**
 

 

**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 September 30, 2019**

 
****☐********
**Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934**

**For the transition period from                     to                    **

**Commission file number 1-8033**

 

 

**PERMIAN BASIN ROYALTY TRUST**

**(Exact Name of Registrant as Specified in the Permian Basin Royalty Trust Indenture)**

 

 

 
**Texas**  **75-6280532**
**(State or Other Jurisdiction of**

**Incorporation or Organization)**
  
**(I.R.S. Employer**

**Identification No.)**

**Royalty Trust Management**

**Simmons Bank**

**2911 TurtleCreek Boulevard**

**Suite 850**

**Dallas, Texas 75219**

**(Address of Principal Executive Offices; Zip Code)**

**(855) 588-7839**

**(Registrant’s Telephone Number, Including Area Code)**

**N/A**

**(Former Name, FormerAddress and Former Fiscal Year, If Changed Since Last Report)**

 

 

Securities registered pursuantto Section 12(b) of the Act: 

 

**Title of Each Class**
  
**Trading Symbol(s)**
  
**Name of Each Exchange on**

**Which Registered**
**Units of Beneficial Interest**  **PBT**  **New York Stock Exchange**
Indicate by check mark whether the registrant (1) has filed all reports required to be filed bySection 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 past90 days.    Yes  ☒    No  ☐ 

Indicate by check mark whether theregistrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for suchshorter period that the registrant was required to submit such files).    Yes  ☒    No  ☐ 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, anon-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reportingcompany,” and “emerging growth company” in Rule 12b-2 of the Exchange Act. 

 
 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 extendedtransition 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 theExchange Act).    Yes  ☐    No  ☒ 

Number of Units of beneficialinterest of the Trust outstanding at November 1, 2019: 46,608,796. 

 

 

 
**

**PERMIAN BASIN ROYALTY TRUST**

**PART I—FINANCIAL INFORMATION**

 
**Item 1.**
**Financial Statements**

The condensed financial statements included herein have been prepared by Simmons Bank as Trustee for the Permian Basin Royalty Trust (the “Trust”),without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Effective February 20, 2018, Simmons Bank (the “Trustee”) became the new trustee for the Trust. Certain information and footnotedisclosures normally included in annual financial statements have been condensed or omitted pursuant to such rules and regulations, although the Trustee believes that the disclosures are adequate to make the information presented not misleading. Itis suggested that these condensed interim financial statements and notes thereto be read in conjunction with the financial statements and the notes thereto included in the Trust’s latest annual report on Form10-K. In the opinion of the Trustee, all adjustments, consisting only of normal recurring adjustments, necessary to present fairly the assets, liabilities and trust corpus of the Permian Basin Royalty Trust asof September 30, 2019, the distributable income and the changes in the trust corpus for the three-month and nine-month periods ended September 30, 2019 and 2018, have been included. The distributable income for such interim periods is notnecessarily indicative of the distributable income for the full year. 

The condensed interim financial statements as of September 30, 2019 and forthe three-month and nine-month periods ended September 30, 2019 and 2018, included herein, have been reviewed by Weaver and Tidwell, L.L.P., an independent registered public accounting firm, as stated in their report appearing herein. 

. 

 
2 

**REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM [WEAVER TO UPDATE]**

The Unit Holders of Permian Basin Royalty Trust and 

SimmonsBank, Trustee 

Dallas, Texas 

**Results of Review ofInterim Financial Statements**

We have reviewed the accompanying condensed statements of assets, liabilities and trust corpus of Permian Basin RoyaltyTrust (the “Trust”) as of September 30, 2019 and the related condensed statements of distributable income and changes in trust corpus for the three-month and nine-month periods ended September 30, 2019 and 2018, and the relatednotes (collectively referred to as the “condensed interim financial statements” or “interim financial information”). Based on our review, we are not aware of any material modifications that should be made to the accompanyingcondensed interim financial statements for them to be in conformity with the modified cash basis of accounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America. 

As described in Note 2 to the condensed interim financial statements, these condensed interim financial statements were prepared on a modified cash basis ofaccounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America. 

We havepreviously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the statement of assets, liabilities, and trust corpus as of December 31, 2018, and the relatedstatements of distributable income and changes in trust corpus for the year then ended (not presented herein); and in our report dated March 18, 2019 we expressed an unqualified opinion on those financial statements. In our opinion, theinformation set forth in the accompanying condensed statement of assets, liabilities and trust corpus as of December 31, 2018, is fairly stated, in all material respects, in relation to the statement of assets, liabilities, and trust corpuswhich it has been derived. 

**Basis for Review Results**

These condensed interim financial statements are the responsibility of the Trustee. We conducted our review in accordance with the standards of the PCAOB. Weare a public accounting firm registered with the PCAOB and are required to be independent with respect to the Trust in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and ExchangeCommission and the PCAOB. A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than anaudit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion. 

/s/ WEAVER AND TIDWELL, L.L.P. 

Dallas, TX 

November 12, 2019 

 
3 

PERMIAN BASIN ROYALTY TRUST 

**CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS**

 
   September 30,2019(Unaudited)   December 31,2018 
ASSETS
    
Cash and short-term investments
  $2,914,923   $3,526,613 
Net overriding royalty interests in producing oil and gas properties (net of accumulatedamortization of $10,539,929 and $10,507,636 at September 30, 2019 and December 31, 2018, respectively)
   435,287    467,580   
 

 
   
 

 
 
TOTAL ASSETS
  $3,350,210   $3,994,193   
 

 
   
 

 
 
LIABILITIES AND TRUST CORPUS
    
Distribution payable to Unit holders
  $1,864,923   $2,476,613 
Commitments and reserves for contingencies (Note 6)
   1,050,000    1,050,000 
Trust corpus – 46,608,796 Units of beneficial interest authorized and outstanding
   435,287    467,580   
 

 
   
 

 
 
TOTAL LIABILITIES AND TRUST CORPUS
  $3,350,210   $3,994,193   
 

 
   
 

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

 
4 

**PERMIAN BASIN ROYALTY TRUST**

**CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)**

 
   THREE MONTHS ENDEDSeptember 30, 2019  THREE MONTHS ENDEDSeptember 30, 2018 
Royalty income
  $6,060,272  $7,236,350 
Interest income
   6,753   6,994   
 

 
  
 

 
    6,067,025   7,243,344 
General and administrative expenditures
   (118,549)   (186,501)   
 

 
  
 

 
 
Distributable income
  $5,948,476  $7,056,843   
 

 
  
 

 
 
Distributable income per Unit (46,608,796 Units)
  $ .13  $ .15   
 

 
  
 

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

 
5 

**PERMIAN BASIN ROYALTY TRUST**

**CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)**

 
   NINE MONTHS ENDEDSeptember 30, 2019  NINE MONTHS ENDEDSeptember 30, 2018 
Royalty income
  $15,357,784  $24,578,777 
Interest income
   18,174   19,224   
 

 
  
 

 
    15,375,958   24,598,001 
General and administrative expenditures
   (876,098)   (1,181,813)   
 

 
  
 

 
 
Distributable income
  $14,499,860  $23,416,188   
 

 
  
 

 
 
Distributable income per Unit (46,608,796 Units)
  $ .31  $ .50   
 

 
  
 

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

 
6 

**PERMIAN BASIN ROYALTY TRUST**

**CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)**

 
   THREE MONTHS ENDEDSeptember 30, 2019  THREE MONTHS ENDEDSeptember 30, 2018 
Trust corpus, beginning of period
  $ 448,358  $ 495,327 
Amortization of net overriding royalty interests
   (13,071)   (10,382) 
Distributable income
   5,948,476   7,056,843 
Distributions declared
   (5,948,476)   (7,056,843)   
 

 
  
 

 
 
Total Trust Corpus, end of period
  $ 435,287  $ 484,945   
 

 
  
 

 
 
Distributions per Unit
  $ .13  $ .15   
 

 
  
 

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

 
7 

**PERMIAN BASIN ROYALTY TRUST**

**CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)**

 
   NINE MONTHS ENDEDSeptember 30, 2019  NINE MONTHS ENDEDSeptember 30, 2018 
Trust corpus, beginning of period
  $ 467,580  $ 529,043 
Amortization of net overriding royalty interests
   (32,293)   (44,098) 
Distributable income
   14,499,959   23,416,188 
Distributions declared
   (14,499,959)   (23,416,188)   
 

 
  
 

 
 
Total Trust Corpus, end of period
  $ 435,287  $ 484,945   
 

 
  
 

 
 
Distributions per Unit
  $ .31  $ .50   
 

 
  
 

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

 
8 

**PERMIAN BASIN ROYALTY TRUST**

**NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)**

 
**1.**
**TRUST ORGANIZATION AND PROVISIONS**

The Permian Basin Royalty Trust (“Trust”) was established as of November 1, 1980. Simmons Bank (“Trustee”) is Trusteefor the Trust. The net overriding royalties conveyed to the Trust include (1) a 75% net overriding royalty in Southland Royalty Company’s fee mineral interest in the Waddell Ranch in Crane County, Texas (the “Waddell Ranchproperties”) and (2) a 95% net overriding royalty carved out of Southland Royalty Company’s major producing royalty properties in Texas (the “Texas Royalty properties”). The net overriding royalty for the Texas Royaltyproperties is subject to the provisions of the lease agreements under which such royalties were created. The net overriding royalties above are collectively referred to as the “Royalties.” 

On November 3, 1980, Units of Beneficial Interest (“Units”) in the Trust were distributed to the Trustee for the benefit ofSouthland Royalty Company’s shareholders of record as of November 3, 1980, who received one Unit in the Trust for each share of Southland Royalty Company common stock held. The Units are traded on the New York Stock Exchange. 

Burlington Resources Oil & Gas Company LP (“BROG”), a subsidiary of ConocoPhillips, is the interest owner for the WaddellRanch properties and Riverhill Energy Corporation (“Riverhill Energy”), formerly a wholly owned subsidiary of Riverhill Capital Corporation (“Riverhill Capital”) and formerly an affiliate of Coastal Management Corporation(“CMC”), is the interest owner for the Texas Royalty properties. BROG currently conducts all field, technical and accounting operations on behalf of BROG with regard to the Waddell Ranch properties. Riverhill Energy currently conducts theaccounting operations for the Texas Royalty properties. 

In February 1997, BROG sold its interest in the Texas Royalty properties toRiverhill Energy. 

The Trustee was advised that in the first quarter of 1998, Schlumberger Technology Corporation (“STC”)acquired all of the shares of stock of Riverhill Capital. Prior to such acquisition by STC, CMC and Riverhill Energy were wholly owned subsidiaries of Riverhill Capital. The Trustee was further advised that in connection with STC’s acquisitionof Riverhill Capital, the shareholders of Riverhill Capital acquired ownership of all of the shares of stock of Riverhill Energy. Thus, the ownership in the Texas Royalty properties referenced above remained in Riverhill Energy, the stock ownershipof which was acquired by the former shareholders of Riverhill Capital. 

 
9 

On January 9, 2014, Bank of America N.A. (as successor to The First National Bank ofFort Worth) gave notice to Unit holders that it would be resigning as trustee of the Trust subject to certain conditions that included the appointment of Southwest Bank as successor trustee. At a Special Meeting of Trust Unit holders, the Unitholders approved the appointment of Southwest Bank as successor trustee of the Trust once the resignation of Bank of America N.A. took effect and also approved certain amendments to the Trust Indenture. The effective date of Bank of AmericaN.A.’s resignation and the effective date of Southwest Bank’s appointment as successor trustee was August 29, 2014. Effective October 19, 2017, Simmons First National Corporation (“SFNC”) completed its acquisition ofFirst Texas BHC, Inc., the parent company of Southwest Bank. SFNC is the parent company of Simmons Bank. SFNC merged Southwest Bank with Simmons Bank effective February 20, 2018. The defined term “Trustee” as used herein shall referto Bank of America N.A. for periods prior to August 29, 2014, and shall refer to Southwest Bank for periods from August 29, 2014 through February 19, 2018 and shall refer to Simmons Bank for periods on and after February 20,2018. 

The terms of the Trust Indenture provide, among other things, that: 

 
 • 
the Trust shall not engage in any business or commercial activity of any kind or acquire any assets other thanthose initially conveyed to the Trust; 

 
 • 
the Trustee may not sell all or any part of the Royalties unless approved by holders of 75% of all Unitsoutstanding in which case the sale must be for cash and the proceeds promptly distributed; 

 
 • 
the Trustee may establish a cash reserve for the payment of any liability which is contingent or uncertain inamount; 

 
 • 
the Trustee is authorized to borrow funds to pay liabilities of the Trust; and 

 
 • 
the Trustee will make monthly cash distributions to Unit holders (see Note 3). 

 
**2.**
**ACCOUNTING POLICIES**

**Basis of Accounting**

Thefinancial statements of the Trust are prepared on the following basis: 

 
 • 
Royalty income recorded for a month is the amount computed and paid to the Trustee on behalf of the Trust by theinterest owners. Royalty income consists of the amounts received by the owners of the interest burdened by the Royalties from the sale of production less accrued production costs, development and drilling costs, applicable taxes, operating chargesand other costs and deductions multiplied by 75% in the case of the Waddell Ranch properties and 95% in the case of the Texas Royalty properties. 

 
10 

 • 
Trust expenses, consisting principally of routine general and administrative costs, recorded are based onliabilities paid and cash reserves established out of cash received or borrowed funds for liabilities and contingencies. 

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

 
 • 
Royalty income is computed separately for each of the conveyances under which the Royalties were conveyed to theTrust. If monthly costs exceed revenues for any conveyance (“excess costs”), such excess costs cannot reduce royalty income from other conveyances, but is carried forward with accrued interest to be recovered from future net proceeds ofthat conveyance. 

The financial statements of the Trust differ from financial statements prepared in accordance withaccounting principles generally accepted in the United States of America (“GAAP”) because revenues are not accrued in the month of production, expenses are recorded when paid and certain cash reserves may be established for contingencieswhich would not be accrued in financial statements prepared in accordance with GAAP. Amortization of the Royalties calculated on a unit-of-production basis is chargeddirectly to trust corpus. This comprehensive basis of accounting other than GAAP corresponds to the accounting permitted for royalty trusts by the U.S. Securities and Exchange Commission as specified by Staff Accounting Bulletin Topic 12:E,*Financial Statements of Royalty Trusts*. 

*Use of Estimates*

The preparation of financial statements in conformity with the basis of accounting described above requires management to make estimates andassumptions that affect reported amounts of certain assets, liabilities, revenues and expenses as of and for the reporting periods. Actual results may differ from such estimates. 

*Contingencies*

Contingencies related to the underlying properties that are unfavorably resolved would generally be reflected by the Trust as reductions tofuture royalty income payments to the Trust with corresponding reductions to cash distributions to Unit holders. 

 
11 

*Distributable Income Per Unit*

Basic distributable income per Unit is computed by dividing distributable income by the weighted average of Units outstanding. Distributableincome per Unit assuming dilution is computed by dividing distributable income by the weighted average number of Units and equivalent Units outstanding. The Trust had no equivalent Units outstanding for any period presented. Therefore, basicdistributable income per Unit and distributable income per Unit assuming dilution are the same. 

*New Accounting Pronouncements*

There are no new accounting pronouncements that are expected to have significant impact on the Trust’s financial statements. 

 
**3.**
**NET OVERRIDING ROYALTY INTERESTS AND DISTRIBUTION TO UNIT HOLDERS**

The amounts to be distributed to Unit holders (“Monthly Distribution Amounts”) are determined on a monthly basis. The MonthlyDistribution Amount is an amount equal to the sum of cash received by the Trustee during a calendar month attributable to the Royalties, any reduction in cash reserves and any other cash receipts of the Trust, including interest, reduced by the sumof liabilities paid and any increase in cash reserves. If the Monthly Distribution Amount for any monthly period is a negative number, then the distribution will be zero for such month. To the extent the distribution amount is a negative number,that amount will be carried forward and deducted from future monthly distributions until the cumulative distribution calculation becomes a positive number, at which time a distribution will be made. Unit holders of record will be entitled to receivethe calculated Monthly Distribution Amount for each month on or before 10 business days after the monthly record date, which is generally the last business day of each calendar month. 

The cash received by the Trustee consists of the amounts received by owners of the interest burdened by the Royalties from the sale ofproduction less the sum of applicable taxes, accrued production costs, development and drilling costs, operating charges and other costs and deductions, multiplied by 75% in the case of the Waddell Ranch properties and 95% in the case of the TexasRoyalty properties. 

 
12 

**4.**
**FEDERAL INCOME TAXES**

For federal income tax purposes, the Trust constitutes a fixed investment trust that is taxed as a grantor trust. A grantor trust is notsubject to federal income tax at the trust level. The Unit holders are considered for federal tax purposes 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 oraccrued by each Unit holder at the time such income is received or accrued by the Trust and not when distributed by the Trust. If the Trust borrows funds to pay liabilities of the Trust, as contemplated in the Trust Indenture, tax-exempt Unit holders could be required to recognize unrelated business taxable income. 

 
**5.**
**STATE TAX CONSIDERATIONS**

All revenues from the Trust are from sources within Texas, which does not impose an individual income tax. Texas imposes a franchise tax at arate of 0.75% on gross revenues less certain deductions, as specifically set forth in the Texas franchise tax statutes. Entities subject to the Texas franchise tax generally include trusts and most other types of entities that provide limitedliability protection, unless otherwise exempt. Trusts that receive at least 90% of their federal gross income from certain passive sources, including royalties from mineral properties and other non-operatedmineral interest income, and do not receive more than 10% of their income from operating an active trade or business, generally are exempt from the Texas franchise tax as “passive entities.” The Trust has been and expects to continue to beexempt from Texas franchise tax as a passive entity. Because the Trust should be exempt from Texas franchise tax at the Trust level as a passive entity, each Unit holder that is a taxable entity under the Texas franchise tax generally will berequired to include its portion of Trust revenues in its own Texas franchise tax computation. This revenue is sourced to Texas under provisions of the Texas Administrative Code providing that such income is sourced according to the principal placeof business of the Trust, which is Texas. 

Unit holders should consult their tax advisors regarding state tax requirements, if any,applicable to such Unit holder’s ownership of Trust units. 

 
13 

**6.**
**COMMITMENTS AND CONTINGENCIES**

Contingencies related to the Underlying Properties that are unfavorably resolved would generally be reflected by the Trust as reductions tofuture royalty income payments to the Trust with corresponding reductions to cash distributions to Unit holders. 

 
**7.**
**SUBSEQUENT EVENTS**

Subsequent to September 30, 2019, the Trust declared a distribution on October 21, 2019 of $0.027711 per Unit payable onNovember 15, 2019 to Unit holders of record on October 31, 2019. 

*    *    *    *    * 

 
14 

**Item 2.**
**Trustee’s Discussion and Analysis**

**Forward Looking Information**

Certain information includedin this report contains, and other materials filed or to be filed by the Trust with the Securities and Exchange Commission (as well as information included in oral statements or other written statements made or to be made by the Trust) may containor include, forward looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934, as amended, and Section 27A of the Securities Act of 1933, as amended. Such forward looking statements may be or may concern,among other things, capital expenditures, drilling activity, development activities, production efforts and volumes, hydrocarbon prices and the results thereof, and regulatory matters. Although the Trustee believes that the expectations reflected insuch forward-looking statements are reasonable, such expectations are subject to numerous risks and uncertainties and the Trustee can give no assurance that they will prove correct. There are many factors, none of which are within the Trustee’scontrol, that may cause such expectations not to be realized, including, among other things, factors such as actual oil and gas prices and the recoverability of reserves, capital expenditures, general economic conditions, actions and policies ofpetroleum-producing nations and other changes in the domestic and international energy markets. Such forward looking statements generally are accompanied by words such as “estimate,” “expect,” “predict,”“anticipate,” “goal,” “should,” “assume,” “believe,” or other words that convey the uncertainty of future events or outcomes. 

**Three Months Ended September 30, 2019 Compared to Three Months Ended September 30, 2018**

For the quarter ended September 30, 2019, royalty income received by the Trust amounted to $6,060,272 compared to royalty income of $7,236,350 during thethird quarter of 2018. The decrease in royalty income is primarily attributable to a decrease in oil and gas pricing offset by an increase in production of oil for the quarter ending September 30, 2019, as compared to the quarter endedSeptember 30, 2018. Average oil and gas prices were $54.30 and $1.82, respectively, for the quarter ending September 30, 2019 compared to $60.19 and $3.64 for the quarter ended September 30, 2018. 

Interest income for the quarter ended September 30, 2019 was $6,753 compared to $6,994 during the third quarter of 2018. The decrease in interest incomeis primarily attributable to substantially decreased amounts of funds available for investment. Total expenses during the third quarter of 2019 amounted to $118,549 compared to $186,501 during the third quarter of 2018. The decrease in totalexpenses can be primarily attributed to decreased expense for professional services and the timing of payment of expenses. 

 
15 

These transactions resulted in distributable income for the quarter ended September 30, 2019 of$5,948,476 or $0.13 per Unit of beneficial interest. Distributions of $0.044227, $0.043387 and $0.040012 per Unit were made to Unit holders of record as of July 31, 2019, August 31, 2019, and September 30, 2019, respectively. For thethird quarter of 2018, distributable income was $7,056,843****or $0.15****per Unit of beneficial interest. 

Royalty income for the Trust for thethird quarter of the calendar year is associated with actual oil and gas production for the period of May, June and July 2019 from the properties from which the Trust’s net overriding royalty interests (“Royalties”) were carved. Oiland gas sales attributable to the Royalties and the properties from which the Royalties were carved are as follows: 

 
   **Third Quarter**    **2019**   **2018** 
**Royalties:**
    
Oil sales (Bbls)
   104,258    101,892 
Gas sales (Mcf)
   310,106    329,291 
**Properties From Which The Royalties Were Carved:**
    
Oil:
    
Total oil sales (Bbls)
   228,405    214,069 
Average per day (Bbls)
   2,510    2,327 
Average price per Bbl
  $54.30   $60.19 
Gas:
    
Total gas sales (Mcf)
   893,060    969,476 
Average per day (Mcf)
   9,814    10,538 
Average price per Mcf
  $1.82   $3.64 
The average received price of oil decreased to an average price per barrel of $54.30 per Bbl in the third quarter of 2019,compared to $60.19 per Bbl in the third quarter of 2018 due to worldwide market variables. The Trustee has been advised by ConocoPhillips that for the period of August 1, 1993, through September 30, 2019, the oil from the Waddell Ranchproperties was being sold under a competitive bid to a third party. The average price of gas (including natural gas liquids) decreased from $3.64 per Mcf in the third quarter of 2018 to $1.82 per Mcf in the third quarter of 2019 due to change inoverall market variables. 

 
16 

Since the oil and gas sales attributable to the Royalties are based on an allocation formula that isdependent on such factors as price and cost (including capital expenditures), the production amounts in the Royalties section of the above table do not provide a meaningful comparison. Oil sales volumes increased and gas sales volumes increased fromthe Underlying Properties (as defined in the Trust’s Annual Report on Form 10-K for the year ended December 31, 2018) for the applicable period in 2019 compared to 2018. 

Capital expenditures for drilling, remedial and maintenance activities on the Waddell Ranch properties during the third quarter of 2019 totaled $351,706 ascompared to $5,200 for the third quarter of 2018. ConocoPhillips has informed the Trustee that the 2019 capital expenditures budget has been approved at $6.6 million (gross) for the Waddell Ranch properties. The total amount of capitalexpenditures for 2018 with regard to the Waddell Ranch properties totaled $4.3 million (gross). 

The Trustee has been advised that there were 0workover wells completed, 0 new wells completed, 0 new wells in progress and 0 workover wells in progress during the three months ended September 30, 2019, as compared to 0 workover wells completed, 0 new wells completed, 0 new wells inprogress and 0 workover wells in progress for the three months ended September 30, 2018, on the Waddell Ranch properties. There were various facility projects in progress for the third quarter of 2019. 

Lease operating expenses and property taxes totaled $5.538 million (gross) for the third quarter of 2019, compared to $6.75 million (gross) for thesame period in 2018 on the Waddell Ranch properties due to decreased maintenance work. 

**Nine Months Ended September 30, 2019 Compared to NineMonths Ended September 30, 2018**

For the nine months ended September 30, 2019, royalty income received by the Trust amounted to$15,357,784****compared to royalty income of $24,578,777****for the nine months ended September 30, 2018. The decrease in royalty income is primarily attributable to a decrease in oil and gas pricing and a decrease in production of oiland gas for the nine months ending September 30, 2019, as compared to the nine months ended September 30, 2018. Average oil and gas prices were $51.25 and $2.68 for the nine months ending September 30, 2019 compared to $59.11 and$3.51****for the nine months ended September 30, 2018. 

Interest income for the nine months ended September 30, 2019, was $18,174 comparedto $19,224 during the nine months ended September 30, 2018. The decrease in interest income is primarily attributable to decreased funds available to invest. Total expenses during the nine months ending September 30, 2019, amounted to$876,098 compared to $1,181,813 during the nine months ended September 30, 2018. The decrease in total expenses can be primarily attributed to decreased expense for professional services and the timing of payment of expenses. 

 
17 

These transactions resulted in distributable income for the nine months ended September 30, 2019 of$14,499,860, or $0.31****per Unit. For the nine months ended September 30, 2018, distributable income was $23,416,188, or $0.50 per Unit. 

Royalty income for the Trust for the nine months ended September 30, 2019, is associated with actual oil and gas production for the period November 2018through July 2019 from the properties from which the Royalties were carved. Oil and gas production attributable to the Royalties and the properties from which the Royalties were carved are as follows: 

 
   **Nine Months Ended**    **2019**   **2018** 
**Royalties:**
    
Oil sales (Bbls)
   296,923    354,843 
Gas sales (Mcf)
   723,334    1,204,229 
**Properties From Which The Royalties Were Carved:**
    
Oil:
    
Total oil sales (Bbls)
   652,868    673,710 
Average per day (Bbls)
   2,400    2,450 
Average price per Bbl
  $51.25   $59.11 
Gas:
    
Total gas sales (Mcf)
   2,783,177    2,976,747 
Average per day (Mcf)
   10,232    10,825 
Average price per Mcf
  $2.68   $3.51 
The average received price of oil decreased****during the nine months ended September 30, 2019 to $51.25 per barrelcompared to $59.11 per barrel for the same period in 2018 due to worldwide market variables. The decrease in the average price of gas (including natural gas liquids) from $3.51****per Mcf for the nine months ended September 30, 2018, to$2.68****per Mcf for the nine months ended September 30, 2019 due to change in overall market variables. 

Since the oil and gas salesattributable to the Royalties are based on an allocation formula that is dependent on such factors as price and cost (including capital expenditures), the production amounts in the Royalties section of the above table do not provide a meaningfulcomparison. Both oil and gas sales volumes from the properties from which the Royalties are carved have decreased for the applicable period of 2019 compared to 2018. 

 
18 

Capital expenditures for drilling, remedial and maintenance activities on the Waddell Ranch properties forthe nine months ended September 30, 2019 totaled $2.9**** million (gross) compared to $0.6 million (gross) to the Trust for the same period in 2018. ConocoPhillips has previously advised the Trust that the 2019 capital expendituresbudget for the Waddell Ranch properties is $6.6 million (gross). 

The Trustee has been advised that 1 workover wells were completed and 2 new wellswere completed (2 vertical, 0 horizontal) on the Waddell Ranch properties during the nine months ended September 30, 2019, as compared to 0 workover wells completed and 0 new wells completed on the Waddell Ranch properties during the ninemonths ended September 30, 2018. There were various facility projects in progress for the third quarter of 2019. 

Lease operating expenses andproperty taxes totaled $17.6 million for the nine months ended September 30, 2019, compared to $17.5 million for the same period in 2018. The increase in lease operating expense is primarily attributable to increased spending onfacilities and maintenance. 

**Calculation of Royalty Income**

The Trust’s royalty income is computed as a percentage of the net profit from the operation of the properties in which the Trust owns net overridingroyalty interests. These percentages of net profits are 75% and 95% in the case of the Waddell Ranch properties and the Texas Royalty properties, respectively. Royalty income received by the Trust for the three months ended September 30, 2019and 2018, respectively, were computed as shown in the table below: 

 
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   **THREE MONTHS ENDED SEPTEMBER 30**    **2019**  **2018**    **WADDELL****RANCH****PROPERTIES**  **TEXAS****ROYALTY****PROPERTIES**  **WADDELL****RANCH****PROPERTIES**  **TEXAS****ROYALTY****PROPERTIES** 
Gross proceeds of sales from the Underlying Properties
     
Oil proceeds
  $8,851,639  $3,549,758  $8,783,168  $4,100,713 
Gas proceeds
   1,375,269   269,135   2,952,887   452,202 
Other (adjustment)
   —     —     67,244   —     
 

 
  
 

 
  
 

 
  
 

 
 
Total
   10,226,908   3,818,893   11,803,299   4,552,915   
 

 
  
 

 
  
 

 
  
 

 
 
Less:
     
Severance tax:
     
Oil
   407,389   130,566   396,372   134,987 
Gas
   53,067   9,878   110,358   25,973 
Lease operating expense and property tax:
     
Oil and gas
   5,537,750   360,000   6,750,047   360,000 
Capital expenditures
   351,707   —     5,198   —     
 

 
  
 

 
  
 

 
  
 

 
 
Total
   6,349,913   500,444   7,261,975   520,960   
 

 
  
 

 
  
 

 
  
 

 
 
Net profits
   3,876,995   3,318,449   4,541,324   4,031,955 
Net overriding royalty interests
   75%   95%   75%   95%   
 

 
  
 

 
  
 

 
  
 

 
 
Royalty income
  $2,907,746   3,152,526  $3,405,993   3,830,357   
 

 
  
 

 
  
 

 
  
 

 
 
 
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**Critical Accounting Policies and Estimates**

A disclosure of critical accounting policies and the more significant judgments and estimates used in the preparation of the Trust’s financial statementsis included in Item 7 of the Trust’s Annual Report on Form 10-K for the year ended December 31, 2018. There have been no significant changes to the critical accounting policies during the nine monthsended September 30, 2019. 

***Distributable Income Per Unit***

Basic distributable income per Unit is computed by dividing distributable income by the weighted average of Units outstanding. Distributable income per Unitassuming dilution is computed by dividing distributable income by the weighted average number of Units and equivalent Units outstanding. The Trust had no equivalent Units outstanding for any period presented. Therefore, basic distributable incomeper Unit and distributable income per Unit assuming dilution are the same. 

*New Accounting Pronouncements*

There are no new accounting pronouncements that are expected to have significant impact on the Trust’s financial statements. 

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

Not applicable due to the Trust’s status as a smaller reporting company. 

 
**Item 4.**
**Controls and Procedures**

On May 14, 2013, the Committee of Sponsoring Organizations of the Treadway Commission issued an updated version of its Internal Control – IntegratedFramework (the “2013 Framework”) which helps organizations design, implement and evaluate the effectiveness of internal control concepts and simplify their use and application. As of the end of the period covered by this report, theTrustee carried out an evaluation of the effectiveness of the design and operation of the Trust’s disclosure controls and procedures pursuant to Exchange Act Rules 13a-15 and 15d-15 based on the criteria established in the 2013 Framework. Based upon that evaluation, the Trustee concluded that the Trust’s disclosure controls and procedures are effective in recording, processing,summarizing and reporting, on a timely basis, information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 and are effective in ensuring that information required to be disclosedby the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 is accumulated and communicated to the Trustee to allow timely decisions regarding required disclosure. In its evaluation of disclosure controls andprocedures, the Trustee has relied, to the extent considered reasonable, on information provided by Burlington Resources Oil & Gas Company LP, the owner of the Waddell Ranch properties, and Riverhill Energy Corporation, the owner of theTexas Royalty properties. There has not been any change in the Trust’s internal control over financial reporting during the period covered by this report that has materially affected, or is reasonably likely to materially affect, theTrust’s internal control over financial reporting. 

 
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**PART II—OTHER INFORMATION**

 
**Item 1A.**
**Risk Factors**

Risk factors relating to the Trust are contained in Item 1A of the Trust’s Annual Report on Form 10-K for thefiscal year ended December 31, 2018. No material change to such risk factors has occurred during the nine months ended September 30, 2019. 

**Items 2 through 5.**

Not applicable. 

 
**Item 6.**
**Exhibits**

 
4.1
Permian Basin Amended and Restated Royalty Trust Indenture dated June 20, 2014, between Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) and The First National Bank of Fort Worth (now Simmons Bank), as Trustee,heretofore filed as Exhibit 4.1 to the Trust’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarterly period ended June 30, 2014, is incorporated herein byreference. *

 
4.2
Net Overriding Royalty Conveyance (Permian Basin Royalty Trust) from Southland Royalty Company (now BurlingtonResources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Simmons 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 to the Securities and Exchange Commission for the fiscal year ended December 31, 1980, is incorporated herein by reference. * (P) 

 
4.3
Net Overriding Royalty Conveyance (Permian Basin Royalty Trust) from Southland Royalty Company (now BurlingtonResources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Simmons 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 to the Securities and Exchange Commission for the fiscal year ended December 31, 1980, is incorporated herein by reference. * (P) 

 
10.1
Registration Rights Agreement dated as of July 21, 2004, by and between Burlington Resources Inc. and Bank of America, N.A., as trustee of Permian Basin Royalty Trust, heretofore filed as Exhibit 10.1 to the Trust’s Quarterly Report on Form 10-Q to the Securities and Exchange Commission for the quarterly period ended June 30, 2004, is incorporated herein by reference. * 

 
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10.2
Underwriting Agreement dated December 15, 2005, among the Permian Basin Royalty Trust, Burlington Resources, Inc., Burlington Resources Oil & Gas L.P. and Lehman Brothers Inc. and Wachovia Capital Markets, LLC as representatives of the severalunderwriters, heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed on December 19, 2005, is incorporated herein byreference. *

 
10.3
Underwriting Agreement dated August 2, 2005, among the Permian Basin Royalty Trust, Burlington Resources, Inc., Burlington Resources Oil & Gas L.P. and Goldman Sachs & Co. and Lehman Brothers Inc. as representatives of theseveral underwriters, heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed on August 8, 2005, is incorporated herein byreference. *

 
10.4
Underwriting Agreement dated August 17, 2006, among Permian Basin Royalty Trust, ConocoPhillips, Burlington Resources Oil & Gas Company LP and Lehman Brothers Inc. and Wachovia Capital Markets, LLC as representatives of the severalunderwriters heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed on August 22, 2006, is incorporated herein by reference.*

 
31.1
Certification by Ron E. Hooper, Senior Vice President Royalty Trust Management of Simmons Bank, Trustee of Permian Basin Royalty Trust, dated November 12, 2019 and submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302 of theSarbanes-Oxley Act of 2002. 

 
32.1
Certificate by Simmons Bank, Trustee of Permian Basin Royalty Trust, dated November 12, 2019 and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350). 

 
*
A copy of this Exhibit is available to any Unit holder, at the actual cost of reproduction, upon writtenrequest to the Trustee, Simmons Bank, 2911 Turtle Creek Boulevard, Suite 850, Dallas, Texas 75219. 

(P) Paper exhibits. 

 
23 

**SIGNATURES**

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this Report to be signed on its behalf by the undersignedthereunto duly authorized. 

 

**SIMMONS BANK,**

TRUSTEE FORTHE

PERMIAN BASIN ROYALTY TRUST
By: /s/ RON E. HOOPER Ron E. Hooper SVP Royalty Trust Management
Date: November 12, 2019 

(The Trust has no directors or executive officers.) 

 

 
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