HGTXU Hugoton Royalty Trust (QB)

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, 2019, 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, 2019 and 2018, 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 statements of assets, liabilities and trust corpus as of December 31, 2018, 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 29, 2019, 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, 2018, is fairly stated, in all material respects, in relation to the statements 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 Trust’s management. 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, 2018 and 2017, 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 June 30, 2019, and for the three-months and six-months then ended, the events and conditions impacting the Trust have

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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, TX

August 9, 2019

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

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

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HUGOTON ROYALTY TRUST

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. During the second quarter of 2019, excess costs on properties attributable to the NPI have continued to accumulate. The Trustee has considered the accumulation of these excess costs as part of its monitoring process and has concluded that there have been no events or changes in circumstances to indicate the carrying value of the NPI may not be recoverable, and there was no impairment of the NPI as of June 30, 2019.

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. 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 June 30, 2019 and $173,943,434 as of December 31, 2018.

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 no net proceeds to the Trust for the last nine months of 2018 and a reduction in the Trust’s expense reserve. In March through May of 2019, the Trust received net profits income from the Wyoming conveyance in an amount that covered all of the Trust’s administrative expenses and allowed for a partial replenishment of the expense reserve, but there were no funds to distribute to unitholders. The net profits income in these months are not necessarily indicative of future cash inflows for the next 12 months. 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 the 2018 development budget to include drilling costs of four horizontal wells in Major County, Oklahoma ($19.6 million net to the Trust) which have created an excess cost position on the Oklahoma conveyance. Additionally, excess cost positions on the Kansas and Wyoming conveyances have resulted in no net proceeds to the Trust for 2018. The Trustee has prepared a preliminary budget estimating the administrative expenses for the next 12 months which assumes no cash inflow from either net profits income or from other sources. This budget estimates that the expense reserve will be depleted by approximately April 2020. If either income or expenses differ from the assumptions in the Trustee’s preliminary

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budget, this date may be sooner or later than the estimate. Both the Trustee and XTO Energy believe the Trust could obtain additional financing, including by borrowing under one or more debt instruments, in an amount sufficient to pay its obligations for the next year. This outcome would ensure that the Trust could continue as a going concern; however, there is no assurance that such additional financing could be obtained. If the Trust obtains debt financing, any funds borrowed must be repaid in full, including accrued interest, before distributions to unitholders could be made. The Trust’s condensed financial statements do not include any adjustments that might result from the outcome of this uncertainty.

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:

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 previously accrued development budget through the end of the quarter. Subsequent to June 30, 2019, XTO Energy has advised the Trustee that the budgeted development cost accrual was fully depleted as of the July 2019 distribution. XTO Energy also had previously advised the Trustee that once the accrual was fully depleted, development costs will be charged to the Trust as they are incurred for all conveyances. XTO Energy has advised the Trustee that drilling in Major County, Oklahoma is complete and resulted in cost overruns due to unforeseen expenditures that will be charged to the Trust subsequent to the second quarter of 2019. XTO Energy has advised the Trustee that 2019 budgeted development costs for the underlying properties are between $2 million and $4 million. The 2019 budget year generally coincides with the Trust distribution months from April 2019 through March 2020. 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.

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.

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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 does not expect to file a Kansas income tax return for the 2019 tax year because it expects to have 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.

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 hearing on the claims related to the Chieftain settlement has been scheduled for October 7, 2019. Other Trustee claims related to disputed amounts on the computation of the Trust’s net proceeds for 2014 through 2016 were bifurcated from the issues regarding XTO’s right to charge the Chieftain settlement as a production cost and will be heard at a later date, which is still to be determined.

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If the approximately $24.3 million allocated portion of the Chieftain settlement results in an adjustment to the Trust’s share of net proceeds, it would result in additional excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance for several years, or more depending on the results of operations of the underlying properties, 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.

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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:

For the quarter ended June 30, 2019, 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 June 30, 2019 totaled $22.6 million, including accrued interest of $0.3  million.

Distributable Income

Quarter

For the quarter ended June 30, 2019, net profits income was $238,725 as compared to $0 for second quarter 2018. This increase in net profits income is primarily the result of decreased development costs ($5.2 million) and higher gas prices ($1.6 million), partially offset by net excess costs activity ($3.8 million), decreased oil and gas production ($1.3 million), increased production expenses ($0.7 million), increased taxes, transportation and other costs ($0.4 million), lower oil prices ($0.2 million), and increased overhead ($0.2 million). See “Net Profits Income” below.

After adding interest income of $5,632, deducting administration expense of $146,636, and partially replenishing $97,721 of the expense reserve to pay Trust expenses, distributable income for the quarter ended June 30, 2019 was $0, or $0.000000 per unit of beneficial interest. Administration expense for the quarter decreased $212,021 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 second quarter 2018, distributable income was $0 or $0.000000 per unit.

Distributions to unitholders for the quarter ended June 30, 2019 were:

Six Months

For the six months ended June 30, 2019, net profits income was $369,458 compared with $1,590,949 for the same 2018 period. This decrease in net profits income is primarily the result of decreased oil and gas production ($3.1 million), increased taxes, transportation and other costs ($1.0 million), increased development costs ($0.8 million), net excess costs activity ($0.7 million), lower oil prices ($0.4 million) and increased production expenses ($0.2 million), partially offset by higher gas prices ($4.5 million), and decreased overhead ($0.5 million). See “Net Profits Income” below.

After adding interest income of $11,912, deducting administration expense of $438,328, and utilizing $56,958 of the expense reserve to pay Trust expenses, distributable income for the six months ended June 30, 2019 was $0, or $0.000000 per unit of beneficial interest. Administration expense for the six months ended June 30, 2019 decreased $222,127 as compared to the same 2018 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 six months ended June 30, 2018, distributable income was $370,040 or $0.009251 per unit.

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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:

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

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The following are explanations of significant variances on the underlying properties from second quarter 2018 to second quarter 2019 and from the first six months of 2018 to the comparable period in 2019:

Sales Volumes

Gas

Gas sales volumes decreased 13% for second quarter and 14% for the six-month period as compared with the same 2018 periods primarily due to natural production decline, timing of cash receipts and change to account for a portion of gas sales as residue that were previously accounted for at the wellhead. This change does not affect the net profits income received by the Trust.

Oil

Oil sales volumes decreased 16% for second quarter and 11% for the six-month period as compared with the same 2018 periods primarily due to natural production decline and the 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 2019 average gas price was $3.30 per Mcf, a 25% increase from the second quarter 2018 average gas price of $2.64 per Mcf. For the six-month period, the average gas price increased 31% to $3.69 per Mcf in 2019 from $2.81 per Mcf in 2018. The second quarter 2019 gas price is primarily related to production from February through April 2019, when the average NYMEX price was $2.84 per MMBtu.

Oil

The second quarter 2019 average oil price was $55.45 per Bbl, a 9% decrease from the second quarter 2018 average oil price of $60.85 per Bbl. The year-to-date average oil price decreased 10% to $52.82 per Bbl in 2019 from $58.39 per Bbl in 2018. The second quarter 2019 oil price is primarily related to production from February through April 2019, when the average NYMEX price was $58.98 per Bbl.

Costs

Taxes, Transportation and Other

Taxes, transportation and other costs increased 25% for the second quarter and 33% for the six-month period primarily because certain adjustments previously included in gas sales revenue are now recorded in this line item.

Production Expense

Production expense increased 19% for the second quarter primarily because of reporting of expense well work activity previously reported in development costs and other higher operating expenses across all conveyances. Production expense increased 3% for the six-month period primarily because of reporting of expense well work activity previously reported in development costs, partially offset by lower labor costs due to timing of charges.

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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 second quarter and increased 14% for the six-month period. Subsequent to June 30, 2019, XTO Energy has advised the Trustee that the budgeted development cost accrual was fully depleted as of the July 2019 distribution. XTO Energy also had previously advised the Trustee that once the accrual was fully depleted, development costs will be charged to the Trust as they are incurred for all conveyances. XTO Energy has advised the Trustee that drilling in Major County, Oklahoma is complete and resulted in cost overruns due to unforeseen expenditures that will be charged to the Trust subsequent to the second quarter of 2019. 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 increased 9% for the quarter and decreased 11% 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, 2019 totaled $22.6 million ($18.1 million NPI), including accrued interest of $0.3 million ($0.3 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 or arbitration, events, or regulatory or court decisions 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, estimated changes in expenses, 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, 2018, 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.

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