10-Q

UNITED STATES

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, 2019

or

☐ 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. 001-08032

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.)

BBVA USA

300 W. 7^th Street, Suite B

Fort Worth, Texas 76102

(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)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Units	SJT	New York Stock Exchange

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  ☒    No  ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted 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, a smaller reporting company or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” or “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer	☐	Accelerated filer	☒
Non-accelerated filer	☐	Smaller reporting company	☒
		Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  ☐

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

Number of Units of beneficial interest outstanding at August 9, 2019: 46,608,796

Table of Contents

	PART I. FINANCIAL INFORMATION
Item 1	Financial Statements	1
Item 2	Trustee’s Discussion and Analysis of Financial Condition and Results of Operations	5
Item 3	Quantitative and Qualitative Disclosures about Market Risk	10
Item 4	Controls and Procedures	10
	PART II. OTHER INFORMATION
Item 1	Legal Proceedings	12
Item 1A	Risk Factors	12
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds	12
Item 3	Defaults Upon Senior Securities	12
Item 4	Mine Safety Disclosures	12
Item 5	Other Information	12
Item 6	Exhibits	13
	SIGNATURE

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SAN JUAN BASIN ROYALTY TRUST

PART I

FINANCIAL INFORMATION

Item 1. Financial Statements.

CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS
	June 30, 2019 (Unaudited)		December 31, 2018 (Audited)
ASSETS
Cash and short-term investments	$	915,057	$	2,125,838
Net overriding royalty interest in producing oil and gas properties (net of accumulated amortization of $127,689,208 and $127,430,801 at June 30, 2019 and December 31, 2018, respectively)		5,586,320		5,844,727
Total assets	$	6,501,377	$	7,970,565
LIABILITIES AND TRUST CORPUS
Distribution payable to Unit Holders	$	—	$	1,125,838
Cash reserves		915,057		1,000,000
Trust corpus – 46,608,796 Units of beneficial interest authorized and outstanding		5,586,320		5,844,727
Total liabilities	$	6,501,377	$	7,970,565

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)
	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
Royalty income	$	2,408,205		$	2,990,520		$	8,957,770		$	9,637,333
Interest income		9,664			3,954			17,714			9,242
Total income		2,417,869			2,994,474			8,975,484			9,646,575
General and administrative expenses		(506,109	)		(462,585	)		(1,048,887	)		(887,287	)
Decrease in cash reserves		84,943			—			84,943			—
Distributable income	$	1,996,703		$	2,531,889		$	8,011,540		$	8,759,288
Distributable income per Unit (46,608,796 Units)	$	0.042840		$	0.054322		$	0.171890		$	0.187932

These Condensed Financial Statements should be read in conjunction with the accompanying

Notes to Condensed Financial Statements included herein.

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CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)
	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
Trust corpus, beginning of period	$	5,673,052		$	6,336,043		$	5,844,727		$	6,577,380
Amortization of net overriding royalty interest		(86,732	)		(178,693	)		(258,407	)		(420,030	)
Distributable income		1,996,703			2,531,889			8,011,540			8,759,288
Distributions declared		(1,996,703	)		(2,531,889	)		(8,011,540	)		(8,759,288	)
Trust corpus, end of period	$	5,586,320		$	6,157,350		$	5,586,320		$	6,157,350
Distributions declared (per Unit)	$	0.042840		$	0.054322		$	0.171890		$	0.187932

These Condensed Financial Statements should be read in conjunction with the accompanying

Notes to Condensed Financial Statements included herein.

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1.    Basis of Presentation

The preceding (a) condensed balance sheet as of December 31, 2018, which has been derived from audited financial statements, and (b) the unaudited interim condensed financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). These condensed financial statements should be read in conjunction with the financial statements and the notes thereto included in San Juan Basin Royalty Trust (the “Trust”) Annual Report on Form 10-K for the year ended December 31, 2018. In the opinion of BBVA USA (formerly known as Compass Bank), the trustee of the Trust (the “Trustee”), and based upon information provided to the Trust by Hilcorp San Juan L.P. (“Hilcorp”), the present owner of certain oil and gas interests originally owned by Southland Royalty Company (the “Subject Interests”) in properties located in the San Juan Basin of northwestern New Mexico (the “Royalty Income”), 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, 2019, and the distributable income and changes in trust corpus for the three-month and six-month periods ended June 30, 2019 and 2018. The distributable income for such interim periods is not necessarily indicative of the distributable income for the full year.

The financial statements of the Trust are prepared on the following basis and are not intended to present the financial position and results of operations of the Trust in conformity with U.S. generally accepted accounting principles (“GAAP”):

• The net proceeds attributable to the 75% net overriding royalty interest (the “Royalty”) that burdens the Subject Interests recorded for a month is the amount computed and paid by Hilcorp to the Trustee for the Trust. Royalty Income consists of the proceeds received by Hilcorp 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%. The calculation of net proceeds by Hilcorp 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. See Item 2 Part I of this Quarterly Report on Form 10-Q entitled “Gross Proceeds and Severance Tax Estimates” for a more detailed explanation of the estimate and true-up process for distributable income reporting and distributions to Unit Holders.

• Although permitted under the Net Overriding Royalty Conveyance that transferred the Royalty to the Trust (the “Conveyance”), Hilcorp has informed the Trust that, for wells operated by Hilcorp, it generally did not intend to accrue lease operating expenses to the Trust.

• Hilcorp has informed the Trust that oil revenue is typically reported to the Trust based on actual volumes and pricing and that due to timing, Hilcorp reports accrued natural gas revenues to the Trust based on actual production volumes from the meters. Generally, Hilcorp reconciles the natural gas revenue accruals with the plant processing statements the month following the previously reported financial information.

• 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 provides that any excess production costs applicable to the Subject Interests over gross proceeds from such properties must be recovered from future net proceeds before Royalty Income is again paid to the Trust. The Trust is not obligated to reimburse Hilcorp for any excess production costs if future gross proceeds from the Subject Interests are insufficient to cover such costs. Gross excess production costs applicable to the Subject Interests were $0.2 million as of June 30, 2019, with 75%, or $0.1 million (net) allocated 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 liabilities and 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 trust corpus instead of as an expense. Most accounting pronouncements apply to entities whose financial statements are prepared in accordance with GAAP, directing such entities to accrue or defer revenues and expenses in a period other than when such revenues were received or expenses were paid. Because the Trust’s financial statements are prepared on the modified cash basis, as described above, most accounting pronouncements are not applicable to the Trust’s financial statements, which include the provisions of the new revenue recognition standard in ASU 2014-09. The Trust has evaluated the impact of ASC 842, Leases, and determined that this standard has no impact on the Trust’s financial statements.

The Trustee has determined that there are no additional disclosures required based on the Trust’s method of accounting. This comprehensive basis of accounting corresponds to the accounting permitted for royalty trusts by the SEC, as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts.

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The Trustee routinely reviews the Trust’s royalty interests in oil and natural gas properties for impairment whenever events or circumstances indicate that the carrying amount of an asset may not be recoverable. If an impairment event occurs and it is determined that the carrying value of the Trust’s royalty interests may not be recoverable, an impairment will be recognized as measured by the amount by which the carrying amount of the royalty interests exceeds the fair value of these assets, which would likely be measured by discounting projected cash flows and is charged directly to trust corpus instead of as an expense. There was no impairment of the Trust’s assets as of June 30, 2019.

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 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 natural 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 natural 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 natural 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 natural 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. 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.

Tax positions taken by the Trust related to the Trust’s pass-through status and state tax positions have been reviewed, and the Trustee is of the opinion that the material tax positions it has taken would more likely than not be sustained by examination. As of June 30, 2019, the Trust’s tax years 2015 and thereafter remain subject to examination.

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.

3.    Commitments and Contingencies

Contingencies related to the Subject Interests that are unfavorably resolved would generally be reflected by the Trust as reductions to future Royalty Income payments to the Trust with corresponding reductions to cash distributions to Unit Holders. See Note 1 Basis of Presentation, for a summary of the terms of the Conveyance with respect to recovery of costs.

4.     Settlements and Litigation

None.

5.    Subsequent Events

There was no Distributable Income in July 2019 due primarily to capital expenditures associated with the Fruitland Coal drill well and multiple well recompletions resulting in gross excess production costs of $1.0 million ($0.8 million net). Accumulated total gross excess production costs as of August 1, 2019 were $1.2 million ($0.9 million net). In July 2019 the net amount of $0.1 million was withdrawn from the $0.9 million cash reserve to pay Trust general and administrative expenses. Total cash reserves were approximately $0.8 million as of August 1, 2019. No cash distributions will be distributed by the Trust until future net proceeds are sufficient to pay then-current Trust liabilities and replenish cash reserves.

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On August 9, 2019, the Trust reported that Hilcorp had informed it that Hilcorp likely will not distribute to the Trust any royalty income for the remainder of 2019, primarily due to Hilcorp’s substantial capital expenditures for 2019. As a result of the lack of royalty income payments from Hilcorp, the Trust will not have any distributable income to pay to its unit holders. The Trust previously reported on May 9, 2019, that Hilcorp had revised its 2019 capital expenditures plan for the Subject Interests from approximately $2.7 million to $12.6 million in order to fund increased well recompletions and additional well drillings in the Subject Interests.

The Trust believes that it has sufficient capacity to draw upon its cash reserves to pay the Trust’s administrative expenses for the remainder of 2019. The Trust will not make any cash distributions to the Trust’s unit holders until future net proceeds from royalty income distributions are sufficient to pay the then-current Trust liabilities and replenish previously utilized cash reserves. In the event that the Trust has insufficient cash reserves to fund its administrative expenses, the Trust believes that it has the ability to borrow funds against the Trust’s royalty interests to cover the Trust’s administrative expenses until its cash reserves can be replenished from royalty income payments from Hilcorp.

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

Overview

The Trust is an express trust created under the laws of the state of Texas by the San Juan Basin Royalty Trust Indenture entered into on November 1, 1980 between Southland Royalty Company (“Southland”) and The Fort Worth National Bank. Effective as of September 30, 2002, the original indenture governing the Trust was amended and restated and, effective as of December 12, 2007, the restated indenture was again amended and restated, which the Trust refers to as the “Indenture.” As a result of a series of mergers and other transactions involving the Trustee of the Trust, the current Trustee of the Trust is BBVA USA, which is a wholly-owned subsidiary of Banco Bilbao Vizcaya Argentaira, S.A.

The Conveyance and the Royalty

Pursuant to the Net Overriding Royalty Conveyance (the “Conveyance”) effective November 1, 1980, Southland conveyed the Royalty that burdens the Subject Interests in properties located in the San Juan Basin of northwestern New Mexico to the Trust. Subsequent to the Conveyance of the Royalty, through a series of sales, assignments and mergers, Southland’s successor became Hilcorp, which acquired the Subject Interests from Burlington Resources Oil & Gas Company LP (“Burlington”), an indirect wholly-owned subsidiary of ConocoPhillips, on July 31, 2017.

The Royalty constitutes the principal asset of the Trust. The beneficial interest in the Royalty is divided into 46,608,796 units (the “Units”) representing undivided fractional interests in the beneficial interest of the Trust equal to the number of shares of the common stock of Southland outstanding as of the close of business on November 3, 1980. Each stockholder of Southland 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 then held. Holders of Units in the Trust are referred to herein as “Unit Holders.”

The Trustee

The primary function of the Trustee is to collect Royalty Income, to pay all expenses and charges of the Trust and distribute the remaining available income to the Unit Holders. The amount of income distributable to Unit Holders, which we refer to as “Distributable Income,” depends on the amount of Royalty Income and interest received by the Trust, as well as the amount of expenses paid by the Trust and any change in cash reserves. The Trust has no employees, officers or directors. All administrative functions of the Trust are performed by the Trustee. Effective June 10, 2019, Compass Bank changed its name to BBVA USA.

Hilcorp

Hilcorp is the principal operator of the majority of the Subject Interests. Hilcorp is also responsible, subject to the terms of a prior agreement with the Trust, for marketing the oil and natural gas production from such properties, either under existing sales contracts or under future arrangements, at the best prices and on the best terms it shall deem reasonably obtainable in the circumstances. A very high percentage of the Royalty Income is attributable to the production and sale by Hilcorp of natural gas from the Subject Interests. 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.

Gross Proceeds and Severance Tax Estimates

The sale of San Juan Basin assets, including the Subject Interests, from Burlington to Hilcorp closed on July 31, 2017. During this transition, the Trust has been advised by Hilcorp that for certain months it recorded estimates of cash revenues and expenses, based on the best information available. Hilcorp has informed the Trust that it believes that its estimates have been prepared in accordance with the Conveyance.

Hilcorp’s process of reconciling actual revenue and severance tax numbers versus previously reported estimated numbers (which the Trust refers to as “true-ups”) during fiscal 2018 are still occurring and being reported in 2019. Thus, distributions to the Trust from Hilcorp in any given month may be subject to adjustment based upon prior months’ true-ups, plus interest due to the Trust. Generally, there is a two or three month lag in Hilcorp truing-up previously reported estimated or accrued financial information; however, Hilcorp has notified the Trustee that as of the date of this quarterly report, it will still need to true-up the previously reported

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natural gas production (and for the trust distribution months of January 2018 and October 2018 through February 2019, oil production) and financial information for the trust distribution months of January 2018 and June 2018 through February 2019 and, therefore, possibly adjust future distributions of net proceeds to reflect such true-ups plus interest on such amounts (as required by the Conveyance) to the extent an underpayment has occurred. The April 2019 distribution included a true-up of the oil and gas production used in the March 2019 distribution, resulting in a net decrease of approximately $0.5 million.

The Trust has been advised by Hilcorp that as a result of its continued transitioning of historic information and knowledge from Burlington, an additional $1.0 million in “Other” revenue was included in the gross proceeds estimates in the December 2017 and January 2018 distribution months. The additional “Other” revenue was based on Hilcorp’s estimated increases in natural gas production that were subsequently offset by lower natural gas pricing. Hilcorp has not yet trued-up the $1.0 million in “Other” gross proceeds included in each of the December 2017 and January 2018 distributions. As a result, once Hilcorp has finalized such true-up during fiscal 2019, there could be a negative adjustment to the “Other” gross proceeds of up to $2.0 million, consisting of $1.0 million in December 2017 and $1.0 million in January 2018.

Results of Operations – for the Three and Six Months Ended June 30, 2019 and 2018

Royalty Income

Royalty Income consists of monthly net proceeds attributable to the Royalty. Royalty Income for the three and six months ended June 30, 2019 and 2018 was determined as shown in the following table:

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
Gross proceeds from the Subject Interests:
Natural Gas	$	12,123,999		$	14,388,363		$	30,762,506		$	29,931,971
Oil		809,378			886,592			1,252,584			1,547,895
Other		507,000	(1)		(2,000,000	)(2)		1,014,000	(1)		(1,000,000	)(3)
Total		13,440,377			13,274,955			33,029,090			30,479,866
Production Costs:
Severance tax – gas		1,309,692			2,026,247			3,443,009			3,772,801
Severance tax – oil		67,671			88,909			104,452			149,269
Other		—			(187	)		—			(3,734	)
Lease operating expense and property tax		6,786,230			7,055,793			14,749,195			13,260,805
Capital expenditures		2,237,344			116,834			2,960,241			450,948
Total		10,400,937			9,287,596			21,256,897			17,630,089
Unreconciled production costs in excess of gross proceeds		171,500						171,500
Net profits		3,210,940			3,987,359			11,943,693			12,849,777
Net overriding royalty interest		75	%		75	%		75	%		75	%
Royalty Income	$	2,408,205		$	2,990,520		$	8,957,770		$	9,637,333

(1) Estimated revenue from non-operated properties.

(2) Reversal of Hilcorp’s increased revenue estimate of $1.0 million gross for each of the Trust months October 2017 and November 2017.

(3) Reflects $1.0 million gross estimated additional revenue received in January 2018 offset by the reversal of $1.0 million gross revenue estimate for each of the Trust months October 2017 and November 2017.

The Royalty Income distributed to the Trust for both the three and six months ended June 30, 2019 was lower than that distributed during the same periods of 2018 due primarily to higher production costs and lower natural gas proceeds for the three months ended June 30, 2019 primarily due to lower production. The average natural gas price increased from $1.65 per Mcf for the three months ended June 30, 2018 to $1.74 per Mcf for the three months ended June 30, 2019, and the average natural gas price increased from $1.83 per Mcf for the six months ended June 30, 2018 to $2.14 per Mcf for the six months ended June 30, 2019.

Gross Proceeds from Subject Interests. Total Gross proceeds increased approximately $0.2 million or 1% for the three months ended June 30, 2019 compared to the three months ended June 30, 2018, and increased approximately $2.5 million or 8% for the six months ended June, 2019 compared to the six months ended June 30, 2018. The increase was primarily attributable to “Other” gross proceeds received in 2019 for estimated revenue from non-operated properties and a reduction of “Other” gross proceeds in 2018 due to Hilcorp’s reversal of previous revenue estimates.

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Capital Expenditures. Capital expenditures increased $2.1 million or approximately 1,815% for the three months ended June 30, 2019 compared to the three months ended June 30, 2018, and increased $2.5 million or approximately 556% for the six months ended June 30, 2019 compared to the six months ended June 30, 2018.

Hilcorp’s original 2019 capital expenditures plan (the “Original Plan”), announced by the Trust on March 1, 2019, estimated Hilcorp’s capital expenditures to be $2.7 million for the Subject Interests. Of this amount, the Original Plan allocated approximately $0.7 million towards five well recompletions and an additional $1.9 million towards the drilling of one new horizontal well.

In May 2019 Hilcorp provided the Trust with an update to the Original Plan (the “CapEx Plan”). The CapEx Plan increased the planned 2019 CapEx budget for the Subject Interests to an estimated $12.6 million, with approximately $3.7 million allocable to 17 well recompletions. Hilcorp provided the Trust with additional updates and comments to its updated CapEx Plan in July 2019, including Hilcorp’s drilling and recompletion plans. Hilcorp reported to the Trust that ten of the 17 wells have been recompleted or were in process of being recompleted as of June 2019, and that well performance from the ten-well recompletion package has exceeded its initial expectations. Hilcorp further informed the Trust that its planned project status for 2019 is fluid, that additional projects may be added, and therefore, actual capital costs may vary from the updated CapEx Plan. Despite currently low natural gas prices, Hilcorp has informed the Trust that it believes the recompletions planned pursuant to the CapEx Plan constitute sound economic projects.

Hilcorp advised the Trust that it plans to spend approximately $8.9 million from the updated CapEx Plan to drill two new wells in the second half of 2019 that will be funded from the capital plan. The first well is a horizontal well targeting the Fruitland Coal formation (Trail Canyon 104H) and the second well is a horizontal well targeting the Mancos formation (Trieb Federal Com 601 #1H). Capital spending on the Fruitland Coal well began in June 2019 and the well is expected to begin production in July 2019. Capital spending on the Mancos well is expected to begin in the third quarter of 2019, contingent on receiving a permit from the BLM, and the well is expected to begin production in the fourth quarter of 2019. Hilcorp informed the Trust that the cost for the Mancos well is higher than the Fruitland Coal well because the anticipated Mancos well will be drilled to a significantly deeper depth, have a longer horizontal lateral, and will be hydraulically fractured.

Severance Taxes. Aggregate severance taxes decreased approximately $0.7 million or approximately 35% for the three months ended June 30, 2019 compared to the three months ended June 30, 2018, and decreased $0.4 million or approximately 10% for the six months ended June 30, 2019 compared to the six months ended June 30, 2018. The decrease was primarily attributable to certain tax exemptions that have been applied to the time period and lower revenue for the three months ended June 30, 2019. Severance taxes represented approximately 10% of gross proceeds for the three months ended June 30, 2019, compared to approximately 16% for the same period of 2018. Severance taxes represented approximately 11% of gross proceeds for the six months ended June 30, 2019 compared to 13% for the same period of 2018.

Lease Operating Expenses and Property Taxes. Lease operating expenses and property taxes decreased $0.3 million or approximately 4% for the three months ended June 30, 2019 compared to the three months ended June 30, 2018 and increased $1.5 million or approximately 11% for the six months ended June 30, 2019 compared to the six months ended June 30, 2018. The decrease in the three-month period is primarily due to decreased compression and non-operated expenses, and the increase over the six-month period is primarily due to increased activity at the Subject Interests by Hilcorp.

Monthly lease operating expenses of the Subject Interests, including property taxes, in second quarter 2019 averaged approximately $2.3 million, as compared to $2.4 million in the second quarter of 2018. Monthly lease operating expenses of the Subject Interests, including property taxes, in the first half of 2019 averaged approximately $2.5 million, as compared to $2.2 million in the first half of 2018.

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Distributable Income

	Three Months Ended June 30,						Six Months Ended June 30,
	2019			2018			2019			2018
Royalty Income	$	2,408,205		$	2,990,520		$	8,957,770		$	9,637,333
Interest Income		9,664			3,954			17,714			9,242
Total Income		2,417,869			2,994,474			8,975,484			9,646,575
Expenses – General and administrative		(506,109	)		(462,585	)		(1,048,887	)		(887,287	)
Decrease in Cash Reserves		84,943			—			84,943			—
Distributable Income		1,996,703			2,531,889			8,011,540			8,759,288
Distributable Income per Unit (46,608,796 Units)	$	0.042840		$	0.054322		$	0.171890		$	0.187932

Distributable Income. Distributable Income decreased by approximately $0.5 million or 21% to $2 million ($0.042840 per Unit) for the three months ended June 30, 2019 from $2.5 million ($0.054322 per Unit) for the three months ended June 30, 2018. Distributable Income decreased by approximately $0.7 million or 9% to $8.0 million ($0.171890 per Unit) for the six months ended June 30, 2019 from $8.8 million ($0.187932 per Unit) for the six months ended June 30, 2018. The decrease in Distributable Income was primarily attributable to higher production costs. There was no Distributable Income in June 2019 due primarily to capital expenditures for well recompletions resulting in gross excess production costs of $0.2 million ($0.1 million net).

Based on 46,608,796 Units outstanding, the per-Unit distributions during the second quarter of 2019 were as follows:

April	$	0.015968
May		0.026872
June		0.000000
Quarter Total	$	0.042840

Interest Income. Interest income was higher for the three and six months ended June 30, 2019 as compared to the same periods in 2018 primarily due to higher yields on short-term investments.

General & Administrative Expenses. General and administrative expenses increased approximately 9% for the three months ended June 30, 2019 compared to the three months ended June 30, 2018, and increased approximately $0.2 million or approximately 18% for the six months ended June 30, 2019 compared to the six months ended June 30, 2018. The increase was primarily attributable to higher compliance auditor costs related to the transition of the Subject Interests from Burlington to Hilcorp.

Cash Reserves. The Trust withdrew approximately $0.1 million from its established $1.0 million cash reserve in June 2019 to pay Trust general and administrative expenses due to the Trust receiving no Distributable Income in June 2019. Total cash reserves were approximately $0.9 million as of June 30, 2019. The primary purpose of the cash reserves is to have sufficient funds to cover monthly general and administrative expenses in the event that there is insufficient Royalty Income to cover such expenses. The Trustee will replenish the cash reserve once it begins receiving Distributable Income from Hilcorp. The Trustee does not anticipate any increases to the cash reserve level of $1.0 million in 2019, although it cannot guarantee that the Trustee will not increase such cash reserves in the future. The Trustee did not increase its cash reserves during fiscal 2018 above the established level.

Liquidity and Capital Resources

The Trust’s principal source of liquidity and capital is Royalty Income. The Trust’s distribution of income to Unit Holders is funded by Royalty Income after payment of Trust expenses. The Trust is not liable for any production costs or liabilities attributable to the Royalty. If at any time the Trust receives more than the amount due under the Royalty, it is not obligated to return such overpayment, but the amounts payable to it for any subsequent period are reduced by such amount, plus interest, at a rate specified in the Conveyance. If the Trustee determines that the Trust does not have sufficient funds to pay the Trust’s liabilities, the Trustee may borrow funds on behalf of the Trust, in which case no distributions will be made to Unit Holders until such borrowings are repaid in full. The Trustee may not sell or dispose of any part of the assets of the Trust without the affirmative vote of 75% of all of the Units outstanding; however, the Trustee may sell up to 1% of the value of the Royalty (as determined pursuant to the Indenture) during any 12-month period without the consent of the Unit Holders.

On August 9, 2019, the Trust reported that Hilcorp had informed it that Hilcorp likely will not distribute to the Trust any royalty income for the remainder of 2019, primarily due to Hilcorp’s substantial capital expenditures for 2019. As a result of the lack of royalty income payments from Hilcorp, the Trust will not have any distributable income to pay to its unit holders. The Trust previously reported on May 9, 2019, that Hilcorp had revised its 2019 capital expenditures plan for the Subject Interests from approximately $2.7 million to $12.6 million in order to fund increased well recompletions and additional well drillings in the Subject Interests.

The Trust believes that it has sufficient capacity to draw upon its cash reserves to pay the Trust’s administrative expenses for the remainder of 2019. The Trust will not make any cash distributions to the Trust’s unit holders until future net proceeds from royalty income distributions are sufficient to pay the then-current Trust liabilities and replenish previously utilized cash reserves. In the event that the Trust has insufficient cash reserves to fund its administrative expenses, the Trust believes that it has the ability to borrow funds against the Trust’s royalty interests to cover the Trust’s administrative expenses until its cash reserves can be replenished from royalty income payments from Hilcorp.

8

Oil and Natural Gas Production

The natural gas volumes reported to the Trust by Hilcorp are based on plant residue gas volumes plus equivalent volumes for natural gas liquids. Hilcorp converts one barrel of natural gas liquids to six Mcf of natural gas using industry standards.

Royalty Income for the quarter ended June 30, 2019 is associated with actual oil and natural gas production during February through April 2019 from the Subject Interests. Royalty Income for the quarter ended June 30, 2018 is associated with actual oil and natural gas production for February 2018 and March 2018 (estimated then subsequently trued-up) and estimated oil and natural gas production for April 2018 (oil subsequently trued-up) from the Subject Interests. Production of oil and natural gas and related average sales prices attributable to each of the Subject Interests and the Royalty for the three months ended June 30, 2019 and 2018 were as follows:

	For the Three Months Ended June 30,
	2019				2018
	Natural Gas (Mcf)		Oil and Condensate (Bbls)		Natural Gas (Mcf)		Oil and Condensate (Bbls)
Production
Subject Interests		6,970,358		16,750		8,708,810		18,134
Royalty		739,859		9,997		2,656,035		11,595
Average Price (per Mcf/Bbl)	$	1.74	$	48.32	$	1.65	$	48.89

Production of oil and natural gas and related average sales prices attributable to each of the Subject Interests and the Royalty for the six months ended June 30, 2019 and 2018 were as follows:

	For the Six Months Ended June 30,
	2019				2018
	Natural Gas (Mcf)		Oil and Condensate (Bbls)		Natural Gas (Mcf)		Oil and Condensate (Bbls)
Production
Subject Interests		14,364,272		27,571		16,369,326		32,507
Royalty		3,363,909		15,234		5,759,892		20,506
Average Price (per Mcf/Bbl)	$	2.14	$	45.43	$	1.83	$	47.62

The Trust recognizes production during the month in which the related net proceeds attributable to the Royalty are paid to the Trust. Royalty Income for a calendar year is based on the actual natural gas and oil production during the period beginning with November of the preceding calendar year through October of the current calendar year. Sales volumes attributable to the Royalty are determined by dividing the net profits by the Trust from the sale of oil and natural gas, respectively, by the prices received by Hilcorp for sales of such volumes from the Subject Interests, taking into consideration production taxes attributable to the Subject Interests. Because the oil and natural gas sales attributable to the Royalty are based upon an allocation formula dependent on such factors as price and cost, including Hilcorp’s capital expenditures and the timing of Hilcorp’s true-ups of prior reported estimated oil and natural gas production data, the aggregate sales amounts from the Subject Interests may not provide a meaningful comparison to sales attributable to the Royalty. Future true-ups will impact future royalty proceeds, but will not change the reported amounts due to the accounting basis used.

Production from the Subject Interests is influenced by the line pressure of the natural gas gathering systems in the San Juan Basin. Other fluctuations in natural gas production that have occurred during the three-month periods ended June 30, 2019 and 2018, respectively, generally result from changes in the demand for natural gas during that time, market conditions, and variances in capital spending to generate production from new and existing wells, as offset by the natural production decline curve. Hilcorp informed the Trust that oil and natural gas production during the three-month period ended June 30, 2019 was reduced due to severe winter conditions not seen in the San Juan Basin in over a decade. Such atypical conditions directly impacted production and physical access to well sites and facilities, maintenance, and transportation. As noted above, oil and natural gas sales attributable to the Royalty are based on an allocation formula dependent on many factors, including oil and natural gas prices and capital expenditures.

9

Marketing

There were no changes to the contracts pursuant to which Hilcorp sells production from the Subject Interests and for the gathering and processing of production during the second quarter of 2019.

Off-Balance Sheet Arrangements

None.

Critical Accounting Policies and Estimates

For a discussion of significant accounting policies and estimates that impact the Trust’s financial statements, see Part I, Item 1. Unaudited Financial Statements, Note 1 Basis of Presentation and Part II, Item 8. Financial Statements and Supplemental Data contained in the Trust’s Annual Report on Form 10-K for the year ended December 31, 2018.

Information Regarding 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 SEC (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 (the “Exchange Act”) 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, 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,” “based,” “estimate,” “expect,” “predict,” “project,” “anticipate,” “believe,” “plan,” “intend,” or other words that convey the uncertainty of future events or outcomes. Such statements are based on certain assumptions of BBVA USA, the Trustee, and by Hilcorp, 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 Hilcorp; and involve risks and uncertainties. However, whether actual results and developments will conform with such expectations and predictions is subject to a number of risks and uncertainties which could affect the future results of the energy industry in general, and the Trust and Hilcorp in particular, and could cause those results to differ materially from those expressed in such forward-looking statements. The actual results or developments anticipated may not be realized or, even if substantially realized, they may not have the expected consequences to or effects on Hilcorp’s business and the Trust. Such statements are not guarantees of future performance and actual results or developments may differ materially from those projected in such forward-looking statements. The Trust undertakes no obligation to publicly update or revise any forward-looking statements, except as required by applicable law.

Hilcorp Information

As a holder of a net overriding royalty interest, the Trust’s reporting of financial information is reliant upon Hilcorp accurately and timely reporting information regarding Hilcorp and its affiliates; the Subject Interests, including the operations, acreage, well and completion count, working interests, production volumes, sales revenues, capital expenditures, operating expenses, reserves, drilling plans, drilling results and leasehold terms related to the Subject Interests, and factors and circumstances that have or may affect the foregoing. See Part I, Item 4. Controls and Procedures.

There have been no material changes to the Trust’s market risk during 2019. For information on the Trust’s exposure to market risk, please see Part II, Item 7A, “Quantitative and Qualitative Disclosures About Market Risk” contained in the Trust’s Annual Report on Form 10-K for the year ended December 31, 2018.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

None.

Item 4. Controls and Procedures.

The Trust maintains a system of internal disclosure controls and procedures that is designed to ensure that the information required to be disclosed in the Trust’s filings under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms. In its evaluation of its disclosure controls and procedures, the Trustee has relied, to the extent considered reasonable, on information provided by Hilcorp, the owner of the properties. Consequently, the Trust’s ability to timely and accurately disclose relevant information in its periodic reports is dependent upon Hilcorp’s timely delivery of accurate oil and gas revenue and production cost information and, therefore, the net proceeds owed to the Trust.

10

The Net Overriding Royalty Conveyance (the “Conveyance”) that transferred the royalty to the Trust obligates Hilcorp to provide the Trust with certain financial and operational 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 Resources Oil & Gas Company LP (“Burlington”), an indirect wholly-owned subsidiary of ConocoPhillips, Burlington agreed to newer, more formal financial reporting and audit procedures as compared to those required to be provided by the Conveyance. As it did with Burlington, once the Trust receives the financial information from Hilcorp, the Trust engages independent public accountants, compliance auditors, attorneys and petroleum engineers in order to assist the Trustee to ensure the accuracy and completeness of the information required to be disclosed in the Trust’s periodic reports. 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 SEC.

The Trust has been advised by Hilcorp that during the transition period since its acquisition of the Subject Interests that there were significant delays in the transfer of historical information and knowledge from Burlington to Hilcorp. During this transition, the Trust has been advised by Hilcorp that it recorded estimates of cash revenues and expenses based on the best information available. Hilcorp informed the Trust that it believed that its estimates were prepared in accordance with the Conveyance. As a result, AMS-PAR, the Trust’s compliance auditors, had to audit vast amounts of new data in a largely unfamiliar format. This new data format necessitated AMS-PAR to develop its own internal systems, processes, and tools to organize and interpret the vast amount of raw data so that it can make a meaningful analysis. Hilcorp is aware that the Trustee and AMS-PAR had to implement additional processes. As a result, Hilcorp informed the Trustee that Hilcorp hired third-party consultants to help it through this transition. Although the Trust and Hilcorp have continued to work through the issues identified during the transition, the Trustee and its third party compliance auditors continue to coordinate with Hilcorp to ensure that Hilcorp can provide the required level of detail on a timely and accurate basis.

Despite the Trust’s internal controls and procedures ensuring the accuracy of the Trust’s reporting based upon the financial information received by the Trust from Hilcorp, Hilcorp’s process of reconciling actual revenue and severance tax numbers versus previously reported estimated numbers (which the Trust refers to as “true-ups”) during fiscal 2018 are still occurring and being reported in 2019. Thus, distributions to the Trust from Hilcorp in any given month may be subject to adjustment based upon prior months’ true-ups, plus interest due to the Trust. Generally, there is a two or three-month lag in Hilcorp reconciling previously reported estimated or accrued financial information. However, Hilcorp has notified the Trustee that as of the date of this quarterly report, it will still need to true-up the previously reported estimated natural gas and oil production and financial information for certain of the Trust’s 2018 and 2019 distribution months. Furthermore, Hilcorp possibly may adjust future distributions of net proceeds to reflect such true-ups plus interest on such amounts (as required by the Conveyance) to the extent an underpayment has occurred.

The Trustee has evaluated the Trust’s internal disclosure controls and procedures as of June 30, 2019, and has concluded that such disclosure controls and procedures are effective, at the “reasonable assurance” level (as such term is used in Rule 13a-15(f) of the Exchange Act), to ensure that material information received from Hilcorp 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 SEC’s rules and forms.

Additionally, during the quarter ended June 30, 2019, there were no changes in the Trust’s internal control over financial reporting (as such term is used in Rule 13a-15(f) of the Exchange Act) that materially affected, or are reasonably likely to materially affect, the Trust’s internal control over financial reporting. Because the Trust does not have, nor does the Indenture provide for, officers, a board of directors or an independent audit committee, 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.

11

PART II

OTHER INFORMATION

Item 1. Legal Proceedings.

None.

Item 1A. Risk Factors.

Not required.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

None.

Item 3. Defaults Upon Senior Securities.

None.

Item 4. Mine Safety Disclosures.

Not applicable.

Item 5. Other Information.

None.

12

Item 6. Exhibits.

Exhibit Number	Description
(4)(a)	San Juan Basin Amended and Restated Royalty Trust Indenture, dated December  12, 2007, filed as Exhibit 99.2 to the Trust’s Current Report on Form 8-K filed with the SEC on December 14, 2007, and incorporated herein by reference.*
(4)(b)	Net Overriding Royalty Conveyance from Southland Royalty Company to The Fort Worth National Bank, as Trustee, dated November  1, 1980 (without Schedules), filed as Exhibit 4(b) to the Trust’s Annual Report on Form 10-K filed with the SEC for the year ended December 31, 2006 on March  1, 2007, and 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 Texas Bank, filed as Exhibit 4(c) to the Trust’s Quarterly Report on Form 10-Q filed with the SEC for the quarter ended September  30, 2002, and incorporated herein by reference.*
31	Certification required by Rule 13a-14(a), dated August  9, 2019, by Joshua R. Peterson, Senior Vice President and Trust Officer of BBVA USA, the Trustee of the Trust.**
32	Certification required by Rule 13a-14(b), dated August  9, 2019, by Joshua R. Peterson, Senior Vice President and Trust Officer of BBVA USA, on behalf of BBVA USA, 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, BBVA USA, 300 W. 7th Street, Suite B, Fort Worth, Texas 76102.

** Filed herewith.

*** Furnished herewith.

13

SIGNATURE

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.

BBVA USA, AS TRUSTEE OF THE SAN JUAN BASIN ROYALTY TRUST
By:	/s/ Joshua R. Peterson
	Joshua R. Peterson Senior Vice President and Trust Officer

Date: August 9, 2019

(The Trust has no directors or executive officers.)

EX-31

EXHIBIT 31

CERTIFICATION

I, Joshua R. Peterson, certify that:

1.    I have reviewed this Quarterly Report on Form 10-Q of San Juan Basin Royalty Trust, for which BBVA USA acts as Trustee;

2.    Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.    Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, distributable income and changes in trust corpus of the registrant as of, and for, the periods presented in this report;

4.    I am responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and I have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under my supervision, to ensure that material information relating to the registrant, including any consolidated subsidiaries, is made known to me by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under my supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes;

c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report my conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.    I have disclosed, based on my most recent evaluation of internal control over financial reporting, to the registrant’s auditors:

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves persons who have a significant role in the registrant’s internal control over financial reporting.

In giving the certifications in paragraphs 4 and 5 above, I have relied to the extent I consider reasonable on information provided to me by Hilcorp San Juan L.P.

Date: August 9, 2019	By:	/s/ Joshua R. Peterson
		Joshua R. Peterson Senior Vice President and Trust Officer, BBVA USA

EX-32

EXHIBIT 32

CERTIFICATION OF

THE TRUSTEE*

OF THE SAN JUAN BASIN ROYALTY TRUST

PURSUANT TO 18 U.S.C. § 1350

In connection with the accompanying report on Form 10-Q for the quarter ended June 30, 2019 and filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Joshua R. Peterson, Senior Vice President and Trust Officer of BBVA USA, on behalf of BBVA USA, the Trustee of the San Juan Basin Royalty Trust (the “Trust”),* not in its individual capacity but solely as Trustee of the Trust, hereby certify that:

1. The Report fully complies in all material respects with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended (as explained in Note 1 to the Trust’s financial statements contained in the Report, in accordance with the Securities and Exchange Commission Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts, the Trust prepares its financial statements in a manner that differs from generally accepted accounting principles; such presentation is customary to other royalty trusts); and

2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Trust.

BBVA USA, AS TRUSTEE OF THE SAN JUAN BASIN ROYALTY TRUST
By:	/s/ Joshua R. Peterson
Name:	Joshua R. Peterson
Title:	Senior Vice President and Trust Officer
Date:	August 9, 2019

* The Trust has no executive officers.