Hugoton Royalty Trust 10Q 2022 Q3 Quarterly report

Hugoton Royalty Trust (HGTXU) 10-Q2022 Q3 Quarterly report

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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, 2022

☐ 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:

Simmons Bank

2911 Turtle Creek Blvd, Suite 850

Dallas, Texas 75219

(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) NONE

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	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 1, 2022

40,000,000

HUGOTON ROYALTY TRUST

FORM 10-Q FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2022

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, 2022 and December 31, 2021	5

	Condensed Statements of Distributable Income for the Three and Nine Months Ended September 30, 2022 and 2021	6

	Condensed Statements of Changes in Trust Corpus for the Three and Nine Months Ended September 30, 2022 and 2021	7

	Notes to Condensed Financial Statements	8

Item 2.	Trustee’s Discussion and Analysis	14

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	19

Item 4.	Controls and Procedures	19

PART II - OTHER INFORMATION		19

Item 1.	Legal Proceedings	19

Item 1A.	Risk Factors	20

Item 6.	Exhibits	20

Signatures		21

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 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 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’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.

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, 2022 and the distributable income and changes in trust corpus for the three-month and nine-month periods ended September 30, 2022 and 2021 have been included. Distributable income for such interim periods is not necessarily indicative of the distributable income for the full year.

HUGOTON ROYALTY TRUST

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


	September 30, 2022		December 31, 2021

ASSETS

Cash and short-term investments (a)	$	3,341,477	$	660,000

Interest to be received		2,603		-

Net profits interests in oil and gas properties - net (Note 1)		-		-


	$	3,344,080	$	660,000


LIABILITIES AND TRUST CORPUS

Distribution payable to unitholders	$	2,344,080	$	-

Performance guarantee deposit (a)		-		660,000

Expense reserve (b)		1,000,000		-

Accounts payable to Simmons Bank (c)		-		1,217,857

Trust corpus (40,000,000 units of beneficial interest authorized and outstanding)		-		(1,217,857	)


	$	3,344,080	$	660,000

(a)

As of December 31, 2021, the only cash and short-term investments held by the Trust was the performance guarantee deposit paid by XTO Energy equal to 10% of the purchase price per Section 3.02 of the purchase and sale agreement. Effective August 22, 2022, the Trustee and XTO Energy mutually agreed to terminate the purchase and sale agreement. As a result of the termination, the Trustee refunded the deposit paid by XTO Energy, together with interest.

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

(c)	As of December 31, 2021, Simmons Bank, the Trustee, had paid expenses for the Trust, subject to its rights to be indemnified and reimbursed pursuant to the terms of the Trust indenture.

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

HUGOTON ROYALTY TRUST

Condensed Statements of Distributable Income (Unaudited)


	Three Months Ended September 30					Nine Months Ended September 30
	2022		2021			2022		2021

Net profits income	$	9,440,853	$	-		$	11,644,580	$	-

Interest income		3,364		-			3,364		-


Total income		9,444,217		-			11,647,944		-

Administration expense		132,309		244,124			465,728		671,798

Cash reserves withheld (used) for Trust expenses		347,549		-			1,000,000		-

Change in accounts payable to Simmons Bank (increase)/decrease		-		(244,124	)		1,217,857		(671,798	)


Distributable income	$	8,964,359	$	-		$	8,964,359	$	-


Distributable income per unit (40,000,000 units)	$	0.224109	$	0.000000		$	0.224109	$	0.000000

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)


	Three Months Ended September 30						Nine Months Ended September 30
	2022			2021			2022			2021

Trust corpus, beginning of period	$	-		$	(710,043	)	$	(1,217,857	)	$	(282,369	)

Distributable income		8,964,359			-			8,964,359			-

Distributions declared		(8,964,359	)		-			(8,964,359	)		-

Change in accounts payable to Simmons Bank (increase)/decrease		-			(244,124	)		1,217,857			(671,798	)


Trust corpus, end of period	$	-		$	(954,167)		$	-		$	(954,167)

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

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 financial position and results of operations in conformity with U.S. generally accepted accounting principles (“GAAP”):

–

Net profits income recorded for a month is the amount computed and paid by XTO Energy Inc. (“XTO Energy”), the owner of the underlying properties, to Simmons Bank, 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 from the underlying properties in the prior month, multiplied by a net profits percentage of 80%.

–

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.

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 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. Between April 2018 and October 2020, accumulated excess costs for the Kansas, Oklahoma and Wyoming conveyances resulted in insufficient net proceeds to the Trust versus its current and anticipated expenses and a reduction in the Trust’s expense reserve to zero. Following depletion of the expense reserve, ongoing expenses and accumulated excess costs continued to result in no net proceeds to the Trust through February 2022. These conditions raised substantial doubt about the Trust’s ability to continue as a going concern as the Trust did not have sufficient cash to meet its obligations during the one year period after the dates that the financial statements were issued. Factors attributable to the cash shortage were primarily the previously disclosed development costs to drill four horizontal wells in Major County, Oklahoma, lower oil and gas prices during 2019 and 2020, and excess cost positions on the Kansas, Oklahoma and Wyoming conveyances which resulted in no unitholder distributions since March 2018. All conveyances have now received enough net profits income to recoup all of the excess costs in those conveyances plus the accrued interest. The net profits income received was also sufficient to reimburse Simmons Bank for the administrative expenses that it advanced after the expense reserve was depleted in October 2020 and fund the expense reserve. As of the July 2022 distribution announcement, the expense reserve has been replenished to $1,000,000. The Trustee does not currently anticipate any increase to the cash reserve in 2022. On May 18, 2021, the arbitration 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 which XTO Energy has estimated to be approximately $14.6 million net to the Trust after the arbitration panel has determined the remaining claims and issued its final award. This adjustment would likely result in the Oklahoma conveyance returning to an excess cost position for a period of time. Excess costs on the Oklahoma conveyance would not affect net proceeds to the Trust from the Kansas or Wyoming conveyances. The Trustee has prepared a preliminary budget estimating the administrative expenses for the year ending December 31, 2022 and the eleven months ending November 30, 2023 which assumes no cash inflow from net profits income other than the payments received from March 2022 through October 2022 totaling approximately $14,921,000. Based on the above assumptions, the Trustee believes that the Trust would be able to meet its financial obligations for the one-year period after the financial statements are issued.

During the period of time in which the Trust received no net profits income, the Trustee reviewed the Trust’s alternatives to continuing as a going concern, which included a potential sale of the Trust’s assets and/or termination of the Trust. On July 2, 2021, the Trustee announced that it had entered into a purchase and sale agreement with XTO Energy pursuant to which XTO Energy would acquire for $6,600,000 in cash the net overriding royalty interest created pursuant to the net profits interest conveyances held by the Trust and certain other assets constituting substantially all of the assets of the Trust.

The consummation of the sale of the assets was 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 held a Special Meeting of unitholders on December 10, 2021 for the purpose of approving the sale of assets. The sale was not approved by unitholders.

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.

Effective August 22, 2022, the Trustee and XTO Energy mutually agreed to terminate the purchase and sale agreement. As a result of the termination, the Trustee refunded the deposit paid by XTO Energy, together with interest.

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 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.

All revenues from the Trust are from sources within Kansas, Oklahoma or Wyoming. Because it 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 a Kansas return for the 2021 tax year because the Trust had no revenues, income or deductions in 2021 attributable to properties located in Kansas. The Trust did not file a Kansas income tax return for the 2020 and 2019 tax years for the same reason.

Wyoming does not impose a state income tax.

The Trust may be required to bear a portion of the settlement costs arising from the Chieftain royalty class action settlement. For information on contingencies, including the Chieftain class action, see Note 3 to Condensed Financial Statements. The Panel has determined the Trust is responsible for a portion of the costs. Pending finalization of all claims included in the arbitration, XTO Energy 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.

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

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 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 the Chieftain settlement on October 12-13, 2020. In the arbitration, 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 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 net to the Trust.

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 excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance while these excess costs are recovered. This award completes the portion of the arbitration related to the Chieftain settlement. Excess costs on any individual conveyance would not affect net proceeds to the Trust on any of the other remaining conveyances.

Other Trustee claims related to disputed amounts on the computation of the Trust’s net proceeds for 2014 through 2019 and 2021 were bifurcated from the initial arbitration. Pursuant to the purchase and sale agreement entered into between the Trustee and XTO Energy, the parties had agreed to stay the arbitration from the date of execution of the purchase and sale agreement to the earlier of the termination of the purchase and sale agreement or closing date of the sale of assets. Effective August 22, 2022, the Trustee and XTO Energy mutually agreed to terminate the purchase and sale agreement. As a result of the termination, the stay of these arbitration proceedings between XTO Energy and the Trustee with respect to the Trust is lifted. The arbitration proceedings have recommenced and the hearing is currently scheduled for May 30-31, 2023.

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.

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.

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 balance and accrued interest to be recovered by conveyance as calculated by XTO Energy:


	Underlying
	KS			OK			WY			Total

Cumulative excess costs remaining at 12/31/21	$	2,965,031		$	12,013,867			$1,238,589		$	16,217,487
Net excess costs (recovery) for the quarter ended 3/31/22		(372,634	)		(8,110,921	)		(1,238,589	)		(9,722,144	)
Net excess costs (recovery) for the quarter ended 6/30/22		(2,331,946	)		(3,902,946	)		-			(6,234,892	)
Net excess costs (recovery) for the quarter ended 9/30/22		(260,451	)		-			-			(260,451	)

Cumulative excess costs remaining at 9/30/22		-			-			-			-
Accrued interest at 9/30/22		-			-			-			-

Total remaining to be recovered at 9/30/22	$	-		$	-			$ -		$	-


	NPI
	KS			OK			WY			Total

Cumulative excess costs remaining at 12/31/21	$	2,372,024		$	9,611,095			$990,871		$	12,973,990
Net excess costs (recovery) for the quarter ended 3/31/22		(298,107	)		(6,488,737	)		(990,871	)		(7,777,715	)
Net excess costs (recovery) for the quarter ended 6/30/22		(1,865,556	)		(3,122,358	)		-			(4,987,914	)
Net excess costs (recovery) for the quarter ended 9/30/22		(208,361	)		-			-			(208,361	)

Cumulative excess costs remaining at 9/30/22		-			-			-			-
Accrued interest at 9/30/22		-			-			-			-

Total remaining to be recovered at 9/30/22	$	-		$	-			$ -		$	-

For the quarter ended September 30, 2022, net recoveries of excess costs were $260,451 ($208,361 net to the Trust) and recoveries of accrued interest were $501,345 ($401,076 net to the Trust) on properties underlying the Kansas net profits interests.

There are no cumulative excess costs balances remaining for any conveyance as of September 30, 2022.

5. 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.

6. Subsequent Events

Development Costs

XTO Energy has advised the Trustee that it has elected to participate in the development of a non-operated well in Major County, Oklahoma. The well was proposed by Comanche Exploration Co. LLC under a joint operating agreement. XTO Energy has advised the Trustee that development costs for the well are anticipated to be approximately $5 million underlying ($4 million net to the Trust), and that drilling has begun and is expected to be completed in the first quarter of 2023. However, no assurances can be made as to the estimated costs or timing to complete the well.

Trustee Resignation

On October 21, 2022, the Trustee announced that it has entered into an agreement with Argent Trust Company, a Tennessee chartered trust company (“Argent”), pursuant to which the Trustee will be resigning as trustee of the Trust and will nominate Argent as successor trustee of the Trust. The Trustee’s resignation as trustee, and Argent’s appointment as successor trustee, are subject to certain conditions set forth in the agreement, including approval by the unitholders of the Trust (or a court) of (i) Argent’s appointment as successor trustee and (ii) any amendments to the indenture of the Trust necessary to permit Argent to serve as successor trustee.

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 2021 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.

Distributable Income

Quarter

For the quarter ended September 30, 2022, net profits income was $9,440,853 as compared to $0 for third quarter 2021 primarily due to higher oil and gas prices ($11.4 million), and net excess costs activity ($4.4 million), partially offset by decreased oil and gas production ($4.4 million), increased production expenses ($1.0 million), increased taxes, transportation and other costs ($0.7 million), increased development costs ($0.2 million), and increased overhead ($0.1 million). See “Net Profits Income” below.

After adding interest income of $3,364, increasing the expense reserve $347,549, and deducting administration expense of $132,309, distributable income for the quarter ended September 30, 2022 was $8,964,359, or $0.224109 per unit of beneficial interest. Administration expense for the quarter decreased $111,815 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 third quarter 2021, distributable income was $0, or $0.000000 per unit.

Distributions to unitholders for the quarter ended September 30, 2022 were:


Record Date	Payment Date		Distribution per Unit
July 29, 2022		August 12, 2022	$	0.068699
August 31, 2022		September 15, 2022		0.096808
September 30, 2022		October 17, 2022		0.058602

			$	0.224109

Nine Months

For the nine months ended September 30, 2022, net profits income was $11,644,580 compared with $0 for the same 2021 period primarily due to higher oil and gas prices ($24.3 million), increased oil production ($1.4 million), and decreased development costs ($1.1 million), partially offset by net excess costs activity ($9.1 million), increased production expenses ($2.2 million), decreased gas production ($2.1 million), increased taxes, transportation and other costs ($1.4 million), increased overhead ($0.3 million), and decreased other proceeds ($0.1 million). See “Net Profits Income” below.

After adding interest income of $3,364, paying off the outstanding payable to Simmons Bank of $1,217,857, establishing an expense reserve of $1,000,000, and deducting administration expense of $465,728, distributable income for the nine months ended September 30, 2022 was $8,964,359, or $0.224109 per unit of beneficial interest. Administration expense for the nine months ended September 30, 2022 decreased $206,070 as compared to the same 2021 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, 2021, distributable income was $0, or $0.000000 per unit.

Net Profits Income

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

oil and gas sales volumes,

oil and gas sales prices, and

costs deducted in the calculation of net profits income.

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


	Three Months Ended September 30 (a)				Increase (Decrease)		Nine Months Ended September 30 (a)				Increase (Decrease)
	2022		2021		Increase (Decrease)		2022		2021		Increase (Decrease)
Sales Volumes
Gas (Mcf) (b)
Underlying properties		2,457,484		2,762,949		(11%)		7,285,730		7,657,510		(5%)
Average per day		26,712		30,032		(11%)		26,688		28,049		(5%)
Net profits interests		1,064,656		-		-		1,433,170		-		-
Oil (Bbls) (b)
Underlying properties		51,005		80,514		(37%)		200,002		179,269		12%
Average per day		554		875		(37%)		733		657		12%
Net profits interests		25,397		-		-		29,129		-		-

Average Sales Prices
Gas (per Mcf)		$ 7.73		$ 3.82		102%		$ 6.93		$ 3.61		92%
Oil (per Bbl)		$104.54		$62.18		68%		$83.09		$55.61		49%

Revenues
Gas sales	$	18,995,538	$	10,553,160		80%	$	50,474,576	$	27,611,443		83%
Oil sales		5,332,099		5,006,440		7%		16,618,651		9,968,732		67%

Total Revenues		24,327,637		15,559,600		56%		67,093,227		37,580,175		79%


Costs
Taxes, transportation and other		3,636,208		2,724,804		33%		9,370,157		7,655,683		22%
Production expense		4,738,010		3,452,989		37%		12,711,259		10,006,271		27%
Development costs		239,373		39,707		503%		1,419,416		2,755,774		(48%)
Overhead		3,151,184		3,050,109		3%		9,502,285		9,085,356		5%
Excess costs (c)		761,796		6,299,933		(88%)		19,534,417		8,174,040		139%

Total Costs		12,526,571		15,567,542		(20%)		52,537,534		37,677,124		39%


Other Proceeds		-		7,942		-		32		96,949		(100%)


Net Proceeds		11,801,066		-		-		14,555,725		-		-

Net Profits Percentage		80%		80%				80%		80%


Net Profits Income	$	9,440,853	$	-		-	$	11,644,580	$	-		-

(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 generally represent production for the period May through July and (2) gas and oil sales for the nine months ended September 30 generally represent production for the period November through July.

(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.

The following are explanations of significant variances on the underlying properties from third quarter 2021 to third quarter 2022 and from the first nine months of 2021 to the comparable period in 2022:

Sales Volumes

Gas

Gas sales volumes decreased 11% for third quarter primarily because of natural production decline, and timing of cash receipts. Gas sales volumes decreased 5% for the nine-month period as compared with the same 2021 periods primarily because of natural production decline, partially offset by timing of cash receipts, and decreased downtime.

Oil

Oil sales volumes decreased 37% for third quarter primarily because of timing of cash receipts, and natural production decline. Oil sales volumes increased 12% for the nine-month period as compared with the same 2021 periods primarily because of timing of cash receipts, and decreased downtime, partially offset by natural production decline.

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 third quarter 2022 average gas price was $7.73 per Mcf, up 102% from the third quarter 2021 average gas price of $3.82 per Mcf. For the nine-month period, the average gas price increased 92% to $6.93 per Mcf in 2022 from $3.61 per Mcf in 2021.

Oil

The third quarter 2022 average oil price was $104.54 per Bbl, up 68% from the third quarter 2021 average oil price of $62.18 per Bbl. For the nine-month period, the average oil price increased 49% to $83.09 per Bbl in 2022 from $55.61 per Bbl in 2021.

Costs

Taxes, Transportation and Other

Taxes, transportation and other costs increased 33% for the third quarter and 22% for the nine-month period primarily because of increased production and property taxes, and gas deductions, partially offset by receipt of production tax refunds.

Production Expense

Production expense increased 37% for the third quarter and 27% for the nine-month period primarily because of increased repairs and maintenance, and plug and abandonment expense, partially offset by decreased labor costs, and timing of the annual Oklahoma Senate Bill 168 fee.

Development Costs

Development costs increased 503% for the third quarter primarily due to equipment purchases in Wyoming. Development costs decreased 48% for the nine-month period primarily because of timing of drilling costs related to non-operated wells. Changes in oil or natural gas prices could impact future development plans on the underlying properties.

XTO Energy has advised the Trustee that it has elected to participate in the development of a non-operated well in Major County, Oklahoma. The well was proposed by Comanche Exploration Co. LLC under a joint operating agreement. XTO Energy has advised the Trustee that development costs for the well are anticipated to be approximately $5 million underlying ($4 million net to the Trust), and that drilling has begun and is expected to be completed in the first quarter of 2023. No assurances can be made as to the estimated costs or timing to complete the well.

Overhead

Overhead increased 3% for the third quarter and 5% for the nine-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. There are no cumulative excess costs balances remaining for any conveyance as of September 30, 2022. For further information on excess costs, see Note 4 to Condensed Financial Statements.

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 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, potential asset sales or termination of the Trust, excess costs, 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 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, competition, war and other political or security disturbances. Such forward-looking statements are based on XTO Energy’s 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, 2021, 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 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. 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

Other Trustee claims related to disputed amounts on the computation of the Trust’s net proceeds for 2014 through 2019 and 2021 were bifurcated from the initial arbitration and will be heard at a later date, which is still to be determined should the arbitration proceed. Pursuant to the purchase and sale agreement entered into between the Trustee and XTO Energy, the parties had agreed to stay the arbitration from the date of execution of the purchase and sale agreement to the earlier of the termination of the purchase and sale agreement or closing date of the sale of assets. Effective August 22, 2022, the Trustee and XTO Energy mutually agreed to terminate the purchase and sale agreement. As a result of the termination, the stay of these arbitration proceedings between XTO Energy and the Trustee with respect to the Trust is lifted. The arbitration proceedings have recommenced and the hearing is currently scheduled for May 30-31, 2023.

Item 1A. Risk Factors

There have been no material changes in the risk factors disclosed under Part I, Item 1A of the Trust’s Annual Report on Form 10-K for the year ended December 31, 2021.

Item 6. Exhibits

(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 March 30, 2022 (incorporated herein by reference)

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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HUGOTON ROYALTY TRUST
By SIMMONS BANK, TRUSTEE

/S/ NANCY WILLIS

Nancy Willis

Vice President