UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

For the quarterly period ended SeptemberJune 30, 20202021

OR

Commission File Number: 1-10476

Hugoton Royalty Trust

(Exact name of registrant as specified in its charter)

c/o The Corporate Trustee:

Simmons Bank

2911 Turtle Creek Blvd, Suite 850

Dallas, Texas 75219

(Address of principal executive offices) (Zip Code)

(855) 588-7839

(Registrant’s telephone number, including area code)

NONE

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

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  ☑☒    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:

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 NovemberAugust 1, 20202021

40,000,000

HUGOTON ROYALTY TRUST

FORM 10-Q FOR THE QUARTERLY PERIOD ENDED SEPTEMBERJUNE 30, 20202021

TABLE OF CONTENTS

HUGOTON ROYALTY TRUST

GLOSSARY OF TERMS

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

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 SeptemberJune 30, 20202021 and the distributable income and changes in trust corpus for the three-month and nine-monthsix-month periods ended SeptemberJune 30, 20202021 and 20192020 have been included. Distributable income for such interim periods is not necessarily indicative of the distributable income for the full year. The condensed financial statements as of SeptemberJune 30, 2020,2021, and for the three-month and nine-monthsix-month periods ended SeptemberJune 30, 20202021 and 20192020 have been subjected to a review by PricewaterhouseCoopers LLP, the Trust’s independent registered public accounting firm, whose report is included herein.

Report of Independent Registered Public Accounting Firm

To the Unitholders of Hugoton Royalty Trust and

Simmons Bank, Trustee

Results of Review of Interim Financial Statements

We have reviewed the accompanying condensed statement of assets, liabilities and trust corpus of Hugoton Royalty Trust (the “Trust”) as of SeptemberJune 30, 2020,2021, and the related condensed statements of distributable income and of changes in trust corpus for the three-month and nine-monthsix-month periods ended SeptemberJune 30, 20202021 and 2019,2020, including the related notes (collectively referred to as the “interim financial statements”). Based on our reviews, we are not aware of any material modifications that should be made to the accompanying interim financial statements for them to be in conformity with the modified cash basis of accounting described in Note 1.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the statement of assets, liabilities and trust corpus as of December 31, 2019,2020, and the related statements of distributable income and of changes in trust corpus for the year then ended (not presented herein), and in our report dated March 30, 2020,31, 2021, which included a paragraph describing the modified cash basis of accounting and a paragraph regarding substantial doubt about the Trust’s ability to continue as a going concern, we expressed an unqualified opinion on those financial statements. In our opinion, the information set forth in the accompanying condensed statement of assets, liabilities and trust corpus as of December 31, 2019,2020, is fairly stated, in all material respects, in relation to the statement of assets, liabilities and trust corpus from which it has been derived.

Substantial Doubt About the Trust’s Ability to Continue as a Going Concern

The accompanying interim financial statements have been prepared assuming that the Trust will continue as a going concern. Note 2 of the Trust’s audited financial statements as of December 31, 2020 and 2019, and for the years then ended, includes a statement that substantial doubt exists about the Trust’s ability to continue as a going concern. Note 2 of the Trust’s audited financial statements also discloses the events and conditions, management’s evaluation of the events and conditions, and management’s plans regarding these matters, including the fact that increases in excess costs have resulted in insufficient net proceeds available to the Trust and the depletion of the expense reserve available to the Trust for the payment of its obligations. Our report on those financial statements includes a paragraph referring to the matters in Note 2 of those financial statements. As indicated in Note 1 of the accompanying interim financial statements, as of June 30, 2021, and for the three-months and six-months then ended, the events and conditions impacting the Trust have not changed, and as a result, the Trust has stated that substantial doubt exists about the Trust’s ability to continue as a going concern. The accompanying interim financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Basis for Review Results

These interim financial statements are the responsibility of the Trustee. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Trust in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB. We conducted our review in accordance with the standards of the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Substantial Doubt about the Company’s Ability to Continue as a Going Concern

The accompanying interim financial statements have been prepared assuming that the Trust will continue as a going concern. Note 2 of the Trust’s audited financial statements as of December 31, 2019 and 2018, and for the years then ended, includes a statement that substantial doubt exists about the Trust’s ability to continue as a going concern. Note 2 of the Trust’s audited financial statements also discloses the events and conditions, management’s evaluation of the events and conditions, and management’s plans regarding these matters, including the fact that a reduction in net profits income as a result of excess costs have led to a decline to the expense reserve available to the Trust for the payment of its obligations. Our report on those financial statements includes a paragraph referring to the matters in Note 2 of those financial statements. As indicated in Note 1 of the accompanying interim financial statements, as of September 30, 2020, and for the three-months and nine-months then ended, the events and conditions impacting the Trust have not changed, and as a result, the Trust has stated that substantial doubt exists about the Trust’s ability to continue as a going concern. The accompanying interim financial statements do not include any adjustments that might result from the outcome of this uncertainty.

HUGOTON ROYALTY TRUST

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

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

HUGOTON ROYALTY TRUST

Condensed Statements of Distributable Income(Unaudited)

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

HUGOTON ROYALTY TRUST

Condensed Statements of Changes in Trust Corpus (Unaudited)

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

HUGOTON ROYALTY TRUST

Notes to Condensed Financial Statements (Unaudited)

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

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.

Impairment of Net Profits Interest

The Trustee reviews the Trust’s net profits interests (“NPI”) in oil and gas properties for impairment whenever events or circumstances indicate that the carrying value of the NPI may not be recoverable. In general, the Trustee does not view temporarily low prices as an indication of impairment. The markets for crude oil and natural gas have a history of significant price volatility and though prices will occasionally drop significantly, industry prices over the long term will continue to be driven by market supply and demand. If events and circumstances indicate that the carrying value may not be recoverable, the Trustee would use the estimated undiscounted future net cash flows from the NPI to evaluate the recoverability of the Trust assets. If the undiscounted future net cash flows from the NPI are less than the NPI carrying value, the Trust would recognize an impairment loss for the difference between the NPI carrying value and the estimated fair value of the NPI. The determination as to whether the NPI is impaired requires a significant amount of judgment by the Trustee and is based on the best information available to the Trustee at the time of the evaluation, including information provided by XTO Energy such as estimates of future production and development and operating expenses.

Significantly, during the third quarter of 2019, long term gas prices used to develop projections of future cash flows declined further and excess costs on all three conveyances increased substantially. In light of these facts and circumstances, a trigger event occurred in the third quarter of 2019 indicating a need for further analysis. An assessment of the estimated undiscounted future net cash flows for the NPI indicated that such cash flows were less than the carrying value of the NPI. Accordingly, during the third quarter of 2019, the NPI was written down to its fair value of zero, resulting in a $15.7 million impairment charged directly to Trust corpus, which did not affect distributable income. The fair value of the NPI was developed using estimates for future oil and gas production attributable to the Trust, future crude oil and natural gas commodity prices published by third-party industry experts (adjusted for basis differentials), estimated taxes, development and operating expenses, and a risk-adjusted discount rate. Impairments recorded for book purposes will not result in a loss for tax purposes for the unitholders until the loss is recognized.

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 value of the NPInet 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 NPInet 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 and charged directly to trust corpus. Accumulated amortization was $174,078,891 as of September 30, 2019, when the NPInet 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. Increases in excess costs for the Kansas, Oklahoma and Wyoming conveyances have resulted in insufficient net proceeds to the Trust and a reduction in the Trust’s expense reserve.reserve to zero. These conditions raise substantial doubt about the Trust’s ability to continue as a going concern as the Trust may not have, based on the current estimated administrative expenses, sufficient cash to meet its obligations during the one year period after the date the condensed financial statements are issued. Factors attributable to the potential cash shortage are primarily the previously disclosed

Trust’s assets, if any) before distributions to unitholders could be made. There can be no assurances that a sale of the Trust’s assets, if any, will produce net proceeds sufficient to allow distributions to the unitholders and if such proceeds are available, there is no assurance when any distribution will be made. The Trust’s condensed financial statements do not include any adjustments that might result from the outcome of these uncertainties.

On April 1, 2020, XTO Energy Inc. made an unsolicited offer to acquire the outstanding units of beneficial interest of the Trust for a price of $0.20 per unit. The Trustee filed its Solicitation/Recommendation Statement on April 14, 2020 taking no position. The original offer was scheduled to expire on April 28, 2020. XTO Energy extended the offering period until May 12, 2020 and again to May 26, 2020, at which time it expired. Tendered units were returned to the unitholders due to an insufficient number of units tendered.

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. The Trustee stated it anticipates seeking reimbursement from XTO Energy upon depletion of the Trust’s cash reserve, which it claims will occur soon if the Trust does not receive net proceeds payments.reserve. XTO Energy has responded that any indemnity claim to XTO Energy is premature before the Trust Estate is exhausted. The Trust’s condensed financial statements do not include any adjustments that might result from the outcome of this uncertainty.

The Trust could potentiallymay be required to bear a portion of the legal settlement costs arising from the Chieftain royalty class action settlement. For information on contingencies, including the Chieftain class action, see Note 4 to Condensed Financial Statements. In the event thatThe Panel has determined the Trust is determined to be responsible for such costs,a portion of the costs. However, the arbitration matter is stayed. Pending finalization of all claims included in the arbitration, XTO willEnergy would have the right to deduct the costs in its calculation of the net profits income payable to the Trust from the applicable net profits interests. Thus, for unitholders, the portion of legal settlement costs for which the Trust is determined to be responsible will be reflected through a reduction in net profits income received from the Trust and thus in a reduction in the gross royalty income reported by and taxable to the unitholders. In the event that the Trustee objects to such claimed reductions, the Trustee may also incur legal fees in representing the Trust’s interests. For unitholders, such costs would be reflected through an increase in the Trust’s administrative expenses, which would be deductible by unitholders in determining the net royalty income from the Trust.

If a sale of the assets of the Trust is consummated (as described in Note 7), each unitholder generally will realize gain or loss equal to the difference between such unitholder’s amount realized on such sale and such unitholder’s adjusted basis in the assets of the Trust. Gain or loss realized by a unitholder who is not a dealer with respect to such assets and who has a holding period for the assets of more than one year generally will be treated as long-term capital gain or loss except to the extent of any depletion recapture amount, which will be treated as ordinary income.

Each unitholder should consult his or hertheir 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.

Litigation

Royalty Class Action and Arbitration

As previously disclosed, XTO Energy advised the Trustee that it reached a settlement with the plaintiffs in the Chieftain class action royalty case. On July 27, 2018 the final plan of allocation was approved by the court. Based on the final plan of allocation, XTO Energy has advised the Trustee that it believes approximately $24.3 million in additional production costs should be allocated to the Trust. On May 2, 2018, the Trustee submitted a demand for arbitration seeking a declaratory judgment that the Chieftain settlement is not a production cost and that XTO Energy is prohibited from charging the settlement as a production cost under the conveyance or otherwise reducing the Trust’s payments now or in the future as a result of the Chieftain litigation. The Trust and XTO Energy conducted the interim hearing on the claims related to theChieftain settlement was conducted on October 12-13, 2020. A decision onIn the outcome is expectedarbitration, the Trustee contended that the approximately $24.3 million allocation related to the Chieftain settlement was not a production cost and, therefore, there should not be a related adjustment to the Trust’s share of net proceeds. However, XTO Energy contended that the approximately $24.3 million was a production cost and should reduce the Trust’s share of net proceeds.

On January 20, 2021, the arbitration panel issued its Corrected Interim Final Award (i) “reject[ing] the Trust’s contention that XTO has no right under the Conveyance to charge the Trust with amounts XTO paid under section 1.18(a)(i) as royalty obligations to settle the Chieftain litigation” and (ii) stating “[t]he next phase will determine how much of the Chieftain settlement can be so charged, if any of it can be, in the first quarter 2021. exercise of the

right found by the Panel.” Following briefing by both parties, on May 18, 2021, the Panel issued its second interim final award over the amount of XTO Energy’s settlement in the Chieftain class action lawsuit that can be charged to the Trust as a production cost. The Panel in its decision has ruled that out of the $80 million settlement, the “Trust is obligated to pay its share under the Conveyance of the $48 million that was received by the plaintiffs in the Chieftain lawsuit by virtue of the settlement of that litigation. The Trust is not obligated by the Conveyance to pay any share of the $32 million received by the lawyers for the plaintiffs in the Chieftain lawsuit by virtue of the settlement.” XTO Energy and the Trustee are in the process of determining the portion of the $48 million that is allocable to Trust properties to be charged as an excess cost to the Trust, but estimate it to be approximately $14.6 million.

The Oklahoma conveyance is already currently subject to excess costs that will need to be recovered prior to any distribution to unitholders. Therefore, the reduction in the Trust’s share of net proceeds from the portion of the settlement amount the Panel has ruled may be charged against the Oklahoma conveyance would result in additional excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance for several additional years while these additional excess costs are recovered. This award completes the portion of the arbitration related to the Chieftain settlement.

Other Trustee claims related to disputed amounts on the computation of the Trust’s net proceeds for 2014 through 2016 were bifurcated from the initial arbitration and will be heard at a later date, which is still to be determined.

If Pursuant to the purchase and sale agreement entered into between the Trustee prevails onand XTO Energy, the claims relatedparties have agreed to stay the arbitration from the date of execution of the purchase and sale agreement to the $24.3 million in alleged additional production costs in connection withearlier of the Chieftain settlement, there will betermination of the purchase and sale agreement or closing date of the sale of assets. The Panel has stayed proceedings and requires a status update no adjustment to the Trust’s share of net proceeds. If XTO Energy prevails as to those same claims, there will be an adjustment of approximately $24.3 million reducing the Trust’s share of net proceeds. The Oklahoma conveyance is already currently subject to excess costs that will need to be recovered prior to any distribution to unitholders. Therefore, an adjustment of approximately $24.3 million reducing the Trust’s share of net proceeds would result in additional excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance for several additional years while these additional excess costs are recovered.later than August 31, 2021.

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

The expense reserve usedOn July 2, 2021, the Trustee announced that it has entered into a purchase and sale agreement with XTO Energy pursuant to pay administrative expenseswhich XTO Energy would acquire for $6,600,000 in cash the absence of current month distributions was depleted in October 2020. As a result, Simmons Bank, as Trustee of Hugoton Royalty Trust, is currently paying the expenses for the Trust, subject to its rights to be indemnified and reimbursednet overriding royalty interest created pursuant to the termsnet profits interest conveyances held by the Trust and certain other assets constituting substantially all of the Trust indenture. This includes reimbursement from proceeds received from aassets of the Trust.

The consummation of the sale of the assets is subject to the satisfaction of customary closing conditions, including approval of the sale from holders of units of beneficial interest in the Trust (“Units”) holding Units representing eighty percent (80%) or more of all the Units outstanding, or a final judicial determination authorizing the Trustee to consummate the sale of the assets. The Trustee intends to call a special meeting of Unit holders for the purpose of approving the sale of assets.

Execution of the purchase and sale agreement followed a process previously announced by the Trust whereby the Trustee had engaged a third party to market the Trust’s assets, if any.assets.

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 20192020 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 web site at www.hgt-hugoton.com.

Distributable Income

Quarter

For the quarter ended SeptemberJune 30, 2020,2021, net profits income was $0 as compared to $0 for thirdsecond quarter 2019. No change in net profits income is2020 primarily the result ofdue to higher oil and gas prices ($6.0 million) and decreased production expenses ($0.7 million), offset by decreased oil and gas production ($3.1 million), net excess costs activity ($5.9 million), lower gas and oil prices ($2.51.9 million), and lower oil production ($0.5 million), partially offset by decreasedincreased development costs ($6.6 million), decreased production expense ($2.0 million), decreased taxes, transportation and other costs ($0.2 million), and higher gas production ($0.11.7 million). See “Net Profits Income” below.

After adding interest income of $79,$0, deducting administration expense of $240,266,$166,738, and utilizing $240,187cash funded by Simmons Bank of $166,738 for the expense reserve to paypayment of Trust expenses, distributable income for the quarter ended SeptemberJune 30, 20202021 was $0, or $0.000000 per unit of beneficial interest. Administration expense for the quarter increased $3,575decreased $31,272 as 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 thirdsecond quarter 2019,2020, distributable income was $0 or $0.000000 per unit.

Distributions to unitholders for the quarter ended SeptemberJune 30, 20202021 were:

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

The following are explanations of significant variances on the underlying properties from thirdsecond quarter 20192020 to thirdsecond quarter 20202021 and from the first ninesix months of 20192020 to the comparable period in 2020:2021:

Sales Volumes

Gas

Gas sales volumes increased 3%decreased 18% for second quarter and 14% for the third quarter and 4% for the nine-monthsix-month period as compared with the same 20192020 periods primarily because of lower gas sales from new wells in Major County, Oklahoma, partially offset byincreased downtime, natural production decline, and timing of cash receipts.

Oil

Oil sales volumes decreased 23%44% for second quarter and 47% for the third quarter primarily because of timing of cash receipts and natural production decline. Oil sales volumes increased 61% for the nine-monthsix-month period as compared with the same 20192020 periods primarily because of lower oil sales from new wells in Major County, Oklahoma, partially offset by theincreased downtime, natural production decline, and timing of cash receipts and natural production decline.receipts.

The estimated rate of natural production decline on the underlying oil and gas properties is approximately 6% to 8% a year.

Sales Prices

Gas

The thirdsecond quarter 2021 average gas price was $3.67 per Mcf, a 110% increase from the second quarter 2020 average gas price was $1.85 per Mcf, an 18% decrease from the third quarter 2019 average gas price of $2.25$1.75 per Mcf. For the nine-monthsix-month period, the average gas price decreased 35%increased 58% to $2.09$3.49 per Mcf in 20202021 from $3.22$2.21 per Mcf in 2019.2020. The thirdsecond quarter 20202021 gas price is primarily related to production from MayFebruary through July 2020,April 2021, when the average NYMEX price was $1.67$2.73 per MMBtu.

Oil

The thirdsecond quarter 2021 average oil price was $58.79 per Bbl, an 81% increase from the second quarter 2020 average oil price was $29.93of $32.56 per Bbl, a 45% decrease from the third quarter 2019Bbl. The year-to-date average oil price of $54.64 per Bbl. For the nine-month period, the average oil price decreased 22%increased 9% to $41.82$50.25 per Bbl in 20202021 from $53.80$45.94 per Bbl in 2019.2020. The thirdsecond quarter 20202021 oil price is primarily related to production from MayFebruary through July 2020,April 2021, when the average NYMEX price was $35.96$61.15 per Bbl.

Beginning in March 2020 and continuing into the third quarter of 2020, numerous events have continued to have a downward impact on sales prices of products produced from the underlying properties. The COVID-19 pandemic and the government responses to this pandemic have significantly decreased the demand for oil and gas. It is not clear at the present time when or whether the pandemic will lift or when government policies may change. Additionally, market factors, including abundant supplies, have also negatively impacted prices. Even when demand returns, it could take time for these accumulated supplies to decrease and a new market equilibrium, which may be lower than the pre-pandemic equilibrium, to emerge.

Development Costs

Development costs deducted are based on the current level of development expenditures, budgeted future development costs and the cumulative actual costs under (over) previous deductions. These development costs decreased 100% for the third quarter and decreased 96% for the nine-month period primarily due to the decrease in the development budget for the drilling of four horizontal wells in Major County, Oklahoma. XTO Energy has advised the Trustee that this monthly deduction will continueactual development costs were charged to be evaluatedthe Trust as incurred. These development costs increased 388% for the second quarter and revised as necessary.305% for the six-month period primarily due to drilling costs on a non-operated well. For further information on development costs, see Note 2 to Condensed Financial Statements.

Overhead

Overhead was relatively flatdecreased 2% for the thirdsecond quarter and increased 13%3% for the nine-monthsix-month period. Overhead is charged by XTO Energy 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 SeptemberJune 30, 20202021 totaled $32.6 million ($26.1 million NPI)net to Trust), including accrued interest of $1.9$2.7 million ($1.52.1 million NPI)net to Trust). This balance does not include the approximately $14.6 million of additional production costs the Panel determined could be charged in the second interim final award of the Chieftain arbitration. For further information on excess costs, see Note 5 to Condensed Financial Statements.

Other Proceeds

The calculation of net profits income for the quarter ended June 30, 2021 included $86,198 ($68,958 net to the Trust) from XTO Energy due to interest received on past due payments. The calculation of net profits income for the six-month period included $89,007 ($71,206 net to the Trust) from XTO Energy due to interest received on past due payments.

Contingencies

For information on contingencies, see Note 4 to Condensed Financial Statements.

those detailed in Part I, Item 1A of the Trust’s Annual Report on Form 10-K for the year ended December 31, 2019,2020, which is incorporated by this reference as though fully set forth herein. XTO Energy and the Trustee assume no duty to update these statements as of any future date.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.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. 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.

PART II - OTHER INFORMATION

Item 1. Legal Proceedings.

Royalty Class Action and Arbitration

As previously disclosed, XTO Energy advised the Trustee that it reached a settlement with the plaintiffs in the Chieftain class action royalty case. On July 27, 2018 the final plan of allocation was approved by the court. Based on the final plan of allocation, XTO Energy has advised the Trustee that it believes approximately $24.3 million in additional production costs should be allocated to the Trust. On May 2, 2018, the Trustee submitted a demand for arbitration seeking a declaratory judgment that the Chieftain settlement is not a production cost and that XTO Energy is prohibited from charging the settlement as a production cost under the conveyance or otherwise reducing the Trust’s payments now or in the future as a result of the Chieftain litigation. The Trust and XTO Energy conducted the interim hearing on the claims related to theChieftain settlement was conducted on October 12-13, 2020. A decision onIn the outcome is expectedarbitration, the Trustee contended that the approximately $24.3 million allocation related to the Chieftain settlement was not a production cost and, therefore, there should not be a related adjustment to the Trust’s share of net proceeds. However, XTO Energy contended that the approximately $24.3 million was a production cost and should reduce the Trust’s share of net proceeds.

On January 20, 2021, the arbitration panel issued its Corrected Interim Final Award (i) “reject[ing] the Trust’s contention that XTO has no right under the Conveyance to charge the Trust with amounts XTO paid under section 1.18(a)(i) as royalty obligations to settle the Chieftain litigation” and (ii) stating “[t]he next phase will determine how much of the Chieftain settlement can be so charged, if any of it can be, in the first quarter 2021. exercise of the right found by the Panel.” Following briefing by both parties, on May 18, 2021, the Panel issued its second interim final award over the amount of XTO Energy’s settlement in the Chieftain class action lawsuit that can be charged to the Trust as a production cost. The Panel in its decision has ruled that out of the $80 million settlement, the “Trust is obligated to pay its share under the Conveyance of the $48 million that was received by the plaintiffs in the Chieftain lawsuit by virtue of the settlement of that litigation. The Trust is not obligated by the Conveyance to pay any share of the $32 million received by the lawyers for the plaintiffs in the Chieftain lawsuit by virtue of the settlement.” XTO Energy and the Trustee are in the process of determining the portion of the $48 million that is allocable to Trust properties to be charged as an excess cost to the Trust, but estimate it to be approximately $14.6 million.

The Oklahoma conveyance is already currently subject to excess costs that will need to be recovered prior to any distribution to unitholders. Therefore, the reduction in the Trust’s share of net proceeds from the portion of the settlement amount the Panel has ruled may be charged against the Oklahoma conveyance would result in additional excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance for several additional years while these additional excess costs are recovered. This award completes the portion of the arbitration related to the Chieftain settlement.

Other Trustee claims related to disputed amounts on the computation of the Trust’s net proceeds for 2014 through 2016 were bifurcated from the initial arbitration and will be heard at a later date, which is still to be determined.

If Pursuant to the purchase and sale agreement entered into between the Trustee prevails onand XTO Energy, the claims relatedparties have agreed to stay the arbitration from the date of execution of the purchase and sale agreement to the $24.3 million in alleged additional production costs in connection withearlier of the Chieftain settlement, there will betermination of the purchase and sale agreement or closing date of the sale of assets. The Panel has stayed proceedings and requires a status update no adjustment to the Trust’s share of net proceeds. If XTO Energy prevails as to those same claims, there will be an adjustment of approximately $24.3 million reducing the Trust’s share of net proceeds. The Oklahoma conveyance is already currently subject to excess costs that will need to be recovered prior to any distribution to unitholders. Therefore, an adjustment of approximately $24.3 million reducing the Trust’s share of net proceeds would result in additional excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance for several additional years while these additional excess costs are recovered.later than August 31, 2021.

Other Lawsuits and Governmental Proceedings

Certain of the underlying properties are involved in various other lawsuits and governmental proceedings arising in the ordinary course of business. XTO Energy has 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.

There may not be an active market for the Trust units.

The Trustee received notice from the OTC Markets Group Inc. dated April 16, 2020, notifying the Trustee that the Trust was no longer in compliance with Section 3.2(a) of the Standards for Continued Qualification of the OTCQX Rules for U.S. Companies, in that as of December 31, 2019 the Trust had less than $2 million in net tangible assets, average revenue of less than $6 million over the past three years, and the Trust’s bid price is below $5 per share. The notice stated that if the Trust was unable to cure the deficiency by May 18, 2020, then it would be moved from OTCQX to the OTC Pink market. The Trust transitioned from the OTCQX to the OTCQB on May 19, 2020. No assurance can be made how such transition may affect the liquidity of the units.

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.

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