<PAGE> 1
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
Form 10-Q
Quarterly Report Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
For the Quarterly Period Ended June 30, 1998
Commission File No. 1-8032
SAN JUAN BASIN ROYALTY TRUST
Texas I.R.S. No. 75-6279898
Bank One, Texas, N.A., Trust Department
P. O. Box 2604
Fort Worth, Texas 76113
Telephone Number 817/884-4630
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 and (2) has been subject to such filing requirements for
the past 90 days. Yes X No
--- ---
Number of units of beneficial interest outstanding at August 14, 1998:
46,608,796
Page 1 of 14
<PAGE> 2
SAN JUAN BASIN ROYALTY TRUST
PART I - FINANCIAL INFORMATION
Item 1. Financial Statements.
The condensed financial statements included herein have been prepared by Bank
One, Texas, N.A. as Trustee for the San Juan 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 San Juan Basin Royalty Trust at June 30,
1998, and the distributable income and changes in trust corpus for the
three-month and six-month periods ended June 30, 1998 and 1997 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 June 30, 1998 and for
the three-month and six-month periods ended June 30, 1998 and 1997 included
herein.
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<PAGE> 3
INDEPENDENT ACCOUNTANTS' REPORT
Bank One, Texas, N.A. as Trustee
for the San Juan Basin Royalty Trust:
We have reviewed the accompanying condensed statement of assets, liabilities and
trust corpus of the San Juan Basin Royalty Trust as of June 30, 1998 and the
related condensed statements of distributable income and changes in trust corpus
for the three-month and six-month periods ended June 30, 1998 and 1997. These
financial statements are the responsibility of the Trustee.
We conducted our reviews in accordance with standards established by the
American Institute of Certified Public Accountants. A review of interim
financial information consists principally of applying analytical procedures to
financial data and making inquiries of persons responsible for financial and
accounting matters. It is substantially less in scope than an audit conducted in
accordance with generally accepted auditing standards, the objective of which is
the expression of an opinion regarding the financial statements taken as a
whole. Accordingly, we do not express such an opinion.
The accompanying condensed financial statements are prepared on a modified cash
basis as described in Note 1, which is a comprehensive basis of accounting other
than generally accepted accounting principles.
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 generally accepted auditing
standards, the statement of assets, liabilities and trust corpus of the San Juan
Basin Royalty Trust as of December 31, 1997, 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 25, 1998, 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, 1997 is fairly stated, in all
material respects, in relation to the statement of assets, liabilities and trust
corpus from which it has been derived.
DELOITTE & TOUCHE LLP
July 25, 1998
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<PAGE> 4
SAN JUAN BASIN ROYALTY TRUST
CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS
- --------------------------------------------------------------------------------
<TABLE>
<CAPTION>
JUNE 30, DECEMBER 31,
ASSETS 1998 1997
(UNAUDITED)
<S> <C> <C>
Cash and short-term investments $ 1,918,871 $ 5,111,832
Net overriding royalty interest in producing
oil and gas properties (net of accumulated
amortization of $79,855,904 and $77,156,080
at June 30, 1998 and December 31, 1997, respectively) 53,419,624 56,119,448
------------ ------------
$ 55,338,495 $ 61,231,280
============ ============
LIABILITIES AND TRUST CORPUS
Distribution payable to Unit holders $ 1,918,871 $ 5,111,832
Commitments and contingencies
Trust corpus - 46,608,796 Units of beneficial
interest authorized and outstanding 53,419,624 56,119,448
------------ ------------
$ 55,338,495 $ 61,231,280
============ ============
</TABLE>
CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)
- --------------------------------------------------------------------------------
<TABLE>
<CAPTION>
THREE MONTHS ENDED SIX MONTHS ENDED
JUNE 30, JUNE 30,
-------------------------------- ---------------------------------
1998 1997 1998 1997
<S> <C> <C> <C> <C>
Royalty income $ 6,678,662 $ 8,899,973 $ 18,341,793 $ 27,371,235
Interest income 17,154 26,888 45,202 54,545
----------- ----------- ------------ ------------
6,695,816 8,926,861 18,386,995 27,425,780
General and administrative
expenditures 288,887 361,751 538,094 593,253
----------- ----------- ------------ ------------
Distributable income $ 6,406,929 $ 8,565,110 $ 17,848,901 $ 26,832,527
=========== =========== ============ ============
Distributable income per Unit
(46,608,796 Units) $ .137462 $ .183766 $ .382951 $ .575696
=========== =========== ============ ============
</TABLE>
The accompanying notes to condensed financial statements are an integral part of
these statements.
-4-
<PAGE> 5
SAN JUAN BASIN ROYALTY TRUST
CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)
- --------------------------------------------------------------------------------
<TABLE>
<CAPTION>
THREE MONTHS ENDED SIX MONTHS ENDED
JUNE 30, JUNE 30,
----------------------------------- ------------------------------------
1998 1997 1998 1997
<S> <C> <C> <C> <C>
Trust corpus, beginning of period $ 54,613,230 $ 60,637,211 $ 56,119,448 $ 62,808,148
Amortization of net overriding
royalty interest (1,193,606) (1,410,107) (2,699,824) (3,581,044)
Distributable income 6,406,929 8,565,110 17,848,901 26,832,527
Distributions declared (6,406,929) (8,565,110) (17,848,901) (26,832,527)
------------ ------------ ------------ ------------
Trust corpus, end of period $ 53,419,624 $ 59,227,104 $ 53,419,624 $ 59,227,104
============ ============ ============ ============
</TABLE>
The accompanying notes to condensed financial statements are an integral part of
these statements.
-5-
<PAGE> 6
SAN JUAN BASIN ROYALTY TRUST
NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)
- --------------------------------------------------------------------------------
1. BASIS OF ACCOUNTING
The San Juan Basin Royalty Trust ("Trust") was established as of November
1, 1980. The financial statements of the Trust are prepared on the
following basis:
o Royalty income recorded for a month is the amount computed and paid
by the working interest owner, Burlington Resources Oil & Gas Company
("BROG"), to the Trustee for the Trust. Royalty income consists of
the amounts received by the owner of the interest burdened by the net
overriding royalty interest ("Royalty") 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%.
o Trust expenses recorded are based on liabilities paid and cash
reserves established from royalty income for liabilities and
contingencies.
o Distributions to Unit holders are recorded when declared by the
Trustee.
o The conveyance which transferred the overriding royalty interest to
the Trust provides that any excess of production costs over gross
proceeds must be recovered from future net profits.
The financial statements of the Trust differ from financial statements
prepared in accordance with generally accepted accounting principles
("GAAP") because revenues are not accrued in the month of production;
certain cash reserves may be established for contingencies which would not
be accrued in financial statements prepared in accordance with GAAP; and
amortization of the Royalty calculated on a unit-of-production basis is
charged directly to trust corpus.
2. FEDERAL INCOME TAXES
For federal income tax purposes, the Trust constitutes a fixed investment
trust which is taxed as a grantor trust. A grantor trust is not subject to
tax at the trust level. The Unit holders are considered to own the Trust's
income and principal as though no trust were in existence. The income of
the Trust is deemed to have been received or accrued by each Unit holder
at the time such income is received or accrued by the Trust rather than
when distributed by the Trust.
The Royalty constitutes an "economic interest" in oil and gas properties
for federal income tax purposes. Unit holders must report their share of
the revenues of the Trust as ordinary income from oil and gas royalties
and are entitled to claim depletion with respect to such income. The
Royalty is treated as a single property for depletion purposes.
The Trust has on file technical advice memoranda confirming the tax
treatment described above.
The Trust began receiving royalty income from coal seam wells beginning in
1989. Under Section 29 of the Internal Revenue Code, production from coal
seam gas wells drilled prior to January 1, 1993, qualifies for the federal
income tax credit for producing non-conventional fuels. This tax credit
was approximately $1.05 per MMBtu for the year 1997 and is adjusted for
inflation annually. The credit currently applies to production through the
year 2002. Production from wells drilled after December 31, 1979, but
prior to January 1, 1993, to a formation beneath a qualifying coal seam
formation which are later completed into such formation also qualifies for
the tax credit. Each Unit holder must determine his pro rata share of such
production based upon the number of Units owned during each month of the
year and apply the tax credit against his own income tax liability, but
such
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<PAGE> 7
credit may not reduce his regular tax liability (after the foreign tax
credit and certain other nonrefundable credits) below his tentative
minimum tax. Section 29 also provides that any amount of Section 29 credit
disallowed for the tax year solely because of this limitation will
increase his credit for prior year minimum tax liability, which may be
carried forward indefinitely as a credit against the taxpayer's regular
tax liability, subject, however, to the limitations described in the
preceding sentence. There is no provision for the carryback or
carryforward of the Section 29 credit in any other circumstances.
The Trustee is provided Section 29 tax credit information related to Trust
Properties by BROG. In 1997, the Tax Court upheld the IRS position that
nonconventional fuel such as coal seam gas does not qualify for the
Section 29 credit unless the producer received a formal certification from
the Federal Energy Regulatory Commission ("FERC"). The FERC's
certification authority expired effective January 1, 1993. Many producers
believe that wells meeting the certification requirements are eligible for
the Section 29 credit regardless of FERC certification. However, this
position is not in accordance with the IRS position or the decision of the
Tax Court. The court decision is on appeal and it is not possible to
predict the likely outcome. In the event the appeal is not successful, the
ability of the Unit holders to utilize allocated Section 29 credits could
be in question.
The classification of the Trust's income for purposes of the passive loss
rules may be important to a Unit holder. As a result of the Tax Reform Act
of 1986, royalty income will generally be treated as portfolio income and
will not reduce passive losses.
3. CONTINGENCIES
See Item 1 Legal Proceedings concerning the status of litigation matters.
******
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<PAGE> 8
ITEM 2. TRUSTEE'S DISCUSSION AND ANALYSIS
FORWARD LOOKING INFORMATION
Certain information included in this report contains, and other materials filed
or to be filed by the Trust with the Securities and Exchange Commission (as well
as information included in oral statements or other written statements made or
to be made by the Trust) may contain or include, forward looking statements
within the meaning of Section 21E of the Securities Exchange Act of 1934, as
amended, and Section 27A of the Securities Act of 1933, as amended. Such forward
looking statements may be or may concern, among other things, capital
expenditures, drilling activity, development activities, production efforts and
volumes, hydrocarbon prices and the results thereof, and regulatory matters.
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.
YEAR 2000 ISSUE
Many existing computer programs use only two digits to identify a year in the
date field. These programs were designed and developed without considering the
impact of the upcoming change in the century. If not corrected, many computer
applications could fail or create erroneous results by or at the Year 2000. The
Year 2000 issue affects virtually all companies and organizations. If a company
or organization does not successfully address its Year 2000 issues, it may face
material adverse consequences.
The Trust is reliant on the performance of BROG and third party vendors for the
receipt of Royalty income, payment of expenses and disbursement of distributable
income. The Trust has made formal inquiries to BROG and significant third party
vendors to determine the extent to which the Trust is vulnerable to BROG and
third parties' failure to remediate their own Year 2000 issues. The Trustee can
provide no assurance as to whether BROG and third party vendors will
successfully address the Year 2000 issue. Failing to successfully address the
Year 2000 issue by BROG and third party vendors could have a material adverse
impact on the Trust and its Unit holders.
THREE MONTHS ENDED JUNE 30, 1998 AND JUNE 30, 1997:
The San Juan Basin Royalty Trust received royalty income of $6,678,662 and
interest income of $17,154 during the second quarter of 1998. After deducting
administrative expenses of $288,887 distributable income for the quarter was
$6,406,929 ($.137462 per Unit). In the second quarter of 1997, royalty income
was $8,899,973, interest income was $26,888, administrative expenses were
$361,751 and distributable income was $8,565,110 ($.183766 per Unit). The tax
credit relating to production from coal seam wells totaled approximately $.04
per Unit for both the second quarter of 1998 and the second quarter of 1997. For
further information concerning this tax credit, Unit holders should refer to the
Trust's Annual Report for 1997. Based on 46,608,796 Units outstanding, the per
Unit distributions during the second quarter of 1998 were as follows:
<TABLE>
<S> <C>
April $ .039897
May .056395
June .041170
---------
Quarter Total $ .137462
=========
</TABLE>
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<PAGE> 9
The royalty income distributed in the second quarter of 1998 was lower than that
distributed in the second quarter of 1997, primarily due to a decrease in the
average gas price from $1.75 per Mcf for the second quarter of 1997 to $1.70 per
Mcf for the second quarter of 1998 and to an increase in capital costs during
the second quarter of 1998. Interest earnings for the quarter ended June 30,
1998, as compared to the quarter ended June 30, 1997, were lower, primarily due
to decreased funds available for investment. Administrative expenses decreased,
primarily as a result of differences in timing of the receipt and payment of
these expenses.
The capital costs attributable to the properties from which the Trust's 75% net
overriding royalty ("Royalty") was carved (the "Underlying Properties") for the
second quarter of 1998 were reported by BROG as $4,040,043 versus $1,793,762 for
the second quarter of 1997. BROG indicates that the majority of the increase in
capital expenditures is attributable to conventional projects, but that based on
its success in 1997, significant capital will be allocated to increasing the
density and productivity of its operations in the Fruitland Coal. BROG has
recently informed the Trustee that its estimated capital budget for 1998 has
been increased from $10 million to $10.9 million. Lease operating expenses and
property taxes were $2,857,822 for the second quarter of 1998 as compared to
$2,767,104 for the second quarter of 1997.
BROG has informed the Trustee that during the second quarter of 1998, 5 gross
(3.36 net) conventional wells were completed on the Underlying Properties. There
was 1 gross (.04 net) coal seam and 27 gross (5.71 net) conventional wells in
progress at June 30, 1998. Six gross (4.30 net) conventional wells were
recompleted and 9 gross (.36 net) coal seam well recavitations were completed on
the Underlying Properties in the second quarter of 1998. Five gross (1.57 net)
conventional well recompletions, 5 gross (.22 net) coal seam recompletions and
12 gross (1.31 net) coal seam recavitations were in progress at June 30, 1998.
By comparison, sixteen gross (1.55 net) conventional wells were completed on the
Underlying Properties in the second quarter of 1997. There was 1 gross (.04 net)
coal seam and 18 gross (.81 net) conventional wells in progress at June 30,
1997. One gross (.87 net) conventional well recompletion and 4 gross (.16 net)
coal seam recompletions were in progress at June 30, 1997. Unit holders are
referred to "Description of the Properties" in the Trust's Annual Report for
1997 for further information concerning BROG's coal seam gas well drilling
program in the San Juan Basin. This program includes properties in which the
Trust owns an interest.
Royalty income for the quarter ended June 30, 1998 is associated with actual gas
and oil production during February 1998 through April 1998 from the Underlying
Properties. Gas and oil sales from the Underlying Properties for the quarters
ended June 30, 1998 and 1997 were as follows:
<TABLE>
<CAPTION>
1998 1997
<S> <C> <C>
Gas:
Total sales (Mcf) 10,166,912 10,213,566
Mcf per day 114,235 114,759
Average price (per Mcf) $1.70 $1.75
Oil:
Total sales (Bbls) 24,744 27,524
Bbls per day 278 309
Average price (per Bbl) $13.22 $19.06
</TABLE>
Gas and oil sales attributable to the Royalty for the quarters ended June 30,
1998 and June 30, 1997, were as follows:
<TABLE>
<S> <C> <C>
Gas sales (Mcf) 4,287,827 5,522,845
Oil sales (Bbls) 10,375 14,550
</TABLE>
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<PAGE> 10
During the second quarter of 1998, gas prices were lower than during the second
quarter of 1997. Gas production decreased slightly in 1998 as compared to 1997.
The price per barrel of oil during the second quarter of 1998 was $5.84 per bbl
lower than that received for the second quarter of 1997 due to decreases in oil
prices in world markets generally including the posted prices applicable to oil
sales attributable to the Royalty.
Since the oil and gas sales attributable to the Royalty are based on an
allocation formula that is dependent on such factors as price and cost,
including capital expenditures, the aggregate production volumes from the
Underlying Properties may not provide a meaningful comparison to volumes
attributable to the Royalty.
Effective January 1, 1998, all volumes of Trust gas became subject to the terms
of a Natural Gas Sales and Purchase Contract between BROG and El Paso Energy
Marketing Company ("El Paso"). That contract is for a term of two years through
and including December 31, 1999, and provides for the sale of Trust gas at
prices which will fluctuate in accordance with published indices for gas sold in
the San Juan Basin of New Mexico. BROG entered into the contract with El Paso
after soliciting and receiving competitive bids in late 1997 from six major gas
marketing firms to market and/or purchase the Trust gas. Unit holders are
referred to Note 6 of the Notes to Financial Statements in the Trust's 1997
Annual Report for further information concerning the marketing of gas produced
from the Underlying Properties.
SIX MONTHS ENDED JUNE 30, 1998 AND JUNE 30, 1997:
For the six months ended June 30, 1998 distributable income was $17,848,901
($.382951 per Unit) which was less than the $26,832,527 ($.575696 per Unit) of
income distributed during the same period in 1997. The decrease resulted
primarily from decreases in gas and oil prices. Interest income for the six
months ended June 30, 1998 was $45,202 compared to $54,545 during the first six
months of 1997. This decrease is due to a decrease in funds available for
investment. General and administrative expenses decreased to $538,094 from
$593,253 during the 1997 period primarily due to differences in timing of the
receipt and payment of these expenses.
Capital expenditures incurred by BROG, attributable to the Underlying
Properties, for the first six months of 1998 amounted to $6,303,086. Capital
expenditures were $4,113,968 for the first six months of 1997.
Lease operating expenses and property taxes totaled $5,803,562 for the first six
months of 1998 compared to $5,654,117 for the first six months of 1997.
BROG informed the Trustee that during the six months ended June 30, 1998, 9
gross (5.09 net) conventional gas wells were completed on the Underlying
Properties. Eight gross (6.05 net) conventional wells were recompleted. Eighteen
gross (.73 net) coal seam wells were recavitated during the first six months of
1998. During the six months ended June 30, 1997, 29 gross (2.06 net)
conventional gas wells were completed on the Underlying Properties. One gross
(.84 net) coal seam and 1 gross (.83 net) conventional well were recompleted
during the first six months of 1997. Four gross (.55 net) coal seam wells were
recavitated during the first six months of 1997.
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<PAGE> 11
Royalty income for the six months ended June 30, 1998 is associated with actual
gas and oil production during November 1997 through April 1998 from the
Underlying Properties. Gas and oil sales from the Underlying Properties for the
six months ended June 30, 1998 and 1997 were as follows:
<TABLE>
<CAPTION>
1998 1997
<S> <C> <C>
Gas:
Total sales (Mcf) 21,128,372 20,827,086
Mcf per day 116,731 115,067
Average price (per Mcf) $ 1.90 $ 2.41
Oil:
Total sales (Bbls) 45,216 48,486
Bbls per day 250 268
Average price (per Bbl) $ 14.53 $ 20.61
</TABLE>
Gas and oil sales attributable to the Royalty for the six months ended June 30,
1998 and 1997 were as follows:
<TABLE>
<S> <C> <C>
Gas sales (Mcf) 10,456,760 12,064,934
Oil sales (Bbls) 21,935 27,213
</TABLE>
During the first six months of 1998, gas and oil prices were lower than during
the first six months of 1997. Since the oil and gas sales attributable to the
Royalty are based on an allocation formula that is dependent on such factors as
price and cost, including capital expenditures, the aggregate sales amounts from
the Underlying Properties may not provide a meaningful comparison to sales
attributable to the Royalty.
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<PAGE> 12
CALCULATION OF ROYALTY INCOME:
Royalty income received by the Trust for the three months and six months ended
June 30, 1998 and 1997, respectively, was computed as shown in the following
table:
<TABLE>
<CAPTION>
THREE MONTHS ENDED SIX MONTHS ENDED
JUNE 30, JUNE 30,
--------------------------------- -----------------------------------
1998 1997 1998 1997
<S> <C> <C> <C> <C>
Gross proceeds of sales from the
Underlying Properties:
Gas proceeds $ 17,283,052 $ 17,840,045 $ 40,077,044 $ 50,244,916
Oil proceeds 327,151 524,649 656,830 999,186
------------ ------------ ------------ ------------
Total 17,610,203 18,364,694 40,733,874 51,244,102
------------ ------------ ------------ ------------
Less production costs:
Severance tax - Gas 1,772,144 1,890,896 4,096,889 4,885,760
Severance tax - Oil 35,311 46,302 74,613 95,277
Lease operating expenses and
property tax 2,857,822 2,767,104 5,803,562 5,654,117
Capital expenditures 4,040,043 1,793,762 6,303,086 4,113,968
------------ ------------ ------------ ------------
Total 8,705,320 6,498,064 16,278,150 14,749,122
------------ ------------ ------------ ------------
Net profits 8,904,883 11,866,630 24,455,724 36,494,980
------------ ------------ ------------ ------------
Net overriding royalty interest 75% 75% 75% 75%
------------ ------------ ------------ ------------
Royalty income $ 6,678,662 $ 8,899,973 $ 18,341,793 $ 27,371,235
============ ============ ============ ============
</TABLE>
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<PAGE> 13
PART II - OTHER INFORMATION
Item 1. Legal Proceedings
The Trust is not a party to any litigation. However, the Trust
is aware that BROG is involved in litigation from time to time
that could affect the royalty income received by the Trust.
A lawsuit has been commenced against BROG by certain royalty and
overriding royalty owners on behalf of those persons similarly
situated. The suit involves properties that are burdened by the
Trust. This case is one of six virtually identical class actions
filed against New Mexico gas producers. All such cases have been
consolidated in the First Judicial District of Santa Fe County,
New Mexico where the case is styled San Juan 1990-A, L.P., et
al. v. El Paso Production Company and Meridian Oil Inc. The
plaintiffs allege that they and members of the proposed class
have been underpaid for royalties and overriding royalties. The
plaintiffs have sought to certify the actions as class actions
and seek monetary damages. The court has denied class
certification. Because of the pending nature of the litigation,
exposure to the Trust from this suit cannot be quantified.
However, if the plaintiffs who have interests in properties that
are burdened by the Trust are successful, royalty income
received by the Trust could decrease.
In addition, the Trust is aware of an administrative claim
brought by the Mineral Management Service of the United States
Department of the Interior (the "MMS") against BROG regarding a
gas contract settlement dated March 1, 1990, between BROG and
certain other parties thereto. The claim alleges that additional
royalties are due on production from federal and Indian leases
in the State of New Mexico on properties that are burdened by
the Royalty. If the MMS claim is successful, royalty income
received by the Trust could decrease.
Items 2-5 Not Applicable
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits
(4)(a) San Juan Basin Royalty Trust Indenture dated
November 3, 1980, between Southland Royalty Company
(now Burlington Resources Oil & Gas Company) and
The Fort Worth National Bank (now Bank One, Texas,
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)(b) Net Overriding Royalty Conveyance from Southland
Royalty Company (now Burlington Resources Oil & Gas
Company) to The Fort Worth National Bank (now Bank
One, Texas, 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.
(27) Financial Data Schedule
(b) Reports on Form 8-K
No reports on Form 8-K were filed during the quarter ended
June 30, 1998.
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<PAGE> 14
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 ONE, TEXAS, N.A., AS TRUSTEE FOR
THE SAN JUAN BASIN ROYALTY TRUST
By LEE ANN ANDERSON
------------------------------
Lee Ann Anderson
Vice President
Date: August 13, 1998
(The Trust has no directors or executive officers.)
-14-
<PAGE> 15
INDEX TO EXHIBITS
<TABLE>
<CAPTION>
SEQUENTIALLY
EXHIBIT NUMBERED
NUMBER EXHIBIT PAGE
<S> <C> <C>
(4)(a) San Juan Basin Royalty Trust Indenture dated November
3, 1980, between Southland Royalty Company (now
Burlington Resources Oil & Gas Company) and The Fort
Worth National Bank (now Bank One, Texas, 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)(b) Net Overriding Royalty Conveyance from Southland
Royalty Company (now Burlington Resources Oil & Gas
Company) to The Fort Worth National Bank (now Bank
One, Texas, 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.*
(27) Financial Data Schedule **
</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 One, Texas,
N.A., P.O. Box 2604, Fort Worth, Texas 76113.
** Filed herewith.
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM THE
UNAUDITED CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS OF SAN
JUAN BASIN ROYALTY TRUST AS OF JUNE 30, 1998, AND THE RELATED CONDENSED
STATEMENTS OF DISTRIBUTABLE INCOME AND CHANGES IN TRUST CORPUS FOR THE SIX-MONTH
PERIOD ENDED JUNE 30, 1998.
</LEGEND>
<S> <C>
<PERIOD-TYPE> 6-MOS
<FISCAL-YEAR-END> DEC-31-1998
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