UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

 

Washington, D.C. 20549

FORM 10-Q

þ		Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

o		Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

Commission file number 1-8033

PERMIAN BASIN ROYALTY TRUST

Texas (State or Other Jurisdiction of Incorporation or Organization)		75-6280532 (I.R.S. Employer Identification No.)

U.S. Trust, Bank of America
Private Wealth Management
Trust Department
901 Main Street
Dallas, Texas 75202
(Address of Principal Executive
Offices; Zip Code)

(214) 209-2400
(Registrant’s Telephone Number, Including Area Code)

     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 o

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 o No o

     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 o		Non-accelerated filer o (Do not check if a smaller reporting company)		Smaller reporting company o

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

     Number of Units of beneficial interest of the Trust outstanding at August 10, 2009: 46,608,796.

 

 

PERMIAN BASIN ROYALTY TRUST

The condensed financial statements included herein have been prepared by Bank of America, N.A. as Trustee for the Permian Basin Royalty Trust, 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. It is suggested that these condensed financial statements and notes thereto 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 to present fairly the assets, liabilities and trust corpus of the Permian Basin Royalty Trust at June 30, 2009, the distributable income for the three-month and six-month periods ended June 30, 2009 and 2008 and the changes in trust corpus for the six-month periods ended June 30, 2009 and 2008, have been included. The distributable income for such interim periods is not necessarily indicative of the distributable income for the full year.

Deloitte & Touche LLP, an independent registered public accounting firm, has made a limited review of the condensed financial statements as of June 30, 2009 and for the three-month and six-month periods ended June 30, 2009 and 2008 as stated in their report included herein.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

Unit Holders of Permian Basin Royalty Trust and
Bank of America, N.A., Trustee

We have reviewed the accompanying condensed statement of assets, liabilities and trust corpus of Permian Basin Royalty Trust as of June 30, 2009, and the related condensed statements of distributable income for the three-month and six-month periods ended June 30, 2009 and 2008 and changes in trust corpus for the six-month periods ended June 30, 2009 and 2008. These condensed financial statements are the responsibility of the Trustee.

We conducted our reviews in accordance with the standards of the Public Company Accounting Oversight Board (United States). 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 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.

As described in Note 1 to the condensed financial statements, these condensed financial statements have been prepared on a modified cash basis of accounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America.

Based on our reviews, we are not aware of any material modifications that should be made to such condensed interim financial statements 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 Permian Basin Royalty Trust as of December 31, 2008, and the related statements of distributable income and changes in trust corpus for the year then ended (not presented herein); and in our report dated March 2, 2009, 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, 2008, is fairly stated, in all material respects, in relation to the statement of assets, liabilities and trust corpus from which it has been derived.

/s/ Deloitte & Touche LLP

Dallas, Texas
August 10, 2009

PERMIAN BASIN ROYALTY TRUST

CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS

		June 30,				December 31,
		2009				2008
		(Unaudited)
ASSETS
Cash and short-term investments		$	2,192,146			$	5,147,216
Net overriding royalty interests in producing oil and gas properties (net of accumulated amortization of $9,844,825 and $9,804,423 at June 30, 2009 and December 31, 2008, respectively)		$	1,130,391			$	1,170,793
TOTAL ASSETS		$	3,322,537			$	6,318,009
LIABILITIES AND TRUST CORPUS
Distribution payable to Unit holders		$	2,192,146			$	5,147,216
Commitments and contingencies
Trust corpus - 46,608,796 Units of beneficial interest authorized and outstanding			1,130,391				1,170,793
TOTAL LIABILITIES AND TRUST CORPUS		$	3,322,537			$	6,318,009

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

PERMIAN BASIN ROYALTY TRUST

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)

		THREE				THREE
		MONTHS				MONTHS
		ENDED				ENDED
		June 30, 2009				June 30, 2008
Royalty income		$	6,725,240			$	27,260,526
Interest income			447				21,520
			6,725,687				27,282,046
General and administrative expenditures			(487,556	)			(359,490	)
Distributable income		$	6,238,131			$	26,922,556
Distributable income per Unit (46,608,796 Units)		$	.13			$	.58

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

PERMIAN BASIN ROYALTY TRUST

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)

		SIX				SIX
		MONTHS				MONTHS
		ENDED				ENDED
		June 30, 2009				June 30, 2008
Royalty income		$	14,438,626			$	53,684,924
Interest income			2,682				55,214
			14,441,308				53,740,138
General and administrative expenditures			(929,972	)			(714,246	)
Distributable income		$	13,511,336			$	53,025,892
Distributable income per Unit (46,608,796 Units)		$	.29			$	1.14

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

PERMIAN BASIN ROYALTY TRUST

CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)

		SIX				SIX
		MONTHS				MONTHS
		ENDED				ENDED
		June 30, 2009				June 30, 2008
Trust corpus, beginning of period		$	1,170,793			$	1,293,935
Amortization of net overriding royalty interests			(40,402	)			(65,592	)
Distributable income			13,511,336				53,025,892
Distributions declared			(13,511,336	)			(53,025,892	)
Total trust corpus, end of period		$	1,130,391			$	1,228,343
Distributions per Unit		$	.29			$	1.14

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

PERMIAN BASIN ROYALTY TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)

1.

BASIS OF ACCOUNTING

The Permian Basin Royalty Trust (“Trust”) was established as of November 1, 1980. The net overriding royalties conveyed to the Trust include: (1) a 75% net overriding royalty carved out of Southland Royalty Company’s fee mineral interests in the Waddell Ranch in Crane County, Texas (the “Waddell Ranch properties”); and (2) a 95% net overriding royalty carved out of Southland Royalty Company’s major producing royalty interests in Texas (the “Texas Royalty properties”). The net overriding royalty for the Texas Royalty properties is subject to the provisions of the lease agreements under which such royalties were created. The financial statements of the Trust are prepared on the following basis:

	•		Royalty income recorded for a month is the amount computed and paid to Bank of America, N.A. (“Trustee”) as Trustee for the Trust by the interest owners: Burlington Resources Oil & Gas Company LP (“BROG”), a subsidiary of ConocoPhillips for the Waddell Ranch properties and Riverhill Energy Corporation (“Riverhill Energy”), formerly a wholly owned subsidiary of Riverhill Capital Corporation (“Riverhill Capital”) and formerly an affiliate of Coastal Management Corporation (“CMC”), for the Texas Royalty properties. Schlumberger Technology Corporation (“STC”) currently conducts all field, technical and accounting operations on behalf of BROG with regard to the Waddell Ranch properties. Riverhill Energy currently conducts the accounting operations for the Texas Royalty properties. Royalty income consists of the amounts received by the owners of the interest burdened by the net overriding royalty interests (“Royalties”) from the sale of production less accrued production costs, development and drilling costs, applicable taxes, operating charges, and other costs and deductions multiplied by 75% in the case of the Waddell Ranch properties and 95% in the case of the Texas Royalty properties.
			As was previously reported, in February 1997, BROG sold its interest in the Texas Royalty properties to Riverhill Energy.
			The Trustee has been advised that in the first quarter of 1998, STC acquired all of the shares of stock of Riverhill Capital. Prior to such acquisition by STC, CMC and Riverhill Energy were wholly owned subsidiaries of Riverhill Capital. The Trustee has further been advised that in connection with STC’s acquisition of Riverhill Capital, the shareholders of Riverhill Capital acquired ownership of all of the shares of stock of Riverhill Energy. Thus, the ownership in the Texas Royalty properties referenced above remained in Riverhill Energy, the stock ownership of which was acquired by the former shareholders of Riverhill Capital.
			In 2007 the Bank of America private wealth management group officially became known as “U.S. Trust, Bank of America Private Wealth Management.” The legal entity that serves as Trustee of the Trust did not change, and references in this Form 10-Q to U.S.

Trust, Bank of America Private Wealth Management shall describe the legal entity Bank of America, N.A.

	•		Trust expenses recorded are based on liabilities paid and cash reserves established out of cash received or borrowed funds for liabilities and contingencies.
	•		Distributions to Unit holders are recorded when declared by the Trustee.
	•		Royalty income is computed separately for each of the conveyances under which the Royalties were conveyed to the Trust. If monthly costs exceed revenues for any conveyance (“excess costs”), such excess costs cannot reduce royalty income from other conveyances, but is carried forward with accrued interest to be recovered from future net proceeds of that conveyance.

The financial statements of the Trust differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) because revenues are not accrued in the month of production and certain cash reserves may be established for contingencies which would not be accrued in financial statements prepared in accordance with GAAP. Amortization of the Royalties calculated on a unit-of-production basis is charged directly to trust corpus. This comprehensive basis of accounting other than 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.

In September 2006, the FASB issued SFAS No. 157, Fair Value Measurements. This statement defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles (GAAP), and expands disclosures about fair value measurements. This statement is effective for financial statements issued for fiscal years beginning after November 15, 2007. The adoption of this statement did not have an effect on the Trust’s financial statements.

In December 2007, the FASB issued SFAS No. 141(R), Business Combinations. This statement requires the acquiring entity in a business combination to recognize the full fair value of assets

acquired and liabilities assumed in the transaction (whether a full or partial acquisition); establishes the acquisition-date fair value as the measurement objective for all assets acquired and liabilities assumed; requires expensing of most transaction and restructuring costs; and requires the acquirer to disclose to investors and other users all of the information needed to evaluate and understand the nature and financial effect of the business combination. This statement applies prospectively to business combinations for which the acquisition date is on or after January 1, 2009. The adoption of this statement did not have a material effect on the Trust’s financial statements.

In December 2007, the FASB issued SFAS No. 160, Noncontrolling Interests in Consolidated Financial Statements — an amendment of Accounting Research Bulletin No. 51. This statement requires reporting entities to present noncontrolling (minority) interests as equity (as opposed to as a liability or mezzanine equity) and provides guidance on the accounting for transactions between an entity and noncontrolling interests. This statement applies prospectively as of January 1, 2009, except for the presentation and disclosure requirements which will be applied retrospectively for all periods presented. The adoption of this statement did not have a material effect on the Trust’s financial statements.

In March 2008, the FASB issued FASB Statement No. 161, Disclosures about Derivative Instruments and Hedging Activities, an amendment of FASB Statement No. 133 (SFAS No. 161), effective for fiscal years and interim periods beginning after November 15, 2008, with early adoption allowed. SFAS No. 161 amends and expands the disclosure requirements of SFAS No. 133 with the intent to provide users of financial statements with an enhanced understanding of an entity’s use of derivative instruments and the effect of those derivative instruments on an entity’s financial statements. The adoption of this statement did not have a material effect on the Trust’s financial statements.

In April 2009, the FASB issued FSP FAS115-2 and FAS 124-2, Recognition and Presentation of Other-Than-Temporary Impairments. This FASB Staff Position (FSP) amends the other-than-temporary impairment guidance in GAAP for debt securities to make the guidance more operational and to improve the presentation and disclosure of other-than-temporary impairments on debt and equity securities in the financial statements. This FSP does not amend existing recognition and measurement guidance related to other-than-temporary impairments of equity securities. This statement is effective for interim and annual reporting periods ending after June 15, 2009, with early adoption permitted for periods ending after March 15, 2009. The adoption of these statements did not have a material effect on the Trust’s financial statements.

In April 2009, the FASB issued FSP FAS 107-1, Interim Disclosures about Fair Value of Financial Instruments. This FSP amends FASB Statement No. 107, Disclosures about Fair Value of Financial Instruments, to require disclosures about fair value of financial instruments for interim reporting periods of publicly traded companies as well as in annual financial statements. The adoption of this statement did not have an effect on the Trust’s financial statements.

In May 2009, the FASB issued SFAS No. 165, Subsequent Events, which establishes accounting and reporting standards for events that occur after the balance sheet date but before financial statements are issued or are available to be issued and requires the disclosure of the date through which a company has evaluated subsequent events. This statement is effective for the Trust for the period ended June 30, 2009 and the adoption did not have an impact on the financial statements. Refer to footnote 4 for required disclosures.

In June 2009, the FASB issued SFAS No. 166, Accounting for Transfers of Financial Assets, which changes the way entities account for securitizations. The new standard is effective for the Trust on January 1, 2010 and the adoption is not expected to have a significant impact on the financial statements.

In June 2009, the FASB issued SFAS No. 167, Amendments to FASB Interpretation No. 46(R), which changes the way entities account for special-purpose entities. The new standard is effective for the Trust on January 1, 2010 and the adoption is not expected to have a significant impact on the financial statements.

In June 2009, the FASB issued SFAS No. 168, The FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles—a replacement of FASB Statement No. 162. The Codification is effective July 1, 2009 at which point all then-existing non-SEC accounting and reporting standards will be superseded. The references to the Codification will be reflected in the Trust’s third quarter 2009 financial statements. This will not have an impact to the financial statements.

Pending Securities and Exchange Commission Rule

In December 2008, the Securities and Exchange Commission (the “SEC”) released Final Rule, Modernization of Oil and Gas Reporting. The new disclosure requirements include provisions that permit the use of new technologies to determine proved reserves if those technologies have been demonstrated empirically to lead to reliable conclusions about reserves volumes. The new requirements also will allow companies to disclose their probable and possible reserves to investors. In addition, the new disclosure requirements require companies to: (a) report the independence and qualifications of its reserves preparer or auditor; (b) file reports when a third party is relied upon to prepare reserves estimates or conducts a reserves audit; and (c) report oil and gas reserves using an average price based upon the prior 12-month period rather than year-end prices. The new disclosure requirements are effective for financial statements for fiscal years ending on or after December 31, 2009. The effect of adopting the SEC rules has not been determined, but it is not expected to have a significant effect on our reported financial position or distributable income.

2.

FEDERAL INCOME TAXES

For Federal income tax purposes, the Trust constitutes a fixed investment trust which is taxed as a grantor trust. A grantor trust is not subject to tax at the trust level. The Unit holders 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 Unit holder at the time such income is received or accrued by the Trust and not when distributed by the Trust.

The Royalties constitute “economic interests” in oil and gas properties for Federal income tax purposes. Unit holders must report their share of the revenues from the Royalties as ordinary income from oil and gas royalties and are entitled to claim depletion with respect to such income.

The Trust has on file technical advice memoranda confirming the tax treatment described above.

The classification of the Trust’s income for purposes of the passive loss rules may be important to a Unit holder. Royalty income generally is treated as portfolio income and does not offset passive losses.

Some Trust Units are held by middlemen, as such term is broadly defined in U.S. Treasury Regulations (and includes custodians, nominees, certain joint owners, and brokers holding an interest for a custodian in street name, collectively referred to herein as “middlemen”). Therefore, the Trustee considers the Trust to be a widely held fixed investment trust (“WHFIT”) for U.S. federal income tax purposes. U.S. Trust, Bank of America Private Wealth Management, 901 Main Street, 17th Floor, Dallas, Texas 75202, telephone number (214) 209-2400, is the representative of the Trust that will provide tax information in accordance with applicable U.S. Treasury Regulations governing the information reporting requirements of the Trust as a WHFIT. Tax information is also posted by the Trustee at www.pbt-permianbasintrust.com. Notwithstanding the foregoing, the middlemen holding Trust Units on behalf of Unit holders, and not the Trustee of the Trust, are solely responsible for complying with the information reporting requirements under the U.S. Treasury Regulations with respect to such Trust Units, including the issuance of IRS Forms 1099 and certain written tax statements. Unit holders whose Trust Units are held by middlemen should consult with such middlemen regarding the information that will be reported to them by the middlemen with respect to the Trust Units.

Unit holders should consult their tax advisors regarding Trust tax compliance matters.

3.

STATE TAX CONSIDERATIONS

All revenues from the Trust are from sources within Texas, which has no individual income tax. However, Texas imposes a margin tax on generally all entity types providing limited liability protection at a rate of 1% on gross revenues less certain deductions, as specifically set forth in the Texas margin tax statute. Entities subject to tax generally include trusts unless otherwise exempt. Trusts that receive at least 90% of their Federal gross income from designated passive sources, including royalties from mineral properties and other non-operated mineral interest income, and do not receive more than 10% of their income from operating an active trade or business, generally are exempt from the Texas margin tax as “passive entities.” The Trust should be exempt from Texas margin tax as a “passive entity.” Since the Trust should be exempt from Texas margin tax at the Trust level as a passive entity, each Unit holder that is considered a taxable entity under the Texas margin tax will generally be required to include its portion of Trust revenues in its own Texas margin tax computation. This revenue is sourced to Texas under provisions of the Texas Administrative Code that provide such income is sourced according to the principal place of business of the Trust, which is Texas.

Each Unit holder is urged to consult his own tax advisor regarding the requirements for filing state tax returns.

4.

SUBSEQUENT EVENTS

Subsequent to June 30, 2009, the Trust declared a distribution of .074511 per unit on July 21, 2009 payable on August 14, 2009, to Unit holders of record on July 31, 2009. Subsequent events have been evaluated through August 10, 2009, the date of issuance of these condensed financial statements.

Item 2.		Trustee’s Discussion and Analysis

Forward Looking Information

Certain information included in this report contains, 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 the Trust) may contain or include, 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. Such forward looking statements may be or may concern, among other things, capital expenditures, drilling activity, development activities, production efforts and volumes, hydrocarbon prices and the results thereof, and regulatory matters. Although the Trustee believes that the expectations reflected in such forward-looking statements are reasonable, such expectations are subject to numerous risks and uncertainties and the Trustee can give no assurance that they will prove correct. There are many factors, none of which is within the Trustee’s control, that may cause such expectations not to be realized, including, among other things, factors such as actual oil and gas prices and the recoverability of reserves, capital expenditures, general economic conditions, actions and policies of petroleum-producing nations and other changes in the domestic and international energy markets. Such forward looking statements generally are accompanied by words such as “estimate,” “expect,” “predict,” “anticipate,” “goal,” “should,” “assume,” “believe,” or other words that convey the uncertainty of future events or outcomes.

Three Months Ended June 30, 2009 Compared to Three Months Ended June 30, 2008

For the quarter ended June 30, 2009 royalty income received by the Trust amounted to $6,725,240 compared to royalty income of $27,260,526 during the second quarter of 2008. The decrease in royalty income is primarily attributable to significant decreases in both oil and gas prices and related production.

Interest income for the quarter ended June 30, 2009, was $447 compared to $21,520 during the second quarter of 2008. The decrease in interest income is primarily attributable to less funds available for investment and significantly lowered interest rates. General and administrative expenses during the second quarter of 2009 amounted to $487,556 compared to $359,490 during the second quarter of 2008. The increase in general and administrative expenses can be primarily attributed to increased printing expenses and other professional expenses.

These transactions resulted in distributable income for the quarter ended June 30, 2009 of $6,238,130 or $.133840 per Unit of beneficial interest. Distributions of $.036633, $.050173 and $.047032 per Unit were made to Unit holders of record as of April 30, 2009, May 29, 2009 and

June 30, 2009, respectively. For the second quarter of 2008, distributable income was $26,922,556, or $.58 per Unit of beneficial interest.

Royalty income for the Trust for the second quarter of the calendar year is associated with actual oil and gas production for the period of February, March and April of 2009 from the properties from which the Trust’s net overriding royalty interests (“Royalties”) were carved. Oil and gas sales attributable to the Royalties and the properties from which the Royalties were carved are as follows:

		Second Quarter
		2009				2008
Royalties:
Oil sales (Bbls)			127,053				194,164
Gas sales (Mcf)			480,941				945,837
Product Sales From Which The Royalties Were Carved:
Oil:
Total oil sales (Bbls)			262,962				272,317
Average per day (Bbls)			2,955				3,026
Average price per Bbl		$	39.47			$	97.94
Gas:
Total gas sales (Mcf)			1,320,596				1,464,597
Average per day (Mcf)			14,838				16,273
Average price per Mcf		$	3.90			$	10.17

The average received price of oil decreased to an average price per barrel of $39.47 per Bbl in the second quarter of 2009 compared to $97.94 per Bbl in the second quarter of 2008 due to worldwide market variables. The Trustee has been advised by ConocoPhillips that for the period of August 1, 1993, through June 30, 2009, the oil from the Waddell Ranch properties was being sold under a competitive bid to a third party. The average price of gas decreased from $10.17 per Mcf in the second quarter of 2008 to $3.90 per Mcf in the second quarter of 2009 due to change in overall market variables.

Since the oil and gas sales attributable to the Royalties are based on an allocation formula that is dependent on such factors as price and cost (including capital expenditures), the production amounts in the Royalties section of the above table do not provide a meaningful comparison. Oil sales volumes increased and gas sales volumes increased from the Underlying Properties (as defined in the Trust’s Annual Report on Form 10-K for the year ended December 31, 2008) for the applicable period in 2009 compared to 2008.

Capital expenditures for drilling, remedial and maintenance activities on the Waddell Ranch properties during the second quarter of 2009 totaled $1.9 million as compared to $1.4 million to the Trust for the second quarter of 2008. ConocoPhillips has informed the Trustee that the 2009 capital expenditures budget has been revised to $27.1 million (gross) for the Waddell Ranch

properties. The total amount of capital expenditures for 2008 was $24.1 million. Through the second quarter of 2009, capital expenditures of $11.4 million (gross) have been expended.

The Trustee has been advised that there was 1 well completed and 2 wells in progress, and 11 workover wells completed and 10 workover wells in progress, during the three months ended June 30, 2009 as compared to 0 wells completed, 2 wells in progress, 8 workover wells completed and 10 workover wells in progress for the three months ended June 30, 2008 on the Waddell Ranch properties. There were no facility projects completed and three projects in progress for the second quarter of 2009.

Lease operating expenses and property taxes totaled $4.5 million for the second quarter of 2009, compared to $3.9 million in the second quarter of 2008 on the Waddell Ranch properties. This increase is primarily attributable to increased ad valorem taxes and an increase in the project management fee.

Six Months Ended June 30, 2009 Compared to Six Months Ended June 30, 2008

For the six months ended June 30, 2009, royalty income received by the Trust amounted to $14,438,626 compared to royalty income of $53,684,924 for the six months ended June 30, 2008. The decrease in royalty income is primarily due to a substantial decrease in oil and gas prices in the first six months of 2009, compared to the first six months in 2008. Interest income for the six months ended June 30, 2009 was $2,682 compared to $55,214 for the six months ended June 30, 2008. The decrease in interest income is attributable primarily to lower interest rates. General and administrative expenses for the six months ended June 30, 2009 were $929,972. During the six months ended June 30, 2008, general and administrative expenses were $714,246. The increase in general and administrative expenses is primarily due to enhanced Unit holder reporting and other professional expenses.

These transactions resulted in distributable income for the six months ended June 30, 2009 of $13,511,336, or $.289888, per Unit. For the six months ended June 30, 2008, distributable income was $53,025,892, or $1.14, per Unit.

Royalty income for the Trust for the six months ended June 30, 2009 is associated with actual oil and gas production for the period November 2008 through April 2009 from the properties from which the Royalties were carved. Oil and gas production attributable to the Royalties and the properties from which the Royalties were carved are as follows:

		Six Months Ended
		2009				2008
Royalties:
Oil sales (Bbls)			252,355				399,045
Gas sales (Mcf)			991,023				1,965,643
Properties From Which The Royalties Were Carved:
Oil:
Total oil sales (Bbls)			546,714				557,907
Average per day (Bbls)			3,021				3,065
Average price per Bbl		$	40.31			$	92.75
Gas:
Total gas sales (Mcf)			2,826,763				3,013,388
Average per day (Mcf)			15,617				16,557
Average price per Mcf		$	4.42			$	9.82

The average received price of oil decreased during the six months ended June 30, 2009 to $40.31 per barrel compared to $92.75 per barrel for the same period in 2008. The decrease in the average price of oil is primarily due to decreased worldwide market demand in 2009. The decrease in the average price of gas from $9.82 per Mcf for the six months ended June 30, 2008 to $4.42 per Mcf for the six months ended June 30, 2009 is primarily the result of a decrease in the spot prices of natural gas.

Since the oil and gas sales volumes attributable to the Royalties are based on an allocation formula that is dependent on such factors as price and cost (including capital expenditures), the production amounts in the Royalties section of the above table do not provide a meaningful comparison. The oil and gas sales volumes from the properties from which the Royalties are carved have declined for the applicable period of 2009 compared to 2008.

Capital expenditures for the Waddell Ranch properties for the six months ended June 30, 2009 totaled $5.5 million compared to $1.7 million net to the Trust for the same period in 2008. ConocoPhillips has previously advised the Trust that the remaining 2009 capital expenditures budget for the Waddell Ranch properties is $15.7 million (gross).

The Trustee has been advised that 6 wells were drilled and completed and 2 wells to be completed on the Waddell Ranch properties during the six months ended June 30, 2009, as compared to no wells drilled and completed and 2 wells to be completed on the Waddell Ranch properties during the six months ended June 30, 2008. Approximately 13 workover wells were completed and approximately 10 workover wells were in progress as of June 30, 2009.

Lease operating expense and property taxes totaled $9.0 million for the six months ended June 30, 2009 compared to $8.0 million for the same period in 2008. The increase in lease operating expense is primarily attributable to the increase in the project management fee.

Calculation of Royalty Income

The Trust’s royalty income is computed as a percentage of the net profit from the operation of the properties in which the Trust owns net overriding royalty interests. These percentages of net profits are 75% and 95% in the case of the Waddell Ranch properties and the Texas Royalty properties, respectively. Royalty income received by the Trust for the three months ended June 30, 2009 and 2008, respectively, were computed as shown in the table below:

		Three Months Ended June 30,
		2009								2008
		Waddell				Texas				Waddell				Texas
		Ranch				Royalty				Ranch				Royalty
		Properties				Properties				Properties				Properties
Gross proceeds of sales from the Underlying Properties
Oil proceeds		$	7,214,806			$	3,164,894			$	18,469,698			$	8,200,052
Gas proceeds			4,347,466				803,528				13,142,139				1,752,905
Total			11,562,272				3,968,422				31,611,837				9,952,957
Less:
Severance tax:
Oil			273,978				119,771				787,842				315,386
Gas			216,299				49,470				765,357				118,635
Lease operating expenses and property tax:
Oil and gas			4,520,015				360,000				3,891,813				330,000
Other			37,775				—				70,016				—
Capital expenditures			1,903,516				—				1,388,760				—
Total			6,951,583				529,240				6,903,788				764,021
Net profits			4,610,689				3,439,182				24,708,049				9,188,936
Net overriding royalty interests			75	%			95	%			75	%			95	%
Royalty income			3,458,017				3,267,223				18,531,037				8,729,489

Critical Accounting Policies and Estimates

The Trust’s financial statements reflect the selection and application of accounting policies that require the Trust to make significant estimates and assumptions. The following are some of the more critical judgment areas in the application of accounting policies that currently affect the Trust’s financial condition and results of operations.

Basis of Accounting

The financial statements of the Trust are prepared on a modified cash basis and are not intended to present financial positions and results of operations in conformity with accounting principles

generally accepted in the United States of America (“GAAP”). Preparation of the Trust’s financial statements on such basis includes the following:

	•		Royalty income and interest income are recorded in the period in which amounts are received by the Trust rather than in the period of production and accrual, respectively.
	•		General and administrative expenses recorded are based on liabilities paid and cash reserves established out of cash received.
	•		Amortization of the royalty interests is calculated on a unit-of-production basis and charged directly to trust corpus when revenues are received.
	•		Distributions to Unit holders are recorded when declared by the Trustee (see Note 1 to the Financial Statements).

The financial statements of the Trust differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America because royalty income is not accrued in the period of production, general and administrative expenses recorded are based on liabilities paid and cash reserves established rather than on accrual basis, and amortization of the royalty interests is not charged against operating results. This comprehensive basis of accounting other than 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.

New Accounting Pronouncements

In September 2006, the FASB issued SFAS No. 157, Fair Value Measurements. This statement defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles (GAAP), and expands disclosures about fair value measurements. This statement is effective for financial statements issued for fiscal years beginning after November 15, 2007. The adoption of this statement did not have an effect on the Trust’s financial statements.

In December 2007, the FASB issued SFAS No. 141(R), Business Combinations. This statement requires the acquiring entity in a business combination to recognize the full fair value of assets

acquired and liabilities assumed in the transaction (whether a full or partial acquisition); establishes the acquisition-date fair value as the measurement objective for all assets acquired and liabilities assumed; requires expensing of most transaction and restructuring costs; and requires the acquirer to disclose to investors and other users all of the information needed to evaluate and understand the nature and financial effect of the business combination. This statement applies prospectively to business combinations for which the acquisition date is on or after January 1, 2009. The adoption of this statement did not have a material effect on the Trust’s financial statements.

In December 2007, the FASB issued SFAS No. 160, Noncontrolling Interests in Consolidated Financial Statements — an amendment of Accounting Research Bulletin No. 51. This statement requires reporting entities to present noncontrolling (minority) interests as equity (as opposed to as a liability or mezzanine equity) and provides guidance on the accounting for transactions between an entity and noncontrolling interests. This statement applies prospectively as of January 1, 2009, except for the presentation and disclosure requirements which will be applied retrospectively for all periods presented. The adoption of this statement did not have a material effect on the Trust’s financial statements.

In March 2008, the FASB issued FASB Statement No. 161, Disclosures about Derivative Instruments and Hedging Activities, an amendment of FASB Statement No. 133 (SFAS No. 161), effective for fiscal years and interim periods beginning after November 15, 2008, with early adoption allowed. SFAS No. 161 amends and expands the disclosure requirements of SFAS No. 133 with the intent to provide users of financial statements with an enhanced understanding of an entity’s use of derivative instruments and the effect of those derivative instruments on an entity's financial statements. The adoption of this statement did not have a material effect on the Trust's financial statements.

In April 2009, the FASB issued FSP FAS115-2 and FAS 124-2, Recognition and Presentation of Other-Than-Temporary Impairments. This FASB Staff Position (FSP) amends the other-than-temporary impairment guidance in GAAP for debt securities to make the guidance more operational and to improve the presentation and disclosure of other-than-temporary impairments on debt and equity securities in the financial statements. This FSP does not amend existing recognition and measurement guidance related to other-than-temporary impairments of equity securities. This statement is effective for interim and annual reporting periods ending after June 15, 2009, with early adoption permitted for periods ending after March 15, 2009. The adoption of these statements did not have a material effect on the Trust’s financial statements.

     In April 2009, the FASB issued FSP FAS 107-1, Interim Disclosures about Fair Value of Financial Instruments. This FSP amends FASB Statement No. 107, Disclosures about Fair Value of Financial Instruments, to require disclosures about fair value of financial instruments for interim reporting periods of publicly traded companies as well as in annual financial statements. The adoption of this statement did not have an effect on the Trust’s financial statements.

In May 2009, the FASB issued SFAS No. 165, Subsequent Events, which establishes accounting and reporting standards for events that occur after the balance sheet date but before financial statements are issued or are available to be issued and requires the disclosure of the date through which a company has evaluated subsequent events. This statement is effective for the Trust for the period ended June 30, 2009 and the adoption did not have an impact on the financial statements. Refer to footnote 4 for required disclosures.

In June 2009, the FASB issued SFAS No. 166, Accounting for Transfers of Financial Assets, which changes the way entities account for securitizations. The new standard is effective for the Trust on January 1, 2010 and the adoption is not expected to have a significant impact on the financial statements.

In June 2009, the FASB issued SFAS No. 167, Amendments to FASB Interpretation No. 46(R), which changes the way entities account for special-purpose entities. The new standard is effective for the Trust on January 1, 2010 and the adoption is not expected to have a significant impact on the financial statements.

In June 2009, the FASB issued SFAS No. 168, The FASB Accounting Standards Codification and the Hierarchy of Generally Accepted Accounting Principles—a replacement of FASB Statement No. 162. The Codification is effective July 1, 2009 at which point all then-existing non-SEC accounting and reporting standards will be superseded. The references to the Codification will be reflected in the Trust’s third quarter 2009 financial statements. This will not have an impact to the financial statements.

Revenue Recognition

Revenues from the royalty interests are recognized in the period in which amounts are received by the Trust. Royalty income received by the Trust in a given calendar year will generally reflect the proceeds, on an entitlement basis, from natural gas produced and sold for the twelve-month period ended October 31^st in that calendar year. Royalty income received by the Trust in the second quarter of 2009 generally reflects the proceeds associated with actual oil and gas production for the period of February 2008 through April 2009.

Reserve Disclosure

As of January 1, 2009, independent petroleum engineers estimated the net proved reserves attributable to the royalty interests. In accordance with Statement of Financial Standards No. 69, “Disclosures About Oil and Gas Producing Activities,” estimates of future net revenues from proved reserves have been prepared using year-end contractual gas prices and related costs. Numerous uncertainties are inherent in estimating volumes and the value of proved reserves and in projecting future production rates and the timing of development of non-producing reserves.

Such reserve estimates are subject to change as additional information becomes available. The reserves actually recovered and the timing of production may be substantially different from the reserves estimates.

Contingencies

Contingencies related to the Underlying Properties that are unfavorably resolved would generally be reflected by the Trust as reductions to future royalty income payments to the Trust with corresponding reductions to cash distributions to Unit holders. The Trustee is aware of no such items as of June 30, 2009.

Use of Estimates

The preparation of financial statements in conformity with the basis of accounting described above requires management to make estimates and assumptions that affect the reported amounts of certain assets, liabilities, revenues and expenses as of and for the reporting period. Actual results may differ from such estimates.

Pending Securities and Exchange Commission Rule

In December 2008, the Securities and Exchange Commission (the “SEC”) released Final Rule, Modernization of Oil and Gas Reporting. The new disclosure requirements include provisions that permit the use of new technologies to determine proved reserves if those technologies have been demonstrated empirically to lead to reliable conclusions about reserves volumes. The new requirements also will allow companies to disclose their probable and possible reserves to investors. In addition, the new disclosure requirements require companies to: (a) report the independence and qualifications of its reserves preparer or auditor; (b) file reports when a third party is relied upon to prepare reserves estimates or conducts a reserves audit; and (c) report oil and gas reserves using an average price based upon the prior 12-month period rather than year-end prices. The new disclosure requirements are effective for financial statements for fiscal years ending on or after December 31, 2009. The effect of adopting the SEC rules has not been determined, but it is not expected to have a significant effect on our reported financial position or distributable income.

Item 3.		Qualitative and Quantitative Disclosures About Market Risk

There have been no material changes in the Trust’s market risk, as disclosed in the Trust’s Annual Report on Form 10-K for the fiscal year ended December 31, 2008.

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 design and operation 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 control 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 Burlington Resources Oil & Gas Company LP, the owner of the Waddell Ranch properties, and Riverhill Energy Corporation, the owner of the Texas Royalty

properties. 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

Items 1 through 5.

Not applicable.

Item 6.		Exhibits

	4.1		Permian Basin Royalty Trust Indenture dated November 3, 1980, between Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) and The First National Bank of Fort Worth (now Bank of America, N.A.), as Trustee, heretofore filed as Exhibit (4)(a) to the Trust’s Annual Report on Form 10-K to the Securities and Exchange Commission for the fiscal year ended December 31, 1980 is incorporated herein by reference.
	4.2		Net Overriding Royalty Conveyance (Permian Basin Royalty Trust) from Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Bank of America, N.A.), as Trustee, dated November 3, 1980 (without Schedules), heretofore filed as Exhibit (4)(b) to the Trust’s Annual Report on Form 10-K to the Securities and Exchange Commission for the fiscal year ended December 31, 1980 is incorporated herein by reference.
	4.3		Net Overriding Royalty Conveyance (Permian Basin Royalty Trust — Waddell Ranch) from Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Bank of America, N.A.), as Trustee, dated November 3, 1980 (without Schedules), heretofore filed as Exhibit (4)(c) to the Trust’s Annual Report on Form 10-K to the Securities and Exchange Commission for the fiscal year ended December 31, 1980 is incorporated herein by reference.
	10.1		Registration Rights Agreement dated as of July 21, 2004 by and between Burlington Resources Inc. and Bank of America, N.A., as trustee of Permian Basin Royalty Trust, heretofore filed as Exhibit 10.1 to the Trust’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarterly period ended June 30, 2004 is incorporated herein by reference.
	10.2		Underwriting Agreement dated December 15, 2005 among the Permian Basin Royalty Trust, Burlington Resources, Inc., Burlington Resources Oil & Gas L.P. and Lehman Brothers Inc. and Wachovia Capital Markets, LLC as representatives of the several underwriters, heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities

			and Exchange Commission filed on December 19, 2005, is incorporated herein by reference.
	10.3		Underwriting Agreement dated August 2, 2005 among the Permian Basin Royalty Trust, Burlington Resources, Inc., Burlington Resources Oil & Gas L.P. and Goldman Sachs & Co. and Lehman Brothers Inc. as representatives of the several underwriters, heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed on August 8, 2005, is incorporated herein by reference.
	10.4		Underwriting Agreement dated August 17, 2006, among Permian Basin Royalty Trust, ConocoPhillips, Burlington Resources Oil & Gas Company LP and Lehman Brothers Inc. and Wachovia Capital Markets, LLC as representatives of the several underwriters heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed on August 22, 2006, is incorporated herein by reference.
	31.1		Certification by Ron E. Hooper, Senior Vice President and Trust Administrator of Bank of America, Trustee of Permian Basin Royalty Trust, dated August 10, 2009 and submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
	32.1		Certificate by Bank of America, Trustee of Permian Basin Royalty Trust, dated August 10, 2009 and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350).

     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.

Date: August 10, 2009

(The Trust has no directors or executive officers.)

Exhibit
Number				Exhibit
	4.1			Permian Basin Royalty Trust Indenture dated November 3, 1980, between Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) and The First National Bank of Fort Worth (now Bank of America, N.A.), as Trustee, heretofore filed as Exhibit (4)(a) to the Trust’s Annual Report on Form 10-K to the Securities and Exchange Commission for the fiscal year ended December 31, 1980 is incorporated herein by reference.*
	4.2			Net Overriding Royalty Conveyance (Permian Basin Royalty Trust) from Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Bank of America, N.A.), as Trustee, dated November 3, 1980 (without Schedules), heretofore filed as Exhibit (4)(b) to the Trust’s Annual Report on Form 10-K to the Securities and Exchange Commission for the fiscal year ended December 31, 1980 is incorporated herein by reference.*
	4.3			Net Overriding Royalty Conveyance (Permian Basin Royalty Trust — Waddell Ranch) from Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Bank of America, N.A.), as Trustee, dated November 3, 1980 (without Schedules), heretofore filed as Exhibit (4)(c) to the Trust’s Annual Report on Form 10-K to the Securities and Exchange Commission for the fiscal year ended December 31, 1980 is incorporated herein by reference.*
	10.1			Registration Rights Agreement dated as of July 21, 2004 by and between Burlington Resources Inc. and Bank of America, N.A., as trustee of Permian Basin Royalty Trust, heretofore filed as Exhibit 10.1 to the Trust’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarterly period ended June 30, 2004 is incorporated herein by reference.*
	10.2			Underwriting Agreement dated December 15, 2005 among the Permian Basin Royalty Trust, Burlington Resources, Inc., Burlington Resources Oil & Gas L.P. and Lehman Brothers Inc. and Wachovia Capital Markets, LLC as representatives of the several underwriters, heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed on December 19, 2005, is incorporated herein by reference.*
	10.3			Underwriting Agreement dated August 2, 2005 among the Permian Basin Royalty Trust, Burlington Resources, Inc., Burlington Resources Oil & Gas L.P. and Goldman Sachs & Co. and Lehman Brothers Inc. as representatives of the several underwriters, heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed on August 8, 2005, is incorporated herein by reference.*

Exhibit
Number				Exhibit
	10.4			Underwriting Agreement dated August 17, 2006, among Permian Basin Royalty Trust, ConocoPhillips, Burlington Resources Oil & Gas Company LP and Lehman Brothers Inc. and Wachovia Capital Markets, LLC as representatives of the several underwriters heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed on August 22, 2006, is incorporated herein by reference.*
	31.1			Certification by Ron E. Hooper, Senior Vice President and Trust Administrator of Bank of America, Trustee of Permian Basin Royalty Trust, dated August 10, 2009 and submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
	32.1			Certificate by Bank of America, Trustee of Permian Basin Royalty Trust, dated August 10, 2009 and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350).