HGTXU 10-Q Quarterly Report June 30, 2010

HUGOTON ROYALTY TRUST

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10-Q 1 v190943_10q.htm Unassociated Document

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 June 30, 2010

¨ 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		(I.R.S. Employer
	incorporation or organization)		Identification No.)

	U.S. Trust, Bank of America
	Private Wealth Management
	P.O. Box 830650, Dallas, Texas		75283-0650
	(Address of principal executive offices)		(Zip Code)

(877) 228-5083

(Registrant’s telephone number, including area code)

NONE

(Former name, former address and former fiscal year, if change since last report)

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 þ No ¨

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files). Yes ¨ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act (check one):

	Large accelerated filer þ		Accelerated filer ¨
	Non-accelerated filer ¨ (Do not check if a smaller reporting company)		Smaller reporting company ¨

Indicate by check mark whether the registrant is a shell company (as defined in Exchange Act Rule 12b-2). Yes o No þ

Indicate the number of units of beneficial interest outstanding, as of the latest practicable date:

Outstanding as of July 1, 2010

40,000,000

HUGOTON ROYALTY TRUST

FORM 10-Q FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2010

	TABLE OF CONTENTS

		Page

	Glossary of Terms	3

PART I.	FINANCIAL INFORMATION

Item 1.	Financial Statements	4

	Report of Independent Registered Public Accounting Firm	5

	Condensed Statements of Assets, Liabilities and Trust Corpus at June 30, 2010 and December 31, 2009	6

	Condensed Statements of Distributable Income for the Three and Six Months Ended June 30, 2010 and 2009	7

	Condensed Statements of Changes in Trust Corpus for the Three and Six Months Ended June 30, 2010 and 2009	8

	Notes to Condensed Financial Statements	9

Item 2.	Trustee’s Discussion and Analysis	12

Item 3.	Quantitative and Qualitative Disclosures about Market Risk	17

Item 4.	Controls and Procedures	17

PART II.	OTHER INFORMATION

Item 1.	Legal Proceedings	18

Item 1A.	Risk Factors	19

Item 6.	Exhibits	19

	Signatures	20

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 tax reporting 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 trust’s financial statements and the notes thereto included in the trust’s Annual Report on Form 10-K. In the opinion of the trustee, all adjustments, consisting only of normal recurring adjustments, necessary to present fairly the assets, liabilities and trust corpus of the Hugoton Royalty Trust at June 30, 2010 and the distributable income and changes in trust corpus for the three- and six-month periods ended June 30, 2010 and 2009 have been included. Distributable income for such interim periods is not necessarily indicative of the distributable income for the full year.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

Bank of America, N.A., as Trustee

for the Hugoton Royalty Trust:

We have reviewed the accompanying condensed statement of assets, liabilities and trust corpus of the Hugoton Royalty Trust as of June 30, 2010 and the related condensed statements of distributable income and changes in trust corpus for the three- and six-month periods ended June 30, 2010 and 2009. These condensed financial statements are the responsibility of the trustee.

We conducted our review in accordance with standards established by the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures to financial data 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 Public Company Accounting Oversight Board (United States), 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.

The accompanying condensed financial statements are prepared on a modified cash basis as described in Note 1 which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America.

Based on our review, we are not aware of any material modifications that should be made to the condensed financial statements referred to above for them to be in conformity with the 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 of the Hugoton Royalty Trust as of December 31, 2009, and the related statements of distributable income and changes in trust corpus for the year then ended (not presented herein), included in the trust’s 2009 Annual Report on Form 10-K, and in our report dated February 22, 2010, 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, 2009 is fairly stated, in all material respects, in relation to the statement of assets, liabilities and trust corpus included in the trust’s 2009 Annual Report on Form 10-K from which it has been derived.

KPMG LLP

Fort Worth, Texas

July 20, 2010

HUGOTON ROYALTY TRUST

Condensed Statements of Assets, Liabilities and Trust Corpus

	June 30,		December 31,
	2010		2009
	(Unaudited)
ASSETS

Cash and short-term investments	$	5,098,720	$	4,284,800

Net profits interests in oil and gas properties - net (Note 1)		131,934,491		139,877,580

	$	137,033,211	$	144,162,380

LIABILITIES AND TRUST CORPUS

Distribution payable to unitholders	$	5,098,720	$	4,284,800

Trust corpus (40,000,000 units of beneficial interest
authorized and outstanding)		131,934,491		139,877,580

	$	137,033,211	$	144,162,380

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				Six Months Ended
	June 30				June 30
	2010		2009		2010		2009

Net profits income	$	18,974,132	$	4,537,110	$	35,873,354	$	10,314,535

Interest income		432		136		534		268

Total income		18,974,564		4,537,246		35,873,888		10,314,803

Administration expense		241,644		273,526		575,848		585,723

Distributable income	$	18,732,920	$	4,263,720	$	35,298,040	$	9,729,080

Distributable income per unit
(40,000,000 units)	$	0.468323	$	0.106593	$	0.882451	$	0.243227

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						Six Months Ended
	June 30						June 30
	2010			2009			2010			2009

Trust corpus,
beginning of period	$	136,036,821		$	145,526,964		$	139,877,580		$	146,722,015

Amortization of
net profits interests		(4,102,330	)		(1,168,788	)		(7,943,089	)		(2,363,839	)

Distributable income		18,732,920			4,263,720			35,298,040			9,729,080

Distributions declared		(18,732,920	)		(4,263,720	)		(35,298,040	)		(9,729,080	)

Trust corpus,
end of period	$	131,934,491		$	144,358,176		$	131,934,491		$	144,358,176

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 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 Bank of America, N.A., as trustee for the trust. On June 25, 2010, XTO Energy became a wholly owned subsidiary of Exxon Mobil Corporation. The merger is not expected to have a material effect on the trust annual distributable income, financial position or liquidity. 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 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.

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.

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. Amortization of the net profits interests is calculated on a unit-of-production basis and charged directly to trust corpus. Accumulated amortization was $115,132,460 as of June 30, 2010 and $107,189,371 as of December 31, 2009.

2.	Development Costs

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

	Three Months Ended						Six Months Ended
	June 30						June 30
	2010			2009			2010			2009
Cumulative actual costs under (over)
the amount deducted - beginning
of period	$	989,364		$	(3,594,645	)	$	909,477		$	(7,314,084	)
Actual costs		(2,145,830	)		(906,768	)		(3,565,943	)		(9,187,329	)
Budgeted costs deducted		1,500,000			5,000,000			3,000,000			17,000,000
Cumulative actual costs under
the amount deducted - end of period	$	343,534		$	498,587		$	343,534		$	498,587

The monthly development cost deduction was $4.0 million from the January 2009 distribution through the March 2009 distribution. As a result of decreased development activity and revisions to the 2009 development budget, the development cost deduction was decreased to $2.0 million beginning with the April 2009 distribution, to $1.0 million beginning with the June 2009 distribution and to $500,000 beginning with the September 2009 distribution and was maintained at that level through the June 2010 distribution. XTO Energy has advised the trustee that revised total 2010 budgeted development costs for the underlying properties are between $8 million and $10 million. 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 this monthly deduction will continue to be evaluated and revised as necessary.

3.	Contingencies

An amended petition for a class action lawsuit, Beer, et al. v. XTO Energy Inc. , was filed in January 2006 in the District Court of Texas County, Oklahoma by certain royalty owners of natural gas wells in Oklahoma and Kansas. The plaintiffs allege that XTO Energy has not properly accounted to the plaintiffs for the royalties to which they are entitled and seek an accounting regarding the natural gas and other products produced from their wells and the prices paid for the natural gas and other products produced, and for payment of the monies allegedly owed since June 2002, with a certain limited number of plaintiffs claiming monies owed for additional time. XTO Energy removed the case to federal district court in Oklahoma City. A hearing on the class certification was conducted in October 2008. At the class certification hearing, the plaintiffs sought to certify a class of royalty owners whose wells were connected to a processing plant owned by a subsidiary of XTO Energy in the Hugoton Field, with two sub-classes consisting of owners in Oklahoma and Kansas. In March 2009, the court granted the motion to certify the class. The plaintiffs filed a motion for summary judgment for only the two named plaintiffs. The court granted the motion in the amount of $12,779. A motion for summary judgment related to the remainder of the class was denied. Trial was scheduled for April 2010; however, the court vacated the trial date. At a hearing in April 2010, the court ruled that the class representatives were no longer proper representatives and stated that it is considering whether to dismiss class counsel or decertify the class in whole or in part. In a subsequent ruling in April 2010, the court decertified the class. In April 2010, new counsel and representative parties filed a motion to intervene and prosecute the Beer class. This motion has not been acted on by the court. XTO Energy has informed the trustee that it believes that it has strong defenses to this lawsuit and intends to vigorously defend its position. However, if XTO Energy ultimately makes any settlement payments or receives a judgment against it, the trust will bear its 80% share of such settlement or judgment related to production from the underlying properties. Additionally, if a judgment or settlement increases the amount of future payments to royalty owners, the trust would bear its proportionate share of the increased payments through reduced net proceeds. XTO Energy has informed the trustee that, although the amount of any reduction in net proceeds is not presently determinable, in its management’s opinion, the amount is not currently expected to be material to the trust’s annual distributable income, financial position or liquidity. It could, however, result in costs exceeding revenues on the properties underlying the Oklahoma and Kansas net profit interests for one or more monthly distributions, depending on the size of the judgment or settlement, if any, and the net proceeds being paid at that time.

In September 2008, a class action lawsuit was filed against XTO Energy styled Wallace B. Roderick Revocable Living Trust, et al. v. XTO Energy Inc. in the District Court of Kearny County, Kansas. XTO Energy removed the case to federal court in Wichita, Kansas. The plaintiffs allege that XTO Energy has improperly taken post-production costs from royalties paid to the plaintiffs from wells located in Kansas, Oklahoma and Colorado. The plaintiffs also seek to represent all royalty owners in these three states as a class. The plaintiffs’ claims overlap the claims made by the plaintiffs in the Beer case as to certain properties. XTO Energy has answered, denying all claims, and has filed motions to dismiss a portion of the claims. In January 2010, the federal court granted XTO Energy’s motion for summary judgment concerning prior settled class actions that overlap plaintiffs’ proposed class action. The court also granted XTO Energy’s motion to dismiss those portions of plaintiffs’ class that are currently being prosecuted in the Beer class action discussed above. The Roderick plaintiffs have also filed a motion to include the former Beer class into this litigation. The motion has not been ruled upon by the court. XTO Energy has informed the trustee that it believes that XTO Energy has strong defenses to this lawsuit and intends to vigorously defend its position. However, if XTO Energy ultimately makes any settlement payments or receives a judgment against it, the trust will bear its 80% share of such settlement or judgment related to production from the underlying properties. Additionally, if the judgment or settlement increases the amount of future payments to royalty owners, the trust would bear its proportionate share of the increased payments through reduced net proceeds. XTO Energy has informed the trustee that, although the amount of any reduction in net proceeds is not presently determinable, in its management’s opinion, the amount is not currently expected to be material to the trust’s annual distributable income, financial position or liquidity. It could, however, result in costs exceeding revenues on the properties underlying the Oklahoma and Kansas net profit interests for one or more monthly distributions, depending on the size of the judgment or settlement, if any, and the net proceeds being paid at that time.

In June 2010, a class action lawsuit was filed against XTO Energy styled Richard Nevins, et al. v. XTO Energy Inc., et al. in federal district court in Oklahoma City, Oklahoma. The case was administratively assigned to the same court where the Beer case is pending because the complaint purports to cover the same class as in Beer . XTO Energy has informed the trustee that it believes that XTO Energy has strong defenses to this lawsuit and intends to vigorously defend its position. However, if XTO Energy ultimately makes any settlement payments or receives a judgment against it, the trust will bear its 80% share of such settlement or judgment related to production from the underlying properties. Additionally, if the judgment or settlement increases the amount of future payments to royalty owners, the trust would bear its proportionate share of the increased payments through reduced net proceeds. XTO Energy has informed the trustee that, although the amount of any reduction in net proceeds is not presently determinable, in its management’s opinion, the amount is not currently expected to be material to the trust’s annual distributable income, financial position or liquidity. It could, however, result in costs exceeding revenues on the properties underlying the Oklahoma and Kansas net profit interests for one or more monthly distributions, depending on the size of the judgment or settlement, if any, and the net proceeds being paid at that time.

Certain of the underlying properties are involved in various other lawsuits and certain governmental proceedings arising in the ordinary course of business. XTO Energy has advised the trustee that it does not believe that the ultimate resolution of these claims will have a material effect on trust annual distributable income, financial position or liquidity.

Other

Several states have enacted legislation to require state income tax withholding from nonresident recipients of oil and gas proceeds. After consultation with its state tax counsel, XTO Energy has advised the trustee that it believes the trust is not subject to these withholding requirements. However, regulations could be issued by the various states which could change this conclusion. Should the trust be required to withhold state taxes, distributions to the unitholders would be reduced by the required amount, subject to the unitholder’s right to file a state tax return to claim any refund due.

4.	Excess Costs

Costs exceeded revenues by $513,475 ($410,780 to the trust) on properties underlying the Kansas net profits interests in October and November 2009. Lower gas prices due to reduced demand as a result of the U.S. recession and excess supply caused costs to exceed revenues on properties underlying the Kansas net profits interests. However, these excess costs did not reduce net proceeds from the remaining conveyances. XTO Energy advised the trustee that increased gas prices led to the partial recovery of excess costs of $410,957 ($328,766 net to the trust), plus accrued interest of $1,958 ($1,566 net to the trust) in December 2009 and the full recovery of excess costs of $102,518 ($82,014 net to the trust), plus accrued interest of $282 ($226 net to the trust) in January 2010.

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 2009 annual report, 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.hugotontrust.com.

Distributable Income

Quarter

For the quarter ended June 30, 2010, net profits income was $18,974,132, as compared to $4,537,110 for second quarter 2009. This 318% increase in net profits income is primarily the result of higher oil and gas prices and lower development costs, partially offset by decreased gas sales volumes and higher taxes, transportation and other costs. See “Net Profits Income” on the following page.

After adding interest income of $432 and deducting administration expense of $241,644, distributable income for the quarter ended June 30, 2010 was $18,732,920, or $0.468323 per unit of beneficial interest. Administration expense for the quarter was lower than the prior year quarter primarily because of the timing of expenditures. For second quarter 2009, distributable income was $4,263,720, or $0.106593 per unit. Distributions to unitholders for the quarter ended June 30, 2010 were:

		Distribution
Record Date	Payment Date	per Unit
April 30, 2010	May 14, 2010	$	0.196000
May 28, 2010	June 14, 2010		0.144855
June 30, 2010	July 15, 2010		0.127468

		$	0.468323

Six Months

For the six months ended June 30, 2010, net profits income was $35,873,354 compared with $10,314,535 for the same 2009 period. This 248% increase in net profits income is primarily the result of higher oil and gas prices and lower development costs, partially offset by decreased gas sales volumes and higher taxes, transportation and other costs. See “Net Profits Income” below.

After adding interest income of $534 and deducting administration expense of $575,848, distributable income for the six months ended June 30, 2010 was $35,298,040, or $0.882451 per unit of beneficial interest. For the six months ended June 30, 2009, distributable income was $9,729,080, or $0.243227 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									Six Months
	Ended June 30 (a)						Increase			Ended June 30 (a)						Increase
	2010			2009			(Decrease)			2010			2009			(Decrease)
Sales Volumes
Gas (Mcf) (b)
Underlying properties		6,113,559			6,462,737			(5	)%		12,044,510			13,573,002			(11	)%
Average per day		68,692			72,615			(5	)%		66,544			74,989			(11	)%
Net profits interests		3,432,982			1,421,757			141	%		6,647,060			2,875,683			131	%

Oil (Bbls) (b)
Underlying properties		71,105			69,193			3	%		134,329			133,811			-
Average per day		799			777			3	%		742			739			-
Net profits interests		41,321			18,718			121	%		75,647			33,207			128	%

Average Sales Prices
Gas (per Mcf)	$	5.17		$	2.96			75	%	$	5.15		$	3.48			48	%
Oil (per Bbl)	$	77.03		$	40.38			91	%	$	74.63		$	42.59			75	%

Revenues
Gas sales	$	31,609,753		$	19,100,449			65	%	$	62,004,921		$	47,296,640			31	%
Oil sales		5,477,186			2,794,176			96	%		10,025,556			5,698,493			76	%

Total Revenues		37,086,939			21,894,625			69	%		72,030,477			52,995,133			36	%

Costs
Taxes, transportation and other		4,319,945			3,029,840			43	%		8,510,316			6,815,720			25	%
Production expense		4,825,144			5,583,928			(14	)%		10,132,035			11,111,916			(9	)%
Development costs (c)		1,500,000			5,000,000			(70	)%		3,000,000			17,000,000			(82	)%
Overhead		2,724,185			2,609,469			4	%		5,443,634			5,174,328			5	%
Excess Costs (d)		-			-			-			102,800			-			-
Total Costs		13,369,274			16,223,237			(18	)%		27,188,785			40,101,964			(32	)%

Net Proceeds		23,717,665			5,671,388			318	%		44,841,692			12,893,169			248	%

Net Profits Percentage		80	%		80	%					80	%		80	%

Net Profits Income	$	18,974,132		$	4,537,110			318	%	$	35,873,354		$	10,314,535			248	%

(a)

Because of the two-month interval between time of production and receipt of net profits income by the trust, (1) oil and gas sales for the quarter ended June 30 generally represent production for the period February through April and (2) oil and gas sales for the six months ended June 30 generally represent production for the period November through April.

(b)

Oil and gas sales volumes are allocated to the net profits interests based upon a formula that considers oil and gas prices and the total amount of production expense and development costs. Changes in any of these factors may result in disproportionate fluctuations in volumes allocated to the net profits interests. Therefore, comparative discussion of oil and gas sales volumes is based on the underlying properties.

(c)	See Note 2 to Condensed Financial Statements.

(d)	See Note 4 to Condensed Financial Statements.

The following are explanations of significant variances on the underlying properties from second quarter 2009 to second quarter 2010 and from the first six months of 2009 to the comparable period in 2010:

Sales Volumes

Gas

Gas sales volumes decreased 5% for the second quarter as compared with the same 2009 period primarily because of natural production decline, partially offset by increased production from new wells and workovers and the timing of cash receipts. Gas sales volumes decreased 11% for the six-month period as compared with the same 2009 period primarily because of natural production decline and the timing of cash receipts, partially offset by increased production from new wells and workovers.

Oil

Oil sales volumes increased 3% for the second quarter as compared with the same 2009 period primarily because of increased production from new wells and workovers, partially offset by natural production decline and the timing of cash receipts. Oil sales volumes remained relatively flat for the six-month period as compared with the same 2009 period primarily because increased production from new wells and workovers was offset by natural production decline and the timing of cash receipts.

Sales Prices

Gas

The second quarter 2010 average gas price was $5.17 per Mcf, a 75% increase from the second quarter 2009 average gas price of $2.96 per Mcf. For the six-month period, the average gas price increased 48% to $5.15 per Mcf in 2010 from $3.48 per Mcf in 2009. Natural gas prices are affected by the level of North American production, weather, crude oil and natural gas liquids prices, the U.S. economy, storage levels and import levels of liquefied natural gas. Due to concerns of oversupply, declining demand due to the U.S. recession, falling oil prices and increased gas storage, gas prices declined during the first nine months of 2009. However, signs of possible economic improvement, higher oil prices and a relatively cold winter led to increased gas prices in late 2009 and early 2010. Gas prices weakened substantially in February and March 2010 due to renewed concerns of oversupply. Natural gas prices are expected to remain volatile. The second quarter 2010 gas price is primarily related to production from February through April 2010, when the average NYMEX price was $4.64 per MMBtu. The average NYMEX price for May and June 2010 was $4.21 per MMBtu. At July 14, 2010, the average NYMEX futures price for the following twelve months was $4.85 per MMBtu. Recent trust gas prices have averaged approximately 9% higher than the NYMEX price.

Oil

The second quarter 2010 average oil price was $77.03 per Bbl, a 91% increase from the second quarter 2009 average oil price of $40.38 per Bbl. The year-to-date average oil price increased 75% to $74.63 per Bbl in 2010 from $42.59 per Bbl in 2009. Lower demand as a result of the U.S. recession and slowing global economy, the tightened credit markets and rising crude oil supplies caused oil prices to decline sharply in 2008. However, signs of possible economic improvement have resulted in steadily higher oil prices during 2009 and early 2010. Oil prices are expected to remain volatile. The second quarter 2010 oil price is primarily related to production from February through April 2010, when the average NYMEX price was $80.68 per Bbl. The average NYMEX price for May and June 2010 was $74.95 per Bbl. At July 14, 2010, the average NYMEX futures price for the following twelve months was $79.46 per Bbl. Recent trust oil prices have averaged approximately 3% lower than the NYMEX price.

Costs

Taxes, Transportation and Other

Taxes, transportation and other increased 43% for the quarter and 25% for the six-month period primarily because of increased production taxes related to higher oil and gas revenues, partially offset by decreased other deductions as a percent of oil and gas revenues.

Production

Production expense decreased 14% for the quarter and 9% for the six-month period primarily because of decreased compressor, chemical and treating and outside operated costs, partially offset by decreased mechanical and marketing rebates included in 2009. In addition, decreased production expense for the six-month period also included decreased water disposal costs.

Development

Development costs deducted in the calculation of net profits income are based on the development budget. These development costs decreased 70% for the second quarter and 82% for the six-month period primarily because of decreased development activity. During the first half of 2010, two wells were completed on the underlying properties and there were no wells pending completion at June 30.

As of December 31, 2009, cumulative budgeted costs exceeded cumulative actual costs by approximately $0.9 million. In calculating net profits income, XTO Energy deducted budgeted development costs of $1.5 million for the quarter and $3.0 million for the six-month period. After considering actual development costs of $2.1 million for the quarter and $3.6 million for the six-month period, cumulative budgeted costs deducted exceeded actual costs by approximately $0.3 million at June 30, 2010.

XTO Energy has advised the trustee that revised total 2010 budgeted development costs for the underlying properties are between $8 million and $10 million. The 2010 budget year generally coincides with the trust distribution months from April 2010 through March 2011. The monthly development cost deduction will be reevaluated by XTO Energy and revised as necessary, based on the 2010 budget and the timing and amount of actual expenditures. See Note 2 to Condensed Financial Statements.

Overhead

Overhead increased 4% for the quarter and 5% for the six-month period primarily because of the annual rate adjustment based on an industry index.

Excess Costs

Contingencies

Other

On June 25, 2010, XTO Energy became a wholly owned subsidiary of Exxon Mobil Corporation. The merger is not expected to have a material effect on trust annual distributable income, financial position or liquidity.

Forward-Looking Statements

This Form 10-Q includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. 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, monthly development cost deductions, oil and gas prices and differentials to NYMEX prices, supply levels, future drilling, workover and restimulation plans, distributions to unitholders, industry and market conditions and the impact of the merger with Exxon Mobil Corporation, are forward-looking statements that are subject to risks and uncertainties which are detailed in Part I, Item 1A of the trust’s Annual Report on Form 10-K for the year ended December 31, 2009, which is incorporated by this reference as though fully set forth herein. Although XTO Energy and the trustee believe that the expectations reflected in such forward-looking statements are reasonable, neither XTO Energy nor the trustee can give any assurance that such expectations will prove to be correct.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

There have been no material changes in the trust’s market risks from the information disclosed in Part II, Item 7A of the trust’s Annual Report on Form 10-K for the year ended December 31, 2009.

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.

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, 2009.

Items 2 through 5.

Not applicable.

Item 6. Exhibits.

(a)

Exhibits.

Exhibit Number
and Description

(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 February 23, 2010 (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 BANK OF AMERICA, N.A., TRUSTEE

	By	/s/ Nancy G. Willis
		Nancy G. Willis
		Vice President

	EXXON MOBIL CORPORATION

Date: July 21, 2010	By	/s/ Patrick T. Mulva
		Patrick T. Mulva
		Vice President and Controller

TABLE OF CONTENTS

Part I - Financial Information Item 1. Financial Statements Item 2. Trustee S Discussion and Analysis Item 3. Quantitative and Qualitative Disclosures About Market Risk Item 4. Controls and Procedures Part II - Other Information Item 1. Legal Proceedings Item 1A. Risk Factors Item 6. Exhibits

HGTXU 10-Q Quarter ended June 30, 2010