e10vq

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q


þ		Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
		For the Quarterly Period Ended September 30, 2009
or
o		Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
		For the transition period from to

Commission File No. 1-8032

SAN JUAN BASIN ROYALTY TRUST

(Exact name of registrant as specified in the Amended and Restated San Juan Basin Royalty Trust Indenture)


Texas		75-6279898
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

Compass Bank
2525 Ridgmar Boulevard, Suite 100
Fort Worth, Texas 76116
(Address of principal executive offices)
(Zip Code)

(866) 809-4553

(Registrant’s telephone number, including area code)

N/A
(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). o Yes o No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer (see definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Act).


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

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

Number of Units of beneficial interest outstanding at November 9, 2009: 46,608,796

TABLE OF CONTENTS


PART I
FINANCIAL INFORMATION
	Item 1. Financial Statements.
	Item 2. Trustee’s Discussion and Analysis of Financial Condition and Results of Operations.
	Item 3. Quantitative and Qualitative Disclosures About Market Risk.
	Item 4. Controls and Procedures.
PART II
OTHER INFORMATION
	Item 1. Legal Proceedings.
	Item 6. Exhibits.
SIGNATURES
INDEX TO EXHIBITS
EX-31
EX-32

SAN JUAN BASIN ROYALTY TRUST

PART I

FINANCIAL INFORMATION


Item 1.	*Financial Statements.*

The condensed financial statements included herein have been prepared without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. The financial statements of the San Juan Basin Royalty Trust (the “Trust”) continue to be prepared in a manner that differs from generally accepted accounting principles in the United States of America (“GAAP”); this form of presentation is customary to other royalty trusts. Certain information and footnote disclosures normally included in annual financial statements have been condensed or omitted pursuant to the rules and regulations of the Securities and Exchange Commission. Nonetheless, Compass Bank, the Trustee of the Trust, believes that the disclosures are adequate to make the information presented not misleading. These condensed financial statements should be read in conjunction with the financial statements and the notes thereto included in the Trust’s Annual Report on Form 10-K for the year ended December 31, 2008. In the opinion of the Trustee, all adjustments, consisting only of normal recurring adjustments, have been included that are necessary to fairly present the assets, liabilities and trust corpus of the Trust at September 30, 2009 and the distributable income and changes in trust corpus for the three-month periods and nine-month periods ended September 30, 2009 and 2008. The distributable income for such interim periods is not necessarily indicative of the distributable income for the full year.

SAN JUAN BASIN ROYALTY TRUST

CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS


	September 30,		December 31,
	2009		2008
	(Unaudited)

ASSETS
Cash and short-term investments	$	2,632,743	$	7,449,767
Net overriding royalty interest in producing oil and gas properties (net of accumulated amortization of $115,997,319 and $115,348,030 at September 30, 2009 and December 31, 2008, respectively)		17,278,209		17,927,498

	$	19,910,952	$	25,377,265


LIABILITIES AND TRUST CORPUS
Distribution payable to Unit Holders	$	2,476,954	$	7,293,978
Cash reserves		155,789		155,789
Trust corpus — 46,608,796 Units of beneficial interest authorized and outstanding		17,278,209		17,927,498

	$	19,910,952	$	25,377,265

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2009		2008		2009		2008

Royalty income	$	7,232,890	$	52,541,763	$	19,257,575	$	113,730,327
Interest income		194,481		32,508		197,892		216,621

Total Revenue		7,427,371		52,574,271		19,455,467		113,946,948
General and administrative expenditures		435,690		351,221		1,706,123		1,554,074

Distributable income	$	6,991,681	$	52,223,050	$	17,749,344	$	112,392,874

Distributable income per Unit (46,608,796 Units)	$	0.150007	$	1.120455	$	0.380814	$	2.411409

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

SAN JUAN BASIN ROYALTY TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)


1.	BASIS OF ACCOUNTING

The San Juan Basin Royalty Trust (the “Trust”) was established as of November 1, 1980. The financial statements of the Trust are prepared on the following basis:


	•	Royalty income recorded for a month is the amount computed and paid with respect to the Trust’s 75% net overriding royalty interest (the “Royalty”) in certain oil and gas leasehold and royalty interests (the “Underlying Properties”) by Burlington Resources Oil & Gas Company LP (“BROG”), the present owner of the Underlying Properties, to the Trustee for the Trust. Royalty income consists of the proceeds received by BROG from the sale of production from the Underlying Properties less accrued production costs, development and drilling costs, applicable taxes, operating charges, and other costs and deductions, multiplied by 75%. The calculation of net proceeds by BROG for any month includes adjustments to proceeds and costs for prior months and impacts the Royalty income paid to the Trust and the distribution to Unit Holders for that month.

	•	Trust expenses recorded are based on liabilities paid and cash reserves established from Royalty income for liabilities and contingencies.

	•	Distributions to Unit Holders are recorded when declared by the Trustee.

	•	The conveyance which transferred the Royalty to the Trust provides that any excess of development and production costs applicable to the Underlying Properties over gross proceeds from such properties must be recovered from future net proceeds before Royalty income is again paid to the Trust.

The financial statements of the Trust differ from financial statements prepared in accordance with 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; expenses are recorded when paid instead of when incurred; and amortization of the Royalty calculated on a unit-of-production basis is charged directly to the Trust corpus instead of as an expense. The basis of accounting used by the Trust is widely used by royalty trusts for financial reporting purposes.

In preparing the condensed interim financial statements, the Trust has evaluated, for potential recognition or disclosure, events or transactions subsequent to the end of the most recent quarterly period through November 9, 2009, the issuance date of these condensed interim financial statements. No such transactions or events resulted in additional recognition or disclosure.


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.

Additionally, the Trust is a widely held fixed investment trust (“WHFIT”) classified as a non-mortgage widely held fixed investment trust (“NMWHFIT”) for federal income tax purposes. The Trustee is the representative of the Trust that will provide tax information in accordance with the applicable U.S. Treasury Regulations governing the information reporting requirements of the Trust as a WHFIT and a NMWHFIT.

The Royalty constitutes an “economic interest” in oil and gas properties for federal income tax purposes. Unit Holders must report their share of the production 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 such tax treatment.

Sales of gas production from certain coal seam wells drilled prior to January 1, 1993, qualified for federal income tax credits under Section 29 (now Section 45K) of the Internal Revenue Code of 1986 (as amended, the

SAN JUAN BASIN ROYALTY TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) — (Continued)

“Code”) through 2002 but not thereafter. Accordingly, under present law, the Trust’s production and sale of gas from coal seam wells does not qualify for tax credit under Section 45K of the Code (the “Section 45 Tax Credit”). Congress has at various times since 2002 considered energy legislation, including provisions to reinstate the Section 45 Tax Credit in various ways and to various extents, but no legislation that would qualify the Trust’s current production for such credit has been enacted. For example, in February 2009, new energy tax legislation was enacted which, among other things, modified the Section 45 Tax Credit in several respects, but did not extend the credit for production from coal seam wells. No prediction can be made as to what future tax legislation affecting Section 45K of the Code may be proposed or enacted or, if enacted, its impact, if any, on the Trust and the Unit Holders.

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 such as that derived through the Trust will generally be treated as portfolio income that may not be offset or reduced by passive losses.


3.	CONTINGENCIES

See Part II, Item 1 — Legal Proceedings, concerning the status of litigation matters.


4.	SETTLEMENTS AND LITIGATION

On March 14, 2008, BROG notified the Trust that the distribution for March would be reduced by $4,921,578. BROG described this amount as the Trust’s portion of what BROG had paid to settle claims for the underpayment of royalties in the case styled United States of America ex rel. Harrold E. (“Gene”) Wright v. AGIP Petroleum Co. et al., Civil Action No. 5:03CV264 (formerly 9:98-CV-30) (E.D. Tex.). The Trust’s consultants continue to analyze this settlement as it may apply to the Trust.

On April 28, 2008, the Trust filed a suit against BROG relating to the Arbitration Award in its favor issued in November 2005, in the amount of $7,683,699. The litigation is styled San Juan Basin Royalty Trust vs. Burlington Resources Oil & Gas Company, L.P., No. D1329-CV-08-751, in the District Court of Sandoval County, New Mexico, 13th Judicial District. The Trust alleges breach of contract and breach of the covenant of good faith and fair dealing and seeks a judgment for damages in the amount of $5,025,000, plus interest and punitive damages. The purpose of the arbitration was to resolve certain compliance audit issues. The arbitrator ruled in favor of the Trust on all five of the issues submitted to arbitration. BROG filed suit in Harris County, Texas alleging that the award should be modified or vacated, and seeking to recover its attorneys’ fees. The trial court denied BROG’s motion to vacate, granted the Trust’s application to confirm and rendered a final judgment in favor of the Trust. BROG paid the award as it related to four of the five issues and appealed the award as to the fifth. In August 2007, the appellate court reversed the judgment of the trial court and vacated the award as it related to the fifth issue and the unpaid balance of the award.

With respect to that fifth issue which was the subject of the appeal, the Trust had asked for damages based on either of two alternative claims. The appellate court ruled that the alternative claim selected by the arbitrator in awarding the Trust approximately $5,000,000 was not technically included within the scope of what the parties intended to submit to arbitration. The appellate court did not rule on whether or not the arbitrator properly decided the fifth issue in favor of the Trust. The litigation filed in New Mexico seeks recovery on the claim which had been resolved in favor of the Trust by the arbitrator.

The appellate court also remanded the case to the District Court, where BROG pursued its claim for attorneys’ fees and costs in the amount of approximately $200,000. Following a trial on the merits of BROG’s claims conducted on June 3, 2009, the District Court ruled in favor of the Trust and ordered that BROG should take nothing in its claims against the Trust. BROG has filed a Notice of Appeal as regards that ruling.

Certain motions for summary judgment filed by BROG and the Trust are to be heard on January 5, 2010. The trial on the merits has been set for the week of May 24, 2011.


Item 2.	*Trustee’s Discussion and Analysis of Financial Condition and Results of Operations.*

Forward-Looking Information

Certain information included in this Quarterly Report on Form 10-Q 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. Such forward-looking statements may be or may concern, among other things, capital expenditures, drilling activity, development activities, production efforts and volumes, hydrocarbon prices, estimated future net revenues, estimates of reserves, the results of the Trust’s activities, and regulatory matters. Such forward-looking statements generally are accompanied by words such as “may,” “will,” “estimate,” “expect,” “predict,” “project,” “anticipate,” “goal,” “should,” “assume,” “believe,” “plan,” “intend,” or other words that convey the uncertainty of future events or outcomes. Such statements reflect the current view of BROG, the working interest owner, with respect to future events; are based on an assessment of, and are subject to, a variety of factors deemed relevant by the Trustee and BROG; and involve risks and uncertainties. These risks and uncertainties include volatility of oil and gas prices, product supply and demand, competition, regulation or government action, litigation and uncertainties about estimates of reserves. Should one or more of these risks or uncertainties occur, actual results may vary materially and adversely from those anticipated.

Business Overview

The Trust is an express trust created under the laws of the state of Texas by the San Juan Basin Royalty Trust Indenture (the “Original Indenture”) entered into on November 3, 1980 between Southland Royalty Company (“Southland Royalty”) and The Fort Worth National Bank. Effective as of September 30, 2002, the Original Indenture was amended and restated (the Original Indenture, as amended and restated, the “First Restated Indenture”) and, effective as of December 12, 2007 the First Restated Indenture was amended and restated (the First Restated Indenture, as amended and restated, the “Indenture”). The Trustee of the Trust is Compass Bank (as a result of the merger discussed below).

On October 23, 1980, the stockholders of Southland Royalty approved and authorized that company’s conveyance of a 75% net overriding royalty interest (equivalent to a net profits interest) 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 (the “Royalty”) carved out of that company’s oil and gas leasehold and royalty interests (the “Underlying Properties”) in properties located in the San Juan Basin of northwestern New Mexico. Pursuant to the Net Overriding Royalty Conveyance (the “Conveyance”) the Royalty was transferred to the Trust on November 3, 1980 effective as to production from and after November 1, 1980 at 7:00 a.m.

As a result of a merger on March 24, 2006, Compass Bank succeeded TexasBank as Trustee of the Trust. On September 7, 2007, Compass Bank’s parent company, Compass Bancshares, Inc., was acquired by and is now a wholly-owned subsidiary of Banco Bilbao Vizcaya Argentaria, S.A.

The Royalty constitutes the principal asset of the Trust. The beneficial interests in the Royalty 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 freely tradable Unit for each share of the common stock of Southland Royalty then held. Holders of Units are referred to herein as “Unit Holders.” Subsequent to the Conveyance of the Royalty, through a series of assignments and mergers, Southland Royalty’s successor became BROG. On March 31, 2006, a subsidiary of ConocoPhillips completed its acquisition of Burlington Resources, Inc., BROG’s parent. As a result, ConocoPhillips became the parent of Burlington Resources, Inc., which in turn, is the parent of BROG.

The function of the Trustee is to collect the net proceeds attributable to the Royalty (“Royalty Income”), to pay all expenses and charges of the Trust and distribute the remaining available income to the Unit Holders. The Trust does not operate the Underlying Properties and, in fact, is not empowered to carry on any business activity. The Trust has no employees, officers or directors. All administrative functions of the Trust are performed by the Trustee.

BROG is the principal operator of the Underlying Properties. A very high percentage of the Royalty Income is attributable to the production and sale by BROG of natural gas from the Underlying Properties. Accordingly, the market price for natural gas produced and sold from the San Juan Basin heavily influences the amount of Royalty Income distributed by the Trust and, by extension, the price of the Units.

Three Months Ended September 30, 2009 and 2008

The Trust received Royalty income of $7,232,890 and interest income of $194,481 during the third quarter of 2009. There was no change in cash reserves. After deducting administrative expenses of $435,690, distributable income for the quarter was $6,991,681 ($0.150007 per Unit). In the third quarter of 2008, Royalty income was $52,541,763, interest income was $32,508, administrative expenses were $351,221 and distributable income was $52,223,050 ($1.120455 per Unit). In August 2008, the Trust recovered $40,930 previously escheated to the State of Texas in the name of the Trust, and those funds were temporarily added to cash reserves pending further research as to the origin of the funds. Based on 46,608,796 Units outstanding, the per-Unit distributions during the third quarter of 2009 were as follows:


July	$	.035394
August		.061470
September		.053143

Quarter Total	$	.150007

The Royalty income distributed in the third quarter of 2009 was lower than that distributed in the third quarter of 2008, primarily due to a decrease in the average gas price from $10.62 per Mcf for the third quarter of 2008 to $2.98 per Mcf for the third quarter of 2009. Gas volumes, however, increased in the quarter ended September 30, 2009 as compared to the quarter ended September 30, 2008. Interest income was higher for the quarter ended September 30, 2009 as compared to the quarter ended September 30, 2008, due to interest BROG paid to the Trust in August 2009 as a result of the granting of certain audit exceptions. Administrative expenses were higher in 2009 primarily as a result of differences in timing in the receipt and payment of these expenses and also due to increased costs associated with the litigation described below.

The capital costs attributable to the Underlying Properties for the third quarter of 2009 and deducted by BROG in calculating Royalty income were approximately $7.4 million. BROG has informed the Trust that the 2009 budget for capital expenditures for the Underlying Properties is $25.2 million. In addition, BROG estimates that during 2009 it will incur capital expenses in the amount of approximately $12.1 million attributable to the capital budgets for 2008 and prior years. Approximately 12% of the planned expenditures attributable to the 2009 budget will be on Fruitland Coal formation projects with the remainder to be spent on conventional projects. BROG reports that based on its actual capital requirements, the pace of regulatory approvals, the mix of projects and swings in the price of natural gas, the actual capital expenditures for 2009 could range from $10 million to $45 million.

BROG anticipates 431 projects in 2009 at an estimated cost of $25.2 million. Approximately $6 million of that budget is allocable to 49 new wells, including 39 wells scheduled to be dually completed in the Mesaverde and Dakota formations and four wells projected to be drilled to formations producing coal seam gas. Approximately $7.1 million will be spent on workovers and facilities projects. Of the $12.1 million attributable to the budgets for prior years, approximately $6.9 million is allocable to new wells, and the $5.2 million balance will be applied to miscellaneous capital projects such as workovers and operated facility projects. BROG also anticipates that the possible implementation of new rules minimizing surface disturbances, requiring the implementation of closed-loop systems for the disposal of drilling fluids and cuttings, and restricting the use of open reserve pits could reduce the number of projects due to increased compliance costs.

BROG has informed the Trust that lease operating expenses and property taxes were $7,756,942 and $213,289, respectively, for the third quarter of 2009, as compared to $7,947,438 and $276,732, respectively, for the third quarter of 2008. BROG reports that lease operating expenses were lower in the third quarter of 2009 compared to the third quarter of 2008 primarily because of lower contract services and maintenance costs. Furthermore, BROG reports that the decrease in costs related to the property taxes are due to the fact that property tax amounts are accrued based on the prior year’s actual costs. In 2009, $71,096 per month in property taxes is accrued, based on the

amount of the actual property tax bill paid in early 2009, as compared with $92,244 per month accrued in 2008, based on the amount of the actual property tax bill paid in early 2008.

BROG has reported to the Trustee that during the third quarter of 2009, 22 gross (4.58 net) conventional wells, two gross (0.84 net) recompletions, 16 gross (8.23 net) coal seam wells and one gross (.85 net) coal seam recompletion were completed on the Underlying Properties. Seven gross (2.20 net) conventional wells were in progress at September 30, 2009.

There were, based on revised information from BROG, seven gross (2.22 net) coal seam wells and 33 gross (4.24 net) conventional wells completed on the Underlying Properties as of September 30, 2008. Five gross (0.92 net) coal seam wells and seven gross (1.42 net) conventional wells were in progress at September 30, 2008.

There were 3,903 gross (1,137 net) producing wells being operated subject to the Royalty as of December 31, 2008, calculated on a well bore basis and not including multiple completions as separate wells.

“Gross” acres or wells, for purposes of this discussion, means the entire ownership interest of all parties in such properties, and BROG’s interest therein is referred to as the “net” acres or wells. A “payadd” is the completion of an additional productive interval in an existing completed zone in a well.

Royalty income for the quarter ended September 30, 2009 is associated with actual gas and oil production during May 2009 through July 2009 from the Underlying Properties. Gas and oil sales from the Underlying Properties for the three months ended September 30, 2009 and 2008 were as follows:


	Three Months Ended
	September 30,
	2009		2008

Gas:
Total sales (Mcf)		8,916,522		8,737,027
Mcf per day		96,919		94,968
Average price (per Mcf)	$	2.98	$	10.62
Oil:
Total sales (Bbls)		17,414		12,793
Bbls per day		189		139
Average price (per Bbl)	$	56.08	$	120.99

Gas and oil sales attributable to the Royalty for the quarters ended September 30, 2009 and 2008 were as follows:


	Three Months Ended
	September 30,
	2009		2008

Gas sales (Mcf)		2,563,130		5,326,507
Oil sales (Bbls)		5,004		7,724

Sales volumes attributable to the Royalty are determined by dividing the net profits received by the Trust and attributable to oil and gas, respectively, by the prices received for sales volumes from the Underlying Properties, taking into consideration production taxes attributable to the Underlying Properties. 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.

During the third quarter of 2009, average gas prices were $7.64 per Mcf lower than the average prices reported during the third quarter of 2008 due in part to the global economic contraction which has depressed energy demand and contributed to lower natural gas wellhead prices, including the posted index prices applicable to gas sold from the San Juan Basin. In addition, many experts attribute the decline in gas prices to record or near record inventories in storage and increased domestic production from the various shale formations. The average price per barrel of oil during the third quarter of 2009 was $64.91 per barrel lower than that received for the third quarter of 2008.

BROG previously entered into three contracts for the sale of all volumes of gas produced from the Underlying Properties to ChevronTexaco Natural Gas, a division of Chevron U.S.A. Inc. (“ChevronTexaco”), Coral Energy Resources, L.P. (“Coral”), and PNM Gas Services (“PNM”), respectively. In March 2008, both ChevronTexaco and Coral notified BROG of their election to terminate their respective contracts effective March 31, 2009. Requests for proposal were circulated to potential purchasers of the packages of gas covered by the expiring contracts. Neither BROG nor PNM gave notice of termination with respect to the PNM contract and, by agreement of the parties, the term of that contract has been extended through at least March 31, 2011. On December 11, 2008, the New Mexico Public Regulatory Commission approved the sale of the gas utility assets of PNM to New Mexico Gas Company, Inc. (“NMGC”) and, effective as of January 30, 2009, the PNM contract was assigned to and assumed by NMGC.

BROG entered into four new contracts effective April 1, 2009, for the sale of all gas produced from the Underlying Properties other than the gas covered by the NMGC contract. The new purchasers are Chevron Natural Gas, a division of Chevron USA, Inc., Pacific Gas and Electric Company, BP Energy Company and Macquarie Cook Energy LLC. All four of the new contracts and the pre-existing NMGC contract provide for (i) the delivery of such gas at various delivery points through March 31, 2011 and from year-to-year thereafter, until terminated by either party on 12 months’ notice; and (ii) the sale of such gas at prices which fluctuate in accordance with the published indices for gas sold in the San Juan Basin of northwestern New Mexico. Although the primary term of the Chevron contract continues until March 31, 2011, a portion of that contract will be remarketed for sale after March 2010.

Confidentiality agreements with purchasers of gas produced from the Underlying Properties prohibit public disclosure of certain terms and conditions of gas sales contracts with those entities, including specific pricing terms and gas receipt points. Such disclosure could compromise the ability to compete effectively in the marketplace for the sale of gas produced from the Underlying Properties.

Nine Months Ended September 30, 2009 and 2008

For the nine months ended September 30, 2009, the Trust received Royalty income of $19,257,575 and interest income of $197,892. After deducting administrative expenses of $1,706,123, distributable income was $17,749,344 ($0.380814 per Unit) for the nine months ended September 30, 2009. There was no change in cash reserves. For the nine months ended September 30, 2008, the Trust received Royalty income of $113,730,327 and interest income of $216,621. Cash reserves increased in August 2008 by $40,930, the amount recovered from the State of Texas. After deducting administrative expenses of $1,554,074, distributable income was $112,392,874 ($2.411409 per Unit) for the nine months ended September 30, 2008.

The decrease in distributable income from 2008 to 2009 resulted primarily from lower gas prices during the first nine months of 2009. However, gas volumes were higher in the nine months ended September 30, 2009, in part, due to unplanned down-time at a facility operated by a third party in the second quarter of 2008. Interest earnings were lower for the nine months ended September 30, 2009 as compared to the nine months ended September 30, 2008, primarily due to a decrease in funds available for investment and to lower interest rates. General and administrative expenses were higher for the nine months ended September 30, 2009, as compared to the same period in 2008, primarily as a result of differences in timing in the receipt and payment of the expenses, but also due to an increase in legal expenses incurred in the litigation between BROG and the Trust described in Part II, Item I, below.

Capital expenditures incurred by BROG, attributable to the Underlying Properties, for the first nine months of 2009 amounted to approximately $28.3 million. Capital expenditures were approximately $19.9 million for the first nine months of 2008. Lease operating expenses and property taxes first nine months of 2009 totaled $24,563,067 and $703,310, respectively, as compared to $23,767,528 and $798,760, respectively, for 2008.

BROG has reported to the Trustee that during the nine months ended September 30, 2009, 68 gross (13.28 net) conventional wells, two gross (0.84 net) recompletions, 36 gross (19.55 net) coal seam wells and one gross (0.85 net) coal seam recompletion were completed on the Underlying Properties. There were 33 gross (13.25 net) coal seam wells and 108 gross (11.69 net) conventional wells completed on the Underlying Properties during the nine months ended September 30, 2008.

Royalty income for the nine months ended September 30, 2009 is associated with actual gas and oil production during November 2008 through July 2009 from the Underlying Properties. Gas and oil sales from the Underlying Properties for the nine months ended September 30, 2009 and 2008 were as follows:


	Nine Months Ended
	September 30,
	2009		2008

Gas:
Total sales (Mcf)		25,986,144		25,133,676
Mcf per day		95,187		91,729
Average price (per Mcf)	$	3.28	$	8.72
Oil:
Total Sales (Bbls)		43,689		36,168
Bbls per day		160		132
Average price (per Bbl)	$	45.34	$	101.88

Gas and oil sales attributable to the Royalty for the nine months ended September 30, 2009 and 2008 were as follows:


	Nine Months Ended
	September 30,
	2009		2008

Gas sales (Mcf)		6,034,462		14,579,826
Oil sales (Bbls)		9,820		20,787

During the first nine months of 2009 gas and oil prices were lower than during the first nine months of 2008. Since the oil and gas sales attributable to the Royalty are based on an allocation formula that is dependant 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.

Calculation of Royalty Income

Royalty Income received by the Trust for the three months and nine months ended September 30, 2009 and 2008, respectively, was computed as shown in the following table:

CALCULATION OF ROYALTY INCOME


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2009			2008			2009			2008

Gross proceeds of sales from the Underlying Properties:
Gas proceeds	$	26,539,822	(1)	$	92,813,502		$	85,149,264		$	212,607,028	(2)
Oil proceeds		976,542			1,547,800			1,980,659			3,684,910

Total		27,516,364			94,361,302			87,129,923			216,291,938

Less production costs:
Severance tax — gas		2,381,417			8,391,694			7,685,851			19,856,326
Severance tax — oil		94,969			152,033			193,945			369,512
Other		—			—			1,020	(3)		—
Lease operating expense and property tax		7,970,231			8,224,170			25,266,377			24,566,288
Capital expenditures		7,425,894			7,537,721			28,305,963			19,859,376

Total		17,872,511			24,305,618			61,453,156			64,651,502

Net profits		9,643,853			70,055,684			25,676,767			151,640,436
Net overriding royalty interest		75	%		75	%		75	%		75	%

Royalty Income	$	7,232,890		$	52,541,763		$	19,257,575		$	113,730,327


(1)		In August 2009, gas proceeds included $540,069 resulting from granted audit exceptions.

(2)		In March 2008, gas proceeds were reduced by $6,562,104 as the amount BROG determined to be the Trust’s portion of BROG’s settlement of a legal matter with the Minerals Management Service and the Bureau of Indian Affairs.

(3)		Reflects the fee for BROG volume exchanges during the production month of April 2009.

Contractual Obligations

Under the Indenture governing the Trust, the Trustee is entitled to an administrative fee for its administrative services and the preparation of quarterly and annual statements of: (i) 1/20 of 1% of the first $100 million of the annual gross revenue of the Trust, and 1/30 of 1% of the annual gross revenue of the Trust in excess of $100 million and (ii) the Trustee’s standard hourly rates for time in excess of 300 hours annually, provided that the administrative fee due under items (i) and (ii) above will not be less than $36,000 per year (as adjusted annually to reflect the increase (if any) in the Producers Price Index as published by the U.S. Department of Labor, Bureau of Labor Statistics, since December 31, 2003).

Effects of Securities Regulation

As a publicly-traded trust listed on the New York Stock Exchange (the “NYSE”), the Trust is and will continue to be subject to extensive regulation under, among others, the Securities Act of 1933, the Securities Exchange Act of 1934 (which contains many of the provisions of the Sarbanes-Oxley Act of 2002), and the rules and regulations of the NYSE. Issuers failing to comply with such authorities risk serious consequences, including criminal as well as civil and administrative penalties. In most instances, these laws, rules, and regulations do not specifically address their applicability to publicly-traded trusts, such as the Trust. In particular, the Sarbanes-Oxley Act of 2002 provides

for the adoption by the Securities and Exchange Commission (the “Commission”) and NYSE of certain rules and regulations that may be impossible for the Trust to literally satisfy because of its nature as a pass-through trust. It is the Trustee’s intention to follow the Commission’s and NYSE’s rulemaking closely, attempt to comply with such rules and regulations and, where appropriate, request relief from these rules and regulations. However, if the Trust is unable to comply with such rules and regulations or to obtain appropriate relief, the Trust may be required to expend presently unknown but potentially material costs to amend the Indenture that governs the Trust to allow for compliance with such rules and regulations. To date, the rules implementing the Sarbanes-Oxley Act of 2002 have generally made appropriate accommodation for passive entities such as the Trust.

Critical Accounting Policies

In accordance with the Commission’s rules and regulations and consistent with other royalty trusts, the financial statements of the Trust are prepared on the following basis:


	•	Royalty Income recorded for a month is the amount computed and paid pursuant to the Conveyance by BROG to the Trustee for the Trust. Royalty Income consists of the proceeds received by BROG from the sale of production from the Underlying Properties less accrued production costs, development and drilling costs, applicable taxes, operating charges, and other costs and deductions, multiplied by 75%. The calculation of net proceeds by BROG for any month includes adjustments to proceeds and costs for prior months and impacts the Royalty Income paid to the Trust and the distribution to Unit Holders for that month.

	•	Trust expenses recorded are based on liabilities paid and cash reserves established from Royalty Income for liabilities and contingencies.

	•	Distributions to Unit Holders are recorded when declared by the Trustee.

	•	The Conveyance which transferred the Royalty to the Trust provides that any excess of development and production costs applicable to the Underlying Properties over gross proceeds from such properties must be recovered from future net proceeds before Royalty Income is again paid to the Trust.


Item 3.	*Quantitative and Qualitative Disclosures About Market Risk.*

The Trust invests in no derivative financial instruments, and has no foreign operations or long-term debt instruments. The Trust is a passive entity and is prohibited from engaging in a trade or business, including borrowing transactions, other than as periodically necessary to pay expenses, liabilities and obligations of the Trust that cannot be paid out of cash held by the Trust. The amount of any such borrowings is unlikely to be material to the Trust. The Trust is also permitted to hold 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 is not permitted to engage in transactions in foreign currencies which could expose the Trust or Unit Holders to any foreign currency related market risk. The Trust is not permitted to market the gas, oil or natural gas liquids from the Underlying Properties; BROG is responsible for such marketing.


Item 4.	*Controls and Procedures.*

The Trust maintains a system of disclosure controls and procedures that is designed to ensure that information required to be disclosed in the Trust’s filings under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in the Commission’s rules and forms. Due to the pass-through nature of the Trust, BROG provides much of the information disclosed in this Form 10-Q and the other periodic reports filed by the Trust with the Commission. Consequently, the Trust’s ability to timely disclose relevant

information in its periodic reports is dependent upon BROG’s delivery of such information. Accordingly, the Trust maintains disclosure controls and procedures designed to ensure that BROG accurately and timely accumulates and delivers such relevant information to the Trustee and those who participate in the preparation of the Trust’s periodic reports to allow for the preparation of such periodic reports and any decisions regarding disclosure.

The Indenture does not require BROG to update or provide information to the Trust. However, the Conveyance transferring the Royalty to the Trust obligates BROG to provide the Trust with certain information, including information concerning calculations of net proceeds owed to the Trust. Pursuant to the settlement of litigation in 1996 between the Trust and BROG, BROG agreed to newer, more formal financial reporting and audit procedures as compared to those provided in the Conveyance.

In order to help ensure the accuracy and completeness of the information required to be disclosed in the Trust’s periodic reports, the Trust employs independent public accountants, joint interest auditors, marketing consultants, attorneys and petroleum engineers. These outside professionals advise the Trustee in its review and compilation of this information for inclusion in this Form 10-Q and the other periodic reports provided by the Trust to the Commission.

The Trustee has evaluated the Trust’s disclosure controls and procedures as of September 30, 2009 and has concluded that such disclosure controls and procedures are effective, at the “reasonable assurance” level, to ensure that material information related to the Trust is gathered on a timely basis to be included in the Trust’s periodic reports. In reaching its conclusion, the Trustee has considered the Trust’s dependence on BROG to deliver timely and accurate information to the Trust. Additionally, during the quarter ended September 30, 2009 there were no changes in the Trust’s internal control over financial reporting that materially affected, or are reasonably likely to materially affect, the Trust’s internal control over financial reporting. The Trustee has reviewed neither the Trust’s disclosure controls and procedures nor the Trust’s internal control over financial reporting in concert with management, a board of directors or an independent audit committee. The Trust does not have, nor does the Indenture provide for, officers, a board of directors or an independent audit committee.

PART II

OTHER INFORMATION


Item 1.	*Legal Proceedings.*

As discussed above under Part I, Item 4 — Controls and Procedures, due to the pass-through nature of the Trust, BROG provides much of the information disclosed in this Form 10-Q and the other periodic reports filed by the Trust with the Commission. Although the Trustee receives periodic updates from BROG regarding activities which may relate to the Trust, the Trust’s ability to timely report certain information required to be disclosed in the Trust’s periodic reports is dependent on BROG’s timely delivery of the information to the Trust.

Certain motions for summary judgment filed by BROG and the Trust are to be heard on January 5, 2010. The trial on the merits has been set for the week of May 24, 2011.

In addition to the litigation described above, BROG is involved in various legal proceedings, the outcome of which may impact the Trust. Should certain legal proceedings to which BROG is a party be decided in a manner adverse to BROG, the amount of Royalty income received by the Trust could materially decrease. The Trust has not received from BROG any estimate of the amount of any potential loss in such proceedings, or the portion of any such potential loss that might be allocated to the Royalty.


Item 6.	*Exhibits.*


	(4)(a)			Amended and Restated Royalty Trust Indenture, dated September 30, 2002 (the original Royalty Trust Indenture, dated November 1, 1980, having been entered into between Southland Royalty Company and The Fort Worth National Bank, as Trustee), heretofore filed as Exhibit 99.2 to the Trust’s Current Report on Form 8-K filed with the Commission on October 1, 2002, is incorporated herein by reference.*
	(4)(b)			Net Overriding Royalty Conveyance from Southland Royalty Company to the Fort Worth National Bank, as Trustee, dated November 3, 1980 (without Schedules), heretofore filed as Exhibit 4(b) to the Trust’s Annual Report on Form 10-K filed with the Commission for the fiscal year ended December 31, 2007, is incorporated herein by reference.*
	(4)(c)			Assignment of Net Overriding Interest (San Juan Basin Royalty Trust), dated September 30, 2002, between Bank One, N.A. and TexasBank, heretofore filed as Exhibit 4(c) to the Trust’s Quarterly Report on Form 10-Q filed with the Commission for the quarter ended September 30, 2002, is incorporated herein by reference.*
	31			Certification required by Rule 13a-14(a), dated November 9, 2009, by Lee Ann Anderson, Vice President and Senior Trust Officer of Compass Bank, the Trustee of the Trust.**
	32			Certification required by Rule 13a-14(b), dated November 9, 2009, by Lee Ann Anderson, Vice President and Senior Trust Officer of Compass Bank, on behalf of Compass Bank, the Trustee of the Trust.***


*	A copy of this exhibit is available to any Unit Holder (free of charge) upon written request to the Trustee, Compass Bank, 2525 Ridgmar Boulevard, Suite 100, Fort Worth, Texas 76116.

**	Filed herewith.

***	Furnished herewith.

INDEX TO EXHIBITS


Exhibit
Number		Description

(4)(a)		Amended and Restated Royalty Trust Indenture, dated September 30, 2002 (the original Royalty Trust Indenture, dated November 1, 1980, having been entered into between Southland Royalty Company and The Fort Worth National Bank, as Trustee), heretofore filed as Exhibit 99.2 to the Trust’s Current Report on Form 8-K filed with the Commission on October 1, 2002, is incorporated herein by reference.*
(4)(b)		Net Overriding Royalty Conveyance from Southland Royalty Company to the Fort Worth National Bank, as Trustee, dated November 3, 1980 (without Schedules), heretofore filed as Exhibit 4(b) to the Trust’s Annual Report on Form 10-K filed with the Commission for the fiscal year ended December 31, 2007, is incorporated herein by reference.*
(4)(c)		Assignment of Net Overriding Interest (San Juan Basin Royalty Trust), dated September 30, 2002, between Bank One, N.A. and TexasBank, heretofore filed as Exhibit 4(c) to the Trust’s Quarterly Report on Form 10-Q with the Commission for the quarter ended September 30, 2002, is incorporated herein by reference.*
31		Certification required by Rule 13a-14(a), dated November 9, 2009, by Lee Ann Anderson, Vice President and Senior Trust Officer of Compass Bank, the Trustee of the Trust.**
32		Certification required by Rule 13a-14(b), dated November 9, 2009, by Lee Ann Anderson, Vice President and Senior Trust Officer of Compass Bank, on behalf of Compass Bank, the Trustee of the Trust.***


*	A copy of this exhibit is available to any Unit Holder (free of charge) upon written request to the Trustee, Compass Bank, 2525 Ridgmar Boulevard, Suite 100, Fort Worth, Texas 76116.

**	Filed herewith.

***	Furnished herewith.


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2009			2008			2009			2008

Trust corpus, beginning of period	$	17,572,134		$	18,975,921		$	17,927,498		$	19,880,888
Amortization of net overriding royalty interest		(293,925	)		(543,459	)		(649,289	)		(1,448,426	)
Distributable income		6,991,681			52,223,050			17,749,344			112,392,874
Distributions declared		(6,991,681	)		(52,223,050	)		(17,749,344	)		(112,392,874	)

Trust corpus, end of period	$	17,278,209		$	18,432,462		$	17,278,209		$	18,432,462

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents

Table of Contents


	By:	/s/ Lee Ann Anderson