Hugoton Royalty Trust 10Q 2021 Q2 Quarterly report

Hugoton Royalty Trust (HGTXU) 10-Q2021 Q2 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 June 30, 2021

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

Commission File Number: 1-10476

Hugoton Royalty Trust

(Exact name of registrant as specified in its charter)

Texas

58-6379215

(State or other jurisdiction of

incorporation or organization)

(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)

(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:


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:

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 August 1, 2021

40,000,000

HUGOTON ROYALTY TRUST

FORM 10-Q FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2021


	TABLE OF CONTENTS

		Page

	Glossary of Terms		3

PART I.	FINANCIAL INFORMATION

Item 1.	Financial Statements (Unaudited)		4

	Report of Independent Registered Public Accounting Firm		5

	Condensed Statements of Assets, Liabilities and Trust Corpus at June 30, 2021 and December 31, 2020		6

	Condensed Statements of Distributable Income for the Three and Six Months Ended June 30, 2021 and 2020		7

	Condensed Statements of Changes in Trust Corpus for the Three and Six Months Ended June 30, 2021 and 2020		8

	Notes to Condensed Financial Statements		9

Item 2.	Trustee’s Discussion and Analysis		15

Item 3.	Quantitative and Qualitative Disclosures about Market Risk		20

Item 4.	Controls and Procedures		20

PART II.	OTHER INFORMATION

Item 1.	Legal Proceedings		21

Item 1A.	Risk Factors		22

Item 6.	Exhibits		22

	Signatures		23

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 June 30, 2021 and the distributable income and changes in trust corpus for the three-month and six-month periods ended June 30, 2021 and 2020 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 June 30, 2021, and for the three-month and six-month periods ended June 30, 2021 and 2020 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 June 30, 2021, and the related condensed statements of distributable income and of changes in trust corpus for the three-month and six-month periods ended June 30, 2021 and 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, 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 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, 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.

Basis of Accounting

As described in Note 1, these financial statements were prepared on the modified cash basis of accounting, which is a comprehensive basis of accounting other than generally accepted accounting principles.

/s/ PricewaterhouseCoopers LLP

Dallas, Texas

August 13, 2021

HUGOTON ROYALTY TRUST

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


	June 30, 2021			December 31, 2020

ASSETS

Cash and short-term investments	$	—		$	—

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


	$	—		$	—


LIABILITIES AND TRUST CORPUS

Distribution payable to unitholders	$	—		$	—

Accounts payable to Simmons Bank (a)		710,043			282,369

Trust corpus (40,000,000 units of beneficial interest authorized and outstanding)		(710,043	)		(282,369	)


	$	—		$	—

(a)

Simmons Bank, as Trustee of the Hugoton Royalty Trust, is currently paying the expenses for the Trust, subject to its rights to be indemnified and reimbursed pursuant to the terms of the Trust indenture. This includes reimbursement from proceeds received from a sale of the Trust’s assets, if any.

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 June 30						Six Months Ended June 30
	2021			2020			2021			2020

Net profits income	$	—		$	—		$	—		$	—

Interest income		—			502			—			2,750


Total income		—			502			—			2,750

Administration expense		166,738			198,010			427,674			349,458

Cash reserves withheld (used) for Trust expenses		—			(197,508	)		—			(346,708	)

Cash funded by Simmons Bank for Trust expenses		(166,738	)		—			(427,674	)		—


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.

HUGOTON ROYALTY TRUST

Condensed Statements of Changes in Trust Corpus (Unaudited)

Three Months Ended
June 30

Six Months Ended
June 30

2021

2020

2021

2020

Trust corpus, beginning of period

(543,305

)

—

(282,369

)

—

Cash funded by Simmons Bank for Trust expenses

(166,738

)

—

(427,674

)

—

Trust corpus, end of period

(710,043

)

—

(710,043

)

—

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 and 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. 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 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 financial statements are issued. Factors attributable to the cash shortage are primarily the previously disclosed increase in 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 have resulted in no net proceeds to the Trust for all of 2020 and the first and second quarters of 2021. In addition, 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 which XTO Energy has estimated to be approximately $14.6 million. This adjustment would further increase excess costs on the Oklahoma conveyance. The Trustee has prepared a preliminary budget estimating the administrative expenses for the year ending December 31, 2021 and the eight months ending August 31, 2022 which assumes no cash inflow from either net profits income or from other sources. The Trustee has sought financing to pay the Trust obligations during the one year period after the date the financial statements are issued, especially now that the expense reserve was depleted in October 2020; however, to date such financing has not become available.

The Trustee is reviewing the Trust’s alternatives to continuing as a going concern, which may include a sale of the Trust’s assets and/or termination of the Trust. The Trustee engaged a third party to market the Trust’s assets, and following an extensive marketing period for the assets, on July 2, 2021, the Trustee entered into a purchase and sale agreement for the Trust’s assets with the highest bidder, XTO Energy for a cash purchase price of $6,600,000 (subject to adjustment as set forth in the purchase and sale agreement). Although the Trustee and XTO Energy have entered into the purchase and sale agreement, there is no assurance that a sale can be completed under the terms of the indenture, or if a sale is completed under the terms of the indenture, that there will be any funds available for distribution to unitholders. Any material sale of assets and/or termination of the Trust requires unitholder approval by at least 80% of all outstanding units. While such review is ongoing, Simmons Bank, as Trustee, is currently paying the expenses for the Trust, subject to its rights to be indemnified and reimbursed pursuant to the terms of the Trust indenture. However, there is nothing in the Trust indenture that requires Simmons Bank to pay the expenses for the Trust. Any funds that Simmons Bank, as Trustee, utilizes to pay expenses of the Trust must be repaid in full (including from proceeds received from a sale of the

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. XTO Energy has responded that any indemnity claim to XTO Energy is premature before the Trust Estate is exhausted.

2.	Development Costs

The monthly deduction is based on the current level of development expenditures, budgeted future development costs and the cumulative actual costs under (over) previous deductions. XTO Energy has advised the Trustee that actual development costs were charged to the Trust as incurred. XTO Energy has advised the Trustee that 2021 budgeted development costs for the underlying properties could be up to $1 million. The 2021 budget year generally coincides with the Trust distribution months from April 2021 through March 2022. Changes in oil or natural gas prices could impact future development plans on the underlying properties. XTO Energy has advised the Trustee that this monthly deduction will continue to be evaluated and revised as necessary.

3.	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 will not file a Kansas return for the 2020 tax year because the Trust had no revenues, income or deductions in 2020 attributable to properties located in Kansas. The Trust did not file a Kansas income tax return for the 2019 and 2018 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 4 to Condensed Financial Statements. The Panel has determined the Trust is responsible for a portion of the costs. However, the arbitration matter is stayed. 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.

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 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.

4.	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.

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. Pursuant to the purchase and sale agreement entered into between the Trustee and XTO Energy, the parties have 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. The Panel has stayed proceedings and requires a status update no 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.

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.

5.	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 12/31/20	$	3,004,413	$	23,933,548		$	4,914,021		$	31,851,982
Net excess costs (recovery) for the quarter ended 3/31/21		121,719		(1,572,241	)		(579,456	)		(2,029,978	)
Net excess costs (recovery) for the quarter ended 6/30/21		110,948		467,270			(422,347	)		155,871

Cumulative excess costs remaining at 6/30/21		3,237,080		22,828,577			3,912,218			29,977,875
Accrued interest at 6/30/21		382,706		2,049,097			239,916			2,671,719

Total remaining to be recovered at 6/30/21	$	3,619,786	$	24,877,674		$	4,152,134		$	32,649,594


	NPI
	KS		OK			WY			Total
Cumulative excess costs remaining at 12/31/20	$	2,403,530	$	19,146,838		$	3,931,217		$	25,481,585
Net excess costs (recovery) for the quarter ended 3/31/21		97,375		(1,257,792	)		(463,565	)		(1,623,982	)
Net excess costs (recovery) for the quarter ended 6/30/21		88,758		373,816			(337,878	)		124,696

Cumulative excess costs remaining at 6/30/21		2,589,663		18,262,862			3,129,774			23,982,299
Accrued interest at 6/30/21		306,165		1,639,277			191,933			2,137,375

Total remaining to be recovered at 6/30/21	$	2,895,828	$	19,902,139		$	3,321,707		$	26,119,674

For the quarter ended June 30, 2021, excess costs on properties underlying the Kansas net profits interests increased by $110,948 ($88,758 net to the Trust).

For the quarter ended June 30, 2021, excess costs on properties underlying the Oklahoma net profits interests increased by $467,270 ($373,816 net to the Trust). Underlying cumulative excess costs remaining on the Oklahoma net profits interests total $24,877,674, including accrued interest of $2,049,097. This balance does not include the portion of the Chieftain settlement the Panel determined could be charged as a production cost. XTO Energy has estimated the amount to be approximately $14.6 million.

For the quarter ended June 30, 2021, excess costs of $422,347 ($337,878 net to the Trust) were recovered on properties underlying the Wyoming net profits interests.

Underlying cumulative excess costs for the Kansas, Oklahoma and Wyoming conveyances remaining as of June 30, 2021 totaled $32.6 million ($26.1 million net to the Trust), including accrued interest of $2.7 million ($2.1 million net to the Trust).

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.

7.	Subsequent Events

On July 2, 2021, the Trustee announced that it has 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 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.

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 2020 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 June 30, 2021, net profits income was $0 as compared to $0 for second quarter 2020 primarily due 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 ($1.9 million), and increased development costs ($1.7 million). See “Net Profits Income” below.

After adding interest income of $0, deducting administration expense of $166,738, and utilizing cash funded by Simmons Bank of $166,738 for the payment of Trust expenses, distributable income for the quarter ended June 30, 2021 was $0, or $0.000000 per unit of beneficial interest. Administration expense for the quarter decreased $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 second quarter 2020, distributable income was $0 or $0.000000 per unit.

Distributions to unitholders for the quarter ended June 30, 2021 were:


Record Date	Payment Date		Distribution per Unit
April 30, 2021		May 14, 2021	$	0.000000
May 28, 2021		June 14, 2021		0.000000
June 30, 2021		July 15, 2021		0.000000

			$	0.000000

Six Months

For the six months ended June 30, 2021, net profits income was $0 compared with $0 for the same 2020 period primarily due to higher oil and gas prices ($6.5 million), decreased production expenses ($1.5 million), and decreased overhead ($0.1 million), offset by decreased oil and gas production ($5.8 million), increased development costs ($1.6 million), and net excess costs activity ($0.7 million). See “Net Profits Income” below.

After adding interest income of $0, deducting administration expense of $427,674, and utilizing cash funded by Simmons Bank of $427,674 for the payment of Trust expenses, distributable income for the six months ended June 30, 2021 was $0, or $0.000000 per unit of beneficial interest. Administration expense for the six months ended June 30, 2021 increased $78,216 as compared to the same 2020 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 six months ended June 30, 2020, 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 June 30 *(a)*						Increase (Decrease)	Six Months Ended June 30 *(a)*				Increase (Decrease)
	2021			2020			Increase (Decrease)	2021		2020		Increase (Decrease)
Sales Volumes
Gas (Mcf) (b)
Underlying properties		2,324,955			2,826,815		(18%)		4,894,561		5,718,279		(14%)
Average per day		26,123			31,409		(17%)		27,042		31,419		(14%)
Net profits interests		—			—		—		—		—		—
Oil (Bbls) (b)
Underlying properties		45,157			80,529		(44%)		98,755		187,261		(47%)
Average per day		507			895		(43%)		546		1,029		(47%)
Net profits interests		—			—		—		—		—		—

Average Sales Prices
Gas (per Mcf)	$	3.67		$	1.75		110%	$	3.49	$	2.21		58%
Oil (per Bbl)	$	58.79		$	32.56		81%	$	50.25	$	45.94		9%

Revenues
Gas sales	$	8,523,900		$	4,938,761		73%	$	17,058,283	$	12,631,504		35%
Oil sales		2,654,932			2,622,271		1%		4,962,292		8,603,611		(42%)

Total Revenues		11,178,832			7,561,032		48%		22,020,575		21,235,115		4%


Costs
Taxes, transportation and other		2,191,612			2,112,806		4%		4,930,879		4,885,642		1%
Production expense		3,445,982			4,288,119		(20%)		6,553,282		8,488,529		(23%)
Development costs (c)		2,700,671			553,177		388%		2,716,067		670,368		305%
Overhead		3,082,636			3,147,313		(2%)		6,035,247		6,215,888		(3%)
Excess costs (d)		(155,871	)		(2,540,383	)	(94%)		1,874,107		974,688		92%

Total Costs		11,265,030			7,561,032		49%		22,109,582		21,235,115		4%


Other Proceeds		86,198			—		—		89,007		—		—


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 June 30 generally represent production for the period February through April and (2) gas and oil sales for the six months ended June 30 generally represent production for the period November through April.

(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 2 to Condensed Financial Statements.

(d)

See Note 5 to Condensed Financial Statements.

The following are explanations of significant variances on the underlying properties from second quarter 2020 to second quarter 2021 and from the first six months of 2020 to the comparable period in 2021:

Sales Volumes

Gas

Gas sales volumes decreased 18% for second quarter and 14% for the six-month period as compared with the same 2020 periods primarily because of lower gas sales from new wells in Major County, Oklahoma, increased downtime, natural production decline, and timing of cash receipts.

Oil

Oil sales volumes decreased 44% for second quarter and 47% for the six-month period as compared with the same 2020 periods primarily because of lower oil sales from new wells in Major County, Oklahoma, increased downtime, natural production decline, and timing of cash 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 second quarter 2021 average gas price was $3.67 per Mcf, a 110% increase from the second quarter 2020 average gas price of $1.75 per Mcf. For the six-month period, the average gas price increased 58% to $3.49 per Mcf in 2021 from $2.21 per Mcf in 2020. The second quarter 2021 gas price is primarily related to production from February through April 2021, when the average NYMEX price was $2.73 per MMBtu.

Oil

The second quarter 2021 average oil price was $58.79 per Bbl, an 81% increase from the second quarter 2020 average oil price of $32.56 per Bbl. The year-to-date average oil price increased 9% to $50.25 per Bbl in 2021 from $45.94 per Bbl in 2020. The second quarter 2021 oil price is primarily related to production from February through April 2021, when the average NYMEX price was $61.15 per Bbl.

Costs

Taxes, Transportation and Other

Taxes, transportation and other costs increased 4% for the second quarter primarily because of increased production taxes, partially offset by decreased gas deductions. Taxes, transportation and other costs increased 1% for the six-month period primarily because of increased production and property taxes, partially offset by decreased gas deductions.

Production Expense

Production expense decreased 20% for the second quarter primarily because of decreased labor, repairs and maintenance, and salt water disposal costs. Production expense decreased 23% for the six-month period primarily because of decreased labor, salt water disposal costs, and repairs and maintenance, partially offset by the absence of credits received for material transfers and increased plug and abandonment costs.

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. XTO Energy has advised the Trustee that actual development costs were charged to the Trust as incurred. These development costs increased 388% for the second quarter and 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 decreased 2% for the second quarter and 3% for the six-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 June 30, 2021 totaled $32.6 million ($26.1 million net to Trust), including accrued interest of $2.7 million ($2.1 million 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.

Forward-Looking Statements

Statements in this report relating to future plans, predictions, potential asset sales or termination of the Trust, continued funding of Trust expenses by Simmons Bank, production, excess costs, litigation, arbitration, liquidity, financing, regulatory or court decisions, economic activity and recovery, and the impact of public health events and the accompanying government response on trade, travel and energy demand and future market pricing are forward-looking statements. All statements other than statements of historical fact included in this Form 10-Q, including, without limitation, statements regarding the net profits interests, underlying properties, development activities, annual and monthly development, production and other costs and expenses, estimated rates of natural production decline, monthly development cost deductions, oil and gas prices and differentials to NYMEX prices, supply levels, drilling, workover and restimulation plans, the outcome of litigation or settlement discussions and the impact on Trust proceeds, distributions to unitholders, and industry and market conditions, are forward-looking statements that are subject to risks and uncertainties, including

those detailed in Part I, Item 1A of the Trust’s Annual Report on Form 10-K for the year ended December 31, 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.

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

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.

Other Lawsuits and Governmental Proceedings

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, 2020.

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 31, 2021 (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.


	HUGOTON ROYALTY TRUST
	By SIMMONS BANK, TRUSTEE

	By	/s/ NANCY WILLIS
		Nancy Willis
		Vice President

	EXXON MOBIL CORPORATION

Date: August 13, 2021	By	/s/ DAVID LEVY
		David Levy
		Vice President - Upstream Business Services

Positive
Negative
Uncertain
Constraining
Legalese
Litigious
Readability	H.S. junior Bad

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company