Form 10-Q

Large accelerated filer

Accelerated filer

Non-accelerated filer

¨ (Do not check if a smaller reporting company)

Smaller reporting company

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

(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 x No ¨

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). Yes ¨ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer, or a smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

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

Number of Units of beneficial interest outstanding at August 10, 2015: 46,608,796

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 (the “Trustee”), 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, 2014. 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 June 30, 2015 and the distributable income and changes in trust corpus for the six-month periods ended June 30, 2015 and 2014. The distributable income for such interim periods is not necessarily indicative of the distributable income for the full year.

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

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:

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.

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 “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. 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.

Each Unit Holder should consult his or her own tax advisor regarding tax compliance matters related to such Unit Holder’s interest in the Trust.

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

On July 31, 2014, the Trustee filed a lawsuit (the “2014 Litigation”) against Burlington in the 1^st Judicial District Court for the County of Santa Fe, State of New Mexico. The case is styled Compass Bank, in its Capacity as Trustee of the San Juan Basin Royalty Trust v. Burlington Resources Oil & Gas Company LP and BROG GP LLC, No. D-101-CV-2014-01765. The Trust asserts claims for breach of contract and breach of the implied covenant of good faith and fair dealing, and seeks a declaratory judgment arising out of a number of unresolved revenue and expense audit exceptions asserted by the Trust’s auditors. More particularly, the claims involve Burlington’s failure to properly account for and pay net overriding royalty interests to the Trust with respect to oil and gas production from numerous properties in the San Juan Basin of northwestern New Mexico. Based on information currently available to the Trust and its auditors, the Trust seeks monetary relief (including actual and punitive damages, costs, expenses, interest and attorney fees) in excess of $12,000,000, along with specific performance of certain contractual obligations, declaratory relief and a judgment for other relief to which it may show itself to be justly entitled. Burlington has filed an answer, the parties have commenced discovery and are working to establish a schedule for mediation.

On March 14, 2008, Burlington notified the Trust that the distribution for March would be reduced by $4,921,578. Burlington described this amount as the Trust’s portion of what Burlington 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 has objected to Burlington’s unilateral decision to deduct any amount of the settlement paid by Burlington from the distributions payable to the Trust and formally complained of that action as part of the 2014 Litigation. The Trust argues that no part of the settlement should have been allocated to the Trust because the claim which gave rise to the settlement was presented to Burlington for payment prior to the effective date of a mutual release of all claims entered into by Burlington and the Trust in 1996. In the alternative, the Trust contends that even if Burlington’s allocation of part of the Wright settlement was not barred by the mutual release, the amount allocated to the Trust by Burlington was improper and excessive.

Burlington has informed the Trust that pursuant to an Order to Perform issued by the Minerals Management Service (“MMS”) dated June 10, 1998 (the “MMS Order”), the Jicarilla Apache Nation (the “Jicarilla”) alleged that in valuing production for royalty purposes one must perform (i) a major portion analysis, which calculates value on the highest price paid or offered for a major portion of the gas produced from the field where the leased lands are situated; and (ii) a dual accounting calculation, which computes royalties on the greater of (a) the value of gas prior to processing or (b) the combined value of processed residue gas and plant products plus the value of any condensate recovered downstream without processing. The MMS Order alleged that Burlington’s dual accounting calculations on Native American leases were based on less than major portion prices. In 2000, Burlington and the Jicarilla entered into a settlement agreement resolving the issues associated with the dual accounting calculation. The major portion calculation issue remains outstanding. Burlington takes the position that a judgment or settlement could entitle Burlington to reimbursement from the Trust for past periods.

In 2007 Burlington obtained an Administrative Order from the Department of the Interior (the “DOI”) rejecting that portion of the MMS Order requiring Burlington to calculate and pay additional royalties based on the major portion price derived by the MMS. The Jicarilla filed suit solely against the DOI in the United States District Court for the District of Columbia in an action entitled 1:07-CV-00803-RJL, Jicarilla Apache Nation v. Department of Interior (the “DOI Case”) seeking a declaration that the Administrative Order is unlawful and of no force and effect, as well as an injunction requiring enforcement of the underlying major portion orders that were rejected by the Assistant Secretary. In 2009, a summary judgment was entered by the district court in the DOI Case upholding the Administrative Order and dismissing the Jicarilla’s claims. The Jicarilla appealed to the U.S. Court of Appeals for the D.C. Circuit. On July 16, 2010, the U.S. Court of Appeals held that the 2007 Administrative Order dismissing the Jicarilla claims was arbitrary and capricious with respect to January 1984 through February 1988 production periods and by Memorandum Order dated October 7, 2011, remanded the matter to the DOI for further proceedings. While a judgment or settlement in the DOI Case could impact the Royalty Income of the Trust, Burlington has informed the Trust that it does not have sufficient information to estimate a range of loss for the Trust because the DOI has not provided a major portion calculation for the January 1984 to February 1988 time period as required by the July 16, 2010 Court of Appeals ruling described above. Burlington indicates that the situation will not be alleviated until the DOI provides Burlington with a new Order to Perform or similar notice, but that it cannot predict when or if the DOI will provide such information or notice. The Trust’s consultants will continue to monitor development in this matter and analyze the appropriateness of the allocation, if any, by Burlington of any portion of any settlement or judgment in calculating the Royalty.

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 Burlington Resources Oil & Gas Company LP (“Burlington”), 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 Burlington; 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.

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.

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.

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 Burlington. In March 2006, a subsidiary of ConocoPhillips completed its acquisition of Burlington Resources, Inc., Burlington’s parent. As a result, ConocoPhillips became the parent of Burlington Resources, Inc., which in turn, is the parent of Burlington.

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.

Burlington is the principal operator of the Underlying Properties. A very high percentage of the Royalty Income is attributable to the production and sale by Burlington 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.

The Trust received Royalty Income of $2,264,542 and interest income of $497 during the second quarter of 2015. No distributions were made in April or May 2015. The Royalty Income received in April was $92,095, and there was a $97,648 decrease in cash reserves as funds were withdrawn to pay administrative expenses in the amount of $189,743. The cash available for distribution in May was applied first to pay $164,889 in administrative costs and to replenish the reserve maintained by the Trustee for liabilities and contingencies. After deducting quarterly administrative expenses of $498,750 and establishing a cash reserve of $536,313, distributable income for the quarter was $1,416,218 ($0.030385 per Unit). In the second quarter of 2014, Royalty Income was $18,124,799, interest income was $70,713, administrative expenses were $483,252 and distributable income was $17,712,260 ($0.380019 per Unit). Based on 46,608,796 Units outstanding, the per-Unit distributions during the second quarter of 2015 were as follows:

The Royalty Income distributed in the second quarter of 2015 was lower than that distributed in the second quarter of 2014 primarily due to lower gas prices and increased capital costs and administrative expenses. The average gas price decreased from $5.23 per Mcf for the second quarter of 2014 to $2.38 for the second quarter of 2015. Interest income was lower for the quarter ended June 30, 2015 as compared to the quarter ended June 30, 2014 due to additional interest Burlington paid to the Trust in 2014 as a result of the granting of certain audit exceptions and to a decrease in funds available for investment. Administrative expenses were higher in 2015 primarily as a result of increased legal costs incurred in the 2014 Litigation and differences in timing in the receipt and payment of certain of these expenses.

The capital costs attributable to the Underlying Properties for the second quarter of 2015 and deducted by Burlington in calculating Royalty Income were approximately $5 million as compared to approximately $1.8 million of capital costs in the second quarter of 2014.

Burlington informed the Trust that its budget for capital expenditures for the Underlying Properties in 2015 is estimated at $14 million. Burlington 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 2015 are subject to change.

Burlington anticipates 91 projects in 2015. Approximately $5.5 million will be attributable to six new wells to be operated by Burlington and $1.7 million of the budget is allocable to 40 miscellaneous facilities projects. The $6.8 million balance is attributable to the budgets for 2014 and prior years’ projects and will be applied to five wells commenced in 2014, and 40 miscellaneous capital projects such as workovers and operated facility projects. In light of the challenged price environment for natural gas and natural gas liquids, Burlington completed its 2015 new well drilling program in the San Juan Basin in March and anticipates no new drilling activity to be commenced during the remainder of this year. However, Burlington reported that it continually monitors natural gas prices and plans to restart the program at some point in the future, dependent upon such gas prices. Existing wells will continue to be operated.

Lease operating expenses and property taxes were $7,862,768 and $109,081, respectively, for the second quarter of 2015, as compared to $9,292,116 and $139,893, respectively, for the second quarter of 2014. Burlington indicates the decrease in operating expenses in the second quarter of 2015 is due to its efforts beginning in 2014 to reduce contracted maintenance and repair costs which continued into the second quarter of 2015, and had the effect of stretching maintenance operators over more wells. Property taxes for the second quarter of 2015 were lower because actual taxes for 2014 were less than accrued, which resulted in a reduction in the current accruals based on a new estimate of ad valorem taxes for 2015.

Burlington has reported to the Trustee that during the second quarter of 2015, one gross (1.00 net) conventional well was completed on the Underlying Properties. There were no wells in progress at June 30, 2015.

There were no conventional wells completed on the Underlying Properties during the second quarter of 2014. There were no wells in progress at June 30, 2014.

There were 4,000 gross (1,154.80 net) producing wells being operated subject to the Royalty as of December 31, 2014, calculated on a well bore basis and not including multiple completions as separate wells. Of those wells, seven gross (5.00 net) are oil wells and the balance are gas wells. Burlington reports that approximately 845 gross (322.52 net) of the wells are multiple completion wells resulting in a total of 4,845 gross (1,477.62 net) completions.

“Gross” acres or wells, for purposes of this discussion, means the entire ownership interest of all parties in such properties, and Burlington’s interest therein is referred to as the “net” acres or wells. In calculating the number of net wells, where a well is completed to multiple formations, Burlington indicates it (a) multiplies the working interest for each zone by a fraction equal to one divided by the total number of completions in that well bore, and (b) adds the interests so calculated for each zone to obtain the net ownership interest in that well. A “payadd” is the completion of an additional productive interval in an existing completed zone in a well.

Royalty Income for the quarter ended June 30, 2015 is associated with actual gas and oil production during February 2015 through April 2015 from the Underlying Properties. Gas and oil sales from the Underlying Properties for the three months ended June 30, 2015 and 2014 were as follows:

During the second quarter of 2015, average gas prices were $2.85 per Mcf lower than the average prices reported during the second quarter of 2014. The average price per barrel of oil during the second quarter of 2015 was $49.67 per barrel lower than that received for the second quarter of 2014.

Gas produced from the Underlying Properties is processed at one of the following five plants: Chaco, Val Verde, Milagro, Ignacio, and Kutz, all located in the San Juan Basin. All of such gas other than that processed at Kutz is being sold to Chevron USA, Inc. (“Chevron”) under a contract with Burlington dated April 1, 2015 which provides for the delivery of gas through March 31, 2016, at which time it will terminate unless both parties agree to extend it on or before October 1, 2015.

Gas produced from the Underlying Properties and processed at Kutz was being sold under three separate contracts with EDF Trading North America, LLC (“EDF”), Shell Energy North America (US), LP (“Shell”) and New Mexico Gas Company, Inc. (“NMGC”). The NMGC contract for the sale of certain winter-only supplies of the Kutz gas is for a five-year term expiring March 31, 2017. The contracts effective as of April 1, 2014 with EDF and Shell were set to expire March 31, 2015. Burlington circulated another round of requests for proposal for the purchase of those volumes and entered into a new contract with EDF for the purchase of the volumes covered by both the prior Shell and EDF contracts through March 31, 2016.

All three of the current contracts provide for (i) the delivery of such gas at various delivery points through their respective termination dates; 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.

Burlington contracts with Williams Four Corners, LLC (“WFC”) and Enterprise Field Services, LLC (“EFS”) for the gathering and processing of virtually all of the gas produced from the Underlying Properties. Four contracts were entered into with WFC, each of which is effective for a term of 15 years, which commenced April 1, 2010. Burlington has signed a similar agreement with EFS which was effective November 1, 2011 for a term of 15 years. Burlington has disclosed to the Trust a summary of that agreement which the Trust has reviewed with its consultants, subject to conditions of confidentiality.

Confidentiality agreements with gatherers and 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.

For the six months ended June 30, 2015 the Trust received Royalty income of $9,609,143 and interest income of $80,444. There was a $350,071 net increase in cash reserves. After deducting administrative expenses of $1,160,488 and the cash reserve increase, distributable income was $8,179,028 ($0.175483 per Unit) for the six months ended June 30, 2015. For the six months ended June 30, 2014, the Trust received Royalty income of $32,650,525 and interest income of $72,167. There was no change in cash reserves. After deducting administrative expenses of $920,589, distributable income was $31,802,103 ($0.682319 per Unit) for the six months ended June 30, 2014.

The decrease in distributable income from 2014 to 2015 resulted primarily from increased capital expenditures and lower average gas prices during the first half of 2015. Interest earnings for the six months ended June 30, 2015, as compared to the six months ended June 30, 2014 were lower due to the receipt of $69,241 in 2014 in interest on the late payment of net proceeds and in interest due on granted and paid audit exceptions as a result of the ongoing negotiation of compliance audit issues. General and administrative expenses were higher for the six months ended June 30, 2015, as compared to the same period in 2014 primarily as a result of increased legal costs incurred in the 2014 Litigation and differences in timing in the receipt and payment of the expenses.

Capital expenditures incurred by Burlington, attributable to the Underlying Properties, for the first six months of 2015 amounted to approximately $9.8 million. Capital expenditures were approximately $3.1 million for the first six months of 2014. Lease operating expenses and property taxes for the first six months of 2015 totaled $15,555,751 and $116,685, respectively, as compared to $18,291,621 and $222,128, respectively, for the first six months of 2014.

Burlington has reported to the Trustee that during the six months ended June 30, 2015, nine gross (5.75 net) conventional wells were completed on the Underlying Properties. There were no conventional wells completed on the Underlying Properties in the six months ending June 30, 2014.

Royalty income for the six months ended June 30, 2015 is associated with actual gas and oil production during November 2014 through April 2015 from the Underlying Properties. Gas and oil sales from the Underlying Properties for the six months ended June 30, 2015 and 2014 were as follows:

Royalty income received by the Trust for the three months and six months ended June 30, 2015 and 2014, respectively, was computed as shown in the following table:

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).

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.

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:

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 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; Burlington is responsible for such marketing.

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, Burlington 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 Burlington’s delivery of such information. Accordingly, the Trust maintains disclosure controls and procedures designed to ensure that Burlington 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 Burlington to update or provide information to the Trust. However, the Conveyance transferring the Royalty to the Trust obligates Burlington 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 Burlington, Burlington 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 engages independent public accountants, compliance 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 June 30, 2015 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 and recorded, processed, summarized and reported within the time periods specified in the Commission’s rules and forms. In reaching its conclusion, the Trustee has considered the Trust’s dependence on Burlington to deliver timely and accurate information to the Trust. Additionally, during the quarter ended June 30, 2015 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.

As discussed above under Part I, Item 4 – Controls and Procedures, due to the pass-through nature of the Trust, Burlington 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 Burlington 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 Burlington’s timely delivery of the information to the Trust.

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.


COMPASS BANK, AS TRUSTEE OF THE SAN JUAN BASIN ROYALTY TRUST

By:		/s/ Lee Ann Anderson
		Lee Ann Anderson
		Vice President and Senior Trust Officer


	June 30, 2015		December 31, 2014
	(Unaudited)
ASSETS

Cash and short-term investments	$	1,952,531	$	4,011,340
Net overriding royalty interest in producing oil and gas properties (net of accumulated amortization of $124,194,393 and $123,912,771 at June 30, 2015 and December 31, 2014, respectively)		9,081,135		9,362,757

	$	11,033,666	$	13,374,097

LIABILITIES AND TRUST CORPUS

Distribution payable to Unit Holders	$	1,416,218	$	3,825,098
Cash reserves		536,313		186,242
Trust corpus – 46,608,796 Units of beneficial interest authorized and outstanding		9,081,135		9,362,757

	$	11,033,666	$	13,374,097


	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
Trust corpus, beginning of period	$	9,162,781		$	10,572,586		$	9,362,757		$	10,968,996
Amortization of net overriding royalty interest		(81,646	)		(408,363	)		(281,622	)		(804,773	)
Distributable income		1,416,218			17,712,260			8,179,028			31,802,103
Distributions declared		(1,416,218	)		(17,712,260	)		(8,179,028	)		(31,802,103	)

Trust corpus, end of period	$	9,081,135		$	10,164,223		$	9,081,135		$	10,164,223


	Three Months Ended June 30,
	2015		2014
Gas:
Total sales (Mcf)		7,238,541		7,591,679
Mcf per day		81,332		85,300
Average price (per Mcf)	$	2.38	$	5.23

Oil:
Total sales (Bbls)		16,533		14,387
Bbls per day		186		162
Average price (per Bbl)	$	37.20	$	86.87


	Six Months Ended June 30,
	2015		2014
Gas:
Total sales (Mcf)	$	14,438,245	$	15,360,961
Mcf per day		79,769		84,867
Average price (per Mcf)	$	2.86	$	4.68

Oil:
Total Sales (Bbls)	$	28,890	$	33,124
Bbls per day		160		183
Average price (per Bbl)	$	41.62	$	84.07



(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 August 10, 2015, 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 August 10, 2015, by Lee Ann Anderson, Vice President and Senior Trust Officer of Compass Bank, on behalf of Compass Bank, the Trustee of the Trust.***


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 August 10, 2015, 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 August 10, 2015, by Lee Ann Anderson, Vice President and Senior Trust Officer of Compass Bank, on behalf of Compass Bank, the Trustee of the Trust.***


April	$	.000000
May		.000000
June		.030385

Quarter Total	$	.030385


	Three Months Ended June 30,						Six Months Ended June 30,
	2015			2014			2015			2014
Gross proceeds of sales from the Underlying Properties:
Gas proceeds	$	17,207,327		$	39,734,602		$	41,348,942		$	71,841,023
Oil proceeds		615,064			1,249,754			1,202,412			2,784,769
Other		(3,030	)⁽¹⁾		-0-			(3,030	)⁽¹⁾		-0-

Total		17,819,361			40,984,356			42,548,324			74,625,792

Less production costs:
Severance tax – gas		1,744,869			5,440,498			4,189,186			9,152,107
Severance tax – oil		61,813			136,195			118,665			293,870
Lease operating expense and property tax		7,971,849			9,432,009			15,672,436			18,513,749
Capital expenditures		5,021,441			1,809,255			9,755,846			3,132,033

Total		14,799,972			16,817,957			29,736,133			31,091,759
Net profits		3,019,389			24,166,399			12,812,191			43,534,033
Net overriding royalty interest		75	%		75	%		75	%		75	%

Royalty Income	$	2,264,542		$	18,124,799		$	9,609,143		$	32,650,525