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, 2018  ☐
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 ofIncorporation or Organization)

(I.R.S. EmployerIdentification No.)  Royalty Trust Management Simmons Bank 2911 Turtle
Creek Boulevard Suite 850 Dallas, Texas 75219 (Address of Principal Executive Offices; Zip Code) (855) 588-7839 (Registrants Telephone Number, Including Area Code)   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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter)
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, a
non-accelerated filer, 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

☐  (Do not check if a smaller reporting company)

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 Exchange
Act).    Yes  ☐    No  ☒ Number of Units of beneficial interest
of the Trust outstanding at August 1, 2018: 46,608,796.




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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 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 information presented 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 Permian Basin Royalty Trust at
June 30, 2018, the distributable income for the three-month and six-month periods ended June 30, 2018 and 2017 and the changes in trust corpus for the
six-month periods ended June 30, 2018 and 2017, have been included. The distributable income for such interim periods is not necessarily indicative of the distributable income for the full year. The condensed interim financial statements as of June 30, 2018 and for the three-month and six-month periods
ended June 30, 2018 and 2017, 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.  1




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REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM To the Unit Holders of Permian Basin Royalty Trust and Simmons
Bank, Trustee Dallas, Texas Results of Review of
Interim Financial Statements We have reviewed the accompanying condensed statement of assets, liabilities and trust corpus of Permian Basin Royalty
Trust (the Trust) as of June 30, 2018 and the related condensed statements of distributable income for the three-month and six-month periods ended June 30, 2018 and 2017 and changes in
trust corpus for the six-month periods ended June 30, 2018 and 2017, and the related notes (collective 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 accompanying condensed 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 of accounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United
States of America. 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 Public Company Accounting Oversight Board (United States) (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 an audit 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. We have served as the
Trusts auditor since 2016. Dallas, TX August 9,
2018  2




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PERMIAN BASIN ROYALTY TRUST CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS  June 30,2018(Unaudited)


December 31,2017ASSETSCash and short-term investments

$
3,104,519


$
3,421,419Net overriding royalty interests in producing oil and gas properties (net of accumulated
amortization of $10,479,889and $10,446,173 at June 30, 2018 and December 31, 2017, respectively)


495,327



529,043TOTAL ASSETS

$
3,599,846


$
3,950,462LIABILITIES AND TRUST CORPUSDistribution payable to Unit holders

$
2,054,519


$
2,371,419Commitments and reserves for contingencies (Note 6)


1,050,000



1,050,000Trust corpus  46,608,796 Units of beneficial interest authorized and outstanding


495,327



529,043TOTAL LIABILITIES AND TRUST CORPUS

$
3,599,846


$
3,950,462 The accompanying notes are an integral part of these condensed financial statements.  3




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PERMIAN BASIN ROYALTY TRUST CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)  THREE MONTHS ENDEDJune 30, 2018


THREE MONTHS ENDEDJune 30, 2017Royalty income

$
7,623,122


$
7,473,738Interest income


6,754



3,0567,629,876



7,476,794General and administrative expenditures


(581,462
)


(504,997
)Distributable income

$
7,048,414


$
6,971,797Distributable income per Unit (46,608,796 Units)

$
.15


$
.15 The accompanying notes are an integral part of these condensed financial statements.  4




---

PERMIAN BASIN ROYALTY TRUST CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)  SIX MONTHS ENDEDJune 30, 2018


SIX MONTHS ENDEDJune 30, 2017Royalty income

$
17,342,427


$
17,025,961Interest income


12,230



5,33817,354,657



17,031,299General and administrative expenditures


(995,312
)


(870,454
)Distributable income

$
16,359,345


$
16,160,845Distributable income per Unit (46,608,796 Units)

$
.35


$
.35 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)  SIX MONTHS ENDEDJune 30, 2018


SIX MONTHS ENDEDJune 30, 2017Trust corpus, beginning of period

$
529,043


$
603,119Amortization of net overriding royalty interests


(33,716
)


(37,072
)Distributable income


16,359,345



16,160,845Distributions declared


(16,359,345
)


(16,160,845
)Total Trust Corpus, end of period

$
495,327


$
566,047Distributions per Unit

$
.35


$
.35 The accompanying notes are an integral part of these condensed financial statements.  6




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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 Trustee
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 Ranch
properties) 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 Royalty
properties 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 of
Southland 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 Waddell
Ranch 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 the
accounting operations for the Texas Royalty properties. In February 1997, BROG sold its interest in the Texas Royalty properties to
Riverhill 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 acquisition
of 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 ownership
of which was acquired by the former shareholders of Riverhill Capital.  7




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On January 9, 2014, Bank of America N.A. (as successor to The First National Bank of
Fort 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 Unit
holders 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 America
N.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 of
First 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 refer
to 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 than
those 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 Units
outstanding 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 in
amount;  

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 The
financial 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 the
interest 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 charges
and 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.  8




---



Trust expenses, consisting principally of routine general and administrative costs, recorded are based on
liabilities 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 the
Trust. 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 of
that conveyance. The financial statements of the Trust differ from financial statements prepared in accordance with
accounting 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 contingencies
which would not be accrued in financial statements prepared in accordance with GAAP. Amortization of the Royalties calculated on a unit-of-production basis is charged
directly 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 and
assumptions 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.  9




---

Contingencies Contingencies related to the underlying properties 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. 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 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, basic distributable income per Unit and distributable income per Unit assuming dilution are the same. New
Accounting Pronouncements In May 2014, the FASB issued updated guidance for recognizing revenue from contracts with customers. This
update amends the existing accounting standards for revenue recognition and is based on the principle that revenue should be recognized to depict the transfer of goods and services to a customer at an amount that reflects the consideration a company
expects to receive in exchange for those goods or services. The Trust adopted this standards update, as required, in the first quarter of 2018, but the adoption of this standard did not have a significant impact on its financial statements due to
the modified cash basis of reporting used by the Trust.  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 Monthly
Distribution 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 sum
of  10




---

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 receive the 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 of
production 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 Texas
Royalty properties.  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 not
subject 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 or
accrued 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 a
rate 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 limited
liability 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-operated
mineral 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 be
exempt from Texas franchise  11




---

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 be required 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 place of 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 to
future royalty income payments to the Trust with corresponding reductions to cash distributions to Unit holders.  7.
SUBSEQUENT EVENTS Subsequent to June 30, 2018, the Trust declared a distribution on July 20, 2018 of $0.057454 per Unit payable on August 14, 2018
to Unit holders of record on July 31, 2018. *    *    *    *    *  12




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Item 2.
Trustees Discussion and Analysis Forward Looking Information Certain information included
in 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 contain
or 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 in
such 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s
control, 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 of
petroleum-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 June 30, 2018 Compared to Three Months Ended June 30, 2017 For the quarter ended June 30, 2018, royalty income received by the Trust amounted to $7,623,122 compared to royalty income of $7,473,738 during the
second quarter of 2017. The increase in royalty income is primarily attributable to a decrease in oil and gas production offset by an increase in price of oil for the quarter ending June 30, 2018, as compared to the quarter ended June 30,
2017. Average oil and gas prices were $60.94 and $3.12 for the quarter ending June 30, 2018, compared to $47.14 and $3.13 for the quarter ended June 30, 2017. Interest income for the quarter ended June 30, 2018, was $6,754 compared to $3,056 during the second quarter of 2017. The increase in interest income is
primarily attributable to substantially increased amounts of funds available for investment. Total expenses during the second quarter of 2018 amounted to $581,462compared to $504,997 during the second quarter of 2017. The increase in total
expenses can be primarily attributed to increased expense for professional services. These transactions resulted in distributable income for the quarter
ended June 30, 2018, of $7,048,414 or $0.15 per Unit of beneficial interest. Distributions of $0.052172, $0.054973 and $0.044080 per Unit were made to Unit holders of record as of April 30, 2018, May 31, 2018, and June 29, 2018,
respectively. For the second quarter of 2017, distributable income was $6,971,797 or $0.15 per Unit of beneficial interest.  13




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Royalty income for the Trust for the second quarter of the calendar year is associated with actual oil and
gas production for the period of February, March and April 2018 from the properties from which the Trusts net overriding royalty interests (Royalties) were carved. Oil and gas sales attributable to the Royalties and the properties
from which the Royalties were carved are as follows:  Second Quarter2018


2017Royalties:Oil sales (Bbls)


109,771



138,456Gas sales (Mcf)


363,560



490,380Properties From Which The Royalties Were Carved:Oil:Total oil sales (Bbls)


223,399



238,581Average per day (Bbls)


2,454



2,651Average price per Bbl

$
60.94


$
47.14Gas:Total gas sales (Mcf)


973,980



1,057,527Average per day (Mcf)


10,703



11,570Average price per Mcf

$
3.12


$
3.13 The average received price of oil increased to an average price per barrel of $60.94 per Bbl in the second quarter of 2018,
compared to $47.14 per Bbl in the second quarter of 2017 due to worldwide market variables. The Trustee has been advised by ConocoPhillips that for the period of August 1, 1993, through June 30, 2018, the oil from the Waddell Ranch
properties was being sold under a competitive bid to a third party. The average price of gas (including natural gas liquids) decreased from $3.13 per Mcf in the second quarter of 2017 to $3.12 per Mcf in the second quarter of 2018 due to change in
overall market variables. Since the oil and gas sales attributable 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 meaningful comparison. Oil sales volumes decreased and gas sales volumes decreased from the Underlying Properties
(as defined in the Trusts Annual Report on Form 10-K for the year ended December 31, 2017) for the applicable period in 2018 compared to 2017.  14




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Capital expenditures for drilling, remedial and maintenance activities on the Waddell Ranch properties
during the second quarter of 2018 totaled $167,801 as compared to $517,000 for the second quarter of 2017. ConocoPhillips has informed the Trustee that the 2018 capital expenditures budget has been approved at $4.3 million (gross) for the
Waddell Ranch properties. The total amount of capital expenditures for 2017 with regard to the Waddell Ranch properties totaled $3.2 million (gross). The Trustee has been advised that there were 2 workover wells completed, 0 new wells completed, 0 new wells in progress and 0 workover wells in progress
during the three months ended June 30, 2018, as compared to 0 workover wells completed, 0 new wells completed, 0 new wells in progress and 0 workover wells in progress for the three months ended June 30, 2017, on the Waddell Ranch
properties. There were various facility projects in progress for the second quarter of 2018. Lease operating expenses and property taxes totaled
$6.3 million (gross) for the second quarter of 2018, compared to $4.0 million (gross) for the same period in 2017 on the Waddell Ranch properties due to increased maintenance work. Six Months Ended June 30, 2018 Compared to Six Months Ended June 30, 2017 For the six months ended June 30, 2018, royalty income received by the Trust amounted to $17,342,427compared to royalty income of $17,025,961 for
the six months ended June 30, 2017. The increase in royalty income is primarily attributable to a reduction of capital expenditures by the operator and an increase in oil and gas prices for the six months ending June 30, 2018, as compared
to the six months ended June 30, 2017. Average oil and gas prices were $58.60 and $3.49 for the six months ending June 30, 2018 compared to $46.69 and $3.15 for the six months ended June 30, 2017. Interest income for the six months ended June 30, 2018, was $12,230 compared to $5,338 during the six months ended June 30, 2017. The increase in
interest income is primarily attributable to substantially increased amounts of funds available for investment. Total expenses during the six months ending June 30, 2018, amounted to $995,312compared to $870,454 during the six months
ended June 30, 2017. The increase in total expenses can be primarily attributed to increased expense for professional services. These transactions
resulted in distributable income for the six months ended June 30, 2018 of $16,359,345, or $0.35 per Unit. For the six months ended June 30, 2017, distributable income was $16,160,845, or $0.35 per Unit.  15




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Royalty income for the Trust for the six months ended June 30, 2018, is associated with actual oil and
gas production for the period November 2017 through April 2018 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:  Six Months Ended2018


2017Royalties:Oil sales (Bbls)


252,951



298,085Gas sales (Mcf)


874,938



1,100,970Properties From Which The Royalties Were Carved:Oil:Total oil sales (Bbls)


459,641



484,516Average per day (Bbls)


2,512



2,662Average price per Bbl

$
58.60


$
46.69Gas:Total gas sales (Mcf)


2,007,271



2,154,632Average per day (Mcf)


10,969



11,839Average price per Mcf

$
3.49


$
3.15 The average received price of oil increased during the six months ended June 30, 2018 to $58.60 per barrel compared to
$46.69 per barrel for the same period in 2017. The increase in the average price of oil is primarily due to worldwide market variables. The increase in the average price of gas (including natural gas liquids) from $3.15 per Mcf for the six months
ended June 30, 2017, to $3.49 per Mcf for the six months ended June 30, 2018, is primarily the result of a change in overall market variables. Since the oil and gas sales volumes attributable 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 meaningful comparison. Both oil and gas sales volumes from the properties from which the Royalties are carved have increased for
the applicable period of 2018 compared to 2017. Capital expenditures for the Waddell Ranch properties for the six months ended June 30, 2018 totaled
$0.6 million (gross) compared to $0.7 million (gross) to the Trust for the same period in 2017. ConocoPhillips has previously advised the Trust that the 2018 capital expenditures budget for the Waddell Ranch properties is
$4.3 million (gross).  16




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The Trustee has been advised that 3 workover wells were completed and 0 new wells were completed (0
vertical, 0 horizontal) on the Waddell Ranch properties during the six months ended June 30, 2018, as compared to 0 workover wells completed and 0 new wells completed on the Waddell Ranch properties during the six months ended June 30,
2017. There were various facility projects in progress for the second quarter of 2018. Lease operating expenses and property taxes totaled
$10.8 million for the six months ended June 30, 2018, compared to $6.8 million for the same period in 2017. The increase in lease operating expense is primarily attributable to increased spending on facilities 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 overriding royalty 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 June 30, 2018 and 2017, respectively, were computed as shown in the table below:  17




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THREE MONTHS ENDED JUNE 302018


2017WADDELLRANCHPROPERTIES


TEXASROYALTYPROPERTIES


WADDELLRANCHPROPERTIES


TEXASROYALTYPROPERTIESGross proceeds of sales from the Underlying PropertiesOil proceeds

$
9,610,039


$
4,005,358


$
7,907,442


$
3,338,381Gas proceeds


2,641,768



433,499



2,936,656



373,683Other (adjustment)














Total


12,251,807



4,438,857



10,844,098



3,712,064Less:Severance tax:Oil


427,083



156,060



350,889



99,586Gas


91,129



22,554



80,782



18,917Other














Lease operating expense and property tax:Oil and gas


6,341,939



360,000



4,016,370



375,000Capital expenditures


167,801







516,972



Total


7,027,952



538,614



4,965,013



493,503Net profits


5,223,855



3,900,243



5,879,084



3,218,561Net overriding royalty interests


75
%


95
%


75
%


95
%Royalty income

$
3,917,891



3,705,231


$
4,409,313



3,057,633 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 statements
is included in Item 7 of the Trusts Annual Report on Form 10-K for the year ended December 31, 2017. There have been no significant changes to the critical accounting policies during the six months
ended June 30, 2018.  18




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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 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, basic distributable income
per Unit and distributable income per Unit assuming dilution are the same. New Accounting Pronouncements In May 2014, the FASB issued updated guidance for recognizing revenue from contracts with customers. This update amends the existing accounting standards for
revenue recognition and is based on the principle that revenue should be recognized to depict the transfer of goods and services to a customer at an amount that reflects the consideration a company expects to receive in exchange for those goods or
services. The Trust adopted this standards update, as required, in the first quarter of 2018, but the adoption of this standard did not have a significant impact on its financial statements due to the modified cash basis of reporting used by the
Trust.  Item 3.
Qualitative and Quantitative Disclosures About Market Risk There have been no material changes in the Trusts market risk, as disclosed in the Trusts Annual Report on Form
10-K for the fiscal year ended December 31, 2017.  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  Integrated
Framework (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, the
Trustee 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 disclosed
by the Trust  19




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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 and procedures, 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 the Texas 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, the Trusts internal control over financial reporting.  20




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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 the
fiscal year ended December 31, 2017. No material change to such risk factors has occurred during the six months ended June 30, 2018. 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 by reference. *4.2

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 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 Burlington Resources 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)  21




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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. *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 on
August 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 Management of Simmons Bank, Trustee of Permian Basin Royalty Trust, dated August 9, 2018 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 Simmons Bank, Trustee of Permian Basin Royalty Trust, dated August 9, 2018 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 written
request to the Trustee, Simmons Bank, 2911 Turtle Creek Boulevard, Suite 850, Dallas, Texas 75219. (P) Paper exhibits.  22




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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 undersigned
thereunto duly authorized.  SIMMONS BANK,TRUSTEE FOR THEPERMIAN BASIN ROYALTY TRUSTBy:

/s/ RON E. HOOPERRon E. HooperSVP Royalty Trust Management
 Date: August 9, 2018 (The Trust has no directors or executive officers.)  23