<PAGE>

--------------------------------------------------------------------------------
--------------------------------------------------------------------------------

                UNITED STATES SECURITIES AND EXCHANGE COMMISSION
                             WASHINGTON, D.C. 20549
                             ---------------------

                                   FORM 10-K

<Table>
<C>          <S>
(Mark One)
    [X]      ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
             OF THE SECURITIES EXCHANGE ACT OF 1934



             FOR THE FISCAL YEAR ENDED DECEMBER 31, 2001



                                   OR




    [ ]      TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
             OF THE SECURITIES EXCHANGE ACT OF 1934
</Table>

                         COMMISSION FILE NUMBER 1-8033

                          PERMIAN BASIN ROYALTY TRUST
   (Exact name of Registrant as Specified in the Permian Basin Royalty Trust
                                   Indenture)
                             ---------------------

<Table>
<S>                                            <C>
                    TEXAS                                        75-6280532
       (State or Other Jurisdiction of                        (I.R.S. Employer
        Incorporation or Organization)                      Identification No.)
</Table>

                             BANK OF AMERICA, N.A.
                                TRUST DEPARTMENT
                                P.O. BOX 830650
                              DALLAS, TEXAS 75202
               (Address of Principal Executive Offices; Zip Code)

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

          SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:

<Table>
<Caption>
             TITLE OF EACH CLASS                 NAME OF EACH EXCHANGE ON WHICH REGISTERED
             -------------------                 -----------------------------------------
<S>                                            <C>
         Units of Beneficial Interest                     New York Stock Exchange
</Table>

          SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
                                      NONE

     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 if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K.  [X]

     At March 1, 2002, there were 46,608,796 Units of Beneficial Interest of the
Trust outstanding with an aggregate market value on that date of $241,899,651.

                      DOCUMENTS INCORPORATED BY REFERENCE

     "Units of Beneficial Interest" at page 1; "Trustee's Discussion and
Analysis for the Three-Year Period Ended December 31, 2001" at pages 7 through
8; "Results of the 4th Quarters of 2001 and 2000" at pages 8 through 9; and
"Statements of Assets, Liabilities and Trust Corpus," "Statements of
Distributable Income," "Statements of Changes in Trust Corpus," "Notes to
Financial Statements" and "Independent Auditors' Report" at page 10 et seq., in
registrant's Annual Report to security holders for fiscal year ended December
31, 2001 are incorporated herein by reference for Item 5, Item 7 and Item 8 of
Part II of this Report.
--------------------------------------------------------------------------------
--------------------------------------------------------------------------------
<PAGE>

                               TABLE OF CONTENTS

<Table>
<Caption>
                                                                        PAGE
                                                                        ----
<S>       <C>                                                           <C>
                                   PART I
ITEM 1.   Business....................................................    2
ITEM 2.   Properties..................................................    3
          PRODUCING ACREAGE, WELLS AND DRILLING.......................    3
          OIL AND GAS PRODUCTION......................................    5
          PRICING INFORMATION.........................................    5
          OIL AND GAS RESERVES........................................    6
          REGULATION..................................................    8
          Federal Natural Gas Regulation..............................    9
          State Regulation............................................    9
          Other Regulation............................................    9
ITEM 3.   Legal Proceedings...........................................    9
ITEM 4.   Submission of Matters to a Vote of Security Holders.........   10

                                  PART II
ITEM 5.   Market for Units of the Trust and Related Security Holder
          Matters.....................................................   10
ITEM 6.   Selected Financial Data.....................................   10
ITEM 7.   Management's Discussion and Analysis of Financial Condition
          and Results of Operation....................................   10
ITEM 7A.  Quantitative and Qualitative Disclosures about Market
          Risk........................................................   10
ITEM 8.   Financial Statements and Supplementary Data.................   10
ITEM 9.   Changes in and Disagreements with Accountants on Accounting
          and Financial Disclosure....................................   11

                                  PART III
ITEM 10.  Directors and Executive Officers of the Registrant..........   11
ITEM 11.  Executive Compensation......................................   11
ITEM 12.  Security Ownership of Certain Beneficial Owners and
          Management..................................................   11
ITEM 13.  Certain Relationships and Related Transactions..............   12

                                  PART IV
ITEM 14.  Exhibits, Financial Statement Schedules and Reports on Form
          8-K.........................................................   12
</Table>

                          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," "anticipate,"
"goal," "should," "assume," "believe," or other words that convey the
uncertainty of future events or outcomes.

                                        1
<PAGE>

                                     PART I

ITEM 1.  BUSINESS

     The Permian Basin Royalty Trust (the "Trust") is an express trust created
under the laws of the state of Texas by the Permian Basin Royalty Trust
Indenture (the "Trust Indenture") entered into on November 3, 1980, between
Southland Royalty Company ("Southland Royalty") and The First National Bank of
Fort Worth, as Trustee. Bank of America, N.A., a banking association organized
under the laws of the United States, as the successor of The First National Bank
of Fort Worth, is now the Trustee of the Trust. The principal office of the
Trust (sometimes referred to herein as the "Registrant") is located at 901 Main
Street, Dallas, Texas (telephone number 214/209-2400).

     On October 23, 1980, the stockholders of Southland Royalty approved and
authorized that company's conveyance of net overriding royalty interests
(equivalent to net profits interests) to the Trust for the benefit of the
stockholders of Southland Royalty of record at the close of business on the date
of the conveyance consisting of a 75% net overriding royalty interest carved out
of that company's fee mineral interests in the Waddell Ranch properties in Crane
County, Texas and a 95% net overriding royalty interest carved out of that
company's major producing royalty properties in Texas. The conveyance of these
interests (the "Royalties") was made on November 3, 1980, effective as to
production from and after November 1, 1980 at 7:00 a.m. The properties and
interests from which the Royalties were carved and which the Royalties now
burden are collectively referred to herein as the "Underlying Properties." The
Underlying Properties are more particularly described under "Item 2. Properties"
herein.

     The function of the Trustee is to collect the income attributable to the
Royalties, to pay all expenses and charges of the Trust, and then distribute the
remaining available income to the Unit holders. The Trust is not empowered to
carry on any business activity and has no employees, all administrative
functions being performed by the Trustee.

     The Royalties constitute the principal asset of the Trust and the
beneficial interests in the Royalties are divided into that number of Units of
Beneficial Interest (the "Units") of the Trust equal to the number of shares of
the common stock of Southland Royalty outstanding as of the close of business on
November 3, 1980. Each stockholder of Southland Royalty of record at the close
of business on November 3, 1980, received one Unit for each share of the common
stock of Southland Royalty then held.

     In 1985, Southland Royalty became a wholly-owned subsidiary of Burlington
Northern Inc. ("BNI"). In 1988, BNI transferred its natural resource operations
to Burlington Resources Inc. ("BRI") as a result of which Southland Royalty
became a wholly-owned indirect subsidiary of BRI. As a result of these
transactions, El Paso Natural Gas Company ("El Paso") also became an indirect
subsidiary of BRI. In March 1992, El Paso completed an initial public offering
of 5,750,000 newly issued shares of El Paso common stock, thereby decreasing
BRI's ownership of El Paso to approximately eighty-five percent (85%). On June
30, 1992, BRI distributed all of the shares of El Paso common stock owned by BRI
to BRI's stockholders of record as of June 15, 1992. See "Pricing Information"
under "ITEM 2. Properties" herein.

     Effective January 1, 1996, Southland Royalty, a wholly-owned subsidiary of
Meridian Oil Inc. ("MOI") was merged with and into MOI, by which action the
separate corporate existence of Southland Royalty ceased and MOI survived and
succeeded to the ownership of all of the assets of Southland Royalty and has
assumed all of its rights, powers and privileges, and all of its liabilities and
obligations. In 1996, MOI changed its name to Burlington Resources Oil & Gas
Company ("BROG").

     The term "net proceeds" as used in the above described conveyance means the
excess of "gross proceeds" received by BROG during a particular period over
"production costs" for such period. "Gross proceeds" means the amount received
by BROG (or any subsequent owner of the Underlying Properties) from the sale of
the production attributable to the Underlying Properties, subject to certain
adjustments. "Production costs" means, generally, costs incurred on an accrual
basis in operating the Underlying Properties, including both capital and
non-capital costs; for example, development drilling, production and processing
costs, applicable taxes, and operating charges. If production costs exceed gross
proceeds in any month, the

                                        2
<PAGE>

excess is recovered out of future gross proceeds prior to the making of further
payment to the Trust, but the Trust is not liable for any production costs or
liabilities attributable to these properties and interests or the minerals
produced therefrom. If at any time the Trust receives more than the amount due
from the Royalties, it shall not be obligated to return such overpayment, but
the amounts payable to it for any subsequent period shall be reduced by such
overpaid amount, plus interest, at a rate specified in the conveyance.

     To the extent it has the legal right to do so, BROG is responsible for
marketing the production from such properties and interests, either under
existing sales contracts or under future arrangements at the best prices and on
the best terms it shall deem reasonably obtainable in the circumstances. BROG
also has the obligation to maintain books and records sufficient to determine
the amounts payable to the Trustee. BROG, however, can sell its interests in the
Underlying Properties.

     Proceeds from production in the first month are generally received by BROG
in the second month, the net proceeds attributable to the Royalties are paid by
BROG to the Trustee in the third month and distribution by the Trustee to the
Unit holders is made in the fourth month. The identity of Unit holders entitled
to a distribution will generally be determined as of the last business day of
each calendar month (the "monthly record date"). The amount of each monthly
distribution will generally be determined and announced ten days before the
monthly record date. Unit holders of record as of the monthly record date will
be entitled to receive the calculated monthly distribution amount for each month
on or before ten business days after the monthly record date. The aggregate
monthly distribution amount is the excess of (i) net revenues from the Trust
properties, plus any decrease in cash reserves previously established for
contingent liabilities and any other cash receipts of the Trust over (ii) the
expenses and payments of liabilities of the Trust plus any net increase in cash
reserves for contingent liabilities.

     Cash held by the Trustee as a reserve for liabilities or contingencies
(which reserves may be established by the Trustee in its discretion) or pending
distribution is placed, at the Trustee's discretion, in obligations issued by
(or unconditionally guaranteed by) the United States or any agency thereof,
repurchase agreements secured by obligations issued by the United States or any
agency thereof, or certificates of deposit of banks having a capital surplus and
undivided profits in excess of $50,000,000, subject, in each case, to certain
other qualifying conditions.

     The income to the Trust attributable to the Royalties is not subject in
material respects to seasonal factors nor in any manner related to or dependent
upon patents, licenses, franchises or concessions. The Trust conducts no
research activities. The Trust has no employees since all administrative
functions are performed by the Trustee.

     BROG has advised the Trustee that it believes that comparable revenues
could be obtained in the event of a change in purchasers of production.

ITEM 2.  PROPERTIES

     The net overriding royalties conveyed to the Trust include: (1) a 75% net
overriding royalty carved out of BROG's (as successor to Southland Royalty) 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 BROG's
(as successor to Southland Royalty) 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. References below to "net" wells and acres are
to the interests of BROG (from which the Royalties were carved) in the "gross"
wells and acres.

     The following information under this ITEM 2 is based upon data and
information furnished to the Trustee by BROG.

                     PRODUCING ACREAGE, WELLS AND DRILLING

     Waddell Ranch Properties.  The Waddell Ranch properties consist of 78,175
gross (34,205 net) producing acres. A majority of the proved reserves are
attributable to six fields: Dune, Sand Hills (Judkins),

                                        3
<PAGE>

Sand Hills (McKnight), Sand Hills (Tubb), University-Waddell (Devonian) and
Waddell. At December 31, 2001, the Waddell Ranch properties contained 750 gross
(332 net) productive oil wells, 182 gross (87 net) productive gas wells and 336
gross (147 net) injection wells.

     BROG is operator of record of the Waddell Ranch properties. All field,
technical and accounting operations have been contracted by an agreement between
the working interest owners and Coastal Management Corporation ("CMC") but
remain under the direction of BROG.

     The Waddell Ranch properties are mature producing properties, and all of
the major oil fields are currently being waterflooded for the purpose of
facilitating enhanced recovery. Proved reserves and estimated future net
revenues attributable to the properties are included in the reserve reports
summarized below. BROG does not own the full working interest in any of the
tracts constituting the Waddell Ranch properties and, therefore, implementation
of any development programs will require approvals of other working interest
holders as well as BROG. In addition, implementation of any development programs
will be dependent upon oil and gas prices currently being received and
anticipated to be received in the future. There were 11 gross (.76 net) wells
drilled and completed on the Waddell Ranch properties during 2001. At December
31, 2001 there were 8 gross (3.75 net) wells in progress on the Waddell Ranch
properties. During 2000 there were no wells drilled on the Waddell Ranch
properties. At December 31, 2000 there were 10 gross (4.88 net) wells in
progress on the Waddell Ranch properties. During 1999 there were 6 gross (2.625
net) wells drilled on the Waddell Ranch properties. At December 31, 1999 there
were 3 gross (1.375 net) wells in progress on the Waddell Ranch properties.

     BROG has advised the Trustee that the total amount of capital expenditures
for 2001 with regard to the Waddell Ranch properties totalled $9.507 million.
Capital expenditures include the cost of remedial and maintenance activities.
This amount spent is approximately $1.493 million less than the budgeted amount
projected by BROG for 2001. BROG has advised the Trustee that the capital
expenditures budget for 2002 totals approximately $9.600 million, of which
approximately $0 is attributable to the 2002 drilling program, and $9.6 million
to workovers and recompletions. Accordingly, there is a minor increase in
capital expenditures for 2002 as compared with the 2001 capital expenditures.

     Texas Royalty Properties.  The Texas Royalty properties consist of royalty
interests in mature producing oil fields, such as Yates, Wasson, Sand Hills,
East Texas, Kelly-Snyder, Panhandle Regular, N. Cowden, Todd, Keystone, Kermit,
McElroy, Howard-Glasscock, Seminole and others. The Texas Royalty properties
contain approximately 303,000 gross (approximately 51,000 net) producing acres.
Detailed information concerning the number of wells on royalty properties is not
generally available to the owners of royalty interests. Consequently, an
accurate count of the number of wells located on the Texas Royalty properties
cannot readily be obtained.

     In February 1997, BROG sold its interests in the Texas Royalty properties
that are subject to the Net Overriding Royalty Conveyance to the Trust dated
effective November 1, 1980 ("Texas Royalty Conveyance") to Riverhill Energy
Corporation ("Riverhill Energy"), which was then a wholly-owned subsidiary of
Riverhill Capital Corporation ("Riverhill Capital") and an affiliate of CMC. At
the time of such sale, Riverhill Capital was a privately owned Texas corporation
with offices in Bryan and Midland, Texas. The Trustee was informed by BROG that,
as required by the Texas Royalty Conveyance, Riverhill Energy succeeded to all
of the requirements upon and the responsibilities of BROG under the Texas
Royalty Conveyance with regard to the Texas Royalty properties. BROG and
Riverhill Energy further advised the Trustee that all accounting operations
pertaining to the Texas Royalty properties were being performed by CMC under the
direction of Riverhill Energy. BROG indicated to the Trustee that BROG will work
together with CMC and Riverhill Energy in an effort to assure that various
administrative functions and reporting requirements assumed by Riverhill Energy
are met. The Trustee has been advised that independent auditors representing
Riverhill Energy and CMC are Arthur Andersen LLP.

     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

                                        4
<PAGE>

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. Accounting operations
pertaining to the Texas Royalty properties are being performed by CMC under the
direction of Riverhill Energy. CMC also currently conducts all field, technical
and accounting operations on behalf of BROG with regard to the Waddell Ranch
properties.

                             OIL AND GAS PRODUCTION

     The Trust recognizes production during the month in which the related
distribution is received. Production of oil and gas attributable to the
Royalties and the Underlying Properties and the related average sales prices
attributable to the Underlying Properties for the three years ended December 31,
2001, excluding portions attributable to the adjustments discussed below, were
as follows:

<Table>
<Caption>
                             WADDELL RANCH PROPERTIES            TEXAS ROYALTY PROPERTIES                     TOTAL
                       ------------------------------------   ------------------------------   ------------------------------------
                          2001         2000         1999        2001       2000       1999        2001         2000         1999
                       ----------   ----------   ----------   --------   --------   --------   ----------   ----------   ----------
<S>                    <C>          <C>          <C>          <C>        <C>        <C>        <C>          <C>          <C>
ROYALTIES:
  Production
    Oil (barrels)....     577,243      584,269      601,148    363,959    335,160    308,204      941,202      919,429      909,352
    Gas (Mcf)........   3,109,734    2,654,731    2,754,393    765,852    691,714    709,815    3,875,586    3,346,445    3,464,208
UNDERLYING
  PROPERTIES:
  Production
    Oil (barrels)....   1,032,678    1,119,835    1,309,396    402,305    366,275    365,502    1,434,983    1,486,110    1,674,898
    Gas (Mcf)........   5,572,143    5,134,829    6,066,149    869,155    755,194    841,018    6,441,298    5,890,023    6,907,167
  Average Price
    Oil/barrel.......  $    25.64   $    28.28   $    14.26   $  23.68   $  26.58   $  14.40   $    24.88   $    27.66   $    14.29
    Gas/Mcf..........  $     4.68   $     3.65   $     2.11   $   4.34   $   3.58   $   2.09   $     4.70   $     3.63   $     2.11
</Table>

     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), production amounts do not necessarily provide
a meaningful comparison.

                              PRICING INFORMATION

     Reference is made to "Regulation" for information as to federal regulation
of prices of natural gas. The following paragraphs provide information regarding
sales of oil and gas from the Waddell Ranch properties. As a royalty owner, BROG
is not furnished detailed information regarding sales of oil and gas from the
Texas Royalty properties.

     Oil.  The Trustee has been advised by BROG that for the period August 1,
1993 through June 30, 2002, the oil from the Waddell Ranch properties is being
sold under a competitive bid to independent third parties.

     Gas.  The gas produced from the Waddell Ranch properties is processed
through a natural gas processing plant and sold at the tailgate of the plant.
Plant products are marketed by Burlington Resources Hydrocarbons Inc., an
indirect subsidiary of BRI. The processor of the gas (Warren Petroleum Company,
L.P.) receives 15% of the liquids and residue gas as a fee for gathering,
compression, treating and processing the gas.

                                        5
<PAGE>

                              OIL AND GAS RESERVES

     The following are definitions adopted by the Securities and Exchange
Commission ("SEC") and the Financial Accounting Standards Board which are
applicable to terms used within this Item:

     "Proved reserves" are those estimated quantities of crude oil, natural gas
and natural gas liquids, which, upon analysis of geological and engineering
data, appear with reasonable certainty to be recoverable in the future from
known oil and gas reservoirs under existing economic and operating conditions.

     "Proved developed reserves" are those proved reserves which can be expected
to be recovered through existing wells with existing equipment and operating
methods.

     "Proved undeveloped reserves" are those proved reserves which are expected
to be recovered from new wells on undrilled acreage, or from existing wells
where a relatively major expenditure is required.

     "Estimated future net revenues" are computed by applying current prices of
oil and gas (with consideration of price changes only to the extent provided by
contractual arrangements and allowed by federal regulation) to estimated future
production of proved oil and gas reserves as of the date of the latest balance
sheet presented, less estimated future expenditures (based on current costs) to
be incurred in developing and producing the proved reserves, and assuming
continuation of existing economic conditions.

     "Estimated future net revenues" are sometimes referred to herein as
"estimated future net cash flows."

     "Present value of estimated future net revenues" is computed using the
estimated future net revenues and a discount factor of 10%.

     The independent petroleum engineers' reports as to the proved oil and gas
reserves attributable to the Royalties conveyed to the Trust were obtained from
Cawley, Gillespie & Associates, Inc. The following table presents a
reconciliation of proved reserve quantities from January 1, 1999 through
December 31, 2001 (in thousands):

<Table>
<Caption>
                                               WADDELL RANCH    TEXAS ROYALTY
                                                PROPERTIES        PROPERTIES          TOTAL
                                              ---------------   --------------   ---------------
                                               OIL      GAS      OIL      GAS     OIL      GAS
                                              (BBLS)   (MCF)    (BBLS)   (MCF)   (BBLS)   (MCF)
                                              ------   ------   ------   -----   ------   ------
<S>                                           <C>      <C>      <C>      <C>     <C>      <C>
January 1, 1999.............................   2,715   17,389   3,786    3,963    6,501   21,352
Extensions, discoveries, and other
  additions.................................      15       49       0        0       15       49
Revisions of previous estimates.............   3,357    8,320     667    2,375    4,024   10,695
Production..................................    (601)  (2,754)   (308)    (710)    (909)  (3,464)
                                              ------   ------   -----    -----   ------   ------
December 31, 1999...........................   5,486   23,004   4,145    5,628    9,631   28,632
Extensions, discoveries, and other
  additions.................................     314    1,106       0        0      314    1,106
Revisions of previous estimates.............   1,095    9,088      97    1,012    1,192   10,099
Production..................................    (584)  (2,655)   (335)    (692)    (919)  (3,346)
                                              ------   ------   -----    -----   ------   ------
December 31, 2000...........................   6,311   30,543   3,907    5,948   10,218   36,491
Extensions, discoveries, and other
  additions.................................       0        0       0        0        0        0
Revisions of previous estimates.............  (1,960)  (7,311)     60      613   (1,890)  (6,698)
Production..................................    (577)  (3,110)   (364)    (766)    (941)  (3,876)
                                              ------   ------   -----    -----   ------   ------
December 31, 2001...........................   3,774   20,122   3,603    5,795    7,377   25,917
                                              ======   ======   =====    =====   ======   ======
</Table>

                                        6
<PAGE>

     Estimated quantities of proved developed reserves of crude oil and natural
gas as of December 31, 2001, 2000 and 1999 were as follows (in thousands):

<Table>
<Caption>
                                                              CRUDE OIL   NATURAL GAS
                                                               (BBLS)        (MCF)
                                                              ---------   -----------
<S>                                                           <C>         <C>
December 31, 2001...........................................    6,614       23,280
December 31, 2000...........................................    8,937       31,665
December 31, 1999...........................................    8,200       24,248
</Table>

     The Financial Accounting Standards Board requires supplemental disclosures
for oil and gas producers based on a standardized measure of discounted future
net cash flows relating to proved oil and gas reserve quantities. Under this
disclosure, future cash inflows are computed by applying year-end prices of oil
and gas relating to the enterprise's proved reserves to the year-end quantities
of those reserves. Future price changes are only considered to the extent
provided by contractual arrangements in existence at year end. The standardized
measure of discounted future net cash flows is achieved by using a discount rate
of 10% a year to reflect the timing of future cash flows relating to proved oil
and gas reserves.

     Estimates of proved oil and gas reserves are by their very nature
imprecise. Estimates of future net revenue attributable to proved reserves are
sensitive to the unpredictable prices of oil and gas and other variables.

     The 2001, 2000 and 1999 change in the standardized measure of discounted
future net cash flows related to future royalty income from proved reserves
discounted at 10% is as follows (in thousands):

<Table>
<Caption>
                                 WADDELL RANCH PROPERTIES         TEXAS ROYALTY PROPERTIES                   TOTAL
                              -------------------------------   -----------------------------   -------------------------------
                                2001        2000       1999       2001       2000      1999       2001        2000       1999
                              ---------   --------   --------   --------   --------   -------   ---------   --------   --------
<S>                           <C>         <C>        <C>        <C>        <C>        <C>       <C>         <C>        <C>
January 1...................  $ 214,029   $102,088   $ 25,043   $ 65,784   $ 52,126   $22,031   $ 279,813   $154,214   $ 47,074
Extensions, discoveries, and
  other additions...........          0     10,281        226          0          0         0           0     10,281        226
Accretion of discount.......     21,403     10,209      2,504      6,578      5,213     2,203      27,981     15,422      4,707
Revisions of previous
  estimates and other.......   (147,806)   116,353     88,598    (26,370)    19,379    33,627    (174,176)   135,732    122,225
Royalty income..............    (28,343)   (24,902)   (14,283)   (11,473)   (10,934)   (5,735)    (39,816)   (35,836)   (20,018)
                              ---------   --------   --------   --------   --------   -------   ---------   --------   --------
December 31.................  $  59,283   $214,029   $102,088   $ 34,519   $ 65,784   $52,126   $  93,802   $279,813   $154,214
                              =========   ========   ========   ========   ========   =======   =========   ========   ========
</Table>

     Oil and gas prices of $17.05 and $17.62 per barrel and $2.15 and $1.93 per
Mcf were used to determine the estimated future net revenues from the Waddell
Ranch properties and the Texas Royalty properties, respectively, at December 31,
2001. The extension, discoveries and other additions for the Waddell Ranch
properties are proved reserves related to the Sand Hills (Tubbs) Unit. The
downward revisions of both reserves and discounted future net cash flows for the
Waddell Ranch properties and the Texas Royalty properties are due to decreases
in oil and gas prices from 2000 to 2001.

     Oil and gas prices of $24.65 and $26.46 per barrel and $8.98 and $7.03 per
Mcf, respectively, were used to determine the estimated future net revenues from
the Waddell Ranch properties and the Texas Royalty properties, respectively, at
December 31, 2000. The extension, discoveries and other additions for the
Waddell Ranch properties are proved reserves related to the Waddell (Greyburg)
and Running WN (Wolfcamp) fields. The upward revisions of both reserves and
discounted future net cash flows for the Waddell Ranch properties and the Texas
Royalty properties are due to increases in oil and gas prices from 1999 to 2000.

     Oil and gas prices of $24.05 and $24.19 per barrel and $2.74 and $3.18 per
Mcf, respectively, were used to determine the estimated future net revenues from
the Waddell Ranch properties and the Texas Royalty properties at December 31,
1999. The extension, discoveries and other additions for the Waddell Ranch
properties are proved developed producing reserves related to the RM (Clearfork)
field. The upward revisions of both reserves and discounted future net cash
flows for the Waddell Ranch properties and the Texas Royalty properties were due
to increases in oil and gas prices from 1998 to 1999.

                                        7
<PAGE>

     The following presents estimated future net revenue and the present value
of estimated future net revenue, for each of the years ended December 31, 2001,
2000 and 1999 (in thousands except amounts per Unit):

<Table>
<Caption>
                                        2001                    2000                    1999
                                ---------------------   ---------------------   ---------------------
                                ESTIMATED    PRESENT    ESTIMATED    PRESENT    ESTIMATED    PRESENT
                                FUTURE NET   VALUE AT   FUTURE NET   VALUE AT   FUTURE NET   VALUE AT
                                 REVENUE       10%       REVENUE       10%       REVENUE       10%
                                ----------   --------   ----------   --------   ----------   --------
<S>                             <C>          <C>        <C>          <C>        <C>          <C>
Total Proved
  Waddell Ranch properties....   $102,860    $59,283     $405,530    $214,029    $184,957    $102,088
  Texas Royalty properties....     71,482     34,519      138,860      65,784     113,838      52,126
                                 --------    -------     --------    --------    --------    --------
          Total...............   $174,342    $93,102     $544,390    $279,813    $298,795    $154,214
                                 ========    =======     ========    ========    ========    ========
Total Proved per Unit.........   $   3.74    $  2.01     $  11.68    $   6.00    $   6.41    $   3.31
                                 ========    =======     ========    ========    ========    ========
Proved Developed
  Waddell Ranch properties....   $ 84,996    $52,778     $334,734    $187,575    $140,808    $ 85,612
  Texas Royalty properties....     71,482     34,519      138,860      65,784     113,838      52,126
                                 --------    -------     --------    --------    --------    --------
          Total...............   $156,478    $87,297     $473,594    $253,359    $254,646    $137,738
                                 ========    =======     ========    ========    ========    ========
</Table>

     Reserve quantities and revenues shown in the preceding tables for the
Royalties were estimated from projections of reserves and revenue attributable
to the combined Southland Royalty and Trust interests in the Waddell Ranch
properties and Texas Royalty properties. Reserve quantities attributable to the
Royalties were estimated by allocating to the Royalties a portion of the total
estimated net reserve quantities of the interests, based upon gross revenue less
production taxes. Because the reserve quantities attributable to the Royalties
are estimated using an allocation of the reserves, any changes in prices or
costs will result in changes in the estimated reserve quantities allocated to
the Royalties. Therefore, the reserve quantities estimated will vary if
different future price and cost assumptions occur.

     Proved reserve quantities are estimates based on information available at
the time of preparation and such estimates are subject to change as additional
information becomes available. The reserves actually recovered and the timing of
production of those reserves may be substantially different from the original
estimate. Moreover, the present values shown above should not be considered as
the market values of such oil and gas reserves or the costs that would be
incurred to acquire equivalent reserves. A market value determination would
include many additional factors.

                                   REGULATION

     Many aspects of the production, pricing and marketing of crude oil and
natural gas are regulated by federal and state agencies. Legislation affecting
the oil and gas industry is under constant review for amendment or expansion,
frequently increasing the regulatory burden on affected members of the industry.

     Exploration and production operations are subject to various types of
regulation at the federal, state and local levels. Such regulation includes
requiring permits for the drilling of wells, maintaining bonding requirements in
order to drill or operate wells, and regulating the location of wells, the
method of drilling and casing wells, the surface use and restoration of
properties upon which wells are drilled and the plugging and abandonment of
wells. Natural gas and oil operations are also subject to various conservation
laws and regulations that regulate the size of drilling and spacing units or
proration units and the density of wells which may be drilled and unitization or
pooling of oil and gas properties. In addition, state conservation laws
establish maximum allowable production from natural gas and oil wells, generally
prohibit the venting or flaring of natural gas and impose certain requirements
regarding the ratability of production. The effect of these regulations is to
limit the amounts of natural gas and oil that can be produced and to limit the
number of wells or the locations which can be drilled.

                                        8
<PAGE>

FEDERAL NATURAL GAS REGULATION

     The Federal Energy Regulatory Commission (the "FERC") is primarily
responsible for federal regulation of natural gas. The interstate transportation
and sale for resale of natural gas is subject to federal governmental
regulation, including regulation of transportation and storage tariffs and
various other matters, by FERC. The Natural Gas Wellhead Decontrol Act of 1989
("Decontrol Act") terminated federal price controls on wellhead sales of
domestic natural gas on January 1, 1993. Consequently, sales of natural gas may
be made at market prices, subject to applicable contract provisions. The FERC's
jurisdiction over natural gas transportation and storage was unaffected by the
Decontrol Act.

     Sales of natural gas are affected by the availability, terms and cost of
transportation. The price and terms for access to pipeline transportation remain
subject to extensive federal and state regulation. Several major regulatory
changes have been implemented by Congress and the FERC from 1985 to the present
that affect the economics of natural gas production, transportation, and sales.
In addition, the FERC continues to promulgate revisions to various aspects of
the rules and regulations affecting those segments of the natural gas industry,
most notably interstate natural gas transmission companies, that remain subject
to the FERC's jurisdiction. These initiatives may also affect the intrastate
transportation of gas under certain circumstances. The stated purpose of many of
these regulatory changes is to promote competition among the various sectors of
the natural gas industry and these initiatives generally reflect more
light-handed regulation of the natural gas industry. The ultimate impact of the
rules and regulations issued by the FERC since 1985 cannot be predicted. In
addition, many aspects of these regulatory developments have not become final
but are still pending judicial and FERC final decisions.

     New proposals and proceedings that might affect the natural gas industry
are considered from time to time by Congress, the FERC, state regulatory bodies
and the courts. The Trust cannot predict when or if any such proposals might
become effective, or their effect, if any, on the Trust. The natural gas
industry historically has been very heavily regulated; therefore, there is no
assurance that the less stringent regulatory approach recently pursued by the
FERC and Congress will continue.

     Sales of crude oil, condensate and gas liquids are not currently regulated
and are made at market prices. Crude oil prices are affected by a variety of
factors. Since domestic crude price controls were lifted in 1981, the principal
factors influencing the prices received by producers of domestic crude oil have
been the pricing and production of the members of the Organization of Petroleum
Export Countries (OPEC).

STATE REGULATION

     The various states regulate the production and sale of oil and natural gas,
including imposing requirements for obtaining drilling permits, the method of
developing new fields, the spacing and operation of wells and the prevention of
waste of oil and gas resources. The rates of production may be regulated and the
maximum daily production allowables from both oil and gas wells may be
established on a market demand or conservation basis, or both.

OTHER REGULATION

     The petroleum industry is also subject to compliance with various other
federal, state and local regulations and laws, including, but not limited to,
environmental protection, occupational safety, resource conservation and equal
employment opportunity. The Trustee does not believe that compliance with these
laws by the operating parties will have any material adverse effect on Unit
holders.

ITEM 3.  LEGAL PROCEEDINGS

     There are no material pending legal proceedings to which the Trust is a
party or of which any of its property is the subject.

                                        9
<PAGE>

ITEM 4.  SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

     No matters were submitted to a vote of Unit holders, through the
solicitation of proxies or otherwise, during the fourth quarter ended December
31, 2001.

                                    PART II

ITEM 5.  MARKET FOR UNITS OF THE TRUST AND RELATED SECURITY HOLDER MATTERS

     The information under "Units of Beneficial Interest" at page 1 of the
Trust's Annual Report to security holders for the year ended December 31, 2001,
is herein incorporated by reference.

ITEM 6.  SELECTED FINANCIAL DATA

<Table>
<Caption>
                                                FOR THE YEAR ENDED DECEMBER 31,
                              -------------------------------------------------------------------
                                 2001          2000          1999          1998          1997
                              -----------   -----------   -----------   -----------   -----------
<S>                           <C>           <C>           <C>           <C>           <C>
Royalty income..............  $39,816,141   $35,835,746   $18,799,659   $10,777,901   $22,598,873
Distributable income........   39,473,395    35,545,141    18,471,842    10,414,382    22,190,115
Distributable income per
  Unit......................     0.846908      0.762627      0.396317      0.223443      0.476092
Distributions per Unit......     0.846908      0.762627      0.396317      0.223443      0.476092
Total assets, December 31...  $ 4,213,606   $ 5,651,376   $ 5,305,223   $ 3,861,776   $ 5,220,786
</Table>

ITEM 7.  MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
         OF OPERATION

     The "Trustee's Discussion and Analysis for the Three Year Period Ended
December 31, 2001" and "Results of the 4th Quarters of 2001 and 2000" at pages 7
through 9 of the Trust's Annual Report to security holders for the year ended
December 31, 2001 is herein incorporated by reference.

ITEM 7A.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

     The Trust is a passive entity and other than the Trust's ability to
periodically borrow money as necessary to pay expenses, liabilities and
obligations of the Trust that cannot be paid out of cash held by the Trust, the
Trust is prohibited from engaging in borrowing transactions. The amount of any
such borrowings is unlikely to be material to the Trust. The Trust periodically
holds short term investments acquired with funds held by the Trust pending
distribution to Unit holders and funds held in reserve for the payment of Trust
expenses and liabilities. Because of the short-term nature of these borrowings
and investments and certain limitations upon the types of such investments which
may be held by the Trust, the Trustee believes that the Trust is not subject to
any material interest rate risk. The Trust does not engage in transactions in
foreign currencies which could expose the Trust or Unit holders to any foreign
currency related market risk. The Trust invests in no derivative financial
instruments and has no foreign operations or long-term debt instruments.

ITEM 8.  FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

     The Financial Statements of the Trust and the notes thereto at page 10 et
seq. of the Trust's Annual Report to security holders for the year ended
December 31, 2001, are herein incorporated by reference.

                                        10
<PAGE>

ITEM 9.  CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
         FINANCIAL DISCLOSURE

     There have been no changes in accountants and no disagreements with
accountants on any matter of accounting principles or practices or financial
statement disclosures during the twenty-four months ended December 31, 2001.

                                    PART III

ITEM 10.  DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT

     The Trust has no directors or executive officers. The Trustee is a
corporate trustee which may be removed, with or without cause, at a meeting of
the Unit holders, by the affirmative vote of the holders of a majority of all
the Units then outstanding.

ITEM 11.  EXECUTIVE COMPENSATION

     During the years ended December 31, 2001, 2000 and 1999, the Trustee
received total remuneration as follows:

<Table>
<Caption>
                                                      CAPACITIES IN       CASH
NAME OF INDIVIDUAL OR NUMBER OF PERSONS IN GROUP      WHICH SERVED    COMPENSATION   YEAR
------------------------------------------------      -------------   ------------   ----
<S>                                                   <C>             <C>            <C>
Bank of America, N.A................................     Trustee        $40,272(1)   1999
                                                                        $57,680(1)   2000
                                                                        $53,796(1)   2001
</Table>

---------------

(1) Under the Trust Indenture, the Trustee is entitled to an administrative fee
    for its administrative services, preparation of quarterly and annual
    statements with attention to tax and legal matters of: (i) 1/20 of 1% of the
    first $100 million and (ii) Trustee's standard hourly rate in excess of 300
    hours annually. The administrative fee is subject to reduction by a credit
    for funds provision.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT

     (a) Security Ownership of Certain Beneficial Owners.  The following table
sets forth as of March 1, 2002, information with respect to each person known to
own beneficially more than 5% of the outstanding Units of the Trust:

<Table>
<Caption>
                                                     AMOUNT AND NATURE OF
NAME AND ADDRESS                                     BENEFICIAL OWNERSHIP   PERCENT OF CLASS
----------------                                     --------------------   ----------------
<S>                                                  <C>                    <C>
Burlington Resources Oil & Gas Company(1)..........     27,577,741 Units         59.17%
5051 Westheimer, Suite 1400
Houston, Texas 77056-2124
McMorgan & Company(2)..............................  5,000,000,000 Units         10.73%
One Bush Street, Suite 800
San Francisco, CA 94104
</Table>

---------------

(1) This information was provided to the Securities and Exchange Commission and
    to the Trust in a Form 4 dated January 6, 1994, filed with the Securities
    and Exchange Commission by Southland Royalty, a wholly-owned subsidiary of
    BRI, and in Amendment 5 to Schedule 13D and Schedule 13E-3 dated December
    28, 1993, filed with the Securities and Exchange Commission by Southland
    Royalty and BRI. Such Units were reported to be owned directly by Southland
    Royalty, now BROG.

    The Form 4 filed by Southland Royalty and the Schedule 13D and Schedule
    13E-3 filed by Southland Royalty and BRI with the Securities and Exchange
    Commission may be reviewed for more detailed information concerning the
    matters summarized herein.

                                        11
<PAGE>

(2) This information was provided to the Securities and Exchange Commission and
    to the Trust in a Schedule 13G filed with the Securities and Exchange
    Commission on July 12, 1999 on behalf of McMorgan & Company, an investment
    adviser registered under the Investment Advisers Act of 1940, (McMorgan),
    Thomas Allan Morton ("Morton"), and Terry Allen O'Toole ("O'Toole"). Such
    Schedule 13G reports that McMorgan, Morton, and O'Toole have beneficial
    ownership of such Units. It is reported in such Schedule 13G that McMorgan,
    Morton, and O'Toole have sole voting and sole dispositive power with regard
    to such Units. Morton and O'Toole filed in their capacities as control
    persons of McMorgan and disclaimed beneficial ownership to such Units
    involved in such Schedule 13G. The address of Morton and O'Toole is One Bush
    Street, Suite 800, San Francisco, California 94104. Subsequent to the filing
    of such Schedule 13G, McMorgan has informed the Trust that it is no longer
    the beneficial owner of such Units.

    The Schedule 13G filed with the Securities and Exchange Commission on behalf
    of McMorgan, Morton, and O'Toole may be reviewed for more detailed
    information concerning the matters summarized herein.

     (b) Security Ownership of Management.  The Trustee owns beneficially no
securities of the Trust. In various fiduciary capacities, Bank of America, N.A.
owned as of March 1, 2002, an aggregate of 193,796 Units with no right to vote
88,794 of these Units, shared right to vote 2,002 of these Units and sole right
to vote 103,000 of these Units. Bank of America, N.A., disclaims any beneficial
interests in these Units. The number of Units reflected in this paragraph
includes Units held by all branches of Bank of America, N.A.

     (c) Change In Control.  The Trustee knows of no arrangements which may
subsequently result in a change in control of the Trust.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

     The Trust has no directors or executive officers. See Item 11 for the
remuneration received by the Trustee during the years ended December 31, 2001,
2000 and 1999 and Item 12(b) for information concerning Units owned by Bank of
America, N.A. in various fiduciary capacities.

                                    PART IV

ITEM 14.  EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K

     The following documents are filed as a part of this Report:

     1. Financial Statements

     Included in Part II of this Report by reference to the Annual Report of the
Trust for the year ended December 31, 2001:

        Independent Auditors' Report

        Statements of Assets, Liabilities and Trust Corpus at December 31, 2001
        and 2000

        Statements of Distributable Income for Each of the Three Years in the
        Period Ended December 31, 2001

        Statements of Changes in Trust Corpus for Each of the Three Years in the
        Period Ended December 31, 2001

        Notes to Financial Statements

     2. Financial Statement Schedules

     Financial statement schedules are omitted because of the absence of
conditions under which they are required or because the required information is
given in the financial statements or notes thereto.

                                        12
<PAGE>

     3. Exhibits

<Table>
<Caption>
EXHIBIT
NUMBER                                  EXHIBIT
-------                                 -------
<C>      <S>  <C>
 (4)(a)  --   Permian Basin Royalty Trust Indenture dated November 3,
              1980, between Southland Royalty 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.*
    (b)  --   Net Overriding Royalty Conveyance (Permian Basin Royalty
              Trust) from Southland Royalty 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.*
    (c)  --   Net Overriding Royalty Conveyance (Permian Basin Royalty
              Trust -- Waddell Ranch) from Southland Royalty 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.*
(13)     --   Registrant's Annual Report to security holders for fiscal
              year ended December 31, 2001.**
(23)     --   Consent of Cawley, Gillespie & Associates, Inc., reservoir
              engineer.**
</Table>

---------------

 * 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.,
   P.O. Box 830650, Dallas, Texas 75283-0650.

** Filed herewith.

                              REPORTS ON FORM 8-K

     During the last quarter of the Trust's fiscal year ended December 31, 2001,
there were no reports on Form 8-K filed by the Trust.

                                        13
<PAGE>

                                   SIGNATURE

     Pursuant to the requirements of Section 13 or 15(d) 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.

                                          PERMIAN BASIN ROYALTY TRUST

                                          By: Bank of America, N.A., Trustee

                                          By        /s/ RON E. HOOPER
                                            ------------------------------------
                                                       Ron E. Hooper
                                                   Senior Vice President

Date: March 26, 2002

              (The Trust has no directors or executive officers.)

                                        14
<PAGE>

                               INDEX TO EXHIBITS

<Table>
<Caption>
EXHIBIT
NUMBER                                  EXHIBIT
-------                                 -------
<C>      <S>  <C>
 (4)(a)  --   Permian Basin Royalty Trust Indenture dated November 3,
              1980, between Southland Royalty 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.*
    (b)  --   Net Overriding Royalty Conveyance (Permian Basin Royalty
              Trust) from Southland Royalty 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.*
    (c)  --   Net Overriding Royalty Conveyance (Permian Basin Royalty
              Trust -- Waddell Ranch) from Southland Royalty 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.*
(13)     --   Registrant's Annual Report to security holders for fiscal
              year ended December 31, 2001.**
(23)     --   Consent of Cawley, Gillespie & Associates, Inc., reservoir
              engineer.**
</Table>

---------------

 * 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.,
   P.O. Box 830650, Dallas, Texas 75283-0650.

** Filed herewith.