HUGOTON ROYALTY TRUST - Quarter Report: 2020 September (Form 10-Q)

HUGOTON ROYALTY TRUST - Quarter Report: 2020 September (Form 10-Q)

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10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

[X]

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

For the quarterly period ended September 30, 2020

☐	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 November 1, 2020

40,000,000

HUGOTON ROYALTY TRUST

FORM 10-Q FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2020

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 September 30, 2020 and December 31, 2019		7

	Condensed Statements of Distributable Income for the Three and Nine Months Ended September 30, 2020 and 2019		8

	Condensed Statements of Changes in Trust Corpus for the Three and Nine Months Ended September 30, 2020 and 2019		9

	Notes to Condensed Financial Statements		10

Item 2.	Trustee’s Discussion and Analysis		16

Item 3.	Quantitative and Qualitative Disclosures about Market Risk		21

Item 4.	Controls and Procedures		21

PART II.	OTHER INFORMATION

Item 1.	Legal Proceedings		22

Item 1A.	Risk Factors		22

Item 6.	Exhibits		24

	Signatures		25

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

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

Basis for Review Results

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

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

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

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 accounting principles generally accepted in the United States of America.

/s/ PricewaterhouseCoopers LLP

Dallas, Texas

November 13, 2020

HUGOTON ROYALTY TRUST

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


	September 30, 2020		December 31, 2019
ASSETS
Cash and short-term investments	$	18,751	$	605,646
Net profits interests in oil and gas properties - net (Note 1)		—		—

	$	18,751	$	605,646

LIABILITIES AND TRUST CORPUS
Distribution payable to unitholders	$	—	$	—
Expense reserve (a)		18,751		605,646
Trust corpus (40,000,000 units of beneficial interest authorized and outstanding)		—		—

	$	18,751	$	605,646

(a)

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

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						Nine Months Ended
	September 30						September 30
	2020			2019			2020			2019
Net profits income	$	—		$	—		$	—		$	369,458
Interest income		79			5,717			2,829			17,629

Total income		79			5,717			2,829			387,087
Administration expense		240,266			236,691			589,724			675,019
Cash reserves withheld (used) for Trust expenses		(240,187	)		(230,974	)		(586,895	)		(287,932	)

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					Nine Months Ended
	September 30					September 30
	2020		2019			2020		2019
Trust corpus, beginning of period	$	—	$	15,681,533		$	—	$	15,816,990
Amortization of net profits interests		—		—			—		(135,457	)
Impairment of net profits interest (Note 1)		—		(15,681,533	)		—		(15,681,533	)
Distributable income		—		—			—		—
Distributions declared		—		—			—		—

Trust corpus, end of period	$	—	$	—		$	—	$	—

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., 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.

Impairment of Net Profits Interest

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

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

Net profits interests in oil and gas properties

The initial carrying value of the net profits interests of $247,066,951 represents XTO Energy’s historical net book value for the interests on December 1, 1998, the date of the transfer to the Trust. During the second quarter 2016, the carrying value of the NPI 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 NPI 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 NPI 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. These conditions raise substantial doubt about the Trust’s ability to continue as a going concern as the Trust may not have, based on the current estimated administrative expenses, sufficient cash to meet its obligations during the one year period after the date the condensed financial statements are issued. Factors attributable to the potential cash shortage are primarily the previously disclosed

increase in development costs to drill four horizontal wells in Major County, Oklahoma (actual costs incurred through third quarter 2020 are $27.9 million net to the Trust) which have created an excess cost position on the Oklahoma conveyance. Cash flows from these new wells have generated recoveries of excess costs in spite of losses from the other wells underlying the Oklahoma conveyance until the second quarter 2020 when they were no longer able to cover losses from the other wells resulting in an increase in excess costs. Additionally, excess cost positions on the Kansas and Wyoming conveyances have resulted in no net proceeds to the Trust from the Kansas conveyance for all of 2019 and 2020 and no net proceeds to the Trust from the Wyoming conveyance for all of 2019 and 2020, with the exception of the March through May 2019 distributions. The Trustee has prepared a preliminary budget estimating the administrative expenses for the year ending December 31, 2020 and the nine months ending September 30, 2021, which assumes no cash inflow from either net profits income or from other sources. This budget estimated that the expense reserve would be depleted by approximately October 2020, and the expense reserve was in fact depleted in October 2020. The Trustee has sought financing to pay the Trust obligations during the one year period after the date the financial statements are issued following the depletion of the expense reserve; 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 has engaged a third party to market the Trust’s assets. 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. On April 1, 2020, XTO Energy Inc. made an unsolicited offer to acquire the outstanding units of beneficial interest of the Trust for a price of $0.20 per unit. The Trustee filed its Solicitation/Recommendation Statement on April 14, 2020 taking no position. The original offer was scheduled to expire on April 28, 2020. XTO Energy extended the offering period until May 12, 2020 and again to May 26, 2020, at which time it expired. Tendered units were returned to the unitholders due to an insufficient number of units tendered. On July 9, 2020, the Trustee notified XTO Energy of the Trustee’s claim to indemnification to the Trust Estate for all liability, expense, claims, damages or loss incurred by the Trustee in connection with the administration of the Trust. The Trustee stated it anticipates seeking reimbursement from XTO Energy upon depletion of the Trust’s cash reserve, which it claims will occur soon if the Trust does not receive net proceeds payments. XTO Energy has responded that any indemnity claim to XTO Energy is premature before the Trust Estate is exhausted. The Trust’s condensed financial statements do not include any adjustments that might result from the outcome of this uncertainty.

2.	Development Costs

The following summarizes actual development costs, development costs deducted in the calculation of net profits income, and the cumulative actual costs compared to the amount deducted for the underlying properties:


	Three Months Ended						Nine Months Ended
	September 30						September 30
	2020			2019			2020			2019
Cumulative actual costs under (over) the amount deducted—beginning of period	$	—		$	2,137,110		$	—		$	13,913,191
Actual costs		(23,065	)		(10,414,724	)		(693,433	)		(30,645,355	)
Budgeted / actual costs deducted		23,065			8,277,614			693,433			16,732,164

Cumulative actual costs under (over) the amount deducted—end of period	$	—		$	—		$	—		$	—

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 for properties underlying the Kansas and Wyoming net profits interests were charged to the Trust as incurred. XTO has advised the Trustee that actual development costs for the properties underlying the Oklahoma net profits interests were charged to the Trust as incurred once the accrual was fully depleted as of the July 2019 distribution. XTO Energy has advised the Trustee that drilling in Major County, Oklahoma is complete and resulted in cost overruns due to unforeseen expenditures that were charged to the Trust in the third quarter of 2019. XTO Energy has advised the Trustee that 2020 budgeted development costs for the underlying properties are between $1 million and $3 million. The 2020 budget year generally coincides with the Trust distribution months from April 2020 through March 2021. 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. Impairments recorded for book purposes will not result in a loss for tax purposes for the unitholders until the loss is recognized.

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 2019 tax year because the Trust had no revenues, income or deductions in 2019 attributable to properties located in Kansas. The Trust did not file a Kansas income tax return for the 2018 and 2017 tax years for the same reason.

Wyoming does not impose a state income tax.

The Trust could potentially be required to bear a portion of the legal settlement costs arising from the Chieftain settlement. For information on contingencies, including the Chieftain class action, see Note 4 to Condensed Financial Statements. In the event that the Trust is determined to be responsible for such costs, XTO will 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 legal settlement costs 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 his or her 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 has advised the Trustee that it believes approximately $24.3 million in additional production costs should be allocated to the Trust. On May 2, 2018, the Trustee submitted a demand for arbitration seeking a declaratory judgment that the Chieftain settlement is not a production cost and that XTO Energy is prohibited from charging the settlement as a production cost under the conveyance or otherwise reducing the Trust’s payments now or in the future as a result of the Chieftain litigation. The interim hearing on the claims related to the Chieftain settlement was conducted on October 12-13, 2020. A decision on the outcome is expected in the first quarter 2021. Other Trustee claims related to disputed amounts on the computation of the Trust’s net proceeds for 2014 through 2016 were bifurcated from the initial arbitration and will be heard at a later date, which is still to be determined.

If the Trustee prevails on the claims related to the $24.3 million in alleged additional production costs in connection with the Chieftain settlement, there will be no adjustment to the Trust’s share of net proceeds. If XTO Energy prevails as to those same claims, there will be an adjustment of approximately $24.3 million reducing the Trust’s share of net proceeds. The Oklahoma conveyance is already currently subject to excess costs that will need to be recovered prior to any distribution to unitholders. Therefore, an adjustment of approximately $24.3 million reducing the Trust’s share of net proceeds would result in additional excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance for several additional years while these additional excess costs are recovered.

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 conveyance, 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:


	Underlying
	KS		OK			WY			Total
Cumulative excess costs remaining at 12/31/19	$	1,795,487	$	25,210,563		$	3,189,747		$	30,195,797
Net excess costs (recovery) for the quarter ended 3/31/20		358,280		(3,631,900	)		(241,451	)		(3,515,071	)
Net excess costs (recovery) for the quarter ended 6/30/20		339,214		1,372,288			828,881			2,540,383
Net excess costs (recovery) for the quarter ended 9/30/20		389,514		637,078			442,464			1,469,056

Cumulative excess costs remaining at 9/30/20		2,882,495		23,588,029			4,219,641			30,690,165
Accrued interest at 9/30/20		300,071		1,452,322			127,349			1,879,742

Total remaining to be recovered at 9/30/20	$	3,182,566	$	25,040,351		$	4,346,990		$	32,569,907


	NPI
	KS		OK			WY			Total
Cumulative excess costs remaining at 12/31/19	$	1,436,389	$	20,168,450		$	2,551,798		$	24,156,637
Net excess costs (recovery) for the quarter ended 3/31/20		286,624		(2,905,520	)		(193,161	)		(2,812,057	)
Net excess costs (recovery) for the quarter ended 6/30/20		271,371		1,097,831			663,104			2,032,306
Net excess costs (recovery) for the quarter ended 9/30/20		311,611		509,662			353,971			1,175,244

Cumulative excess costs remaining at 9/30/20		2,305,995		18,870,423			3,375,712			24,552,130
Accrued interest at 9/30/20		240,057		1,161,858			101,879			1,503,794

Total remaining to be recovered at 9/30/20	$	2,546,052	$	20,032,281		$	3,477,591		$	26,055,924

For the quarter ended September 30, 2020, lower revenues in relation to costs resulted in net excess costs on properties underlying the Kansas, Oklahoma and Wyoming net profits interests.

Underlying cumulative excess costs for the Kansas, Oklahoma and Wyoming conveyances remaining as of September 30, 2020 totaled $32.6 million, including accrued interest of $1.9 million.

6.	Subsequent Events

The expense reserve used to pay administrative expenses in the absence of current month distributions was depleted in October 2020. As a result, Simmons Bank, as Trustee of Hugoton Royalty Trust, is currently paying the expenses for the Trust, subject to its rights to be indemnified and 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.

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 2019 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 September 30, 2020, net profits income was $0, as compared to $0 for third quarter 2019. No change in net profits income is primarily the result of net excess costs activity ($5.9 million), lower gas and oil prices ($2.5 million), and lower oil production ($0.5 million), partially offset by decreased development costs ($6.6 million), decreased production expense ($2.0 million), decreased taxes, transportation and other costs ($0.2 million), and higher gas production ($0.1 million). See “Net Profits Income” below.

After adding interest income of $79, deducting administration expense of $240,266, and utilizing $240,187 of the expense reserve to pay Trust expenses, distributable income for the quarter ended September 30, 2020 was $0 or $0.000000 per unit of beneficial interest. Administration expense for the quarter increased $3,575 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 and interest rates. For third quarter 2019, distributable income was $0 or $0.000000 per unit.

Distributions to unitholders for the quarter ended September 30, 2020 were:


Record Date	Payment Date		Distribution per Unit
July 31, 2020		August 14, 2020	$	0.000000
August 31, 2020		September 15, 2020		0.000000
September 30, 2020		October 15, 2020		0.000000

			$	0.000000

Nine Months

For the nine months ended September 30, 2020, net profits income was $0 compared with $369,458 for the same 2019 period. This decrease in net profits income is primarily the result of net excess costs activity ($10.2 million), lower oil and gas prices ($8.8 million), and increased overhead ($0.9 million), partially offset by decreased development costs ($12.8 million), increased oil and gas production ($3.8 million), decreased production expenses ($2.5 million), and decreased taxes, transportation and other costs ($0.4 million). See “Net Profits Income” below.

After adding interest income of $2,829, deducting administration expense of $589,724, and utilizing $586,895 of the expense reserve to pay Trust expenses, distributable income for the nine months ended September 30, 2020 was $0 or $0.000000 per unit of beneficial interest. Administration expense for the nine months ended September 30, 2020 decreased $85,295 as compared to the same 2019 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 and interest rates. For the nine months ended September 30, 2019, 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								Nine Months
	Ended September 30 *(a)*						Increase		Ended September 30 *(a)*						Increase
	2020			2019			(Decrease)		2020			2019			(Decrease)
Sales Volumes
Gas (Mcf) (b)
Underlying properties		2,761,470			2,672,338			3%		8,479,749			8,143,162			4%
Average per day		30,016			29,047			3%		30,948			29,828			4%
Net profits interests		—			—			—		—			109,541			(100%)
Oil (Bbls) (b)
Underlying properties		64,909			84,215			(23%)		252,170			156,357			61%
Average per day		706			915			(23%)		920			573			61%
Net profits interests		—			—			—		—			249			(100%)
Average Sales Prices
Gas (per Mcf)	$	1.85		$	2.25			(18%)	$	2.09		$	3.22			(35%)
Oil (per Bbl)	$	29.93		$	54.64			(45%)	$	41.82		$	53.80			(22%)
Revenues
Gas sales	$	5,101,237		$	6,018,411			(15%)	$	17,732,741		$	26,207,342			(32%)
Oil sales		1,942,439			4,601,214			(58%)		10,546,050			8,411,806			25%

Total Revenues		7,043,676			10,619,625			(34%)		28,278,791			34,619,148			(18%)

Costs
Taxes, transportation and other		2,039,091			2,227,020			(8%)		6,924,733			7,482,909			(7%)
Production expense		3,330,095			5,793,859			(43%)		11,818,624			14,920,810			(21%)
Development costs (c)		23,065			8,277,614			(100%)		693,433			16,732,164			(96%)
Overhead		3,120,481			3,134,794			—		9,336,369			8,260,296			13%
Excess costs (d)		(1,469,056	)		(8,813,662	)		(83%)		(494,368	)		(13,238,854	)		(96%)

Total Costs		7,043,676			10,619,625			(34%)		28,278,791			34,157,325			(17%)

Net Proceeds		—			—			—		—			461,823			(100%)
Net Profits Percentage		80%			80%					80%			80%

Net Profits Income	$	—		$	—			—	$	—		$	369,458			(100%)

(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 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 third quarter 2019 to third quarter 2020 and from the first nine months of 2019 to the comparable period in 2020:

Sales Volumes

Gas

Gas sales volumes increased 3% for the third quarter and 4% for the nine-month period as compared with the same 2019 periods primarily because of gas sales from new wells in Major County, Oklahoma, partially offset by natural production decline and timing of cash receipts.

Oil

Oil sales volumes decreased 23% for the third quarter primarily because of timing of cash receipts and natural production decline. Oil sales volumes increased 61% for the nine-month period as compared with the same 2019 periods primarily because of oil sales from new wells in Major County, Oklahoma, partially offset by the timing of cash receipts and 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 2020 average gas price was $1.85 per Mcf, an 18% decrease from the third quarter 2019 average gas price of $2.25 per Mcf. For the nine-month period, the average gas price decreased 35% to $2.09 per Mcf in 2020 from $3.22 per Mcf in 2019. The third quarter 2020 gas price is primarily related to production from May through July 2020, when the average NYMEX price was $1.67 per MMBtu.

Oil

The third quarter 2020 average oil price was $29.93 per Bbl, a 45% decrease from the third quarter 2019 average oil price of $54.64 per Bbl. For the nine-month period, the average oil price decreased 22% to $41.82 per Bbl in 2020 from $53.80 per Bbl in 2019. The third quarter 2020 oil price is primarily related to production from May through July 2020, when the average NYMEX price was $35.96 per Bbl.

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

Costs

Taxes, Transportation and Other

Taxes, transportation and other costs decreased 8% for the third quarter primarily because of decreased production taxes due to lower revenues, partially offset by increased gas deductions on higher gas production. Taxes, transportation and other costs decreased 7% for the nine-month period primarily because of decreased production taxes due to lower gas revenues, partially offset by increased production taxes due to higher oil revenues and increased gas deductions including amounts related to certain adjustments previously included in gas sales revenue are now recorded in this line item.

Production Expense

Production expense decreased 43% for the third quarter primarily because of decreased repairs and maintenance and labor. Production expense decreased 21% for the nine-month period primarily because of decreased repairs and maintenance, and credits received for material transfers, partially offset by increased labor due to timing of charges.

Development Costs

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

Overhead

Overhead was relatively flat for the third quarter and increased 13% 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. Underlying cumulative excess costs for the Kansas, Oklahoma and Wyoming conveyances remaining as of September 30, 2020 totaled $32.6 million ($26.1 million NPI), including accrued interest of $1.9 million ($1.5 million NPI). For further information on excess costs, see Note 5 to Condensed Financial Statements.

Contingencies

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

Forward-Looking Statements

Statements in this report relating to future plans, predictions, production, excess costs, litigation, arbitration, liquidity, financing, regulatory or court decisions, economic activity and recovery, and the impact of one or more waves of the COVID-19 pandemic and the accompanying government response on trade, travel and energy demand and 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, 2019, 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

Other Lawsuits and Governmental Proceedings

Item 1A. Risk Factors.

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

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

The recent spread of COVID-19, or the novel coronavirus, and the continually changing measures taken to mitigate the impact of single or multiple waves of the COVID-19 pandemic, are likely adversely affecting the business and operations of the operators of the properties underlying the net profits interests, which in turn could have an adverse effect on Trust distributions.

The business of the operators of the properties underlying the net profits interests is likely being adversely affected by the COVID-19 pandemic and measures being taken to mitigate its impact, especially to the extent areas experience multiple waves of the pandemic. As the coronavirus pandemic and government responses are rapidly escalating and de-escalating, the extent of the impact on domestic sales of crude oil and natural gas remains unknown and is constantly evolving. The industry has experienced a sharp and rapid decline in the demand for crude oil and natural gas as the U.S. and global economy, and commodity prices, have been negatively impacted as economic activity is curtailed in response to the COVID-19 pandemic, as well as due to other geopolitical factors. Official restrictions on non-essential activities, including “shelter in place” and “stay at home” orders, have recently been introduced or re-introduced throughout the U.S. and the world, which may impact operators’ production activities and the length of time such measures are in place may further adversely affect Trust distributions. Fewer businesses than normal are open and fewer people are going to work which has reduced the demand for oil and natural gas, plus our operators’ reliance on third-party suppliers, contractors, and service providers exposes them to possibility of delay or interruption of operations. At this time, the full extent to which COVID-19 will negatively impact the global economy and the oil and gas industry is uncertain, but pandemics or other significant public health events will most likely have a material adverse effect on operators’ business and financial condition which would likely have an adverse effect on Trust distributions.

Although the Trustee has decided to market the sale of the Trust’s assets, there is no assurance that a buyer of such assets will be found, or that if a buyer is found, there will be any funds available for distribution to unitholders.

The Trustee has decided to market the sale of the Trust’s assets, however, the Trustee is unable to predict whether a buyer for the Trust’s assets will be found, or if a buyer for such assets is found, the amount that may be paid for the Trust’s assets. Any material sale of assets and/or termination of the Trust requires at least 80% unitholder approval. The expense reserve used to pay liabilities of the Trust in the absence of current distributions was depleted in October 2020. Simmons Bank, the Trustee is currently paying the current liabilities of the Trust, which will include the ongoing costs and expenses of the Trust as well as the costs and expenses incurred to sell the Trust’s assets and dissolve the Trust. These costs and expenses will reduce the proceeds that are available from any sale of the Trust’s assets. 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. Accordingly, there can be no assurances as to the amount, if any, of the proceeds that will be available for distribution to unitholders.

Risk factors relating to the Trust are contained in Item 1A of the Trust’s Annual Report on Form 10-K for the fiscal year ended December 31, 2019. Other than the items listed above, 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, 2019.

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, 2020 (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: November 13, 2020	By	/s/ DAVID LEVY
		David Levy
		Vice President—Upstream Business Services

Large accelerated filer

Accelerated filer

Non-accelerated filer

Smaller reporting company

Emerging growth company