) gas and oil sales for the nine months ended September 30, 2025, generally represent production for the period November through June, and for the nine months ended September 30, 2024, generally represent production for the period November through July, respectively.

(b)Gas and oil sales volumes are allocated to the net profits interests by dividing Trust net cash inflows by average sales prices. As gas and oil prices change, the Trust’s allocated production volumes are impacted as the quantity of production necessary to cover expenses changes inversely with price. As such, the underlying property production volume changes may not correlate with the Trust’s allocated production volumes in any given period. Therefore, comparative discussion of gas and oil sales volumes is based on the underlying properties.

(c)See Note 4 to Condensed Financial Statements.

17

Table of Contents

The following are explanations of significant variances on the underlying properties from third quarter 2024 to third quarter 2025 and from the first nine months of 2024 to the comparable period in 2025:

Sales Volumes

Gas

Gas sales volumes decreased 41 percent for third quarter 2025 and decreased 13 percent for the nine-month period as compared with the same 2024 periods primarily because of change in the timing of oil and gas sales relating to the Mach acquisition of the Trust’s underlying properties, along with cash receipts and natural production decline, partially offset by the timing of cash receipts.

Oil

Oil sales volumes decreased 48 percent for third quarter 2025 and decreased 11 percent for the nine-month period as compared with the same 2024 periods primarily because of change in the timing of oil and gas sales relating to the Mach acquisition of the Trust’s underlying properties along with natural production decline, partially offset by timing of cash receipts.

The estimated rate of natural production decline on the underlying oil and gas properties is approximately six to eight percent a year.

Sales Prices

Gas

The third quarter 2025 average gas price was $3.32 per Mcf, a 38 percent increase from the third quarter 2024 average gas price of $2.40 per Mcf. For the nine-month period, the average gas price increased 27 percent to $3.65 per Mcf in 2025 from $2.87 per Mcf in 2024.

Oil

The third quarter 2025 average oil price was $61.99 per Bbl, an 18 percent decrease from the third quarter 2024 average oil price of $75.84 per Bbl. The year-to-date average oil price decreased 12 percent to $65.53 per Bbl in 2025 from $74.78 per Bbl in 2024.

Costs

Taxes, Transportation and Other

Taxes, transportation and other costs increased eight percent and 23 percent for third quarter and for the nine-month periods in 2025, respectively, as compared with the same 2024 periods primarily because of the change in accounting period from a three-month lag to a two-month lag due to the change in operator to Mach, partially offset by decreased gas production taxes and gas deductions due to lower revenues.

Production Expense

Production expense decreased 32 percent for third quarter 2025 primarily because of the Chieftain Settlement in 2024, partially offset by the change in accounting period from a three month lag to a two-month lag due to the change in operator to Mach. Production expense decreased 13 percent for the nine-month period as compared with the same 2024 period primarily because of increased labor costs, the change in accounting period from a three month lag to a two-month lag due to the change in operator to Mach, partially offset by the absence of the Chieftain Settlement.

18

Table of Contents

Development Costs

Development costs decreased 54 percent for third quarter 2025 and increased 191 percent for the nine-month period primarily due to the timing of drilling costs related to non-operated wells in Major County, Oklahoma. Changes in oil or natural gas prices could impact future development plans on the underlying properties.

As previously disclosed, XTO Energy advised the Trustee that it elected to participate in the development of four non-operated wells in Major County, Oklahoma. XTO Energy advised the Trustee that the total development costs for the four non-operated wells was anticipated to be approximately $10 million underlying ($8 million net to the Trust). Two wells were completed in second quarter of 2024, the third was completed in fourth quarter 2024, and the fourth was completed in first quarter 2025. No assurances can be made as to the estimated costs of the non-operated wells or timing of receipt of costs for completing the wells.

Mach has advised the Trustee that it does not have a development budget finalized for the properties underlying the Hugoton Royalty Trust at this time.

Overhead

Overhead increased 29 percent for third quarter 2025 and increased 12 percent for the nine-month period, mainly due to the change in accounting period from a three month lag to a two-month lag due to the change in operator to Mach. Overhead is charged by XTO Energy, Mach and other operators for administrative expenses incurred to support operations of the underlying properties. Overhead fluctuates based on changes in the active well count and drilling activity on the underlying properties, as well as an annual cost level adjustment based on an industry index.

Excess Costs

If monthly costs exceed revenues for any conveyance, these excess costs must be recovered, with accrued interest, from future net proceeds of that conveyance and cannot reduce net profits income from another conveyance. Underlying cumulative excess costs for the Kansas, Oklahoma and Wyoming conveyances remaining as of September 30, 2025, totaled $21.7 million ($17.4 million net to the Trust), including accrued interest of $1.7 million ($1.4 million net to the Trust). For further information on excess costs, see Note 4 to Condensed Financial Statements.

Other Proceeds

The calculation of net profits income for the nine months ended September 30, 2025, included $18,242 ($14,594 net to the Trust) from XTO Energy due to interest received on past due payments. The calculation of net profits income for the quarter and nine-month period ended September 30, 2024, included $25,677 ($20,542 net to the Trust) from XTO Energy due to interest received on past due payments.

Contingencies

For information on contingencies, see Note 3 to Condensed Financial Statements.

Forward-Looking Statements

Certain information included in this Quarterly Report and other materials filed, or to be filed, by the Trust with the Securities and Exchange Commission (as well as information included in oral statements or other written statements made or to be made by XTO Energy, Mach or the Trustee) contain forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended, and Section 27A of the Securities Act of 1933, as amended, relating to the Trust, operations of the underlying properties and the oil and gas industry. Such forward-looking statements may concern, among other things, excess costs, continuation of the Trust as a going-concern, or alternatives to a going-concern, listing of the Trust units reserve-to-production ratios, future production, development activities and associated operating expenses, future development plans by area, increased density drilling, maintenance projects, development, production, regulatory and other costs, oil and gas prices and expectations for future demand, the impact of inflation and economic downturns on

19

Table of Contents

economic activity, government policy and its impact on oil and gas prices and future demand, the development and competitiveness of alternative energy sources, pricing differentials, proved reserves, future net cash flows, production levels, expense reserve budgets, availability of financing, arbitration, litigation, liquidity, financing, political and regulatory matters, such as tax and environmental policy, climate policy, trade barriers, sanctions, tariffs, competition, war and other political or security disturbances. Such forward-looking statements are based on XTO Energy’s, Mach and the Trustee’s current plans, expectations, assumptions, projections and estimates and are identified by words such as “may,” “intends,” “plans,” “anticipates,” “believes,” “estimates,” “should,” “could,” “would,” and similar words that convey the uncertainty of future events. These statements are not guarantees of future performance and involve certain risks, uncertainties and assumptions that are difficult to predict, including those detailed in Part I, Item 1A of the Trust’s Annual Report on Form 10-K for the year ended December 31, 2024, which is incorporated by this reference as though fully set forth herein. Therefore, actual financial and operational results may differ materially from expectations, estimates or assumptions expressed in, implied in, or forecasted in such forward-looking statements. XTO Energy, Mach and the Trustee assume no duty to update these statements as of any future date.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Not applicable. Upon qualifying as a smaller reporting company, this information is no longer required.

Item 4. Controls and Procedures

As of the end of the period covered by this report, the Trustee carried out an evaluation of the effectiveness of the Trust’s disclosure controls and procedures pursuant to Exchange Act Rules 13a-15 and 15d-15. Based upon that evaluation, the Trustee concluded that the Trust’s disclosure controls and procedures are effective in recording, processing, summarizing and reporting, on a timely basis, information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 and are effective in ensuring that information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 is accumulated and communicated to the Trustee to allow timely decisions regarding required disclosure. In its evaluation of disclosure controls and procedures, the Trustee has relied, to the extent considered reasonable, on information provided by XTO Energy and Mach. There has not been any change in the Trust’s internal control over financial reporting during the period covered by this report that has materially affected, or is reasonably likely to materially affect, the Trust’s internal control over financial reporting.

20

Table of Contents

PART II - OTHER INFORMATION

Item 1. Legal Proceedings

Lawsuits and Governmental Proceedings

Certain of the underlying properties are involved in various lawsuits and governmental proceedings arising in the ordinary course of business. XTO Energy and Mach have both advised the Trustee that, based on the information available at this stage of the various proceedings, it does not believe that the ultimate resolution of these claims will have a material effect on the financial position or liquidity of the Trust, but may have an effect on annual distributable income.

Item 1A. Risk Factors

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

The Trust may not have sufficient cash to meet its obligations during the one-year period after the date that the financial statements are issued, and the Trustee has reviewed and intends to continue to review alternatives to the Trust continuing as a going concern.

All three of the Trust’s conveyances are in excess costs resulting in no net proceeds to the Trust and a reduction in the Trust’s expense reserve, which have resulted in no unitholder distributions since July 2023. As a result of these conditions, substantial doubt exists about the Trust’s ability to continue as a going concern as the Trust may not have sufficient cash to meet its obligations during the one-year period after the date the financial statements are issued. The Trust’s financial statements do not include any adjustments that might result from the outcome of this uncertainty. Pursuant to the Settlement Agreement, XTO Energy has advanced $500,000 to the Trust and pursuant to the Advance Distribution Agreement, XTO Energy has advanced an additional $500,000 to the Trust (which advances may be recouped by Mach, who has assumed the right to recoup this advance following the conveyance of XTO Energy’s interest on April 30, 2025, together with interest from what would otherwise be distributable net profits under any of the three conveyances; provided, however, that such recoupment does not leave the Trust with less than $250,000 of available cash). There are no assurances that even with such advances, the Trust will receive net profits income sufficient to pay its obligations during the one-year period after the date the financial statements are issued. The Trustee has sought sources of financing, but currently believes that financing in an amount sufficient to satisfy the Trust's long-term liquidity needs is unlikely to be a viable option for the Trust moving forward. Nothing in the Trust Indenture obligates the Trustee to pay for the Trust’s expenses if the Trust’s cash reserves were to be completely depleted, and the Trustee currently does not intend to advance funds to the Trust. As a result, the Trustee has reviewed and intends to continue to review options for the Trust, which may include alternatives to the Trust continuing as a going concern such as seeking to terminate the Trust or marketing the Trust’s interests (which are net profits interests burdened by excess costs) for a potential sale. The Trustee has reached out to potential third parties regarding interest in the Trust’s assets, but no interest has resulted from such discussions. As a result, the Trustee believes a potential sale of the Trust’s assets may be unlikely in the near term; however, it will continue to consider any and all viable options. Even if a sale of the Trust assets were to occur, there is no assurance that the proceeds would result in funds to distribute to unitholders after all financial obligations of the Trust are met. Any material sale of assets and/or termination of the Trust requires unitholder approval by at least 80 percent of all outstanding units. Once the Trust's cash reserves are depleted, the Trust will likely be unable to continue to make SEC filings, provide reporting to unitholders, or provide audited financial statements or third-party reserve reports. As a result, the unitholders and potential investors may have limited or no information on which to base investment decisions, which could have a negative impact on the market price for the Trust units. If the Trust is unable to continue as a going concern, unitholders could incur significant losses on their investment in the Trust or lose their entire investment in the Trust altogether. For further information see Notes to Condensed Financial Statements - 1. Basis of Accounting – Liquidity and Going Concern.

Items 2-4. Not applicable.

21

Table of Contents

Item 5. Other Information

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

Item 6. Exhibits

(10.1)	April 30, 2025 Advance Distribution Agreement on Form 8-K filed with the Securities and Exchange Commission on May 1, 2025 (incorporated herein by reference)
(31)	Rule 13a-14(a)/15d-14(a) Certification
(32)	Section 1350 Certification
(99)	Items 1A, 7 and 7A to the Annual Report on Form 10-K for Hugoton Royalty Trust filed with the Securities and Exchange Commission on April 1, 2024 (incorporated herein by reference)

22

Table of Contents

SIGNATURES

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

	HUGOTON ROYALTY TRUST
	By ARGENT TRUST COMPANY, TRUSTEE
Date: November 13, 2025	By	/s/ NANCY WILLIS
		Nancy Willis
		Director of Royalty Trust Services

(The Trust has no directors or executive officers.)

23

FAQ

Did HGTXU declare any distributions for Q3 2025?

No. Distributable income was $0, and per‑unit distributions were $0.000000 for each of the quarter’s record dates.

What are HGTXU’s excess costs as of September 30, 2025?

Underlying cumulative excess costs were $21.7 million ($17.4 million net to the Trust), including accrued interest of $1.7 million ($1.4 million net).

How much cash does HGTXU have for expenses?

Cash and short‑term investments were $360,188 as of September 30, 2025, held as an expense reserve.

How much do the advance distributions total for HGTXU?

The Trust owes $1,060,336 on two advance distributions, including $60,336 of accrued interest, recoupable subject to a $250,000 cash minimum.

Who operates the underlying properties for HGTXU?

Mach Natural Resources assumed operatorship on April 30, 2025 and the obligations under the Trust Indenture.

How many units of HGTXU are outstanding?

There were 40,000,000 units outstanding as of November 13, 2025.

Is there a going concern warning for HGTXU?

Yes. The filing states substantial doubt about the Trust’s ability to continue as a going concern due to excess costs and limited cash.