UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form10-Q

(Mark One)

For the quarterly period ended SeptemberJune 30, 20172018

OR

For the transition period from                    to                    .

Commission file number000-08677

Tidelands Royalty Trust “B”

(Exact name of registrant as specified in its charter)

c/o The Corporate Trustee:

SouthwestSimmons Bank

2911 Turtle Creek Blvd.

Dallas, Texas 75219

(Address of principal executive offices)

(Zip Code)

(855)588-7839

(Registrant’s telephone number, including area code)

None

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    Yes  ☒    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 RegulationS-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, anon-accelerated filer, a 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 Rule12b-2 of the Exchange Act. (Check one):

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 Rule12b-2 of the Exchange Act).    Yes  ☐    No   ☒

Indicate the number of units of beneficial interest outstanding as of the latest practicable date:

As of November 1, 2017,August 14, 2018, Tidelands Royalty Trust “B” had 1,386,375 units of beneficial interest outstanding.

TIDELANDS ROYALTY TRUST “B”

INDEX

PART I. FINANCIAL INFORMATION

Item 1.

Financial Statements

TIDELANDS ROYALTY TRUST “B” AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF ASSETS, LIABILITIES

AND TRUST CORPUS

As of SeptemberJune 30, 20172018 and December 31, 20162017

See the accompanying notes to condensed consolidated financial statements.

TIDELANDS ROYALTY TRUST “B” AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF DISTRIBUTABLE INCOME

For the Three and NineSix Months Ended SeptemberJune 30, 20172018 and 20162017

(Unaudited)

See the accompanying notes to condensed consolidated financial statements.

TIDELANDS ROYALTY TRUST “B” AND SUBSIDIARY

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN TRUST CORPUS

For the NineSix Months Ended SeptemberJune 30, 20172018 and 20162017

(Unaudited)

See the accompanying notes to condensed consolidated financial statements.

TIDELANDS ROYALTY TRUST “B” AND SUBSIDIARY

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

SeptemberJune 30, 20172018

(Unaudited)

Note 1. Accounting Policies

The financial statements herein include the financial statements of Tidelands Royalty Trust “B” (the “Trust”) and Tidelands Royalty “B” Corporation, its wholly owned subsidiary (“Tidelands Corporation,” and collectively with the Trust, “Tidelands”). The financial statements are condensed and consolidated and should be read in conjunction with Tidelands’ Annual Report on Form10-K for the year ended December 31, 2016.2017. The financial statements included herein are unaudited, but in the opinion of SouthwestSimmons Bank (the “Trustee”), the Trustee of the Trust, they include all adjustments necessary for a fair presentation of the results of operations for the periods presented. Operating results for the interim periods reported herein are not necessarily indicative of the results that may be expected for the year ending December 31, 2017.2018.

Note 2. Basis of Accounting

The financial statements of Tidelands are prepared on the modified cash basis method and are not intended to present Tideland’s financial position and results of operations in conformity with generally accepted accounting principles in the United States (“GAAP”). Under the modified cash basis method the financial statements of Tidelands differ from financial statements prepared in conformity with GAAP because of the following:

The modified cash basis method of accounting corresponds to the accounting principles permitted for royalty trusts by the U.S. Securities and Exchange Commission (the “SEC”), as specified by Staff Accounting Bulletin Topic 12:E,Financial Statements of Royalty Trusts. Because the Trust’s financial statements are prepared on the modified cash basis, as described above, most accounting pronouncements are not applicable to the Trust’s financial statements, which includes the provision of the new revenue recognition standard in ASU2014-09.

Note 3. Distributable Income

The Trust’s Indenture, as amended (the “Indenture”), provides that the Trustee is to distribute all cash in the Trust, less an amount reserved for payment of accrued liabilities and estimated future expenses, to unitholders of record on the last business day of March, June, September and December of each year. There was no$16,500 and $33,000 estimated reserve for future expenses deducted from calculated distributable income for the three and ninesix months ended SeptemberJune 30, 2017.2018, respectively. Such payments are to be made within 15 days after the record date.

As stated under “Note 1. Accounting Policies” above, the financial statements in this Quarterly Report on Form10-Q are the condensed and consolidated financial statements of the Trust and Tidelands Corporation. However, distributable income is paid from the account balances of the Trust. Distributable income is comprised of (i) royalties from offshore Texas leases owned directly by the Trust, (ii) 95% of the overriding royalties received by Tidelands Corporation from offshore Louisiana leases owned by Tidelands Corporation, which are retained by and delivered to the Trust on a quarterly basis, and (iii) dividends paid to the Trust by Tidelands Corporation, less (iv) administrative expenses incurred by the Trust. Distributions fluctuate from quarter to quarter primarily due to changes in oil and natural gas prices and production quantities and expenses incurred.

Item 2.

Trustee’s Discussion and Analysis of Financial Condition and Results of Operations

Organization

Tidelands Royalty Trust “B” (the “Trust”) is a royalty trust that was created on June 1, 1954 under the laws of the State of Texas. Effective February 20, 2018, Simmons Bank became corporate trustee of the Trust (the “Trustee”) as a result of a merger between Simmons Bank and Southwest Bank, an independent state bank chartered under the lawsformer corporate Trustee of the State of Texas and headquartered in Fort Worth, Texas, serves as corporate trustee (the “Trustee”).Trust. The Trust’s Indenture (the “Indenture”) provides that the term of the Trust will expire on April 30, 2021, unless extended by the vote of the holders of a majority of the outstanding units of beneficial interest. The Trust is not permitted to engage in any business activity because it was organized for the sole purpose of providing an efficient, orderly and practical means for the administration and liquidation of rights to interests in certain oil, natural gas or other mineral leases formerly owned by Gulf Oil Corporation (“Gulf”) in a designated area of the Gulf of Mexico. These rights are evidenced by a contract between the Trust’s predecessors and Gulf dated April 30, 1951 (the “1951 Contract”), which is binding upon the assignees of Gulf. As a result of various transactions that have occurred since 1951, the rights to interests that were subject to the 1951 Contract now are held by Chevron U.S.A., Inc. (“Chevron”), which is a subsidiary of Chevron Corporation, and its assignees. The Trust holds title to interests in properties subject to the 1951 Contract that are situated offshore of Texas.

The Trust’s wholly owned subsidiary, Tidelands Royalty “B” Corporation (“Tidelands Corporation,” and collectively with the Trust, “Tidelands”), holds title to interests in properties subject to the 1951 Contract that are situated offshore of Louisiana because at the time the Trust was created, trusts could not hold these interests under Louisiana law. Tidelands Corporation is prohibited from engaging in a trade or business and only takes those actions that are necessary for the administration and liquidation of its properties.

Tidelands’ rights are generally referred to as overriding royalty interests in the oil and natural gas industry. An overriding royalty interest is created by an assignment by the owner of a working interest in an oil or natural gas lease. The royalty rights associated with an overriding royalty interest terminate when the underlying lease terminates. All production and marketing functions are conducted by the working interest owners of the leases. Income from the overriding royalties is paid to Tidelands either (i) on the basis of the selling price of oil, natural gas and other minerals produced, saved or sold or (ii) at the value at the wellhead as determined by industry standards, when the selling price does not reflect the value at the wellhead.

The Trustee assumes that some units of beneficial interest are held by middlemen, as such term is broadly defined in U.S. Treasury Regulations (and includes custodians, nominees, certain joint owners and brokers holding an interest for a customer in street name). Therefore, the Trustee considers the Trust to be a widely held fixed investment trust (“WHFIT”) for U.S. federal income tax purposes. Accordingly, the Trust will provide tax information in accordance with applicable U.S. Treasury Regulations governing the information reporting requirements of the Trust as a WHFIT. The Trustee will provide the required information and the contact information for the Trustee is below:

Southwest Bank

2911 Turtle Creek Blvd., Suite 850

		Simmons Bank
		2911 Turtle Creek Blvd., Suite 850
		Dallas, Texas 75219
		Telephone number: (855)588-7839

Each unitholder should consult its own tax advisor for compliance with U.S. federal income tax laws and regulations.

Liquidity and Capital Resources

As stated in the Indenture, there is no requirement for capital due to the limited purpose of the Trust. The Trust’s only obligation is to distribute the distributable income that is actually collected to unitholders. As an administrator of oil and natural gas royalty interests, the Trust collects royalties monthly, pays administrative expenses and disburses all net royalties that are collected to its unitholders each quarter, subject to the availability of distributable income on the distribution determination date after the payment of expenses.

The Indenture (and Tidelands Corporation’s charter andby-laws) expressly prohibits the operation of any kind of trade or business. The Trust’s oil and natural gas properties are depleting assets that are not being replaced due to the prohibition against investments. These restrictions, along with other factors, allow the Trust to be treated as a grantor trust. As a grantor trust, all income and deductions for state and U.S. federal income tax purposes generally flow through to each individual unitholder. The State of Texas imposes a franchise tax, but the Trust does not believe that it is subject to the franchise tax because at least 90% of its income is from passive sources. Please see Tidelands’ Annual Report on Form10-K for the year ended December 31, 20162017 for further information. Tidelands Corporation is a taxable entity that pays U.S. federal income taxes and state franchise taxes. However, Tidelands Corporation’s income specifically excludes 95% of the oil and natural gas royalties collected by Tidelands Corporation, which are retained by and delivered to the Trust because of the Trust’s net profits interest.

The Leases

As of NovemberAugust 1, 2017,2018, Tidelands had an overriding royalty interest in four oil and natural gas leases covering 17,188 gross acres in the Gulf of Mexico in the Sabine Pass and West Cameron areas. As of NovemberAugust 1, 20172018, all four of Tidelands’ assigned leases contained active wells. Production ceased on West Cameron Block 225 in July 2012 but went back on stream in September 2013, and Tidelands recently began receiving royalty payments from EnVen Energy Ventures LLC for West Cameron Block 225.2013. Tidelands’ overriding royalty interest on three of the four leases is 4.1662%. On the fourth lease, the overriding royalty interest is 1.0416%. The overriding royalty interest on the fourth lease is lower because Chevron only acquired a 25% working interest in the lease. These leases and related overriding royalty interests are identified in the table below:

Based on the latest public records reviewed by Tidelands, there are seven active oil or natural gas wells that had production during the past 12 months on leases that are subject to Tidelands’ overriding royalty interest based on the records of the Bureau of Ocean Energy, Management, Regulation and Enforcement, a division of the U.S. government. The wells vary in age from approximately four years to fourteenfifteen years. Information on each of the seven wells is presented in the following table:

The number of active wells did not change from SeptemberJune 30, 20162017 to SeptemberJune 30, 2017.2018.

Critical Accounting Policies and Estimates

In accordance with the Staff Accounting Bulletin Topic 12:E,Financial Statements of Royalty Trusts, Tidelands uses the modified cash basis method of accounting. Under this accounting method, royalty income is recorded when received and distributions to unitholders are recorded when declared by the Trustee of the Trust. Expenses of Tidelands (including accounting, legal, other professional fees, trustees’ fees andout-of-pocket expenses) are recorded on an actual paid basis. Tidelands also reports distributable income instead of net income under the modified cash basis method of accounting. Cash reserves are permitted to be established by the Trustee for certain contingencies that would not be recorded under generally accepted accounting principles in the United States.

Tidelands did not have any changes in its critical accounting policies or estimates during the ninethree months and six months ended SeptemberJune 30, 2017.2018. Please see Tidelands’ Annual Report on Form10-K for the year ended December 31, 20162017 for a detailed discussion of its critical accounting policies.

New Accounting Pronouncements

There are no new pronouncements that are expected to have a significant impact on Tidelands’ financial statements.

General

Tidelands’ royalty income is derived from the oil and natural gas production activities of third parties. Tidelands’ royalty income fluctuates from period to period based upon factors beyond Tidelands’ control, including, without limitation, the number of productive wells drilled and maintained on leases that are subject to Tidelands’ interest, the level of production over time from such wells and the prices at which the oil and natural gas from such wells are sold.

Important aspects of Tidelands’ operations are conducted by third parties. Tidelands’ royalty income is dependent on the operations of the working interest owners of the leases on which Tidelands has an overriding royalty interest. The oil and natural gas companies that lease tracts subject to Tidelands’ interests are responsible for the production and sale of oil and natural gas and the calculation of royalty payments to Tidelands. The only obligation of the working interest owners to Tidelands is to make monthly overriding royalty payments that reflect Tidelands’ interest in the oil and natural gas sold. Tidelands’ distributions are processed and paid by its transfer agent, American Stock Transfer & Trust Company, LLC.

The volume of oil and natural gas produced and the selling prices of oil and natural gas are the primary factors in calculating overriding royalty payments. Production is affected by the natural production decline of the producing wells, the number of new wells drilled, and the number of existing wells that arere-worked and placed back in production on the leases. Production from existing wells is anticipated to decrease in the future due to normal well depletion. The operators do not provide Tidelands with information regarding future drilling orre-working operations that could impact the oil and natural gas production from the leases for which Tidelands has an overriding royalty interest.

Summary of Operating Results

During the ninesix months ended SeptemberJune 30, 2018, Tidelands realized approximately 79% of its royalty income from the sale of oil and approximately 21% of its royalty income from the sale of natural gas. During the six months ended June 30, 2017, Tidelands realized approximately 61% of its royalty income from the sale of oil and approximately 39% of its royalty income from the sale of natural gas. During the nine months ended September 30, 2016, Tidelands realized approximately 72% of its royalty income from the sale of oil and approximately 28% of its royalty income from the sale of natural gas. Royalty income includes royalties from oil and natural gas received from producers.

Distributable income (loss) per unit for the ninesix months ended SeptemberJune 30, 20172018 decreased to $0.02$0.00 from $0.04$0.02 for the same period in 2016.2017. Distributions per unit amounted to $0.00 for the six months ended June 30, 2018, down from $0.03 for the ninesame period in 2017. During the six months ended September 30, 2017, down from $0.06 for the comparable period in 2016. During the nine months ended SeptemberJune 30, 2017, the difference between distributable income per unit and distributions per unit resulted from timing differences between the closing of the financial statements and the determination date of the distributions to unitholders.

The following table presents the net production quantities of oil and natural gas and distributable income per unit and distributions per unit for the last six quarters.

Results of Operations – Three Months Ended SeptemberJune 30, 20172018 Compared to the Three Months Ended SeptemberJune 30, 20162017

Income from oil and natural gas royalties decreased to $28,090$22,696 during the three months ended SeptemberJune 30, 20172018 from $51,876$52,572 realized for the comparable period in 2016.2017. The decrease was primarily due to a decrease in the production of oil and natural gas and a delay in payment by an operator of one month’s revenue, offset in part by increases in the price of oil and natural gas.

Distributable income decreased to $483 for the three months ended September 30, 2017 compared to distributable income of $30,978 for the comparable period in 2016. As a result of a decrease in the production of both oil and natural gas and a decrease in the price of natural gas, as well as the timing of revenue receipts and the payment of expenses, which was partially offset by an increase in the price of oil, there were no funds available for distribution on October 13, 2017 to the unitholders of record as of September 29, 2017.

Income from oil royalties decreased to $17,542 for the three months ended September 30, 2017 from $37,464 realized for the comparable period in 2016, primarily due to a delay in payment by an operator of one month’s revenue, offset in part by an increase in the price of oil. The volume

Distributable income decreased to a loss of oil sold in$25,176 for the three months ended SeptemberJune 30, 2017 decreased2018 compared to 375 bbls from 913 bbls realizeddistributable loss of $7,877 for the comparable period in 2016, and2017. As a result, after the average price realizedpayment of expenses, there were no funds available for oil increased to $46.86 per bbl for the three months ended Septemberdistribution on June 30, 2017 from $41.02 per bbl realized for the comparable period in 2016.

Income from natural gas royalties decreased to $10,548 (net of expenses) for the three months ended September 30, 2017 from $14,412 realized for the comparable period in 2016, primarily due to a delay in payment by an operator of one month’s revenue and a decrease in natural gas production, offset in part by an increase in the price of natural gas. The volume of natural gas sold in the three months ended September 30, 2017 decreased to 4,170 mcf from 7,877 mcf realized for the comparable period in 2016, and the average price realized for natural gas increased to $2.53 per mcf from $1.83 per mcf realized for the comparable period in 2016.

The following table presents the quantities of oil and natural gas sold and the average price realized for the three months ended September 30, 2017 and 2016.

		Three Months Ended September 30,
		2017				2016
		(Unaudited)				(Unaudited)
Oil
Bbls sold			375				913
Average price		$	46.86			$	41.02
Natural gas
Mcf sold			4,170				7,877
Average price (net of expenses)		$	2.53			$	1.83

General and administrative expenses increased to $28,228 for the three months ended September 30, 2017 from $20,656 for the comparable period in 2016 primarily due2018 to the timingunitholders of payments, and an increase in, transfer agent fees, professional services and printing costs.

Resultsrecord as of Operations – Nine Months Ended SeptemberJune 30, 2017 Compared to the Nine Months Ended September 30, 2016

Income from oil and natural gas royalties decreased to $128,036 during the nine months ended September 30, 2017 from $169,815 realized for the comparable period in 2016.The decrease was primarily due to a delay of payment by operator of one month’s revenue and a decrease in the production of oil and natural gas, offset in part by increases in the price of oil and natural gas.

Distributable income decreased to $22,411 for the nine months ended September 30, 2017 compared to distributable income of $55,564 for the comparable period in 2016.2018.

Income from oil royalties decreased to $78,055$18,898 for the ninethree months ended SeptemberJune 30, 20172018 from $123,838$32,086 realized for the comparable period in 2016,2017 primarily due to a delay of payment by operator of one month’s revenue and a decrease in the production of oil, offset in part by an increase in the price of oil. The volume of oil sold in the ninethree months ended SeptemberJune 30, 20172018 decreased to 1,675322 bbls from 3,331658 bbls realized for the comparable period in 2016,2017, and the average price realized for oil increased to $46.60$58.69 per bbl for the ninethree months ended SeptemberJune 30, 20172018 from $37.17$48.73 per bbl realized for the comparable period in 2016.2017.

Income from natural gas royalties increaseddecreased to $49,981$3,798 (net of expenses) for the ninethree months ended SeptemberJune 30, 20172018 from $45,977 (net of expenses)$20,486 realized for the comparable period in 2016,2017, primarily due to an increasedecreases in the price of natural gas that was partially offset by a delay of payment by operator of one month’s revenueproduction and decrease in the production of natural gas.prices. The volume of natural gas sold in the ninethree months ended SeptemberJune 30, 20172018 decreased to 20,9831,405 mcf from 26,2267,302 mcf realized for the comparable period in 2016,2017, and the average price realized for natural gas increaseddecreased to $2.38$2.70 per mcf from $1.75$2.80 per mcf realized for the comparable period in 2016.2017.

The following table presents the quantities of oil and natural gas sold and the average price realized for the ninethree months ended SeptemberJune 30, 20172018 and 2016.2017.

General and administrative expenses decreased to $106,474$49,560 for the ninethree months ended SeptemberJune 30, 20172018 from $111,020$61,081 for the comparable period in 20162017, primarily due to the timing of payments related to professional services and printing fees.

Results of Operations – Six Months Ended June 30, 2018 Compared to the Six Months Ended June 30, 2017

Income from oil and natural gas royalties decreased to $56,581 during the six months ended June 30, 2018 from $99,946 realized for the comparable period in 2017. The decrease was primarily due to a decrease in the production of oil and natural gas that was partially offset by the increases in the price of oil and natural gas.

Distributable loss of $4,998 was incurred for the six months ended June 30, 2018 compared to distributable income of $21,928 for the comparable period in 2017.

Income from oil royalties decreased to $44,593 for the six months ended June 30, 2018 from $60,497 realized for the comparable period in 2017, primarily due to a decrease in the production of oil, offset in part by an increase in the price of oil. The volume of oil sold in the six months ended June 30, 2018 decreased to 852 bbls from 1,300 bbls realized for the comparable period in 2017, and the average price realized for oil increased to $52.34 per bbl for the six months ended June 30, 2018 from $46.53 per bbl realized for the comparable period in 2017.

Income from natural gas royalties decreased to $11,988 (net of expenses) for the six months ended June 30, 2018 from $39,449 realized for the comparable period in 2017, primarily due to a decrease in the production of natural gas, offset in part by an increase in the price of natural gas. The volume of natural gas sold in the six months ended June 30, 2018 decreased to 4,558 mcf from 16,813 mcf realized for the comparable period in 2017, and the average price realized for natural gas increased to $2.63 per mcf from $2.40 per mcf realized for the comparable period in 2017.

The following table presents the quantities of oil and natural gas sold and the average price realized for the six months ended June 30, 2018 and 2017.

General and administrative expenses decreased to $64,329 for the six months ended June 30, 2018 from $78,246 for the comparable period in 2017 primarily due to the timing of payments of, and a reduction in, transfer agent fees and professional services offset by an increase inand printing costs.fees.

Forward-Looking Statements

The statements discussed in this Quarterly Report on Form10-Q regarding Tidelands’ future financial performance and results, and other statements that are not historical facts, are forward-looking statements as defined in Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). This report uses the words “anticipate,” “believe,” “budget,” “continue,” “estimate,” “expect,” “intend,” “may,” “plan,” or other similar words to identify forward-looking statements. You should read statements that contain these words carefully because they discuss future expectations, contain projections of Tidelands’ financial condition, and/or state other “forward-looking” information. Actual results may differ from expected results because of factors, risks and uncertainties including, but not limited to, the following: reductions in prices or demand for oil and natural gas, which might then lead to decreased production or impair Tidelands’ ability to make distributions; reductions in production due to the depletion of existing wells or disruptions in service, which may be caused by storm damage to production facilities, blowouts or other production accidents, or geological changes such as cratering of productive formations; changes in regulations; general economic conditions; actions and policies of petroleum producing nations; other changes in domestic and international energy markets; the resignation of the Trustee; and the expiration, termination or release of leases subject to Tidelands’ interests. Additional risks are set forth in Tidelands’ Annual Report on Form10-K for the year ended December 31, 2016.2017. Events may occur in the future that Tidelands is unable to accurately predict, or over which it has no control. If one or more of these uncertainties materialize, or if underlying assumptions prove incorrect, actual outcomes may vary materially from those forward-looking statements included in this Quarterly Report on Form10-Q. Except as required by applicable securities laws, Tidelands does not undertake any obligation to update or revise any forward-looking statements.

Website

Tidelands makes available, free of charge, Tidelands’ Annual Reports on Form10-K, Quarterly Reports on Form10-Q, Current Reports on Form8-K, and amendments to such reports at its website atwww.tirtz-tidelands.com. Each of these reports will be posted on this website as soon as reasonably practicable after such report is electronically filed with or furnished to the SEC.

Item 3.

Quantitative and Qualitative Disclosures About Market Risk

Tidelands did not experience any material changes in market risk during the period covered by this Quarterly Report on Form10-Q. Tidelands’ market risk is described in more detail in “Item 7A. Quantitative and Qualitative Disclosures About Market Risk” in Tidelands’ Annual Report onForm10-K for the year ended December 31, 2016.2017.

Item 4.

Controls and Procedures

Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures

SouthwestSimmons Bank, as Trustee of the Trust, is responsible for establishing and maintaining Tidelands’ disclosure controls and procedures. Tidelands’ disclosure controls and procedures include controls and other procedures that are designed to ensure that information required to be disclosed by Tidelands in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by Tidelands in the reports that it files or submits under the Exchange Act is accumulated and communicated to the Trustee as appropriate to allow timely decisions regarding required disclosure.

As of SeptemberJune 30, 2017,2018, the Trustee carried out an evaluation of the effectiveness of the design and operation of Tidelands’ disclosure controls and procedures pursuant toRules 13a-15(b) and15d-15(b) of the Exchange Act. Based upon that evaluation, the Trustee concluded that Tidelands’ disclosure controls and procedures were effective as of SeptemberJune 30, 2017.2018.

Changes in Internal Control Over Financial Reporting

There have not been any changes in Tidelands’ internal control over financial reporting during the quarter ended SeptemberJune 30, 20172018 that have materially affected, or are reasonably likely to materially affect, Tidelands’ internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1A.

Risk Factors

There have been no material changes from the risk factors previously disclosed under the heading “Item 1A. Risk Factors” in Tidelands’ Annual Report filed on Form10-K for the year ended December 31, 2016.2017.

Item 6.

Exhibits

The following exhibits are included herein:

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.