**
 

 

**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 March 31, 2023**

 
****☐********
**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.)**

**Argent Trust Company**

**2911 Turtle Creek Boulevard**

**Suite 850**

**Dallas, Texas75219**

**(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)**

 

 

**Securitiesregistered pursuant to 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 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 90days.    Yes  ☒    No  ☐ 

Indicate by check mark whether the registrant hassubmitted 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 such shorter periodthat 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, a non-acceleratedfiler, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” 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 extended transition periodfor 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 ExchangeAct).    Yes  ☐    No  ☒ 

Number of Units of beneficial interest of the Trustoutstanding at May 1, 2023: 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 Argent Trust Company 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 December 30, 2022, Argent Trust Company (the “Trustee”) became the new trustee for the Trust. Certaininformation and footnote disclosures normally included in annual financial statements have been condensed or omitted pursuant to such rules and regulations, although the Trustee believes that the disclosures are adequate to make the informationpresented not misleading. It is 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 Form 10-K. In the opinion of the Trustee, all adjustments, consisting only of normal recurring adjustments, necessary to present fairly the assets, liabilities and trust corpus of the Trust as of March 31, 2023, andthe distributable income and the changes in trust corpus for the three-month period ended March 31, 2023 and 2022, have been included. The distributable income for such interim periods is not necessarily indicative of the distributable incomefor the full year. Unless specified otherwise, all amounts included herein are presented in US dollars. 

The condensed interim financial statements as ofMarch 31, 2023 and for the three-month periods ended March 31, 2023 and 2022, 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**

To the Unit Holders of Permian Basin Royalty Trust and 

ArgentTrust Company, Trustee 

Dallas, Texas 

**Results of Reviewof Interim Financial Statements**

We have reviewed the accompanying condensed statements of assets, liabilities and trust corpus of Permian BasinRoyalty Trust (the Trust) as of March 31, 2023, and the related condensed statements of distributable income and changes in trust corpus for the three-month periods ended March 31, 2023 and 2022, andthe related notes (collectively referred to as the “condensed interim financial statements or interim financial information”). Based on our reviews, 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 basisof accounting, 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, 2022, 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 1, 2023 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, 2022, is fairly stated, in all material respects, in relation to the statement of assets, liabilities, and trust corpusfrom which it has been derived. 

**Basis for Review Results**

These condensed interim financial statements are the responsibility of the Trustee. We conducted our reviews 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 ofpersons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the PCAOB, the objective of which is the expression of an opinion regarding the financialstatements taken as a whole. Accordingly, we do not express such an opinion. 

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

Dallas, Texas 

May 10, 2023 

 
3 

PERMIAN BASIN ROYALTY TRUST 

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

 
   March 31,2023(Unaudited)   December 31,2022 
ASSETS
    
Cash and short-term investments
  $2,199,132   $2,855,444 
Net overriding royalty interests in producing oil and gas properties (net of accumulatedamortization of $10,735,783 and $10,695,783 at March 31, 2023 and December 31, 2022, respectively)
   239,433    279,433   
 

 
   
 

 
 
TOTAL ASSETS
  $2,438,565   $3,134,877   
 

 
   
 

 
 
LIABILITIES AND TRUST CORPUS
    
Distribution payable to Unit holders
  $1,099,132   $1,755,444 
Commitments and reserves for contingencies (Note 6)
   1,100,000    1,100,000 
Trust corpus – 46,608,796 Units of beneficial interest authorized and outstanding
   239,433    279,433   
 

 
   
 

 
 
TOTAL LIABILITIES AND TRUST CORPUS
  $2,438,565   $3,134,877   
 

 
   
 

 
 
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 ENDEDMarch 31, 2023  THREE MONTHS ENDEDMarch 31, 2022 
Royalty income
  $5,206,602  $4,078,645 
Interest income
   14,107   1,233   
 

 
  
 

 
    5,220,709   4,079,878 
General and administrative expenditures
   (480,094)   (345,184)   
 

 
  
 

 
 
Distributable income
  $4,740,615  $3,734,694   
 

 
  
 

 
 
Distributable income per Unit (46,608,796 Units)
  $.10  $.08   
 

 
  
 

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

 
5 

**PERMIAN BASIN ROYALTY TRUST**

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

 
   THREE MONTHS ENDEDMarch 31, 2023  THREE MONTHS ENDEDMarch 31, 2022 
Trust corpus, beginning of period
  $279,433  $352,688 
Amortization of net overriding royalty interests
   (40,000)   (16,143) 
Distributable income
   4,740,615   3,734,694 
Distributions declared
   (4,740,615)   (3,734,694)   
 

 
  
 

 
 
Total Trust Corpus, end of period
  $239,433  $336,545   
 

 
  
 

 
 
Distributions per Unit
  $ .10  $ .08   
 

 
  
 

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

 
6 

**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. Argent Trust Company (“Trustee”) isTrustee for 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, was 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. In February 1997, BROG sold its interest in the Texas Royalty properties to Riverhill Energy. Riverhill Energy currently conducts all field, technical and accountingoperations for the Texas Royalty Properties. BROG notified the Trust that on November 1, 2019, the Waddell Ranch properties that are subject to the Net Overriding Royalty Conveyance (Permian Basin Royalty Trust — Waddell Ranch) datedNovember 1, 1980, were sold to Blackbeard Operating, LLC (“Blackbeard”) of Fort Worth, Texas. Blackbeard became the operator effective as of April 1, 2020. 

The Trustee was advised that in the first quarter of 1998, Schlumberger Technology Corporation (“STC”) acquired all of the shares ofstock 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 acquisition of Riverhill Capital, theshareholders 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 ownership of which was acquired bythe former shareholders of Riverhill Capital. 

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. 

On November 4, 2021, the Trustee announced that it had entered into an agreement with Argent Trust Company, a Tennessee chartered trustcompany (“Argent”), pursuant to which the Trustee would be resigning as trustee of the Trust and would nominate Argent as successor trustee of the Trust. The effective date of Simmons Bank’s resignation and Argent’s appointmentas successor trustee was December 30, 2022. The defined term “Trustee” as used herein shall refer to Bank of America N.A. for periods prior to August 29, 2014, shall refer to Southwest Bank for periods from August 29, 2014through February 19, 2018, shall refer to Simmons Bank for periods from February 20, 2018 through December 29, 2022, and shall refer to Argent for periods on and after December 30, 2022. 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). 

 
7 

**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. 

 
 • 
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. 

The financial statements of the Trust differ from financial statements prepared in accordance with accounting principles generally accepted inthe 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 contingencies which would not be accrued in financialstatements prepared in accordance with GAAP. Amortization of the Royalties calculated on a unit-of-production basis is charged directly to trust corpus. Thiscomprehensive 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. 

*Distributable IncomePer Unit*

Basic distributable income per Unit is computed by dividing distributable income by the weighted average of Unitsoutstanding. Distributable income 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 periodpresented. Therefore, basic distributable income per Unit and distributable income per Unit assuming dilution are the same. 

*NewAccounting Pronouncements*

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

 
8 

**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. 

 
**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 March 31, 2023, the Trust declared a distribution on April 18, 2023 of $0.026846 per Unit payable on May 12, 2023to Unit holders of record on April 28, 2023. 

*    *    *    *    * 

 
9 

**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. 

**Commodity Prices**

The Trust’s income and monthlydistributions are heavily influenced by commodity prices. Commodity prices may fluctuate widely in response to (i) relatively minor changes in the supply of and demand for oil and natural gas, (ii) market uncertainty and (iii) avariety of additional factors that are beyond the Trustee’s control. Recently, there has been volatility in oil and natural gas prices due in part to significantly decreased demand as a result of the novel coronavirus (“COVID-19”) pandemic, beginning in 2020, followed by increasing prices in 2021, and the first half of 2022. A combination of these factors resulted in the price of oil falling below zero to $(37.63) perbarrel of oil on April 20, 2020, recovering the following day to $10.01 per barrel of oil. As of April 24, 2023, the price of oil was $78.64. It is uncertain how the war in Ukraine, resulting sanctions against Russia, and OPEC productionwill affect oil prices in the coming months. Factors that may impact future commodity prices, including the price of oil and natural gas, include but are not limited to: 

 
 • 
political conditions in major oil producing regions, especially in the Middle East and Russia;

 
 • 
worldwide economic conditions; 

 
 • 
weather conditions; 

 
 • 
trade barriers; 

 
 • 
public health concerns, including the COVID-19 pandemic;

 
 • 
the supply and price of domestic and foreign crude oil or natural gas; 

 
 • 
the level of consumer demand; 

 
 • 
the price and availability of alternative fuels; 

 
 • 
the proximity to, and capacity of, transportation facilities; 

 
 • 
the effect of worldwide energy conservation measures; and 

 
 • 
the nature and extent of governmental regulation and taxation. 

Although the Trustee cannot predict the occurrence of events that may affect future commodity prices or the degree to which these prices will be affected, gasroyalty income for a given period generally relates to production three months prior to the period and crude oil royalty income for a given period generally relates to production two months prior to the period and will generally approximate currentmarket prices in the geographic region of the production at the time of production. When crude oil and natural gas prices decline, the Trust is affected in two ways. First, distributable income from the Royalty Properties is reduced. Second,exploration and development activity by operators on the Royalty Properties may decline as some projects may become uneconomic and are either delayed or eliminated. It is impossible to predict future crude oil and natural gas price movements, andthis reduces the predictability of future cash distributions to Unit holders. 

**Three Months Ended March 31, 2023 Compared to Three Months EndedMarch 31, 2022**

For the quarter ended March 31, 2023, royalty income received by the Trust amounted to $5,206,602 compared to royalty incomeof $4,078,645 during the first quarter of 2022. The increase in royalty income is primarily attributable to an increase in oil and natural gas production and pricing for the quarter ended March 31, 2023. Average oil and gas prices were $77.63and $3.19, respectively, for the quarter ending March 31, 2023 compared to $75.95 and $4.52 for the quarter ended March 31, 2022. 

Interestincome for the quarter ended March 31, 2023, was $14,107 compared to $1,233 during the first quarter of 2022. The increase in interest income is primarily attributable to increased amounts of funds available for investment and rising interestrates. Total expenses during the first quarter of 2023 amounted to $480,094 compared to $345,184 during the first quarter of 2022. The increase in total expenses can be primarily attributed to increased expense for professional services and thetiming of payment of expenses. 

 
10 

These transactions resulted in distributable income for the quarter ended March 31, 2023, of $4,740,615or $.10 per Unit of beneficial interest. Distributions of $0.036797, $0.041356 and $0.023556 per Unit were made to Unit holders of record as of January 31, 2023, February 28, 2023, and March 31, 2023, respectively. For the firstquarter of 2022, distributable income was $3,734,694****or $.08****per Unit of beneficial interest. 

Royalty income for the Trust for the firstquarter of the calendar year is associated with actual oil and gas production for the period of November and December 2022 and January 2023 from the properties from which the Trust’s net overriding royalty interests (“Royalties”) werecarved. Oil and gas sales attributable to the Royalties and the properties from which the Royalties were carved are as follows: 

 
   **First Quarter**    **2023**   **2022** 
**Royalties:**
    
Oil sales (Bbls)
   519,492    377,243 
Gas sales (Mcf)
   2,829,662    2,180,498 
**Properties From Which The Royalties Were Carved:**
    
Oil:
    
Total oil sales (Bbls)
   676,790    488,922 
Average per day (Bbls)
   7,520    5,432 
Average price per Bbl
  $77.63   $75.95 
Gas:
    
Total gas sales (Mcf)
   3,754,816    2,898,454 
Average per day (Mcf)
   41,720    32,205 
Average price per Mcf
  $3.19   $4.52 
The average received price of oil increased to an average price per barrel of $77.63 per Bbl in the first quarter of 2023,compared to $75.95 per Bbl in the first quarter of 2022 due to worldwide market variables. The average price of gas (including natural gas liquids) decreased from $4.52 per Mcf in the first quarter of 2022 to $3.19 per Mcf in the first quarter of2023 due to change in overall market variables. 

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 decreased fromthe Underlying Properties (as defined in the Trust’s Annual Report on Form 10-K for the year ended December 31, 2022) for the applicable period in 2023 compared to 2022.     

Capital expenditures for drilling, remedial and maintenance activities on the Waddell Ranch properties during the first quarter of 2023 totaled$35.2 million as compared to $20.5 million for the first quarter of 2022. Blackbeard has previously informed the Trustee that the proposed 2023 capital expenditures budget will be $96.8 million (net) for the Waddell Ranch properties.The total amount of capital expenditures for 2022 with regard to the Waddell Ranch properties totaled $124 million (gross). 

The Trustee has beenadvised that there were 6.8 workover wells completed, 11.3 new wells completed, 10.9 new wells in progress and 8 workover wells in progress during the three months ended March 31, 2023, as compared to 11.6 workover wells completed, 10.9 newwells completed, 3.4 new wells in progress and 4.1 workover wells in progress for the three months ended March 31, 2022, on the Waddell Ranch properties. There were various facility projects in progress for the first quarter of 2023. 

Lease operating expenses and property taxes totaled $16.4 million (gross) for the first quarter of 2023, compared to $9.5 million (gross) for thesame period in 2022 on the Waddell Ranch properties due to increased maintenance work. 

 
11 

**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. The royalty income received and recorded by the Trust was determined by the operator as noted below. 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 March 31, 2023 and 2022, respectively, were computed as shown in the table below: 

 
   **THREE MONTHS ENDED MARCH 31**    **2023**  **2022**    **WADDELL****RANCH****PROPERTIES**  **TEXAS****ROYALTY****PROPERTIES**  **WADDELL****RANCH****PROPERTIES**  **TEXAS****ROYALTY****PROPERTIES** 
Gross proceeds of sales from the Underlying Properties
     
Oil proceeds
  $48,093,456   4,444,019  $32,878,644  $4,253,792 
Gas proceeds
   11,643,448   348,353   12,789,221   301,957 
Other (adjustments)
   (548,980)(1)   —     (11,497,699)(1)   —     
 

 
  
 

 
  
 

 
  
 

 
 
Total
   60,285,884   4,792,372   34,170,166   4,555,749   
 

 
  
 

 
  
 

 
  
 

 
 
Less:
     
Severance tax:
     
Oil
   2,192,055   178,697   1,475,946   166,135 
Gas
   464,549   18,997   928,438   15,905 
Other
   4,842,697   23,981   1,849,347   —   
Lease operating expense and property tax:
     
Oil and gas
   16,127,065   240,000   9,433,459   80,380 
Capital expenditures
   35,202,932   —     20,482,976   —     
 

 
  
 

 
  
 

 
  
 

 
 
Total
   58,829,298   461,675   34,170,166   262,438   
 

 
  
 

 
  
 

 
  
 

 
 
Net profits
   1,456,586   4,330,697   —     4,293,311 
Net overriding royalty interests
   75%   95%   75%   95%   
 

 
  
 

 
  
 

 
  
 

 
 
Royalty income
  $1,092,440   4,114,162  $—     4,078,645   
 

 
  
 

 
  
 

 
  
 

 
 
 
(1)
Due to the NPI deficit, the Waddell Ranch properties did not contribute to Royalty income for the three monthsended March 31, 2022. Beginning on May 1, 2022, the NPI deficit was fully recovered, therefore the Waddell Ranch properties began contributing to Royalty income from that time until March 2023 when it once again returned to a deficitposition. As of March 31, 2023, the cumulative NPI deficit is $411,735 for the underlying property (at 75%). The NPI deficit must be recovered from future proceeds of the Waddell Ranch properties prior to any other proceeds being paid to theTrust. 

**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, 2022. There have been no significant changes to the critical accounting policies during the threemonths ended March 31, 2023. 

*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. 

 
12 

**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 Blackbeard, the owner of the Waddell Ranch properties, and Riverhill Energy Corporation, the owner of the Texas Royalty properties. There has notbeen 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, the Trust’s internal control over financialreporting. 

 
13 

**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, 2022. Except as set forth in such filing, no material change to such risk factors has occurred during the three months ended March 31, 2023. 

**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 Argent Trust Company), 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 by reference. *  4.2  Amendment No. 1 to the Amended and Restated Royalty Trust Indenture of Permian Basin Royalty Trust, dated May 4, 2022, heretofore filed as Exhibit 4.1 to the Trust’s Form 8-K to the Securities and Exchange Commission filed on May 6, 2022, is incorporated herein by reference. *  4.3  Net Overriding Royalty Conveyance (Permian Basin Royalty Trust) from Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Argent Trust Company), 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 endedDecember 31, 1980, is incorporated herein by reference. * (P) 4.4  Net Overriding Royalty Conveyance (Permian Basin Royalty Trust) from Southland Royalty Company (now Burlington Resources Oil & Gas Company LP) to The First National Bank of Fort Worth (now Argent Trust Company), 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 endedDecember 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 Securitiesand Exchange Commission for the quarterly period ended June 30, 2004 is incorporated herein by reference. * 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 several 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 December 19, 2005, is incorporated herein by reference. * 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 the several underwriters, heretofore filed as Exhibit 10.1 to the Trust’s current report on Form 8-K to the Securities and Exchange Commission filed onAugust 8, 2005, is incorporated herein by reference. * 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 several 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 22, 2006, is incorporated herein by reference. * 31.1  Certification by Ron E. Hooper, Senior Vice President Royalty Trust Services of Argent Trust Company, Trustee of Permian Basin Royalty Trust, dated May 10, 2023 and submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.32.1  Certificate by Argent Trust Company, Trustee of Permian Basin Royalty Trust, dated May 10, 2023 and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section1350).*  A copy of this Exhibit is available to any Unit holder, at the actual cost of reproduction, upon written request to the Trustee, Argent Trust Company, 2911 Turtle Creek Boulevard, Suite 850, Dallas, Texas 75219.(P)  Paper exhibits.
 
14 

**SIGNATURES**

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

 

ARGENT TRUST COMPANY,

TRUSTEE FORTHE

PERMIAN BASIN ROYALTY TRUST

By:
 
/s/ RON E. HOOPER

Ron E. Hooper

SVP Royalty Trust Services

Date: May 10, 2023 

(The Trust has nodirectors or executive officers.) 

 
15