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

For the Quarterly Period ended September 30, 2007

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

For the transition period from                      to                     

PERMIAN BASIN ROYALTY TRUST

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

Bank of America, N.A.
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 is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act.

     Large accelerated filer o      Accelerated filer þ      Non-accelerated filer 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 November 1, 2007: 46,608,796.

 

 

PERMIAN BASIN ROYALTY TRUST

PART I – FINANCIAL INFORMATION

Item 1. Financial Statements

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 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 September 30, 2007, and the distributable income for the three-month and nine-month periods ended September 30, 2007 and 2006 and the changes in trust corpus for the nine-month periods ended September 30, 2007 and 2006 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 September 30, 2007 and for the three-month and nine-month periods ended September 30, 2007 and 2006 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 September 30, 2007, and the related condensed statements of distributable income for the three-month and nine-month periods ended September 30, 2007 and 2006 and the changes in trust corpus for the nine-month periods ended September 30, 2007 and 2006. 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 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, 2006, 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 13, 2007, 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, 2006, 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
November 6, 2007

PERMIAN BASIN ROYALTY TRUST

CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS

		September 30,				December 31,
		2007				2006
		(Unaudited)				(Unaudited)
ASSETS
Cash and short-term investments		$	6,576,732				5,135,136
Net overriding royalty interests in producing oil and gas properties (net of accumulated amortization of $9,639,410 and $9,536,002 at September 30, 2007 and December 31, 2006, respectively)			1,335,806				1,439,214
TOTAL ASSETS		$	7,912,538				6,574,350
LIABILITIES AND TRUST CORPUS
Distribution payable to Unit holders		$	6,576,732				5,135,136
Commitments and contingencies
Trust corpus – 46,608,796 Units of beneficial interest authorized and outstanding			1,335,806				1,439,214
TOTAL LIABILITIES AND TRUST CORPUS		$	7,912,538				6,574,350

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 MONTHS ENDED								NINE MONTHS ENDED
		September 30								September 30
		2007				2006				2007				2006
Royalty income		$	18,000,323			$	18,697,269			$	45,320,284			$	51,655,740
Interest income			28,609				31,634				86,602				95,350
			18,028,932				18,728,903				45,406,886				51,751,090
General and administrative expenditures			(99,342	)			(152,561	)			(743,962	)			(677,389	)
Distributable income		$	17,929,590			$	18,576,342			$	44,662,924			$	51,073,701
Distributable income per Unit (46,608,796 Units)		$	.384683			$	.398559			$	.958251			$	1.095795

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

PERMIAN BASIN ROYALTY TRUST

CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)

		NINE MONTHS ENDED
		September 30
		2007				2006
Trust corpus, beginning of Period		$	1,439,214			$	1,610,630
Amortization of net overriding royalty interests			(103,408	)			(129,951	)
Distributable income			44,662,924				51,073,701
Distributions declared			(44,662,924	)			(51,073,701	)
Total Trust Corpus, end of period		$	1,335,806			$	1,480,679
Distributions per unit		$	.958251			$	1.095795

The accompanying notes are an integral part of these condensed 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 (“BRI”) 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 interests 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 was 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 was 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.
	•		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 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 under 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.

New Accounting Pronouncements

		In February 2006, the FASB issued SFAS No. 155, Accounting for Certain Hybrid Financial Instruments – an amendment of FASB Statements No. 133 Accounting for Derivative Instruments and No. 140 Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities. This statement resolves issues addressed in Statement 133 Implementation Issue No. D1, Application of Statement 133 to Beneficial interests in Securitized Financial Assets. This statement is effective for all financial instruments acquired or issued after the beginning of an entity’s first fiscal year that begins after September 15, 2006. The Trust has no financial instruments and accordingly, the adoption of this new Standard did not impact the financial statements of the Trust.
		In March 2006, the FASB issued SFAS No. 156, Accounting for Servicing of Financial Assets – an amendment of FASB Statements No. 140 Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities. This statement requires an entity to recognize a servicing asset or servicing liability each time it undertakes an obligation to service a financial asset by entering into a servicing contract in certain situations. This statement is effective as of the beginning of an entity’s first fiscal year that begins after September 15, 2006. The adoption of this statement did not have an effect on the Trust’s financial statements.
		In July 2006, the FASB issued FASB Interpretation No. 48 (“FIN 48”), “Accounting for Uncertainty in Income Taxes,” which clarifies the accounting for uncertainty in income taxes recognized in the financial statements in accordance with SFAS No. 109, “Accounting for Income Taxes.” FIN 48 is effective for fiscal years beginning after December 15, 2006. The adoption of this statement did not have an effect on the Trust’s financial statements.

		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 Trustee does not believe that the adoption of this statement will have a material effect on the Trust’s financial statements.
		In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities, including an amendment of FASB Statement No. 115. This statement permits entities to chose to measure many financial instruments and certain other items at fair value. This statement is effective as of the beginning of an entity’s first fiscal year that begins after November 15, 2007. The Trustee does not believe that the adoption of this statement will have a material effect on the Trust’s financial statements.

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.
		The Trustee assumes that some Trust Units are held by a middleman, 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). Therefore, the Trustee considers the Trust to be a widely held fixed investment trust (“WHFIT”) for U.S. federal income tax purposes. Bank of America, N.A., 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.

Unit holders should consult their tax advisors for further information.

3.

STATE TAX CONSIDERATIONS

		All revenues from the Trust are from sources within Texas, which has no individual income tax. However, in May 2006, the State of Texas passed legislation to implement a new margin tax at a rate of 1% to be imposed on gross revenues less certain deductions as specifically set forth in the new legislation. The effective date of the new legislation is January 1, 2008, but the tax generally will be imposed on gross revenues generated in 2007 and thereafter. Entities subject to tax generally include trusts unless otherwise exempt and most other types of entities that provide limited liability protection. Trusts that meet certain statutory requirements are generally exempt from the margin tax as “passive entities.” Tex H.B. 3928, 80th Leg. R.S. (2007), which was recently passed by the Texas legislature and signed by Governor Rick Perry on June 15, 2007, clarifies that the Trust is exempt from margin tax as a passive entity. Accordingly, each Unit holder that is a business entity subject to the margin tax will generally include its share of the Trust’s revenues in its own margin tax computation.
		Each Unit holder is urged to consult his own tax advisor regarding the requirements for filing state tax returns.

4.

SUBSEQUENT EVENTS

Subsequent to September 30, 2007, the Trust declared a distribution on October 19, 2007 of $.147137 per unit payable on November 15, 2007, to Unit holders of record on October 31, 2007.

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.

     On October 15, 2007, the Bank of America private wealth management group officially became known as “U.S. Trust, Bank of America Private Wealth Management” as a result of Bank of America’s acquisition of U.S. Trust Corporation. This change is a brand name change only and the legal entity that serves as the Trustee for the Trust will continue to be Bank of America, N. A.

Three Months Ended September 30, 2007 Compared to Three Months Ended September 30, 2006

For the quarter ended September 30, 2007 royalty income received by the Trust amounted to $18,000,323 compared to royalty income of $18,697,269 during the third quarter of 2006. The decrease in royalty income is primarily attributable to decreases in oil prices and oil production but offset by increased gas prices and gas production.

Interest income for the quarter ended September 30, 2007, was $28,609 compared to $31,635 during the third quarter of 2006. The decrease in interest income is primarily attributable to lower interest rates and less funds available for investment. General and administrative expenses during the third quarter of 2007 amounted to $99,342 compared to $152,561 during the third quarter of 2006. The decrease in general and administrative expenses can be primarily attributed to the timing of payment of expenses.

These transactions resulted in distributable income for the quarter ended September 30, 2007 of $17,929,590 or $.384683 per Unit of beneficial interest. Distributions of $.116911, $.126665 and $.141104 per Unit were made to Unit holders of record as of July 31, 2007, August 31, 2007 and September 28, 2007, respectively. For the third quarter of 2006, distributable income was $18,576,342, or $.398559 per Unit of beneficial interest.

Royalty income for the Trust for the third quarter of the calendar year is associated with actual oil and gas production for the period of May, June and July 2007 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:

		Third Quarter
		2007				2006
Royalties:
Oil sales (Bbls)			188,507				198,283
Gas sales (Mcf)			901,602				869,934
Properties From Which The Royalties Were Carved:
Oil:
Total oil sales (Bbls)			294,548				308,150
Average per day (Bbls)			3,202				3,349
Average price per Bbl		$	61.78			$	65.95
Gas:
Total gas sales (Mcf)			1,611,556				1,539,034
Average per day (Mcf)			17,517				16,729
Average price per Mcf		$	8.02			$	7.42

The posted price of oil decreased to an average price per barrel of $61.78 per Bbl in the third quarter of 2007, compared to $65.95 per Bbl in the third quarter of 2006. The Trustee has been advised by ConocoPhillips that for the period of August 1, 1993, through September 30, 2007, the oil from the Waddell Ranch properties was being sold under a competitive bid to a third

party. The average price of gas increased from $7.42 per Mcf in the third quarter of 2006 to $8.02 per Mcf in the third quarter of 2007 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 and gas sales volumes from the Underlying Properties (as defined in the Trust’s Annual Report on Form 10-K for the year ended December 31, 2006) decreased for the applicable period in 2007 compared to 2006.

Capital expenditures for drilling, remedial and maintenance activities on the Waddell Ranch properties during the third quarter of 2007 totaled $2,936,440 as compared to $3,332,426 for the third quarter of 2006. ConocoPhillips has informed the Trustee that the 2007 capital expenditures budget has been revised to $19.6 million for the Waddell Ranch properties. The total amount of capital expenditures for 2006 was $15.3 million. Through the third quarter of 2007, capital expenditures of $11.5 million have been expended.

The Trustee has been advised that there were no wells completed and only 1 drill well in progress, and no workover wells completed and 1 workover well in progress, during the three months ended September 30, 2007 as compared to 7 wells completed, 6 wells in progress, 6 workover wells completed and 19 workover wells in progress for the three months ended September 30, 2006 on the Waddell Ranch properties. There were no facility projects completed and no projects in progress for the third quarter of 2007.

Lease operating expense and property taxes totaled $3.6 million for the third quarter of 2007, compared to $3.4 million in the third quarter of 2006 on the Waddell Ranch properties. This increase is primarily attributable to increased electrical costs and increased ad valorem taxes paid for the third quarter in 2007.

Nine Months Ended September 30, 2007 and 2006

For the nine months ended September 30, 2007, royalty income received by the Trust amounted to $45,320,284 compared to royalty income of $51,655,740 for the nine months ended September 30, 2006. The decrease in royalty income is primarily due to a decrease in oil and gas prices in the first nine months of 2007 compared to the first nine months in 2006. Interest income for the nine months ended September 30, 2007 was $86,602 compared to $95,350 for the nine months ended September 30, 2006. The decrease in interest income is attributable primarily to a decrease in interest rates and less funds available for investment. General and administrative expenses for the nine months ended September 30, 2007 were $743,962. During the nine months ended September 30, 2006, general and administrative expenses were $677,389. The increase in general and administrative expenses is primarily due to enhanced Unit holder tax reporting to more Unit holders.

These transactions resulted in distributable income for the nine months ended September 30, 2007 of $44,662,924, or $.958251 per Unit. For the nine months ended September 30, 2006, distributable income was $51,073,701, or $1.095795 per Unit.

Royalty income for the Trust for the period ended September 30, 2007 is associated with actual oil and gas production for the period November 2006 through July 2007 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:

		First Nine Months
		2007				2006
Royalties:
Oil sales (Bbls)			524,564				574,593
Gas sales (Mcf)			2,4111,577				2,420,037
Properties From Which The Royalties Were Carved:
Oil:
Total oil sales (Bbls)			881,724				912,712
Average per day (Bbls)			3,230				3,343
Average price per Bbl		$	56.41			$	59.43
Gas:
Total gas sales (Mcf)			4,763,647				4,394,940
Average per day (Mcf)			17,449				16,099
Average price per Mcf		$	7.31			$	8.05

The average price of oil decreased during the nine months ended September 30, 2007 to $56.41 per barrel compared to $59.43 per barrel for the same period in 2006. The decrease in the average price of oil is primarily due to decreased demand in 2007, caused by a worldwide market conditions. The decrease in the average price of gas from $8.05 per Mcf for the nine months ended September 30, 2006 to $7.31 per Mcf for the nine months ended September 30, 2007 is primarily the result of an 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 remained relatively constant for the applicable period of 2007 compared to 2006.

Capital expenditures for the Waddell Ranch properties for the nine months ended September 30, 2007 totaled $11.5 million compared to $9.6 million for the same period in 2006. ConocoPhillips has previously advised the Trust that the remaining 2007 capital expenditures budget for the Waddell Ranch properties is $8.1 million.

The Trust has been advised that 13 wells were drilled and completed and only 1 well to be completed on the Waddell Ranch properties during the nine months ended September 30, 2007, as compared to 15 wells drilled and completed and 6 wells to be completed on the Waddell Ranch Properties during the nine months ended September 30, 2006. Approximately 22 workover wells were completed and approximately 1 workover well was in progress as of September 30, 2007. Approximately 1 facilities project was completed and 0 facilities projects were in progress.

Lease operating expense and property taxes totaled $11.2 million in 2007 compared to $10.4 million for the same period in 2006. The increase in lease operating expense is primarily attributable to higher electrical costs than in 2006 and increased property taxes.

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 September 30, 2007 and 2006, respectively, were computed as shown in the table below:

		THREE MONTHS ENDED SEPTEMBER 30,
		2007								2006
		WADDELL				TEXAS				WADDELL				TEXAS
		RANCH				ROYALTY				RANCH				ROYALTY
		PROPERTIES				PROPERTIES				PROPERTIES				PROPERTIES
Gross proceeds of sales from the Underlying Properties
Oil proceeds		$	12,973,597			$	5,222,568			$	14,384,090			$	5,937,295
Gas proceeds			11,539,620				1,386,647				10,074,892				1,340,989
Total			24,513,217				6,609,215				24,458,982				7,278,284
Less:
Severance tax:
Oil			563,061				198,641				626,555				202,914
Gas			859,692				90,839				677,834				90,410
Lease operating expense and property tax:
Oil and gas			3,740,591				330,000				3,379,091				285,000
Capital expenditures			2,936,440								3,332,426
Total			8,099,784				619,480				8,015,906				578,324
Net profits			16,413,433				5,989,735				16,443,076				6,699,960
Net overriding royalty interests			75	%			95	%			75	%			95	%
Royalty income		$	12,310,075			$	5,690,248			$	12,332,307			$	6,364,962

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 the 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.

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 31st in that calendar year. Royalty income received by the Trust in the third quarter of 2007 generally reflects the proceeds associated with actual oil and gas production for the period of May, June and July 2007.

Reserve Disclosure

As of January 1, 2007, 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 not aware of any such items as of September 30, 2007.

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.

New Accounting Pronouncements

In February 2006, the FASB issued SFAS No. 155, Accounting for Certain Hybrid Financial Instruments – an amendment of FASB Statements No. 133 Accounting for Derivative Instruments and No. 140 Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities. This statement resolves issues addressed in Statement 133 Implementation Issue No. D1, Application of Statement 133 to Beneficial interests in Securitized Financial Assets. This statement is effective for all financial instruments acquired or issued after the beginning of an entity’s first fiscal year that begins after September 15, 2006. The Trust has no financial instruments and accordingly, the adoption of this new Standard did not impact the financial statements of the Trust.

In March 2006, the FASB issued SFAS No. 156, Accounting for Servicing of Financial Assets – an amendment of FASB Statements No. 140 Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities. This statement requires an entity to recognize a servicing asset or servicing liability each time it undertakes an obligation to service a financial asset by entering into a servicing contract in certain situations. This statement is effective as of the beginning of an entity’s first fiscal year that begins after September 15, 2006. The adoption of this statement did not have an effect on the Trust’s financial statements.

In July 2006, the FASB issued FASB Interpretation No. 48 (“FIN 48”), “Accounting for Uncertainty in Income Taxes,” which clarifies the accounting for uncertainty in income taxes recognized in the financial statements in accordance with SFAS No. 109, “Accounting for Income Taxes.” FIN 48 is effective for fiscal years beginning after December 15, 2006. The adoption of this statement did not have an effect on the Trust’s financial statements.

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 Trustee does not believe that the adoption of this statement will have a material effect on the Trust’s financial statements.

In February 2007, the FASB issued SFAS No. 159, The Fair Value Option for Financial Assets and Financial Liabilities, including an amendment of FASB Statement No. 115. This statement permits entities to chose to measure many financial instruments and certain other items at fair value. This statement is effective as of the beginning of an entity’s first fiscal year that begins after November 15, 2007. The Trustee does not believe that the adoption of this statement will have a material effect on the Trust’s financial statements.

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, 2006.

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 timely alerting the Trustee to material information relating to the Trust required to be included in the Trust’s periodic filings with the Securities and Exchange Commission. 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 and Reports on Form 8-K

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 filed 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 filed 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 November 7, 2007 and submitted pursuant to Rule 13a-14(a)/15d-14(a).
32.1		Certificate by Bank of America, Trustee of Permian Basin Royalty Trust, dated November 7, 2007 and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

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.

		BANK OF AMERICA, N.A.,
		TRUSTEE FOR THE
		PERMIAN BASIN ROYALTY TRUST
		By:		/s/ RON E. HOOPER
				Ron E. Hooper,
				Senior Vice President and Trust Administrator
				Bank of America, N.A.

Date: November 7, 2007

(The Trust has no directors or executive officers.)

INDEX TO EXHIBITS

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 filed 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 filed 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 November 7, 2007 and submitted pursuant to Rule 13a-14(a)/15d-14(a).
32.1		Certificate by Bank of America, Trustee of Permian Basin Royalty Trust, dated November 7, 2007 and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.