UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

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

For the quarterly period ended September 30, 2022March 31, 2023

OR

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

For the transition period from                 to                 .

Hugoton Royalty Trust

(Exact name of registrant as specified in its charter)

c/o The Corporate Trustee:

Simmons BankArgent Trust Company

2911 Turtle Creek Blvd, Suite 850

Dallas, Texas 75219

(Address of principal executive offices) (Zip Code)

Registrant’s telephone number, including area code (855) 588-7839

(Former name, former address and former fiscal year, if change since last report) NONE

Securities registered pursuant to Section 12(b) of the Act: None

Securities registered pursuant to Section 12(g) of the Act:

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 NovemberMay 1, 20222023

40,000,000

HUGOTON ROYALTY TRUST

FORM 10-Q FOR THE QUARTERLY PERIOD ENDED SEPTEMBER 30, 2022MARCH 31, 2023

TABLE OF CONTENTS

HUGOTON ROYALTY TRUST

GLOSSARY OF TERMS

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

HUGOTON ROYALTY TRUST

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

The condensed financial statements included herein are presented, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Unless specified otherwise, all amounts included herein are presented in U.S. dollars. Certain information and footnote disclosures normally included in annual financial statements have been condensed or omitted pursuant to such rules and regulations, although the Trustee believes that the disclosures are adequate to make the information presented not misleading. These condensed financial statements should be read in conjunction with the financial statements and the notes thereto included in the Trust’s latest Annual Report on Form 10-K. In the opinion of the Trustee, all adjustments, consisting only of normal recurring adjustments, necessary for a fair statement of the assets, liabilities and trust corpus of the Hugoton Royalty Trust at September 30, 2022March 31, 2023, and the distributable income and changes in trust corpus for the three-month and nine-month periods ended September 30,March 31, 2023 and 2022 and 2021 have been included. Distributable income for such interim periods is not necessarily indicative of the distributable income for the full year.

HUGOTON ROYALTY TRUST

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

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

HUGOTON ROYALTY TRUST

Condensed Statements of Distributable Income (Unaudited)

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

HUGOTON ROYALTY TRUST

Condensed Statements of Changes in Trust Corpus (Unaudited)

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

HUGOTON ROYALTY TRUST

Notes to Condensed Financial Statements (Unaudited)

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

The Trust’s financial statements differ from those prepared in conformity with U.S. GAAP because revenues are recognized when received rather than accrued in the month of production, expenses are recognized when paid rather than when incurred and certain cash reserves may be established by the Trustee for contingencies which would not be recorded under U.S. GAAP. This comprehensive basis of accounting other than U.S. GAAP corresponds to the accounting permitted for royalty trusts by the U.S. Securities and Exchange Commission, as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts.

Most accounting pronouncements apply to entities whose financial statements are prepared in accordance with U.S. GAAP, directing such entities to accrue or defer revenues and expenses in a period other than when such revenues were received or expenses were paid. Because the Trust’s financial statements are prepared on the modified cash basis, as described above, most accounting pronouncements are not applicable to the Trust’s financial statements.

Net profits interests in oil and gas properties

The initial carrying value of the net profits interests of $247,066,951 represents XTO Energy’s historical net book value for the interests on December 1, 1998, the date of the transfer to the Trust. During the second quarter 2016, the carrying value of the net profits interests was written down to its fair value of $28,801,000, resulting in an impairment of $57,306,527 charged directly to trust corpus. During the third quarter 2019, the carrying value of the net profits interests was written down to its fair value of zero, resulting in an impairment of $15,681,533 charged directly to trust corpus. Amortization of the net profits interests is calculated on a unit-of-production basis using proved reserves and is charged directly to trust corpus. Accumulated amortization was $174,078,891 as of September 30, 2019, when the net profits interests was written down to its fair value of zero.

Liquidity and Going Concern

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

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

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 theChieftain settlement on October 12-13, 2020. In the arbitration, the Trustee contended that the approximately $24.3 million allocation related to the Chieftain settlement was not a production cost and, therefore, there should not be a related adjustment to the Trust’s share of net proceeds. However, XTO Energy contended that the approximately $24.3 million was a production cost and should reduce the Trust’s share of net proceeds.

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

The reduction in the Trust’s share of net proceeds from the portion of the settlement amount the Panel has ruled may be charged against the Oklahoma conveyance would result in excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance while these excess costs are recovered. This award completes the portion of the arbitration related to the Chieftain settlement. Excess costs on any individual conveyance would not affect net proceeds to the Trust on any of the other remaining conveyances.

Other 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.

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.

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.

Trustee Resignation

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

Item 2. Trustee’s Discussion and Analysis

The following discussion should be read in conjunction with the Trustee’s discussion and analysis contained in the Trust’s 20212022 Annual Report on Form 10-K, as well as the condensed financial statements and notes thereto included in this Quarterly Report on Form 10-Q. The Trust’s Annual Report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all amendments to those reports are available on the Trust’s website at www.hgt-hugoton.comwww.hgt-hugoton.com..

Distributable Income

Quarter

For the quarter ended September 30, 2022,March 31, 2023, net profits income was $9,440,853$10,459,753 as compared to $0$347,410 for thirdfirst quarter 20212022 primarily due to higher oil and gas prices ($11.4 million), and net excess costs activity ($4.48.0 million), higher gas and oil prices ($7.8 million), and decreased overhead ($0.1 million), partially offset by increased taxes, transportation and other costs ($2.1 million), decreased oilgas and gasoil production ($4.42.0 million), increased production expenses ($1.0 million), increased taxes, transportation and other costs ($0.7 million), increased development costs ($0.2 million), and increased overhead ($0.10.7 million). See “Net Profits Income” below.

After adding interest income of $3,364, increasing the expense reserve $347,549,$17,544, and deducting administration expense of $132,309,$301,537, distributable income for the quarter ended September 30, 2022March 31, 2023, was $8,964,359,$10,175,760, or $0.224109$0.254394 per unit of beneficial interest. Administration expense for the quarter decreased $111,815increased $134,136 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 thirdfirst quarter 2021,2022, distributable income was $0, or $0.000000 per unit.

Distributions to unitholders for the quarter ended September 30, 2022March 31, 2023, were:

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

The following are explanations of significant variances on the underlying properties from third quarter 2021 to thirdfirst quarter 2022 and from theto first nine months of 2021 to the comparable period in 2022:quarter 2023:

Sales Volumes

Gas

Gas sales volumes decreased 11%6% for thirdfirst quarter 2023 primarily because of natural production decline, and timing of cash receipts. Gas sales volumes decreased 5% for the nine-month period as compared with the same 2021 periods primarily because of natural production decline, partially offset by timing of cash receipts, and decreased downtime.

Oil

Oil sales volumes decreased 37%23% for thirdfirst quarter 2023 primarily because of timing of cash receipts, and natural production decline. Oil sales volumes increased 12% for the nine-month period as compared with the same 2021 periods primarily because of timing of cash receipts, and decreased downtime, partially offset by natural production decline.

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

Sales Prices

Gas

The thirdfirst quarter 2023 average gas price was $10.56 per Mcf, up 57% from the first quarter 2022 average gas price was $7.73of $6.71 per Mcf, up 102% from the third quarter 2021 average gas price of $3.82 per Mcf. For the nine-month period, the average gas price increased 92% to $6.93 per Mcf in 2022 from $3.61 per Mcf in 2021.

Oil

The thirdfirst quarter 2023 average oil price was $79.00 per Bbl, up 5% from the first quarter 2022 average oil price was $104.54of $75.12 per Bbl, up 68% from the third quarter 2021 average oil price of $62.18 per Bbl. For the nine-month period, the average oil price increased 49% to $83.09 per Bbl in 2022 from $55.61 per Bbl in 2021.

Costs

Taxes, Transportation and Other

Taxes, transportation and other costs increased 33%107% for the thirdfirst quarter and 22% for the nine-month period2023 primarily because of the absence of Oklahoma production tax refunds and increased gas production and property taxes and gas deductions partially offset by receipt of production tax refunds.due to higher revenues.

Production Expense

Production expense increased 37%35% for the thirdfirst quarter and 27% for the nine-month period2023 primarily because of increased labor, repairs and maintenance, field expenses, and plug and abandonment expense, partially offset by decreased labor costs, and timing of the annual Oklahoma Senate Bill 168 fee.salt water disposal costs.

Overhead

Overhead increaseddecreased 3% for the thirdfirst quarter and 5% for the nine-month period.2023. Overhead is charged by XTO Energy and other operators for administrative expenses incurred to support operations of the underlying properties. Overhead fluctuates based on changes in the active well count and drilling activity on the underlying properties, as well as an annual cost level adjustment based on an industry index.

Excess Costs

If monthly costs exceed revenues for any conveyance, these excess costs must be recovered, with accrued interest, from future net proceeds of that conveyance and cannot reduce net profits income from another conveyance. There are no cumulative excess costs balances remaining for any conveyance as of September 30, 2022.March 31, 2023. For further information on excess costs, see Note 4 to Condensed Financial Statements.

Successor Trustee

Effective April 10, 2023, Argent Trust Company became the Trustee of the Trust. References herein to the Trustee for periods prior to April 10, 2023, shall refer to Simmons Bank, the former Trustee of the Trust.

Contingencies

For information on contingencies, see Note 3 to Condensed Financial Statements.

Forward-Looking Statements

Certain information included in this quarterly report and other materials filed, or to be filed, by the Trust with the Securities and Exchange Commission (as well as information included in oral statements or other written statements made or to be made by XTO Energy or the Trustee) contain forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended, and Section 27A of the Securities Act of 1933, as amended, relating to the Trust, operations of the underlying properties and the oil and gas industry. Such forward-looking statements may concern, among other things, potential asset sales or termination of the Trust, excess costs, reserve-to-production ratios, future production, development activities and associated operating expenses, future development plans by area, increased density drilling, maintenance projects, development, production, regulatory and other costs, oil and gas prices and expectations for future demand, the impact of inflation and economic downturns on economic activity, government policy and its impact on oil and gas prices and future demand, the development and competitiveness of alternative energy sources, pricing differentials, proved reserves, future net cash flows, production levels, expense reserve budgets, availability of financing, arbitration, litigation, liquidity, financing, political and regulatory matters, such as tax and environmental policy, climate policy, trade barriers, sanctions, competition, war and other political or security disturbances. Such forward-looking statements are based on XTO Energy’s and the Trustee’s current plans, expectations, assumptions, projections and estimates and are identified by words such as “may,” “intends,” “plans,” “anticipates,” “believes,” “estimates,” “should,” “could,” “would,” and similar words that convey the uncertainty of future events. These statements are not guarantees of future performance and involve certain risks, uncertainties and assumptions that are difficult to predict, including those detailed in Part I, Item 1A of the Trust’s Annual Report on Form 10-K for the year ended December 31, 2021,2022, which is incorporated by this reference as though fully set forth herein. Therefore, actual financial and operational results may differ materially from expectations, estimates or assumptions expressed in, implied in, or forecasted in such forward-looking statements. XTO Energy and the Trustee assume no duty to update these statements as of any future date.

Item 3.  Quantitative and Qualitative Disclosures about Market Risk

Not applicable. Upon qualifying as a smaller reporting company, this information is no longer required.

Item 4.  Controls and Procedures

As of the end of the period covered by this report, the Trustee carried out an evaluation of the effectiveness of the Trust’s disclosure controls and procedures pursuant to Exchange Act Rules 13a-15 and 15d-15. Based upon that evaluation, the Trustee concluded that the Trust’s disclosure controls and procedures are effective in recording, processing, summarizing and reporting, on a timely basis, information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 and are effective in ensuring that information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 is accumulated and communicated to the Trustee to allow timely decisions regarding required disclosure. In its evaluation of disclosure controls and procedures, the Trustee has relied, to the extent considered reasonable, on information provided by XTO Energy. There has not been any change in the Trust’s internal control over financial reporting during the period covered by this report that has materially affected, or is reasonably likely to materially affect, the Trust’s internal control over financial reporting.

PART II - OTHER INFORMATION

Item 1.  Legal Proceedings

Royalty Class Action and Arbitration

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 theChieftainlitigation. The Trust and XTO Energy conducted the interim hearing on the claims related to theChieftain settlement on October 12-13, 2020. In the arbitration, the Trustee contended that the approximately $24.3 million allocation related to the Chieftainsettlement was not a production cost and, therefore, there should not be a related adjustment to the Trust’s share of net proceeds. However, XTO Energy contended that the approximately $24.3 million was a production cost and should reduce the Trust’s share of net proceeds.

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

The reduction in the Trust’s share of net proceeds from the portion of the settlement amount the Panel has ruled may be charged against the Oklahoma conveyance would result in excess costs under the Oklahoma conveyance that would likely result in no distributions under the Oklahoma conveyance while these excess costs are recovered. This award completes the portion of the arbitration related to the Chieftain settlement. Excess costs on any individual conveyance would not affect net proceeds to the Trust on any of the other remaining conveyances.

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

Item 1A.  Risk Factors

There have been no material changes in the risk factors disclosed under Part I, Item 1A of the Trust’s Annual Report on Form 10-K for the year ended December 31, 2021.2022.

Item 6.   Exhibits

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this Report to be signed on its behalf by the undersigned thereunto duly authorized.

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