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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549   FORM 10-Q
 [ X ] Quarterly Report Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934 For the Quarterly
Period ended September 30, 2004
 [  ] Transition Report Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934 For the transition
period from  to
 Commission file number 1-8033 PERMIAN BASIN ROYALTY TRUST (Exact Name of
Registrant as Specified in the Permian Basin Royalty Trust
Indenture)
 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 [ X ] No [  ] Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of Security Exchange Act of 1934). Yes [ X ] No [  ] Number of Units of beneficial interest of the Trust outstanding at
November 1, 2004: 46,608,796.




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TABLE OF CONTENTS  PART I  FINANCIAL INFORMATIONItem 1. Financial StatementsREPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRMCONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUSCONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)Item 2. Trustees Discussion and Analysis of Financial Condition and Results of OperationsItem 3. Quantitative and Qualitative Disclosures About Market RiskItem 4. Controls and ProceduresPART II  OTHER INFORMATIONItems 1 through 5.Item 6. ExhibitsSIGNATURESINDEX TO EXHIBITSCertification Pursuant to Rule 13a-14(a)/15d-14(a) and Section 302Certificate Pursuant to Section 906    Table of Contents  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, 2004, and the distributable income and changes in trust corpus
for the three-month and nine-month periods ended September 30, 2004 and 2003
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, independent certified public accountants, has made a
limited review of the condensed financial statements as of September 30, 2004
and for the three-month and nine-month periods ended September 30, 2004 and
2003 as stated in their report included herein. 2




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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, 2004, and
the related condensed statements of distributable income for the three-month
and nine-month periods ended September 30, 2004 and 2003 and changes in trust
corpus for the three-month and nine-month periods ended September 30, 2004 and
2003. These condensed financial statements are the responsibility of the
Trustee. We conducted our reviews in accordance with standards of the Public Company
Accounting Oversight Board (United States). A review of interim financial
information consists principally of applying analytical procedures to financial
data and of making inquiries of persons responsible for financial and
accounting matters. It is substantially less in scope than an audit conducted
in accordance with 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,
2003, 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 9, 2004, 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,
2003, 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 5, 2004 3




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PERMIAN BASIN ROYALTY TRUST 
 CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS September 30,2004(Unaudited)
    
    December 31,2003ASSETSCash and short-term investments
    
    $
    4,523,057
    
    
    $
    2,873,975Net overriding royalty interests in
producing oil and gas properties (net
of accumulated amortization of
$9,123,213,and $8,983,700 at September 30, 2004 and December 31, 2003,
respectively)
    
    
    1,852,081
    
    
    
    1,991,594TOTAL ASSETS
    
    $
    6,375,138
    
    
    $
    4,865,569LIABILITIES AND TRUST CORPUSDistribution payable to Unit holders
    
    $
    4,523,057
    
    
    $
    2,873,975Commitments and contingenciesTrust corpus - 46,608,796 Units of
beneficial interest authorized and
outstanding
    
    
    1,852,081
    
    
    
    1,991,594TOTAL LIABILITIES
AND TRUST CORPUS
    
    $
    6,375,138
    
    
    $
    4,865,569
 The accompanying notes to condensed financial statements are an integral part of these statements. 4




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PERMIAN BASIN ROYALTY TRUST 
 CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED) THREE MONTHS ENDED
    
    NINE MONTHS ENDEDSeptember 30
    
    September 302004
    
    2003
    
    2004
    
    2003Royalty income
    
    $
    11,647,036
    
    
    $
    8,692,172
    
    
    $
    29,899,365
    
    
    $
    24,244,896Interest income
    
    
    4,185
    
    
    
    3,468
    
    
    
    10,837
    
    
    
    10,40211,651,221
    
    
    
    8,695,640
    
    
    
    29,910,202
    
    
    
    24,255,298General and
administrative
expenditures
    
    
    (84,828
    )
    
    
    (71,646
    )
    
    
    (412,929
    )
    
    
    (436,780
    )Distributable income
    
    $
    11,566,393
    
    
    $
    8,623,994
    
    
    $
    29,497,273
    
    
    $
    23,818,518Distributable income per
Unit (46,608,796 Units)
    
    $
    .248159
    
    
    $
    .185029
    
    
    $
    .632869
    
    
    $
    .511031
 The accompanying notes to condensed financial statements are an integral part
of these statements. 5




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PERMIAN BASIN ROYALTY TRUST 
 CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED) THREE MONTHS ENDED
    
    NINE MONTHS ENDEDSeptember 30
    
    September 302004
    
    2003
    
    2004
    
    2003Trust corpus,
beginning of period
    
    $
    1,902,570
    
    
    $
    2,085,667
    
    
    $
    1,991,594
    
    
    $
    2,192,393Amortization of net
overriding royalty
interests
    
    
    (50,489
    )
    
    
    (47,364
    )
    
    
    (139,513
    )
    
    
    (134,090
    )Distributable income
    
    
    11,566,393
    
    
    
    8,623,994
    
    
    
    29,497,273
    
    
    
    23,818,518Distributions declared
    
    
    (11,566,393
    )
    
    
    (8,623,994
    )
    
    
    (29,497,273
    )
    
    
    (23,818,518
    )Total Trust Corpus,
end of period
    
    $
    1,852,081
    
    
    $
    2,038,303
    
    
    $
    1,852,081
    
    
    $
    2,038,303Distributions per unit
    
    $
    .248159
    
    
    $
    .185029
    
    
    $
    .632869
    
    
    $
    .511031
 The accompanying notes to condensed financial statements are an integral part
of these statements. 6




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PERMIAN BASIN ROYALTY TRUST 
 NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)  1.
    
    BASIS OF ACCOUNTINGThe 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 whhich 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
(BROG) 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. CMC currently conducts all field,
technical and accounting operations on behalf of BROG with regard to
the Waddell Ranch properties. CMC also conducts the accounting
operations for the Texas Royalty properties on behalf of Riverhill
Energy. 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,
Schlumberger Technology Corporation (Schlumberger) acquired all
of the shares of stock of Riverhill Capital. Prior to such
acquisition by Schlumberger, CMC and Riverhill Energy were wholly-owned subsidiaries of Riverhill Capital. The Trustee has further
been advised that in connection with Schlumberger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. 7




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
    
    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 in financial statements.
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.2.
    
    FEDERAL INCOME TAXESFor 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.Unit holders should consult their tax advisors for further information.3.
    
    SUBSEQUENT EVENTSSubsequent to September 30, 2004, the Trust declared a distribution on
October 19, 2004 of $.111463 payable on November 15, 2004, to Unit
holders of record on October 29, 2004. 8




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Item 2. Trustees Discussion and Analysis of Financial Condition and Results of
Operations 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 September 30, 2004 Compared to Three Months Ended September
30, 2003 For the quarter ended September 30, 2004 royalty income received by the Trust
amounted to $11,647,036 compared to royalty income of $8,692,172 during the
third quarter of 2003. The increase in royalty income is primarily
attributable to significant increases in both oil and gas prices. Interest income for the quarter ended September 30, 2004, was $4,185 compared
to $3,468 during the third quarter of 2003. The increase in interest income is
primarily attributable to higher interest rates and more funds available for
investment. General and administrative expenses during the third quarter of
2004 amounted to $84,828 compared to $71,646 during the third quarter of 2003.
The increase 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, 2004 of $11,566,393 or $.248159 per Unit of beneficial interest.
Distributions of $.077787, $.073328 and $.097042 per Unit were made to Unit
holders of record as of July 30, 2004, August 31, 2004 and September 30, 2004,
respectively. For the third quarter of 2003, distributable income was
$8,623,994, or $.185029 per Unit of beneficial interest. 9




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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 2004 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 Quarter2004
    
    2003Royalties:Oil sales (Bbls)
    
    
    198,032
    
    
    
    183,456Gas sales (Mcf)
    
    
    849,226
    
    
    
    859,067Product
Sales From Which The Royalties Were Carved:Oil:Total oil sales (Bbls)
    
    
    319,176
    
    
    
    300,864Average per day (Bbls)
    
    
    3,496
    
    
    
    3,270Average price per Bbl
    
    $
    36.74
    
    
    $
    27.85Gas:Total gas sales (Mcf)
    
    
    1,535,078
    
    
    
    1,589,614Average per day (Mcf)
    
    
    16,686
    
    
    
    17,278Average price per Mcf
    
    $
    5.82
    
    
    $
    4.71
 The posted price of oil increased to an average price per barrel of $36.74 per
Bbl in the third quarter of 2004, compared to $27.85 per Bbl in the third
quarter of 2003. The Trustee has been advised by BROG that for the period
August 1, 1993, through September 30, 2004, 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 $4.71 per Mcf in the third quarter of 2003
to $5.82 per Mcf in the third quarter of 2004. This increase is primarily
attributable to a significant increase in gas prices earlier in the year of
2004. 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 volumes
from the Underlying Properties (as defined in the Trusts Annual Report on Form
10-K for the year ended December 31, 2003) increased for the applicable period
in 2004 compared to 2003. Capital expenditures for drilling, remedial and maintenance activities on the
Waddell Ranch properties during the third quarter of 2004 totaled $2,685,591 as
compared to $1,479,891 for the third quarter of 2003. BROG has informed the
Trustee that the 2004 capital expenditures budget has been revised to $13.2
million for the Waddell Ranch. The total amount of capital expenditures for
2003 was $9.1 million. Through the third quarter of 2004, capital expenditures
of $6.0 million have been expended. The Trustee has been advised that there were 3 wells completed and no wells in
progress and 4 workover wells in progress during the three months ended
September 30, 2004 as compared to 2 10




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wells completed or in progress for the three months ended September 30, 2003 on
the Waddell Ranch properties. Lease operating expense and property taxes totaled $2.2 million for the third
quarter of 2004, compared to $2.5 million in the third quarter of 2003 on the
Waddell Ranch properties. This decrease is primarily attributable to lower
maintenance costs for the quarter. Nine Months Ended September 30, 2004 and 2003 For the nine months ended September 30, 2004, royalty income received by the
Trust amounted to $29,899,365 compared to royalty income of $24,244,896 for the
nine months ended September 30, 2003. The increase in royalty income is
primarily due to a increase in both oil and gas prices in the first nine months
of 2004 compared to the first nine months in 2003. Interest income for the nine
months ended September 30, 2004 was $10,837 compared to $10,402 for the nine
months ended September 30, 2003. The increase in interest income is primarily
attributable to higher interest rates. General and
administrative expenses for the nine months ended September 30, 2004 were
$412,929. During the nine months ended September 30, 2003, general and
administrative expenses were $436,780. The decrease in general and
administrative expenses is primarily due to timing differences in the receipt
and payment of these expenses. These transactions resulted in distributable income for the nine months ended
September 30, 2004 of $29,497,273, or $.632869 per Unit. For the nine months
ended September 30, 2003, distributable income was $23,818,518, or $.51 per
Unit. Royalty income for the Trust for the nine months ended September 30, 2004 is
associated with actual oil and gas production for the nine-month period November 2003
through July 2004 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 Months2004
    
    2003Royalties:Oil sales (Bbls)
    
    
    556,209
    
    
    
    518,481Gas sales (Mcf)
    
    
    2,250,966
    
    
    
    2,306,295Product
Sales From Which The Royalties Were Carved:Oil:Total oil sales (Bbls)
    
    
    899,708
    
    
    
    909,377Average per day (Bbls)
    
    
    3,284
    
    
    
    3,331Average price per Bbl
    
    $
    33.58
    
    
    $
    28.59Gas:Total gas sales (Mcf)
    
    
    4,445,109
    
    
    
    4,681,576Average per day (Mcf)
    
    
    16,223
    
    
    
    17,149Average price per Mcf
    
    $
    5.23
    
    
    $
    4.67
 The average price of oil increased during the nine months ended September 30,
2004 to $33.58 per barrel compared to $28.59 per barrel for the same period in
2003. The increase in the 11




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average price of oil is primarily due to increasing demand in 2004, caused by
overseas influence. The increase in the average price of gas from $4.67 per
Mcf for the nine months ended September 30, 2003 to $5.23 per Mcf for the nine
months ended September 30, 2004 is primarily the result of a increase 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 2004 compared to
2003. Capital expenditures for the Waddell Ranch properties for the nine months ended
September 30, 2004 totaled $6.0 million compared to $7.0 million for the same
period in 2003. BROG has previously advised the Trust that the remaining 2004
capital expenditures budget for the Waddell Ranch properties is $7.2 million. The Trust has been advised that 4 gross and 1 net productive oil wells were
drilled and completed on the Waddell Ranch properties during the nine months
ended September 30, 2004 and 4 gross and 1 net productive oil wells were
drilled and completed on the Waddell Ranch properties during the nine months
ended September 30, 2003. Lease operating expense and property taxes totaled $7.0 million in 2004
compared to $7.7 million in 2003. The decrease in lease operating expense is
primarily attributable to less activity on the Waddell Ranch properties. 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,
2004 and 2003, respectively, were computed as shown in the table below: 12




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THREE MONTHS ENDED SEPTEMBER 30,2004
    
    2003WADDELL
    
    TEXAS
    
    WADDELL
    
    TEXASRANCH
    
    ROYALTY
    
    RANCH
    
    ROYALTYPROPERTIES
    
    PROPERTIES
    
    PROPERTIES
    
    PROPERTIESGross proceeds of sales from the
Underlying PropertiesOil proceeds
    
    $
    8,539,737
    
    
    $
    3,186,730
    
    
    $
    6,086,789
    
    
    $
    2,291,291Gas proceeds
    
    
    7,916,495
    
    
    
    1,011,491
    
    
    
    6,626,340
    
    
    
    867,421Total
    
    
    16,456,232
    
    
    
    4,198,221
    
    
    
    12,713,129
    
    
    
    3,158,712Less:Severance tax:Oil
    
    
    364,217
    
    
    
    120,328
    
    
    
    262,812
    
    
    
    87,739Gas
    
    
    439,973
    
    
    
    71,200
    
    
    
    438,299
    
    
    
    29,099Lease operating expense and
property tax:Oil and gas
    
    
    2,246,213
    
    
    
    210,000
    
    
    
    2,548,606
    
    
    
    195,000Capital expenditures
    
    
    2,685,591
    
    
    
    
    
    
    
    1,479,890
    
    
    
    Total
    
    
    5,735,994
    
    
    
    401,528
    
    
    
    4,729,607
    
    
    
    311,837Net profits
    
    
    10,720,238
    
    
    
    3,796,693
    
    
    
    7,983,522
    
    
    
    2,846,875Net overriding royalty interests
    
    
    75
    %
    
    
    95
    %
    
    
    75
    %
    
    
    95
    %Royalty income
    
    $
    8,040,178
    
    
    $
    3,606,858
    
    
    $
    5,987,641
    
    
    $
    2,704,531
 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. 13




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
    
    Distributions to Unitholders 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 GAAP 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. Revenue Recognition Revenues from 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 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 2004 generally
reflects the proceeds associated with actual oil and gas production for the
period of May, June and July 2004. Reserve Disclosure As of January 1, 2004, independent petroleum engineers estimated the net proved
reserves attributable to the royalty interest. 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 Unitholders. The Trustee is aware of no such items as of
September 30, 2004. 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 effect the reported amounts of certain assets, liabilities,
revenues and expenses as of and for the reporting period. Actual results may
differ from such estimates. 14




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Item 3. Quantitative and Qualitative 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,
2003. 
 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 Rule 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, 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. 15




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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) 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) 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) 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.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 9, 2004 and
submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002. 16




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32.1
    
    Certificate by Bank of America, Trustee of
Permian Basin Royalty Trust, dated November 9, 2004 and
submitted pursuant to Section 906 of the Sarbanes-Oxley Act of
2002 (18 U.S.C. Section 1350). 17




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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 THEPERMIAN BASIN ROYALTY TRUSTBy:
    
    /s/ RON E. HOOPERRon E. Hooper,Senior Vice President and Trust AdministratorBank of America, N.A.Date: November 9, 2004
 (The Trust has no directors or executive officers.) 18




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INDEX TO EXHIBITS ExhibitNumber
    
    Exhibit4.1
    
    Permian Basin Royalty Trust Indenture dated November 3,
1980, between Southland Royalty Company (now Burlington
Resources Oil & Gas Company) 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) 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) 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.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 9, 2004 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 November 9, 2004 and submitted
pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
(18 U.S.C. Section 1350).
  *
    
    A copy of this Exhibit is available to any Unit holder, at the actual cost of
reproduction, upon written request to the Trustee, Bank of America, N.A., 901
Main Street, Dallas, Texas 75202. 19