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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-Q

ý		Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 for the quarterly period ended ~~September~~March 3031, ~~2016~~2017
Or
o		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: 000-06910

TEL OFFSHORE TRUST
(Exact name of registrant as specified in its charter)


Texas (State or other jurisdiction of incorporation or organization)		76-6004064 (I.R.S. Employer Identification No.)
The Bank of New York Mellon Trust Company, N.A. 919 Congress Avenue Austin, Texas (Address of principal executive offices)		78701 (Zip Code)

(512) 236-6599
(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 ý No o

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 o No o

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

Large accelerated filer o Accelerated filer o Non-accelerated filer ý (Do not check if a smaller reporting company) Smaller reporting company o Emerging growth company o

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 account standards provided pursuant to Section 13(a) of the Exchange Act. o

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

As of ~~November~~May 1112, ~~2016~~2017, 4,751,510 Units of Beneficial Interest in TEL Offshore Trust were outstanding.

NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (this "Form 10-Q") includes "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical facts included in this Form 10-Q, including without limitation, statements under "Trustee's Discussion and Analysis of Financial Condition and Results of Operations" in Item 2 of Part I and elsewhere herein regarding the financial position, production and reserve growth, and other plans and objectives are forward-looking statements. Forward-looking statements are generally accompanied by words such as "estimate," "project," "predict," "believe," "expect," "anticipate," "could," "may," "should," "intend" or other words that convey the uncertainty of future events or outcomes. These forward-looking statements are based on current expectations and assumptions about future events. Although Chevron USA, Inc., the Managing General Partner of the TEL Offshore Trust Partnership, has advised the Trust that the Managing General Partner believes that the expectations reflected in the forward-looking statements contained herein are reasonable, no assurance can be given that such expectations will prove to have been correct. Important factors that could cause actual results to differ materially from expectations are disclosed in the risk factors discussed in Item 1A of Part I of the Trust's Annual Report on Form 10-K for the year ended December 31, ~~2015~~2016 (the "~~2015~~ 2016 10-K") and such other factors as may be set forth from time to time in the Trust's filings with the Securities and Exchange Commission. All subsequent written and oral forward-looking statements attributable to the Managing General Partner or the Trust or persons acting on behalf of the Managing General Partner or the Trust are expressly qualified in their entirety by such factors. The Trust assumes no obligation, and disclaims any duty, to update these forward-looking statements. Risk factors that may affect actual results and distributions to unit holders include, without limitation:

•: the terms of the previously announced settlements of the Probate Proceedings (as defined in "Note 5 to the Financial Statements—Probate Proceeding") and the expected termination of the Trust in the Probate Proceeding; and
•: the utilization of the Trust's cash, cash equivalents and restricted cash to pay expenses incurred in the Probate Proceeding as contemplated by the terms of the settlement.

PART I—FINANCIAL INFORMATION

Item 1. Condensed Financial Statements.

TEL OFFSHORE TRUST
CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS (UNAUDITED)

	September 30, 2016			December 31, 2015
	March 31, 2017			December 31, 2016
Assets
Cash and cash equivalents	$	22184,~~230~~755		$	~~328,040~~—
Cash—Restricted		1,~~761~~097,~~572~~598			—1,451,135
Net overriding royalty interest in oil and gas properties, net of accumulated amortization of $0 and $28,258,358, respectively		—			9,297
Total assets	$	1,282,353		$	1,451,135

Total assets	$	1,783,802		$	337,337



Liabilities and Trust Corpus
Distribution payable to Unit holders	$	—		$	—
Cash advances		68252,~~224~~979			868,~~303~~224
Account payable		—			878
Note payable		1,056,885			1,056,885
Reserve for future Trust expenses		—			—
Trust corpus (4,751,510 Units of beneficial interest authorized and outstanding)		(27,511	)		326,026
Trust corpus (4,751,510 Units of beneficial interest authorized and outstanding)		658,693			(728,729	)

Total liabilities and Trust corpus	$	1,~~783~~282,~~802~~353		$	~~337~~1,~~337~~451,135

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)

	Three Months Ended September 30,						Nine Months Ended September 30,
	Three Months Ended March 31,
	2016			2015			2016			2015
	2017			2016
Royalty income	$	—		$	—713		$	~~117,142~~		$	—
Interest income		~~658~~1,257			59			~~805~~
Proceeds from sale of overriding royalty interest		—			—			1,756,624			—


		1,257			772
		658			—			1,874,571			—
Income withheld for future probate distribution		—			—
Income withheld for future probate distribution		(658	)		—			(1,873,799	)		—
Proceeds from Note and cash advances used for Trust expenses		—			142,097
Decrease in reserve for future Trust expenses		—			—			—			—
Proceeds from sale used for Probate expenses		353,537			—
Proceeds from Note and cash advances used for Trust expenses		153,757			96,765			477,079			334,255
General and administrative expenses		(354,794	)		(142,869	)
General and administrative expenses		(153,757	)		(96,765	)		(477,851	)		(334,255	)


Distributable income		—			—
Distributable income		—			—			—			—


Distributable income per Unit (basic and diluted (4,751,510 Units))	$	.000000		$	.000000
Distributable income per Unit (basic and diluted (4,751,510 Units))	$	0.000000		$	0.000000		$	0.000000		$	0.000000




Distributions per Unit (4,751,510 Units)	$	.000000		$	.000000
Distributions per Unit (4,751,510 Units)	$	0.000000		$	0.000000		$	0.000000		$	0.000000

CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)

	Three Months Ended September 30,						Nine Months Ended September 30,
	Three Months Ended March 31,
	2016			2015			2016			2015
	2017			2016
Trust corpus, beginning of period	$	~~811~~326,~~792~~026		$	(~~462~~728,~~050~~729	)	$	~~(728,729~~	)	$	~~(223,304~~	)
Distributable income		—			—			—			—
Distribution payable to Unit holders		—			—			—			—
Sales proceeds		—			—			1,873,052			—
Proceeds from Note and cash advances used for Trust expenses		—			(142,097	)
Proceeds from Note and cash advances used for Trust expenses		(153,757	)		(96,765	)		(477,079	)		(334,255	)
Proceeds from sale used for Probate expenses		(354,794	)		—
Interest Income		~~658~~1,257			—			~~746~~			—
Amortization of net overriding royalty interest		—			(~~537~~1,028	)		~~(9,297~~	)		~~(1,793~~	)

Trust corpus, end of period	$	~~658~~(27,~~693~~511	)	$	(~~559~~871,~~352~~854	)	$	~~658,693~~		$	~~(559,352~~	)

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

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)

(1) Trust Organization

Tenneco Offshore Company, Inc. ("Tenneco Offshore") created the TEL Offshore Trust ("Trust") effective January 1, 1983, pursuant to the Plan of Dissolution ("Plan") approved by Tenneco Offshore's stockholders on December 22, 1982. In accordance with the Plan, the TEL Offshore Trust Partnership ("Partnership") was formed in which the Trust owns a 99.99% interest and Tenneco Oil Company had initially owned a .01% interest. In general, the Plan was effected by transferring an overriding royalty interest equivalent to a 25% net profits interest (the "Original Royalty") in the oil and gas properties (the "Royalty Properties") of Tenneco Exploration, Ltd. located offshore Louisiana to the Partnership and issuing certificates evidencing units of beneficial interest in the Trust ("Units") in liquidation and cancellation of Tenneco Offshore's common stock. The term "Original Royalty" shall refer to the initial 25% net profits interest in the Royalty Properties and the term "Royalty" shall refer to the applicable net profits interest ~~previously~~ held from time to time by the Partnership following the Royalty Sales (as defined in Note 3 below).

On January 14, 1983, Tenneco Offshore distributed Units to holders of Tenneco Offshore's common stock on the basis of one Unit for each common share owned on such date.

The terms of the Trust Agreement, dated January 1, 1983 (as amended, the "Trust Agreement"), provide, among other things, that:

(a) the Trust is a passive entity and cannot engage in any business or investment activity or purchase any assets;

(b) the interest in the Partnership can be sold in part or in total for cash upon approval of a majority of the Unit holders;

(c) the Trustees, as defined below, can establish cash reserves and borrow funds to pay liabilities of the Trust and can pledge the assets of the Trust to secure payments of the borrowings. At ~~September~~March 3031, ~~2016~~2017 and December 31, ~~2015~~2016 the reserve amount was $0;

(d) the Trustees will make cash distributions to the Unit holders in January, April, July and October of each year as discussed in Note 4; and

(e) the Trust will terminate upon the first to occur of the following events: (i) total future net revenues attributable to the Partnership's interest in the Royalty, as determined by independent petroleum engineers, as of the end of any year, are less than $1.2.0 million (~~assuming~~without noconsidering ~~further~~any sales of ~~any interests in~~ the Royalty) or (ii) a decision to terminate the Trust by the affirmative vote of Unit holders representing a majority of the Units. ~~Future~~However, ~~net~~as ~~revenues~~a ~~attributable~~result ~~to the Royalty were estimated at approximately $1.9 million (unaudited) as~~ of ~~November 1, 2015. Such future net revenues include projected reserves attributable to~~ the ~~four~~terms ~~wells drilled by Arena Offshore, LP ("Arena") but did not include capital expenditures attributable to the redevelopment~~ of ~~Eugene Island 339. Upon termination of~~ the ~~Trust,~~Corporate inTrustee ~~accordance~~Settlement ~~with the Trust~~ Agreement, ~~the Corporate Trustee~~ (as defined ~~below~~in Note 5), ~~would sell for cash~~there ~~all~~is ~~assets~~a ~~held~~request inthat the Trust ~~estate~~be ~~and~~modified ~~make~~to aallow ~~final~~the ~~distribution~~Trust to ~~the~~terminate ~~Unit~~on ~~holders~~a ofdate ~~any~~established ~~funds~~by ~~remaining,~~the ~~after~~Court ~~all~~(as ~~Trust~~defined ~~liabilities~~in ~~had been satisfied~~Note 5).

On October 27, 2011, the Partnership consummated the 2011 Royalty Sale (as defined in Note 3) and sold 20% of the Original Royalty (or 5% of 8/8ths). See Note 3.

On October 31, 2013, the Partnership consummated the 2013 Royalty Sale (as defined in Note 3) and sold 25% of its remaining interest in the Original Royalty (or 5% of 8/8ths). See Note 3.

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(1) Trust Organization (Continued)

On ~~October~~June 2724, ~~2011~~2016, the Partnership consummated the 2016 Royalty Sale (as defined in Note 3) and sold ~~20%~~all of its remaining interest in the Original Royalty (or 515% of 8/8ths). ~~for~~As ~~gross~~a ~~proceeds~~result of $1consummation of the sale,~~600,000~~ the Partnership no longer owns any overriding royalty interest in the Royalty Properties. See Note 3.

OnThe ~~October 31,~~Trust ~~2013~~is currently administered by The Bank of New York Mellon Trust Company, N.A. (the ~~Partnership~~"Corporate ~~consummated~~Trustee"), which succeeded JPMorgan Chase Bank, N.A. as the ~~sale~~corporate oftrustee, effective ~~25%~~October 2, 2006 pursuant to an agreement under which The Bank of ~~its~~New ~~remaining~~York ~~interest~~Mellon inTrust Company, N.A. acquired substantially all of the ~~Original~~corporate ~~Royalty~~trust business of JPMorgan Chase (orformerly 5%known ofas ~~8/8ths~~The Chase Manhattan Bank), ~~for~~and ~~gross~~Gary ~~proceeds~~C. ofEvans, $1Thomas H. Owen,~~200~~ Jr.,~~000~~ and Jeffrey S. ~~See~~Swanson (the "Individual Trustees"), as trustees (collectively, the "Trustees"). The Individual ~~Note~~Trustees tendered their resignations on January 317, 2017 and such resignations will become effective, subject to any earlier termination of the Trust, on September 1, 2017.

On June 24, 2016, the Partnership consummated the sale of all of its remaining interest in the Original Royalty (or 15% of 8/8ths) owned by the Partnership. As a result of consummation of the sale, the Partnership no longer owns any overriding royalty interest in the Royalty Properties. See Note 3.

The Trust is currently administered by The Bank of New York Mellon Trust Company, N.A. (the "Corporate Trustee"), which succeeded JPMorgan Chase Bank, N.A. as the corporate trustee, effective October 2, 2006 pursuant to an agreement under which The Bank of New York acquired substantially all of the corporate trust business of JPMorgan Chase (formerly known as The Chase Manhattan Bank), and Gary C. Evans, Thomas H. Owen, Jr., and Jeffrey S. Swanson (the "Individual Trustees"), as trustees (collectively, the "Trustees").

The Trustees, including the Corporate Trustee, have no authority over, have not evaluated and make no statement concerning, the internal control over financial reporting of any of the owner or owners of the Royalty Properties (the "Working Interest Owners").

(2) Basis of Accounting and Going Concern

The accompanying unaudited financial information has been prepared by the Corporate Trustee. The accompanying financial information is prepared on a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America ("GAAP"). The Trustees believe that the information furnished reflects all adjustments that are, in the opinion of the Trustees, necessary for a fair presentation of the results for the interim periods presented. Such adjustments are of a normal and recurring nature. The financial information should be read in conjunction with the financial statements and notes thereto included in the Trust's Annual Report on Form 10-K for the year ended December 31, ~~2015~~2016.

Overriding Royalty Interest. The Trust uses the modified cash basis of accounting to report Trust receipts from the overriding royalty and payments of expenses incurred. Actual cash distributions to the Trust were made based on the terms of the conveyance that created the Trust's overriding royalty interest. Prior to the Royalty Sales (as defined in Note 3), the overriding royalty interest entitled the Trust to receive revenues (oil, gas and natural gas liquid sales) less expenses (the amount by which all royalties, lease operating expenses including well workover costs, production and property taxes, post-production costs including plugging and abandonment, and producing overhead of the underlying properties) multiplied by the Partnership's interest in the Original Royalty. The Original Royalty initially represented a 25% net profits interest but after the Royalty Sales, the Partnership no longer owns any overriding interest in the Royalty properties. ~~Actual cash receipts would vary due to timing~~

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(2) Basis of Accounting and Going Concern (Continued)

delays of cash receipts from the property operators or purchasers and due to wellhead and pipeline volume balancing agreements or practices.

Modified Cash Basis of Accounting. The condensed financial statements of the Trust, as prepared on a modified cash basis, reflect the Trust's assets, liabilities, Trust corpus, earnings and distributions, as follows:

(a): Royalty income from the overriding royalty interest was recorded when received, including the effect of overtaken or undertaken positions and negative or positive adjustments, by the Corporate Trustee on the last business day of each calendar quarter. In addition, Royalty income included amounts related to funds deposited or released from the Special Cost Escrow account—see (d);
(b): Trust general and administrative expenses (which include the Trustee's fees as well as accounting, engineering, legal, and other professional fees) and expenses related to the Probate Proceeding are recorded when paid by the Trust rather than when incurred;
(c): Cash reserves for Trust expenses may be established by the Trustee for certain expenditures that would not be recorded as contingent liabilities under GAAP;
(d): The funds deposited or released from the Special Cost Escrow account were recorded at the time of payment or receipt. The Special Cost Escrow account is an account of the Working Interest Owners and is not reflected in the condensed financial statements of the Trust;
(e): Amortization of the investment in overriding royalty interest was calculated based on the units-of-production method. Such amortization is charged directly to Trust corpus and does not affect distributable income; and
(f): Proceeds from loans and cash advances used to pay for Trust expenses is charged directly to Trust corpus.

This manner of reporting income and expenses is considered to be the most meaningful because the quarterly distributions to Unit holders are based on net cash receipts received from the Working Interest Owners. The condensed financial statements of the Trust differ from condensed financial statements prepared in accordance with GAAP, because, under such principles, Royalty income and Trust general and administrative expenses for a quarter would be recognized on an accrual basis. In addition, amortization of the net overriding royalty interest, calculated on a units-of-production basis, was charged directly to Trust corpus since such amount did not affect distributable income. 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.

Oil and Gas Reserves. The proved oil and gas reserves for the underlying properties ~~have~~were ~~been~~previously estimated by independent petroleum engineers. ~~Reserve~~ Reserve engineering is a subjective process that is dependent upon the quality of available data and the interpretation thereof. Estimates by different engineers often vary, sometimes significantly. In addition, physical factors such as the results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(2) Basis of Accounting and Going Concern (Continued)

~~engineers often vary, sometimes significantly. In addition, physical factors~~ such ~~as the results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors~~ ~~such~~ as changes in product prices and production costs, may justify revision of such estimates. Accordingly, oil and gas quantities ultimately recovered and the timing of production may be substantially different from estimates.

The standardized measure of discounted future net cash flows iswas prepared using assumptions made pursuant to FASB and SEC guidelines. Such assumptions include using average fiscal-year oil and gas prices (calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month reporting period) and year-end costs for estimated future production expenditures. Discounted future net cash flows are calculated using a 10% discount rate. Changes in any of these assumptions could have a significant impact on the standardized measure. The standardized measure does not necessarily result in an estimate of the current fair market value of proved reserves.

Amortization of Overriding Royalty Interest. The Trust amortized the investment in overriding royalty interest using the units-of-production method. The Trust's rate of recording amortization was dependent upon the estimates of total proved reserves, which incorporated various assumptions and future projections. If the estimates of total proved reserves declined significantly, the rate at which the Trust recorded amortization expense would have increased, reducing Trust corpus. Such a decline in reserves may result from lower commodity prices, which may make it uneconomic to produce from higher cost fields. As a result of the 2016 Royalty Sale, the Trust no longer holds any investment in the overriding royalty interest and there will be no further amortization.

Impairment of Investment in Overriding Royalty Interest. The Trust reviewed overriding royalty interests in oil and gas properties for possible impairment whenever events or circumstances indicated the carrying amount of the asset may not be recoverable. If there was an indication of impairment, the Trust prepared an estimate of future cash flows (undiscounted and without interest charges) expected to result from the use of the asset and its eventual disposition. If these cash flows were less than the carrying amount of the asset, an impairment loss was recognized to write down the asset to its estimated fair value. Preparation of estimated expected future cash flows is inherently subjective and was based on the Corporate Trustee's best estimate of assumptions concerning expected future conditions. As a result of the 2016 Royalty Sale, the Trust no longer holds any investment in the overriding royalty interest and there will be no further impairments.

Cash and Cash Equivalents. Cash and cash equivalents include all highly liquid short-term investments with original maturities of three months or less.

Restricted Cash. Restricted cash reported on the Condensed Statement of Assets, Liabilities and Trust Corpus consists of (i) proceeds received by the Trust from the 2016 Royalty Sale and (ii) the distribution received by the Trust as a result of the Cox Oil Sale (as defined ~~in Note 6~~below). The proceeds from the 2016 Royalty Sale are required to be held in a segregated account pending resolution of the Probate Proceeding (as defined in Note 5). The distribution received from Cox Oil, resulting from Chevron's sale of ship shoal 182/183 to Cox Oil effective as of August 1, 2015 (the "Cox Oil Sale"), is also being withheld by the Trust pending resolution of the Probate Proceeding.

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(2) Basis of Accounting and Going Concern (Continued)

Probate Proceeding (as defined in Note 6). The distribution received in connection with the Cox Oil Sale (as defined in Note 6) is also being withheld by the Trust pending resolution of the Probate Proceeding.

Reserve for future Trust expenses. Represents cash reserves for future Trust expenses established by the Trustee. The changes in reserves for future Trust expenses include both changes of amounts deemed necessary by the Trustees and related distributions, as well as amounts paid from the reserve during periods when the Trust has insufficient income to pay Trust expenses. See Note 6.

Proceeds from Sale of Overriding Royalty. The Trust recorded proceeds from the sale of overriding royalty interests when received.

Special Cost Escrow account. The Special Cost Escrow account was established for future costs to be incurred to plug and abandon wells, dismantle and remove platforms, pipelines and other production facilities, and for the estimated amount of future capital expenditures on the Royalty Properties. The funds previously held in the Special Cost Escrow account were not reflected in the condensed financial statements of the Trust. However, funds deposited to or released from the Special Cost Escrow account were included in Royalty income. See Note 5.

Use of Estimates. The preparation of financial statements requires the Trustees to make use of estimates and assumptions that affect amounts reported in the condensed financial statements as well as certain disclosures. Actual results could differ from those estimates.

Recent Accounting Pronouncements. There were no accounting pronouncements issued during the three months ended ~~September~~March 3031, ~~2016~~2017, applicable to to the Trust or its condensed financial statements.

Going Concern. The accompanying condensed financial statements have been prepared assuming that the Trust will continue as a going concern. Financial statements prepared on the going concern basis assume the realization of assets and the settlement of liabilities in the normal course of business. ~~During~~As ~~the~~discussed ~~first quarter of 2016, the Trust received $713~~ in ~~Royalty income from Fieldwood Energy Offshore~~Note ~~LLC~~5 ~~("Fieldwood"),~~to the ~~operator~~condensed financial ofstatements ~~Eugene Island 342. In addition, as a result~~ of the ~~sale~~Trust ~~by Chevron of its interest~~ in ~~Ship~~this ~~Shoal 182/183 effective August~~Form 110-Q, ~~2015~~certain conditions toraise ~~Cox~~substantial ~~Oil~~doubt ~~Offshore,~~about ~~L.L.C. ("Cox Oil"),~~ the Trust ~~received a distribution of $116,429 in May 2016. As a result of the Partnership~~'s ~~sale~~ability ~~of the remaining Royalty in the 2016 Royalty Sale (as defined in Note 3 below), the Trust will not be receiving any further Royalty income and the proceeds from such sale are required~~ to becontinue ~~held in a segregated interest bearing account, which is presented~~ as ~~Cash-Restricted in the Condensed Statements of Assets, Liabilities and Trust Corpus, pending~~ a ~~subsequent~~going ~~court order from the Court (as defined in Note 6)~~concern. The ~~Trust~~Trustees' ~~will~~plans ~~not~~concerning ~~make~~this ~~any~~matter ~~distribution~~are ofalso ~~the~~discussed ~~proceeds from the 2016 Royalty Sale to Unit holders until it receives a subsequent order from the Court or the Remaining Matters (as defined~~ in Note 6)5 ~~are~~to ~~otherwise settled. In addition,~~ the ~~Trust~~condensed ~~may~~financial statements ~~refrain from making any distribution~~ of ~~such proceeds until after~~ the ~~expiration~~Trust ~~of the audit period provided for~~ in ~~the conveyance~~this ~~document for the 2016 Royalty Sale, which expires on December~~Form ~~29, 2016~~10-Q. The ~~lack~~condensed offinancial ~~Net~~statements ~~Proceeds~~do ~~and~~not ~~the~~include ~~inability~~any toadjustments ~~maintain~~that ~~adequate~~might ~~cash~~result ~~reserves~~from ~~raise~~the ~~substantial~~outcome ~~doubt~~of ~~about the~~this ~~Trust's~~uncertainty.

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(2) Basis of Accounting and Going Concern (Continued)

ability to continue as a going concern. The condensed financial statements do not include any adjustments that might result from the outcome of the Probate Proceeding.

(3) Net Overriding Royalty Interest

The Original Royalty entitled the Trust to its share (99.99%) of 25% of the Net Proceeds attributable to the Royalty Properties. The Conveyance, dated January 1, 1983, provided that the Working Interest Owners would calculate, for each period of three months commencing the first day of February, May, August and November, an amount equal to 25% of the Net Proceeds from their oil and gas properties for the period. Generally, "Net Proceeds" means the amount received by the Working Interest Owners from the sale of minerals from the Royalty Properties less operating and capital costs incurred, management fees and expense reimbursements owing to the Managing General Partner of the Partnership, applicable taxes other than income taxes, and the Special Cost Escrow account. The Special Cost Escrow account was established for the future costs to be incurred to plug and abandon wells, dismantle and remove platforms, pipelines and other production facilities, and for the estimated amount of future capital expenditures on the Royalty Properties. Net Proceeds did not include amounts received by the Working Interest Owners as advance gas payments, "take-or-pay" payments or similar payments unless and until such payments were extinguished or repaid through the future delivery of gas.

On October 27, 2011, the Trust issued a press release announcing that the Partnership had consummated the sale (the "2011 Royalty Sale") of 20% of the Original Royalty (or 5% of 8/8ths). The 2011 Royalty Sale was made to RNR Production, Land and Cattle Company, Inc. ("RNR Production") on October 27, 2011, though the assignment was effective as of August 1, 2011. ~~Refer to Note 6 for further discussion of the 2011 Royalty Sale.~~

On October 31, 2013, the Trust issued a press release announcing that the Partnership had consummated the sale (the "2013 Royalty Sale") of 25% of its remaining interest in the Original Royalty (or 5% of 8/8ths). The 2013 Royalty Sale to RNR Production closed on October 31, 2013, though the assignment was effective as of August 1, 2013. Refer to Note 6 for further discussion of the 2013 Royalty Sale.

On June 27, 2016, the Trust issued a press release announcing that the Partnership had consummated the sale (the "2016 Royalty Sale" and, together with the 2011 Royalty Sale and the 2013 Royalty Sale, the "Royalty Sales") of all of its remaining interest in the Original Royalty (60% or 15% of 8/8ths). As a result of consummation of the 2016 Royalty Sale, the Partnership no longer owns any Royalty in the Royalty Properties. The 2016 Royalty Sale was made to Arena Energy, LP and closed on June 24, 2016, but was effective as of February 1, 2016. The 2016 Royalty Sale generated $1,830,000 in gross proceeds and occurred as part of the previously announced formal auction process for the overriding royalty interest. The Trust received a distribution of approximately $1,756.624, representing 99.99% of the net proceeds from the Royalty Sale of $1,756,800 in July 2016. See Note 6 ~~for a further discussion of the 2016 Royalty Sale.~~

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(3) Net Overriding Royalty Interest (Continued)

Royalty On(or ~~the last business day of each calendar quarter prior to August 1, 2011, the Working Interest Owners were to pay to the Partnership 25~~5% of ~~the Net Proceeds for the immediately preceding Quarterly Period; however, (i~~8/8ths) as. aThe ~~result~~2013 ~~of the 2011~~ Royalty Sale, ~~on the last business day of each calendar quarter after August 1, 2011 and prior~~ to ~~August 1,~~RNR ~~2013, the~~Production ~~Working~~closed ~~Interest Owners were to pay to the Partnership 20% of the Net Proceeds for the immediately preceding Quarterly Period (ii) as a result of the 2013 Royalty Sale,~~ on ~~the last business day of each calendar quarter after August~~October 131, 2013, ~~the~~though ~~Working Interest Owners were to pay to~~ the ~~Partnership~~assignment ~~15%~~was ofeffective ~~the Net Proceeds for the immediately preceding Quarterly Period and (iii)~~ as ~~a result~~ of ~~the 2016 Royalty Sale, from and after February~~August 1, ~~2016, the Working Interest Owners are no longer required to pay to the Partnership any Net Proceeds~~2013. A Quarterly Period is each period of three months commencing on the first day of February, May, August and November. In turn, the Partnership distributed funds to its partners on the last business day of each calendar quarter. Cash distributions from the Trust, if any, were made in January, April, July and October of each year, and were payable to Unit holders of record as of the last business day of each calendar quarter. The financial and operating information included in this Form 10-Q for the three and nine months ended September 30, 2016 and September 30, 2015 represents financial and operating information with respect to the Royalty Properties for the immediately preceding months of November, December, January, February, March, April, May, June and July. Income received pursuant to the Partnership's overriding royalty interest was recorded by the Trust on a cash basis, when it was received by the Trust from the Partnership.

On June 27, 2016, the Trust issued a press release announcing that the Partnership had, pursuant to a Final Judgment entered in the Severed Proceeding (as defined in Note 5), consummated the sale (the "2016 Royalty Sale" and, together with the 2011 Royalty Sale and the 2013 Royalty Sale, the "Royalty Sales") of all of its remaining interest in the Original Royalty (60% or 15% of 8/8ths). As a result of consummation of the 2016 Royalty Sale, the Partnership no longer owns any Royalty in the Royalty Properties. The 2016 Royalty Sale was made to Arena Energy, LP and closed on June 24, 2016, but was effective as of February 1, 2016. The 2016 Royalty Sale generated $1,830,000 in gross proceeds and occurred as part of the previously announced formal auction process for the overriding royalty interest. The Trust received a distribution of approximately $1,756.624, representing 99.99% of the net proceeds from the Royalty Sale of $1,756,800 in July 2016.

(4) Distributions to Unit Holders

In accordance with the provisions of the Trust Agreement, generally all Net Proceeds received by the Trust, net of Trust general and administrative expenses and any cash reserves established for the payment of contingent or future obligations of the Trust, ~~are~~were distributed quarterly to the Unit holders. These distributions are referred to as "distributable income." The amounts distributed, if any, ~~are~~were determined on a quarterly basis and are payable to Unit holders of record as of the last business day of each calendar quarter. Cash distributions, when available, ~~are~~were made in in January, April, July and October and ~~include~~included interest earned from the quarterly record date to the date of distribution.

~~Production~~The ~~ceased~~Trust atcurrently ~~Eugene~~holds ~~Island~~the ~~339~~remaining ~~and~~net ~~Ship~~proceeds ~~Shoal~~from ~~182~~the ~~and~~2016 ~~183~~Royalty ~~following~~Sale ~~damages~~and ~~inflicted~~remaining byproceeds ~~Hurricane~~received ~~Ike~~as ina ~~September~~result ~~2008.~~of ~~Future~~the ~~Net~~Cox ~~Proceeds~~Oil ~~took~~Sale, ~~into~~a ~~account~~portion ~~the Trust's share~~ of ~~project~~such ~~costs~~proceeds ~~and~~having ~~other~~been used ~~related~~to ~~expenditures~~pay ~~that~~certain ~~were~~expenses ~~not covered by insurance~~ of the ~~operator~~ad oflitem in the ~~Royalty~~Probate ~~Properties~~Proceeding. OnThe ~~December 19, 2008, the~~ Trust ~~announced~~will ~~its~~not ~~fourth~~make ~~quarter~~ any distribution of ~~approximately~~these ~~$0.7 million,~~funds ~~which~~to ~~was~~Unit ~~paid~~holders onuntil ~~January 9,~~it ~~2009.~~receives ~~The~~a ~~funds~~subsequent ~~available~~order ~~for~~from the ~~fourth~~Court; provided, ~~quarter~~if ~~distribution~~the ~~were~~Court ~~severely~~approves ~~negatively~~the ~~impacted~~terms byof ~~lower production~~the asCorporate aTrustee ~~result~~Settlement ofAgreement ~~shutdowns~~(as ~~and~~defined ~~damage~~in toNote 5) ~~producing~~and ~~assets~~enters ~~because~~an oforder ~~Hurricane~~approving ~~Ike.~~the OnCorporate ~~March 25,~~Trustee ~~2009~~Settlement Agreement, the remaining ~~Trust~~funds ~~announced~~held ~~that~~in ~~there~~the ~~would~~segregated beaccount nowill ~~trust~~be ~~distribution~~paid ~~for~~to the ~~first quarter~~QSF of(as ~~2009,~~defined ~~and~~in ~~the~~Note 5) ~~Trust~~pursuant ~~has~~to ~~not~~the ~~made~~terms aof ~~distribution~~the ~~since~~Corporate ~~January 9,~~Trustee ~~2009~~Settlement Agreement.

~~The~~ ~~Trust currently holds the net proceeds from the 2016 Royalty Sale and remaining proceeds received as a result of the Cox Oil Sale~~ (~~as defined in Note 6~~5), aProbate ~~portion of such proceeds having been~~ Proceeding

As previously disclosed on July 10, 2014, the Trustees filed a Petition for Modification and Termination of the Trust (the "Petition") with the Probate Court of Travis County, Texas (the "Court"). The Petition requested that the Court modify the Trust Agreement to (1) allow for the termination of the Trust by a court order, and (2) allow the Trustees, as necessary to fulfill the purposes of the Trust and without Unit holder approval to (a) sell all or any portion of the Trust's interests in the Partnership or any other assets of the Trust, (b) exercise their rights to dissolve the Partnership, or (c) cause the Partnership to sell the Royalty. The Trust completed the process of serving the Petition on the Trust's

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(5) Probate Proceeding (Continued)

Unit holders in connection with such probate proceeding (the "Probate Proceeding"). The Court appointed Glenn M. Karisch, attorney ad litem (the "Ad Litem") to represent any Unit holders that were not personally served. The Ad Litem filed a Counterclaim against the Trust on November 16, 2015 requesting (1) an order to sell all of the Royalty, and (2) an accounting of the general and administrative expenses of the Trust from 2008 through the present.

The Probate Proceeding was set for trial on January 15, 2016. Prior to trial, the Ad Litem filed a Motion to Sever asking the Court to sever all matters related to the requested modification of the Trust and the sale of Trust assets, into a separate cause to proceed to trial. The Ad Litem also filed a Motion for Continuance requesting that the Court continue the trial of all remaining matters, including the Ad Litem's request for an accounting and the issues concerning the termination of the Trust, to a later date (the "Remaining Matters"). Prior to calling the case to trial, the Court granted the Ad Litem's Motion to Sever and Motion for Continuance, severed the matters related to the modification of the Trust and the sale of Trust assets ("Severed Proceeding"), and continued the Remaining Matters to a later date. The Severed Proceeding has been assigned Cause No. C 1 PB 16 000096 and is styled In re: TEL Offshore Trust.

The Severed Proceeding proceeded to trial before the Court on January 15, 2016. At trial, the Court entered a Final Judgment and Order granting the Trustees' request that the Trust Agreement be modified to permit the Trustees to direct the Partnership to sell the remaining overriding royalty interest held by the Partnership as soon as reasonably possible and granting the Ad Litem's request to sell all of the Royalty, notwithstanding any requirements of the Trust Agreement to the contrary. The Partnership completed the sale of the remaining overriding royalty interest on June 24, 2016.

On August 17, 2016, the Ad Litem filed a Second Amended Answer and First Amended Counterclaim seeking an accounting and asserting, among other causes of action, breach of fiduciary duties; negligence; gross negligence; intentional conduct and bad faith; and forfeiture of fees and punitive damages. The Ad Litem has also asserted other allegations against the Trustees.

The Remaining Matters were originally set for trial on November 7, 2016. The Trustees filed a motion for continuance of the Remaining Matters and a hearing for such continuance occurred on September 14, 2016. At the hearing, the Court granted the Trustees' motion for continuance of the Remaining Matters and scheduled the trial for June 12, 2017.

On October 3, 2016, the trial judge realigned the parties, such that the Ad Litem is now the plaintiff and the Trustees are the defendants. The Ad Litem then filed an Original Petition as Realigned Plaintiff ("Realigned Petition") on October 10, 2016, and a First Amended Petition as Realigned Plaintiff ("Amended Realigned Petition") on October 28, 2016, which continued to assert claims for breach of fiduciary duties and other claims against the Trustees on behalf of the beneficiaries. RNR Production Land and Cattle ("RNR") also filed its own petition on October 28, 2016, which asserted similar claims against the Trustees as the Ad Litem had asserted. Two other unitholders, Albert and Joyce Speisman ("Speismans" and, together with the Ad Litem and RNR, the

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(5) Probate Proceeding (Continued)

"Plaintiffs") also filed a counterclaim on November 15, 2016, adopting the claims of the Realigned Petition.

On December 13, 2016, all parties in the Remaining Matters attended a mediation. As a result of the mediation, the Individuals Trustees, and former individual trustee Daniel O. Conwill IV (collectively, the "Settling Individual Trustees") agreed to a settlement of the Remaining Matters and a Settlement Agreement (the "Individual Trustees Settlement Agreement") was entered into effective January 17, 2017, among the Settling Individual Trustees, the Ad Litem, RNR, and the Speismans. The Corporate Trustee was not a party to the Individual Trustees Settlement Agreement. The Individual Trustees Settlement Agreement requires a payment on behalf of the Settling Individual Trustees of $2 million, which will be funded by an existing director and officer insurance policy, into a special fund to be administered by a person or entity appointed by the Court as administrator ("Administrator"). The special fund will be used as the Court orders and approves, including the payment of the Plaintiffs' attorneys' fees and expenses, the fees and expenses of the Administrator, and the remainder, if any, distributed to Unit holders and/or former Unit holders of the Trust according to a procedure as approved by the Court. Subject to the Individual Trustees Settlement Agreement being approved by the Court and the proposed final judgment being entered, all claims of the Plaintiffs against the Settling Individual Trustees relating in any way to the Trust, and all claims of any type that were brought or could have been brought by any current or former Unit holders of the Trust against the Settling Individuals Trustees relating in any way to the Trust, will be released and will be dismissed with prejudice. A hearing was set for January 20, 2017 before the Court to consider all pending motions for Court approval of the Individual Trustees Settlement Agreement, the entry of a proposed final judgment dismissing with prejudice all claims against the Settling Individual Trustees (the "Individual Trustees Final Judgment"), and other related matters.

At the January 20, 2017 hearing, the Court approved the Individual Trustees Settlement Agreement. The Court also signed the Individual Trustees Final Judgment, along with an order severing the Final Judgment as to the Settling Individual Trustees, into a separate cause number. The Court also granted the Ad Litem's Motion to Establish the TEL Offshore Trust Qualified Settlement Fund (the "QSF") and to Appoint Trustee and Administrator. According to the terms of the Individual Trustees Settlement Agreement, the Settling Individual Trustees (funded by an existing director and officer insurance policy) paid $2.0 million into the QSF.

On December 30, 2016, the Court entered an order that the Corporate Trustee had breached its fiduciary duties by paying itself compensation in violation of the Trust Agreement. The Court further found that the breach was intentional and a clear and serious breach. The Corporate Trustee believes that such ruling is legally improper.

On April 18, 2017, the Corporate Trustee, the Ad Litem, RNR and the Speismans attended a mediation. As a result of the mediation, the Corporate Trustee has agreed to a settlement of all claims asserted against the Corporate Trustee pursuant to a Mediation Settlement Agreement (the "Mediation Settlement Agreement") that was signed April 18, 2017 among the Corporate Trustee, the Ad Litem,

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(45) ~~Distributions~~Probate toProceeding ~~Unit Holders~~ (Continued)

~~used~~RNR toand ~~pay certain expenses of~~ the adSpeismans. ~~litem~~While in the ~~Probate~~Mediation ~~Proceeding.~~Settlement ~~The~~Agreement ~~Trust~~is ~~will~~binding, ~~not make any distribution of these funds to Unit holders until~~ it ~~receives~~contemplates athat ~~subsequent order from~~ the ~~Court~~parties ~~or the~~will ~~Remaining~~enter ~~Matters~~into ~~are~~a ~~otherwise~~formal ~~settled.~~compromise Inand ~~addition,~~settlement ~~the~~agreement ~~Trust~~reflecting ~~may refrain from making any distribution of such proceeds until after~~ the ~~expiration~~terms of the Mediation ~~audit~~Settlement ~~period~~Agreement ~~provided~~and providing for indismissal ~~the conveyance~~with ~~document~~prejudice ~~for~~of the ~~2016~~Remaining ~~Royalty Sale, which expires on December 24, 2016~~Matters.

On May 5, 2017, the Ad Litem filed a Motion for Leave to Amend Petition to file its Third Amended Petition as Realigned Plaintiff, and the Corporate Trustee filed a Motion for Leave to File Its Amended Counterclaim for Modification and Termination of Trust as to Attorney Ad Litem, RNR, and the Speismans. The petitions request that the Trust Agreement be modified to (i) allow the Trust to be terminated on a date to be established by the Court, and (ii) establish a Trust termination date, which shall also serve as the record date, at which time the Trust's transfer agent will close the transfer books of the Trust and thereafter no further transfers or transactions in the Trust's units will be registered or effected. The Ad Litem also filed a Motion to Approve Allocation Agreement. The Allocation Agreement is an agreement among the Ad Litem, RNR and the Speismans that sets forth terms for the distribution of the QSF and provides that 20% ~~(5)~~of ~~Special~~the ~~Cost~~QSF ~~Escrow~~shall ~~Account~~ be distributed among unit holders as of a date in 2014 to be approved by the Court and the remainder will be distributed among unit holders as of the Trust termination date as approved by the Court. The Corporate Trustee is not a party to the Allocation Agreement.

~~The~~On May 15, ~~Special~~2017, ~~Cost~~the ~~Escrow~~Corporate isTrustee, anthe ~~account~~Ad ofLitem, ~~the~~RNR ~~Working~~and ~~Interest~~the ~~Owners,~~Speismans ~~and~~entered itinto isa ~~described~~Settlement ~~herein~~Agreement ~~for~~(the ~~informational~~"Corporate ~~purposes~~Trustee ~~only~~Settlement Agreement"). The ~~Conveyance~~Corporate Trustee ~~provides~~Settlement ~~for~~Agreement ~~reserving~~requires ~~funds~~a ~~for estimated~~payment ~~future~~by the Corporate Trustee of $4 million into the QSF on a date (the "~~Special~~Settlement ~~Costs~~Payment Date") ofwithin ~~plugging~~five ~~and~~business ~~abandoning~~days ~~wells,~~after ~~dismantling~~(i) the approval ~~platforms~~of the settlement by the Court and ~~other~~the ~~costs~~entry of ~~abandoning~~a proposed final judgment (the ~~Royalty~~"Proposed ~~Properties~~CT Final Judgment") dismissing with prejudice all claims against the Corporate Trustee, as ~~well~~more particularly asdescribed ~~for~~below, and (ii) the ~~estimated~~expiration ~~amount~~ of ~~future~~the ~~drilling projects~~time for appeal and ~~other~~exhaustion ~~capital~~of ~~expenditures~~all appeals. At the hearing held on May 15, 2017, the ~~Royalty~~Court ~~Properties~~approved the settlement, the Corporate Trustee Settlement Agreement and the Proposed CT Final Judgment. ~~Deposits~~The Corporate Trustee Settlement Agreement also requires the Corporate Trustee to transfer into ~~this~~the QSF all funds remaining in the segregated account ~~reduce~~on ~~current~~the ~~distributions~~Settlement Payment Date. Once the settlement payment and ~~are~~any ~~placed~~remaining funds in anthe ~~escrow~~segregated account are paid to the QSF and ~~invested~~the inCorporate ~~short-term~~Trustee ~~certificates~~has performed ofcertain ~~deposit.~~other ~~Such~~obligations ~~account~~under isthe ~~herein~~Corporate ~~referred~~Trustee toSettlement asAgreement, the ~~"Special~~Corporate ~~Cost~~Trustee ~~Escrow"~~shall ~~account.~~have Asno further obligations or duties under the Trust Agreement and any Unit holder's sole rights by virtue of ~~September 30,~~their ~~2016,~~status ~~$1,000~~as ~~remained~~a inUnit ~~the~~holder ~~Special~~or ~~Cost~~a ~~Escrow~~former ~~account.~~Unit ~~The~~holder ~~funds~~shall ~~held~~be intheir right to receive any distribution from the ~~Special Cost~~QSF. ~~Escrow~~The ~~account~~QSF ~~are~~will ~~not~~be ~~reflected~~used inas the ~~condensed~~Court ~~financial~~orders ~~statements~~and ofapproves, including the ~~Trust.~~payment ~~All~~ of the ~~Partnership~~Plaintiff's ~~rights~~attorneys' fees and ~~obligations~~expenses, ~~with~~the ~~respect~~fees toand expenses of the ~~Special~~Administrator, ~~Cost~~and ~~Escrow~~the ~~were~~remainder, ~~assigned~~if inany, distributed to Unit holders according to the Allocation ~~connection~~Agreement ~~with~~entered into among the ~~Royalty~~Plaintiffs ~~Sales~~allocating the proceeds of the QSF, subject to the approval of the Court.

Historically, the Trust generally maintained a cash reserve, equal to approximately three times the average annual expenses of the Trust during each of the then past three years, to provide for future administrative expenses in connection with the winding up of the Trust. However, as a result of the damage inflicted upon certain of the Royalty Properties by Hurricane Ike in September 2008, the Trust has not received sufficient Net Proceeds to maintain the reserve at such level. As of September 30, 2016 and December 31, 2015 the reserve amount was $0.

During the first quarter of 2016, the Trust received Royalty income of $713 attributable to Eugene Island 342. On April 15, 2016, but effective as of August 1, 2015, Chevron conveyed certain oil and gas properties to Cox Oil, including Chevron's interest in Ship Shoal 182/183 that was subject to the Royalty (the "Cox Oil Sale"). Any Net Proceeds from Cox Oil attributable to Ship Shoal 182/183 are not subject to offset by Chevron against the undistributed net loss carry forward attributable to the Royalty Properties held by Chevron. As a result of the August 1, 2015 effective time and the Ship Shoal 182/183 properties not being subject to the undistributed net loss carry forward, the Trust received a distribution from Cox Oil of $116,429 in May 2016. The Trust also received net proceeds of $1,756,624 from the 2016 Royalty Sale; however, the net proceeds from the 2016 Royalty Sale are not available to the Trust for the payment of costs and expenses pending the resolution of the Probate Proceeding. In addition, the remaining proceeds received as a result of the Cox Oil Sale are also being separately withheld and are not available to the Trust for the payment of costs and expenses unless approved by the ad litem pending the resolution of the Probable Proceeding. As a result of the 2016 Royalty Sale, the Trust will not receive any further Net Proceeds from the Royalty Properties. As of

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(65) ~~Reserve For Future Trust Expenses;~~ Probate Proceeding (Continued)

~~September 30~~assigns, ~~2016,~~except ~~including~~for ~~the~~any ~~proceeds~~claims arising from debts or extensions of credit by and between the ~~2015~~Corporate ~~Note~~Trustee ~~(as~~and ~~defined~~the ~~below)~~Plaintiffs, their agents, representatives, counsel, insurers, heirs, successors and ~~additional~~assigns ~~cash~~or ~~advances~~any Unit holders, unrelated to the Trust's ~~available~~or ~~cash~~the ~~was~~Probate ~~approximately $22,230~~Proceeding. ~~Based~~The ~~upon~~Court ~~currently estimated~~has ~~expenditures,~~previously ~~inclusive~~ruled ofthat all damages payable by the ~~costs~~Corporate ~~and~~Trustee ~~expenses~~shall ~~relating~~be tofor the benefit of all Unit holders not just those who have sued in the Probate Proceeding,. itThe isCorporate ~~anticipated~~Trustee Settlement Agreement provides that the ~~Trust's~~Corporate ~~available~~Trustee ~~cash~~is ~~will~~settling beall ~~depleted~~such ~~during~~claims ~~the~~and ~~fourth~~all ~~quarter~~such ofclaims ~~2016.~~are ~~Following~~released ~~the~~by ~~depletion~~virtue of the ~~Trust's~~Corporate ~~available~~Trustee ~~cash,~~Settlement Agreement and the ~~Trustees~~Proposed ~~will~~CT ~~endeavor~~Final Judgment to ~~cause~~be ~~the~~entered ~~Trust~~pursuant tothereto. ~~pay~~The Corporate Trustee, in return, releases all claims against the ~~administrative~~Ad Litem, ~~costs~~RNR, the Speismans, their agents, representatives, counsel, insurers, heirs, successors and assigns, and all current and former Unit holders, except for any claims arising from any debts or extensions of credit by and between the Corporate Trustee and the Plaintiffs, their agents, representatives, counsel, insurers, heirs, successors and assigns or any Unit holders, unrelated to the Trust inor ~~accordance~~the ~~with~~Probate Proceeding. The Proposed CT Final Judgment dismisses all claims released in the ~~Trust~~Corporate Trustee Settlement Agreement. ~~There~~The ~~are~~Corporate ~~no assurances~~Trustee Settlement Agreement further provides that the ~~Trust~~Corporate ~~will~~Trustee bereleases ~~able~~any toclaims ~~continue~~for the repayment of loans or other extensions of credit to ~~pay~~the ~~its~~Trust ~~administrative~~by ~~expenses~~the Corporate Trustee or any affiliate thereof and further provides that the Corporate Trustee shall withdraw any application or claim for payment of funds out of the QSF or the segregated account maintained by the Trust.

~~Pursuant~~The toCorporate Trustee Settlement Agreement and the ~~terms~~Proposed ofCT Final Judgment provide for certain modifications to the Trust Agreement, including the ~~Trustees~~termination ~~are~~of ~~authorized~~the toTrust. ~~borrow~~The Proposed ~~funds,~~CT ~~and~~Final ~~pledge~~Judgment provides that the ~~assets~~Trust ofshall terminate at 5:00 p.m. Eastern Daylight Saving Time on June 30, 2017 (the ~~Trust~~"Record toDate ~~secure~~and ~~payments~~Time"); ofprovided such ~~borrowings,~~date will be delayed in the event ~~that cash~~an onappeal ~~hand~~ is ~~not~~filed ~~sufficient~~and tomay ~~pay~~be ~~the~~delayed ~~liabilities~~upon request of the ~~Trust.~~Ad InLitem or the ~~event~~Corporate ~~that~~Trustee ~~the~~if ~~Trustees~~necessary. ~~borrow~~Upon ~~funds~~the toRecord ~~pay~~Date ~~the~~and ~~liabilities~~Time, all rights of Unit holders in and under the Trust, noAgreement ~~distributions~~shall ~~may~~terminate beand ~~made~~all Units and any beneficial interests therein shall cease to ~~the~~exist. ~~Unit~~The ~~holders until~~Proposed CT Final Judgment provides that as of the ~~indebtedness~~Record ~~created~~Date byand ~~such~~Time ~~borrowings~~each ~~has~~Unit holder ~~been~~shall ~~paid~~be inlimited ~~full.~~to Asits ~~discussed~~rights inwith ~~Note 9,~~respect to the ~~Trustees~~QSF. ~~borrowed,~~The ~~and~~Proposed ~~may~~CT inFinal Judgment further provides that the ~~future~~Trust's ~~borrow,~~transfer ~~funds~~books ~~from~~will ~~which~~be aclosed ~~portion~~and that trading of ~~the~~Units ~~proceeds~~shall not be ~~were,~~permitted orafter ~~may~~the ~~be,~~Settlement ~~used~~Payment toDate ~~pay~~and ~~for~~the Trust's ~~expenses~~transfer agent will stop processing any Unit transfers as of the Record Date and Time.

The ~~Trust~~Corporate Trustee Settlement Agreement ~~further~~was ~~provides~~conditioned ~~that~~upon Court approval. A hearing was held on May 15, if2017 ~~necessary~~before the Court to ~~provide~~consider ~~for~~all ~~the~~pending ~~payment~~motions for approval of the ~~specific~~Corporate ~~liabilities~~Trustee ofSettlement Agreement, the ~~Trust~~Proposed ~~then~~CT ~~due~~Final Judgment, the ~~Trustees~~modification ~~may~~of ~~without~~the aTrust ~~vote~~Agreement and termination of the ~~Unit~~Trust, ~~holders (a) sell~~and ~~all~~the orAllocation aAgreement ~~portion~~previously ofexecuted by the ~~Trust's~~Ad ~~interest~~Litem, inRNR and the ~~Partnership~~Speisman orproviding ~~any~~for ~~other~~the ~~assets~~distribution of the ~~Trust~~QSF. ~~for~~At ~~such~~the ~~cash~~hearing, ~~consideration~~the asCourt approved the ~~Trustees~~Corporate ~~shall~~Trustee ~~deem~~Settlement ~~appropriate~~Agreement, ~~(b) exercise their~~the ~~rights~~Proposed ~~under~~CT Final Judgment, the modification ~~Partnership~~of the Trust Agreement toand ~~dissolve~~the termination of the ~~Partnership,~~Trust. orThe ~~(c) cause~~Court adid ~~sale~~not byapprove the ~~Partnership~~Allocation ofAgreement ~~the~~and ~~overriding~~it ~~royalty~~will ~~interest~~be ~~owned~~considered byat ~~the~~a ~~Partnership~~subsequent hearing.

In connection with the 2011 Royalty Sale, the Trust received from the Partnership a distribution of approximately $1,485,851 and used such net proceeds solely for the payment of expenses of the Trust. In connection with the 2013 Royalty Sale, the Trust received from the Partnership a distribution of approximately $1,151,885 and used approximately $300,000 of the net proceeds received in October 2013 to repay the Trust's indebtedness under a previous note payable to BONYM and used the remaining net proceeds solely for the payment of expenses of the Trust. See Note 3 for more information about the Royalty Sales.

In March 2014, the Trustees unanimously determined to suspend future payments of fees to the Trustees effective as of January 1, 2014, until a date to be determined in the future by the Trustees. As of September 30, 2016, the amount of such fees was approximately $471,470 in the aggregate. Such suspended fees will be recorded as an expense of the Trust when invoiced by the Trustees and paid.

On July 10, 2014, the Trustees filed a Petition for Modification and Termination of the Trust (the "Petition") with the Probate Court of Travis County, Texas (the "Court"). The Petition requested that the Court modify the Trust Agreement to (1) allow for the termination of the Trust by a court order, and (2) allow the Trustees, as necessary to fulfill the purposes of the Trust and without Unit holder approval to (a) sell all or any portion of the Trust's interests in the Partnership or any other assets of the Trust, (b) exercise their rights to dissolve the Partnership, or (c) cause the Partnership to sell the Royalty. The goals in filing such probate proceeding (the "Probate Proceeding") were to permit the

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(6) ~~Reserve~~Federal ~~For~~Income ~~Future~~Tax ~~Trust Expenses; Probate Proceeding (Continued)~~ Matters

Trustees to direct the Partnership to sell the Royalty; to distribute the net proceeds resulting from such sale, after payment of the Trust's liabilities, to the Unit holders; and, to, thereafter terminate the Partnership and the Trust. The Trust has completed the process of serving the Petition on the Trust's Unit holders. The Court appointed an attorney ad litem to represent any Unit holders that were not personally served. The Court appointed attorney ad litem filed a Counterclaim against the Trust on November 16, 2015 requesting (1) an order to sell all of the Royalty, and (2) an accounting of the general and administrative expenses of the Trust from 2008 through the present.

The Probate Proceeding was set for trial on January 15, 2016. Prior to trial, the attorney ad litem filed a Motion to Sever asking the Court to sever all matters related to the requested modification of the Trust and the sale of Trust assets, as plead for, in part, in the petition originally filed by the Trustees and in the attorney ad litem's Counterclaim, into a separate cause to proceed to trial. The attorney ad litem also filed a Motion for Continuance requesting that the Court continue the trial of all remaining matters, including the attorney ad litem's request for an accounting and the issues concerning the termination of the Trust, to a later date (the "Remaining Matters"). Prior to calling the case to trial, the Court granted the attorney ad litem's Motion to Sever and Motion for Continuance, severed the matters related to the modification of the Trust and the sale of Trust assets ("Severed Proceeding"), and continued the Remaining Matters to a later date. The Severed Proceeding has been assigned Cause No. C-1-PB-16-000096 and is styled In re: TEL Offshore Trust.

The Severed Proceeding proceeded to trial before the Court on January 15, 2016. At trial, the Court entered a Final Judgment and Order (the "Order") granting the Trustees' request that the Trust Agreement be modified to permit the Trustees to direct the Partnership to sell the remaining overriding royalty interest held by the Partnership as soon as reasonably possible and granting the ad litem's request to sell all of the Royalty, notwithstanding any requirements of the Trust Agreement to the contrary. Thereafter, the Court ordered that the Trustees direct the Partnership to sell all of the Royalty owned by the Partnership on or before May 1, 2016. On April 25, 2016, the Court approved an extension of the May 1, 2016 deadline to June 30, 2016.

On August 17, 2016, the attorney ad litem filed a Second Amended Answer and First Amended Counterclaim seeking an accounting and asserting, among other causes of action, that the Trustees have breached their fiduciary duties to the beneficiaries of the Trust. The Remaining Matters were originally set for trial on November 7, 2016. Trustees filed a motion for continuance of the Remaining Matters and a hearing for such continuance occurred on September 14, 2016. At the hearing, the Court granted the Trustees' motion for continuance of the Remaining Matters and scheduled the trial for June 12, 2017. There can be no assurances as to the outcome of the Remaining Matters and whether the Court will grant the requested relief, and if such relief is granted, when such actions will be completed.

On June 27, 2016, the Trust issued a press release announcing that the Partnership had consummated the 2016 Royalty Sale on June 24, 2016. The sale was made in accordance with the Order pursuant to which the Court ordered that the Trustees of the Trust direct the Partnership to sell all of the royalty interests owned by the Partnership. In connection with the 2016 Royalty Sale the Trust

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(6) Reserve For Future Trust Expenses; Probate Proceeding (Continued)

received a distribution of approximately $1,756.624. Due to the Remaining Matters, the Trust must hold the net proceeds in a segregated account until the Court's final resolution of the Remaining Matters. Distributions may be made from such segregated account for the payment of Trust expenses, which may include the payment of the ad litem's expenses, with the approval of the Court. Any final disposition of the remaining net proceeds will be made in accordance with the final resolution of the Remaining Matters. In addition, the Trust may refrain from making any distribution of the net proceeds received from the 2016 Royalty Sale until the expiration of the audit period provided for in the conveyance document for the 2016 Royalty Sale, which expires on December 24, 2016.

(7) Federal Income Tax Matters

The IRS has ruled that the Trust is a grantor trust and that the Partnership is a partnership for federal income tax purposes. Thus, the Trust will incur no federal income tax liability and each Unit holder will be treated as owning an interest in the Partnership.

(87) Related Party Transactions

Each of the Working Interest Owners owned interests, for its own account, in leases that were in the same area as leases in which the Partnership had previously held an interest. Such relationships may have given rise to potential conflicts of interests in, among other things, the operation of such leases and in the acquisition and operation of any drainage leases acquired by a Working Interest Owner for its own account. Additionally, the Working Interest Owners and their affiliates were not prohibited from purchasing oil and gas produced from or attributable to any leases in which the Partnership had an interest.

Crude oil sales to Chevron Corporation accounted for 0%approximately ~~and~~ 100% of crude oil and gas revenues from the Royalty Properties for the three ~~and nine~~ months ended ~~September~~March 3031, 2016. ~~and~~As ~~2015,~~a ~~respectively.~~result ~~Sales~~of tothe ~~Chevron~~2016 ~~Corporation~~Royalty ~~accounted~~Sale, ~~for~~there 0%were ~~and~~no ~~100%~~crude ofoil ~~total~~or gas revenues ~~from~~attributable ~~the~~to ~~Royalty Properties during~~ the ~~three~~Trust ~~and~~in ~~nine months ended September 30, 2016 and 2015, respectively~~2017.

The Trust's share of Royalty income was reduced by approximately $~~0 and $13,891 for each of the three months ended September 30, 2016 and September 30, 2015, respectively, and $~~11,644 ~~and $43,457~~ for ~~each of~~ the ~~nine~~three months ended ~~September~~March 3031, 2016 ~~and September 30, 2015, respectively,~~ for management fees paid to the Working Interest Owners as reimbursement for expenses incurred by them on behalf of the Trust. The aggregate amount of management fees paid to the Working Interest Owners was calculated as 3% of the Trust's share of the sum of revenues, production expenses and capital expenditures attributable to the Royalty Properties in ~~each of~~ the ~~periods above~~period.

(98) Note Payable and Cash Advances

On October 1, 2014, The Bank of New York Mellon Trust Company, N.A. made an advance to the Trust in the amount of $363,000, and the Corporate Trustee, on behalf of the Trust as the borrower, executed a Demand Promissory Note (the "2014 Note") relating to the unsecured $363,000 advance, which evidenced an extension of credit for borrowed money authorized under Section 6.08 of the Trust Agreement. The 2014 Note was mistakenly made payable to The Bank of New York Mellon ("BONYM"). In addition to the advances evidenced by the 2014 Note, The Bank of New York Mellon Trust Company, N.A., made additional cash advances in the amount of $209,885 to the Trust for the payment of its ~~capacity~~liabilities asand expenses, primarily in connection with the Probate ~~corporate~~Proceeding. ~~trustee~~On September 25, 2015, The Bank of New York Mellon Trust Company, N.A. made an additional advance to the Trust in the amount of $484,000 and the Corporate Trustee, on behalf of the Trust as the borrower, ~~entered~~executed ~~into~~ a Renewal Demand Promissory Note (the "~~2014~~2015 Note") ~~with~~relating ~~BONYM~~to (i) the unsecured $484,000 advance, (ii) the renewal and extension of the indebtedness originally evidenced by the 2014 Note in the original principal amount of $363,000, and (iii) previous advances in the amount of $209,885 made by The Bank of New York Mellon Trust Company, N.A. on behalf of the Trust. The 2015 Note provides for interest at the rate of one half percent (0.5%) per annum. The 2015 Note became due and payable on December 31, 2016 and remains outstanding. The 2015 Note was also

1312

TEL OFFSHORE TRUST

NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED) (Continued)

(98) Note Payable and Cash Advances (Continued)

~~relating~~mistakenly tomade ~~the~~payable ~~unsecured~~to ~~$363,000~~BONYM. ~~advance,~~The ~~which~~2015 ~~evidenced~~Note anhas ~~extension~~been ofassigned ~~credit~~to ~~for~~The ~~borrowed~~Bank ~~money~~of ~~authorized~~New ~~under~~York ~~Section 6.08~~Mellon ~~of the~~ Trust ~~Agreement~~Company, N.A., ~~The~~the ~~2014~~party ~~Note~~that ~~provided~~has ~~for~~made ~~interest at~~ the ~~rate~~advances ofto ~~one-half~~the ~~percent (0~~Trust.~~5%)~~ ~~per~~In ~~annum.~~addition ~~Pursuant~~ to the ~~terms~~indebtedness owing ofunder the ~~2014~~2015 Note, ~~all~~the ~~amounts~~Trust ~~outstanding~~has ~~under~~received ~~the~~through ~~2014~~December 31, ~~Note~~2016 ~~were~~advances ~~scheduled~~from toThe beBank ~~due~~of ~~and~~New ~~payable~~York inMellon ~~cash~~Trust onCompany, ~~the~~N.A. ~~earliest~~in ~~to occur~~the amount of ~~(i) the~~$68,224 ~~date~~and ~~written~~on ~~demand~~March 31, ~~for~~2017 the ~~payment~~Trust isreceived ~~made~~an byadditional ~~BONYM~~unsecured oradvance ~~(ii) December 31,~~of ~~2015~~$184,751.55 from The ~~Trust~~Bank ~~could~~of ~~prepay~~New ~~any~~York Mellon ~~outstanding~~Trust ~~principal~~Company, ~~and~~N.A. ~~accrued~~During ~~and~~the ~~unpaid~~year ~~interest~~ended ~~under the~~December 31, ~~2014 Note~~2016, ina ~~whole~~portion orof inthe ~~part~~proceeds from the 2015 Note, atwere ~~any~~used ~~time~~to ~~without~~pay ~~penalty~~Trust expenses. In addition to the ~~2014~~2015 Note, ~~through~~the ~~September 25,~~Corporate Trustee ~~2015,~~used ~~BONYM~~the ~~made~~ additional ~~cash~~ advances received in ~~the~~2016 ~~amount~~and of2017 ~~$209,885 to the Trust~~ for the payment of its liabilities and expenses, ~~primarily~~including those incurred in connection with the Probate Proceeding.

OnPursuant ~~September 25, 2015, BONYM made an additional advance~~ to the ~~Trust~~Corporate inTrustee ~~the~~Settlement ~~amount of $484~~Agreement,~~000,~~ ~~and~~ the ~~Corporate~~ Trustee, aswaives ~~the~~any ~~borrower,~~claim ~~has~~for ~~entered~~reimbursement ~~into~~or apayment ~~Renewal~~on ~~Demand Promissory Note (~~the "2015 Note") ~~with~~and ~~BONYM, in~~ the ~~original~~additional ~~principal~~advances ~~amount~~described ofabove ~~$1,056,885~~out ~~relating to (i) the unsecured $484,000 advance, (ii) the renewal and extension~~ of ~~the~~any ~~indebtedness~~funds ~~originally~~held ~~evidenced~~ by the ~~2014~~Trust ~~Note~~ in the ~~original~~segregated ~~principal~~account ~~amount~~or ~~of $363,000, and (iii) previous advances in~~ the ~~amount~~QSF. ofIn ~~$209~~addition,~~885~~ ~~made~~the byCorporate ~~BONYM~~Trustee onagrees ~~behalf~~to ofwithdraw ~~the~~any ~~Trust.~~pending ~~The 2015~~applications ~~Note~~or ~~bears~~claims ~~interest~~for atpayment ~~the rate~~ of ~~one-half~~funds ~~percent~~out ~~(0.5%) per annum. Pursuant to the terms~~ of the ~~2015~~segregated account ~~Note,~~or ~~all amounts outstanding under~~ the ~~2015~~QSF. ~~Note,~~It ~~including~~is ~~accrued~~contemplated ~~and~~that ~~unpaid~~The ~~interest, will~~Bank ~~be due and payable in cash on the earliest to occur~~ of ~~(i) the~~New ~~date~~York ~~written~~Mellon ~~demand~~Trust ~~for payment is made by BONYM or (ii) December 31~~Company, ~~2016~~N. ~~In addition~~A., ~~the~~will ~~accrued~~either ~~and~~advance ~~unpaid interest~~funds ~~remaining~~to ~~due from~~ the ~~2014~~Trust ~~Note~~for in the ~~amount of $1,790 is due and payable concurrently with the~~ payment of ~~the 2015 Note. The~~ Trust ~~may~~expenses ~~prepay~~incurred ~~any~~in ~~outstanding~~the ~~principal~~ordinary ~~and~~course ~~accrued and~~of ~~unpaid~~business ~~interest~~for ~~under~~which the ~~2015~~Trust ~~Note,~~is incontractually ~~whole~~obligated orto inpay ~~part,~~or atpay ~~any~~such ~~time~~expenses ~~without penalty~~directly.

In addition to the 2015 Note, through September 30, 2016, BONYM has made additional advances in the amount of $68,224 to the Trust for the payment of its liabilities and expenses, primarily in connection with the Probate Proceeding. 13

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

Overview

The TEL Offshore Trust, which we refer to herein as the "Trust," was created under the laws of the State of Texas in 1983 and maintains its offices at the office of The Bank of New York Mellon Trust Company, N.A., whom we refer to as the "Corporate Trustee," 919 Congress Avenue, Suite 500, Austin, Texas 78701. The telephone number of the Corporate Trustee is (512) 236-6599. Gary C. Evans, Thomas H. Owen, Jr. and Jeffrey S. Swanson serve as individual trustees of the Trust and are referred to herein as the "Individual Trustees." The Individual Trustees tendered their resignations on January 17, 2017 and ~~the~~such ~~Corporate~~resignations ~~Trustee~~will ~~may~~become beeffective, ~~referred~~subject to ~~hereinafter~~any ~~collectively~~earlier astermination of the ~~"Trustees~~Trust, on September 1, 2017."

The Individual Trustees and the Corporate Trustee may be referred to hereinafter collectively as the "Trustees."

The Corporate Trustee does not maintain a website for filings by the Trust with the U.S. Securities and Exchange Commission, which we refer to herein as the "SEC." Electronic filings by the Trust with the SEC are available free of charge through the SEC's website at www.sec.gov. The Trust will also provide paper copies of its recent filing free upon request to the Corporate Trustee.

The principal asset of the Trust consists of a 99.99% interest in the TEL Offshore Trust Partnership, which we refer to herein as the "Partnership." Chevron U.S.A., Inc., or "Chevron," owns the remaining .01% interest in the Partnership and is the Managing General Partner of the Partnership. Until October 27, 2011, the Partnership owned 100% of an overriding royalty interest equivalent to a 25% net profits interest (the "Original Royalty"), in certain oil and gas properties, which we refer to herein as the "Royalty Properties," located offshore Louisiana. The term "Original Royalty" shall refer to the initial 25% net profits interest in the Royalty Properties and the term "Royalty" shall refer to the applicable net profits interest held from time to time by the Partnership following the Royalty Sales (as defined below).

On June 27, 2016, the Trust issued a press release announcing that the Partnership had consummated the sale of all of its remaining interest in the Original Royalty (60% or 15% of 8/8ths) (the "2016 Royalty Sale"). The 2016 Royalty Sale ~~was made to Arena Energy, LP and~~ closed on June 24, 2016, but was effective as of February 1, 2016. Due to the effective time of the 2016 Royalty Sale, the Trust no longer had any interest in, or any operating and financial results attributable to, the Royalty or the Royalty Properties as of February 1, 2016. As a result, the Trust has not provided any additional explanation for the corresponding decreases in revenues and production under "—Three Months Ended ~~September~~March 3031, ~~2016~~2017 and ~~2015~~2016" below.

Liquidity and Capital Resources; Termination of the Trust

Prior to the sale of the remaining Royalty held by the Partnership in June 2016, the Trust's primary source of liquidity and capital had been the Royalty income received from its share of the Net Proceeds from the Royalty Properties. Generally, "Net Proceeds" means the amounts received by the owner or owners of the Royalty Properties (the "Working Interest Owners") from the sale of minerals from the Royalty Properties less operating and capital costs incurred, management fees and expense reimbursements owing to the Managing General Partner of the Partnership, applicable taxes other than income taxes, and the Special Cost Escrow account. The Special Cost Escrow account, ~~as more fully detailed in Note 5 to the condensed financial statements,~~ was established for the future costs to be incurred to plug and abandon wells, dismantle and remove platforms, pipelines and other production facilities, and for the estimated amount of future capital expenditures on the Royalty Properties. Net Proceeds did not include amounts received by the Working Interest Owners as advance gas payments,

for the future costs to be incurred to plug and abandon wells, dismantle and remove platforms, pipelines and other production facilities, and for the estimated amount of future capital expenditures on the Royalty Properties. Net Proceeds did not include amounts received by the Working Interest Owners as advance gas payments, "take- or-pay" payments or similar payments unless and until such payments were extinguished or repaid through the future delivery of gas.

During the first quarter of 2016, the Trust received Royalty income of $713 attributable to Eugene Island 342 and in the fourth quarter of 2015, the Trust received $1,316 of Royalty income attributable to Eugene Island 342. The Trust had not received any distributions of Net Proceeds from Chevron, as operator of the Royalty Properties, since December 2008. On April 15, 2016, but effective as of August 1, 2015, Chevron conveyed certain oil and gas properties to Cox Oil Offshore, L.L.C. ("Cox Oil"), including Chevron's interest in Ship Shoal 182/183 that was subject to the Royalty (the "Cox Oil Sale"). The Net Proceeds from Cox Oil attributable to Ship Shoal 182/183 were not subject to offset by Chevron against the undistributed net loss carry forward attributable to the Royalty Properties held by Chevron. As a result of the August 1, 2015 effective time and the Ship Shoal 182/183 properties not being subject to the undistributed net loss carry forward, the Trust received a distribution from Cox Oil of $116,429 in May 2016. The distribution received from Cox Oil has been set aside by the Trust and will be paid into the QSF (as defined below) upon approval of the Corporate Trustee Settlement Agreement and entry of the Proposed CT Final Judgment (each as defined below).

Because of the lack of Net Proceeds, the Trust has in the past not had sufficient cash flow to pay expenses on a current basis and as described below, the Trust has been required to borrow funds and to cause the Partnership to sell part of the Original Royalty in order to pay Trust expenses. Reference is made to Note 3 and Note 8 in the Notes to the condensed financial statements contained in Part I, Item 1 herein. As of March 31, 2017, including the proceeds from the 2015 Note (as defined in Note 3), the previous cash advances from The Bank of New York Mellon Trust Company, N.A. ("BONYM") included in the principal amount of the 2015 Note and subsequent cash advances by BONYM, the Trust's unrestricted cash was approximately $184,755 at March 31, 2017. As of May 15, 2017 the Trust's unrestricted cash has been fully depleted. While it is contemplated that The Bank of New York Mellon Trust Company, N.A. will, pending the termination of the Trust, either provide funds to the Trust for the payment of its expenses incurred in the ordinary course of business for which the Trust is contractually obligated to pay or pay such expenses directly, there are no assurances that the Trust will be able to continue to pay its administrative expenses.

As more fully addressed in Part II, Item 1—Legal Proceedings, the Corporate Trustee has entered into a Settlement Agreement (the "Corporate Trustee Settlement Agreement") with the Ad Litem, RNR and the Speismans that provides for the settlement of the Remaining Matters in the Probate Proceeding (as such terms are defined in Part II, Item 1—Legal Proceedings). The Corporate Trustee Settlement Agreement requires a payment by the Corporate Trustee of $4 million into the QSF (as defined in Part II, Item 1—Legal Proceedings) on a date (the "Settlement Payment Date") within five business days after (i) the approval of the settlement by the Court and the entry of the Proposed CT Final Judgment (as such terms are defined in Part II, Item 1—Legal Proceedings), and (ii) the expiration of the time for appeal and exhaustion of all appeals. At the hearing held on May 15, 2017, the Court approved the settlement, the Corporate Trustee Settlement Agreement and the Proposed CT Final Judgment (as such terms are defined in Part II, Item 1—Legal Proceedings). The Corporate Trustee Settlement Agreement and the Proposed CT Final Judgment also require the Corporate Trustee to transfer into the QSF all remaining funds in the segregated account on the Payment

~~"take-~~Settlement ~~or-pay"~~Date. ~~payments~~Following orthe ~~similar~~transfer ~~payments~~of ~~unless~~the ~~and~~segregated ~~until~~account ~~such~~to ~~payments~~QSF, ~~were~~the ~~extinguished~~Trust orshall ~~repaid~~have ~~through~~no further assets and the ~~future~~Corporate ~~delivery~~Trustee Settlement Agreement and Proposed CT Final Judgment provide for the termination of ~~gas~~the Trust as more fully described in Part II, Item 1—Legal Proceedings.

~~During~~The ~~the~~accompanying ~~first~~condensed ~~quarter~~financial ofstatements ~~2016,~~have ~~the~~been ~~Trust~~prepared ~~received~~assuming ~~Royalty~~that ~~income of $713 attributable to Eugene Island 342 and in~~ the ~~fourth quarter of 2015, the~~ Trust ~~received~~will ~~$1,316~~continue ofas ~~Royalty income~~a ~~attributable~~going ~~to Eugene Island 342~~concern. ~~The~~Financial ~~Trust~~statements ~~had~~prepared ~~not~~on ~~received any distributions of Net Proceeds from Chevron, as operator of~~ the ~~Royalty~~going ~~Properties,~~concern ~~since December 2008. On April 15,~~basis ~~2016,~~assume ~~but~~the ~~effective~~realization as of ~~August 1,~~assets ~~2015, Chevron conveyed certain oil~~ and ~~gas~~the ~~properties~~settlement toof ~~Cox~~liabilities ~~Oil Offshore, L.L.C. ("Cox Oil"), including Chevron's interest~~ in ~~Ship Shoal 182/183 that was subject to~~ the ~~Royalty~~normal ~~(the~~course ~~"Cox~~of ~~Oil Sale")~~business. ~~Any~~As ~~Net~~discussed ~~Proceeds~~in ~~from~~Note 5 ~~Cox Oil attributable~~ to ~~Ship Shoal 182/183 are not subject to offset by Chevron against~~ the ~~undistributed~~condensed ~~net~~financial ~~loss~~statements ~~carry~~of ~~forward attributable to~~ the ~~Royalty~~Trust ~~Properties~~in ~~held by Chevron. As a result of the August~~this Form 110-Q, ~~2015~~certain ~~effective~~conditions ~~time~~raise ~~and~~substantial ~~the~~doubt ~~Ship~~about ~~Shoal 182/183 properties not being subject to~~ the ~~undistributed net loss carry forward, the~~ Trust's ~~was~~ability ~~entitled~~ to ~~receive~~continue as a ~~distribution~~going ~~from Cox Oil of $116,429~~concern. The ~~Trust~~Trustees' ~~received~~plans ~~the~~concerning ~~distribution~~this inmatter ~~May~~are ~~2016~~also ~~and~~discussed asin aNote 5 ~~result, the undistributed net loss carry forward attributable~~ to the ~~Royalty~~condensed ~~Properties~~financial ~~increased~~statements ~~by $116,429 from $524,335, as~~ of ~~January 31, 2016, to $640,764. Despite~~ the ~~receipt of such funds, as long as the~~ Trust ~~has~~in ~~outstanding indebtedness,~~this noForm 10-Q. ~~distributions~~The ~~may~~condensed befinancial ~~made~~statements bydo ~~the~~not ~~Trust~~include toany ~~the~~adjustments ~~Unit~~that ~~holders.~~might ~~As a~~ result offrom the ~~2016~~outcome ~~Royalty~~of ~~Sale,~~this ~~the~~uncertainty. ~~Trust~~See Note 2 ~~will~~to ~~not receive any further Net Proceeds from~~ the ~~Royalty~~condensed ~~Properties~~financial statements.

~~Because~~ ~~of the lack of Net Proceeds, the Trust has in the past not had sufficient cash flow to pay expenses on a current basis and as described below, the Trust has been required to~~ ~~borrow funds and to cause the Partnership to sell part of the Original Royalty in order to pay Trust expenses. As of September 30, 2016, including the proceeds from the 2015 Note (as herein~~ ~~defined), the previous cash advances from The Bank of New York Mellon ("BONYM") included in the principal amount of the 2015 Note and subsequent cash advances by BONYM, the Trust's unrestricted cash~~ ~~was~~ Three ~~approximately~~Months ~~$22,230.~~Ended ~~Based upon currently estimated expenditures~~March 31, ~~inclusive~~2017 ~~of the costs~~ and ~~expenses relating to the Probate Proceeding (as defined below), it is anticipated that the Trust's available cash will be depleted in the fourth quarter of~~ 2016. Following the depletion of the Trust's available cash, the Trustees will endeavor to cause the Trust to pay the administrative costs of the Trust in accordance with the Trust Agreement. There are no assurances that the Trust will be able to continue to pay its administrative expenses.

The Trust Agreement provides that, if necessary to provide for the payment of specific liabilities of the Trust then due, the Trustees may without a vote of the Unit holders (a) sell all or a portion of the Trust's interest in the Partnership or any other assets of the Trust for such cash consideration as the Trustees shall deem appropriate, (b) exercise their rights under the Partnership Agreement to dissolve the Partnership, or (c) cause a sale by the Partnership of the overriding royalty interest owned by the Partnership. Additionally, the Trustees, on behalf of the Trust, were authorized to borrow funds, and pledge the assets of the Trust to secure payments of such borrowings, in the event that cash on hand was not sufficient to pay the liabilities of the Trust. In the event that the Trustees borrows funds to pay the liabilities of the Trust, no distributions will be made to the Unit holders until the indebtedness created by such borrowings has been paid in full.

On October 27, 2011, the Trust issued a press release announcing that the Partnership had consummated the sale (the "2011 Royalty Sale") of 20% of the Original Royalty (or 5% of 8/8ths), which generated $1,600,000 in gross proceeds and occurred as part of a formal auction process for the Partnership's overriding royalty interest in the Royalty Properties. The Trust received from the

Partnership a distribution of approximately $1,485,851, representing 99.99% of the net proceeds from the sale of $1,486,000. The 2011 Royalty Sale was made to RNR Production, Land and Cattle Company, Inc. ("RNR Production") on October 27, 2011, though the assignment was effective as of August 1, 2011.

On October 31, 2013, the Trust issued a press release announcing that the Partnership had consummated the sale (the "2013 Royalty Sale") of 25% of its remaining interest in the Original Royalty (or 5% of 8/8ths), which generated $1,200,000 in gross proceeds and occurred as part of a formal auction process for the Partnership's remaining overriding royalty interest in the Royalty Properties. The Trust received from the Partnership a distribution of approximately $1,151,885, representing 99.99% of the net proceeds from the sale of $1,152,000. The 2013 Royalty Sale was made to RNR Production on October 31, 2013, though the assignment was effective as of August 1, 2013. The Trust used approximately $300,000 of the net proceeds received in October 2013 to repay the Trust's indebtedness under a previous note payable to BONYM and used the remaining net proceeds solely for the payment of expenses of the Trust.

In March 2014, the Trustees unanimously determined to suspend future payments of fees to the Trustees effective as of January 1, 2014, until a date to be determined in the future by the Trustees. As of September 30, 2016, the accumulated amount of such suspended fees was approximately $414,918 in the aggregate. The cumulative suspended fees will be recorded as an expense of the Trust when invoiced by the Trustees and paid.

On October 1, 2014, BONYM made a loan to the Trust in the amount of $363,000, and the Corporate Trustee, as the borrower, entered into a Demand Promissory Note (the "2014 Note") with BONYM, as lender, relating to the unsecured $363,000 advance, which evidenced an extension of credit for borrowed money authorized under Section 6.08 of the Trust Agreement. On September 25, 2015, BONYM made an additional advance to the Trust in the amount of $484,000 and the Corporate Trustee, as the borrower, entered into a Renewal Demand Promissory Note (the "2015 Note") with BONYM, as lender, relating to (i) the unsecured $484,000 advance, (ii) the renewal and extension of the 2014 Note, and (iii) previous advances in the amount of $209,885 made by BONYM on behalf of the Trust. The 2015 Note bears interest at the rate of one-half percent (0.5%) per annum. Pursuant to the terms of the 2015 Note, all amounts outstanding under the 2015 Note including accrued and unpaid interest will be due and payable in cash on the earliest to occur of (x) the date written demand for payment is made by BONYM or (y) December 31, 2016. The Trust may prepay any outstanding principal and accrued and unpaid interest under the 2015 Note, in whole or in part, at any time without penalty. In addition, the accrued and unpaid interest remaining due from the 2014 Note in the amount of $1,790 is due and payable concurrently with the payment of the 2015 Note. During the three months ended September 30, 2016, a portion of the proceeds from the 2014 Note, as renewed and extended by the 2015 Note, were used to pay Trust expenses.

As indicated above, the Trustees have previously authorized the Trust to borrow funds and the Partnership to sell portions of the Original Royalty in an effort to pay the ongoing costs and expenses incurred by the Trust in fulfilling its obligations under the Trust Agreement. As a result of the ongoing costs and expenses of the Trust and the lack of any distributions or assurances of future distributions, on July 10, 2014, the Trustees filed a Petition for Modification and Termination of the Trust (the "Petition") with the Probate Court of Travis County, Texas (the "Court"). The Petition requested that the Court modify the Trust Agreement to (1) allow for the termination of the Trust by a court order, and (2) allow the Trustees, as necessary to fulfill the purposes of the Trust and without Unit holder

approval to (a) sell all or any portion of the Trust's interests in the Partnership or any other assets of the Trust, (b) exercise their rights to dissolve the Partnership, or (c) cause the Partnership to sell the Royalty. The goals in filing such probate proceeding (the "Probate Proceeding") were to permit the Trustees to direct the Partnership to sell the Royalty; to distribute the net proceeds resulting from such sale, after payment of the Trust's liabilities, to the Unit holders; and, to, thereafter terminate the Partnership and the Trust. The Trust has completed the process of serving the Petition on the Trust's Unit holders. The Court appointed an attorney ad litem to represent any Unit holders that were not personally served. The Court appointed attorney ad litem filed a Counterclaim against the Trust on November 16, 2015 requesting (1) an order to sell all of the Royalty, and (2) an accounting of the general and administrative expenses of the Trust from 2008 through the present.

The Severed Proceeding proceeded to trial before the Court on January 15, 2016. At trial, the Court entered a Final Judgment and Order (the "Order") granting the Trustees' request that the Trust Agreement be modified to permit the Trustees to direct the Partnership to sell the remaining overriding royalty interest held by the Partnership as soon as reasonably possible and granting the ad litem's request to sell all of the Royalty, notwithstanding any requirements of the Trust Agreement to the contrary. Thereafter, the Court ordered that the Trustees direct the Partnership to sell all of the Royalty owned by the Partnership through a sale to be conducted by EnergyNet.com, Inc. on or before May 1, 2016. On April 25, 2016, the Court approved an extension of the May 1, 2016 deadline to June 30, 2016.

On June 27, 2016, the Trust issued a press release announcing that the Partnership had consummated the 2016 Royalty Sale (the 2016 Royalty Sale, together with the 2011 Royalty Sale and the 2013 Royalty Sale, the "Royalty Sales"). The sale was made in accordance with the Order pursuant to which the Court ordered that the Trustees of the Trust direct the Partnership to sell all of the royalty interests owned by the Partnership.

The 2016 Royalty Sale was made to Arena Energy, LP and closed on June 24, 2016, but was effective as of February 1, 2016. The 2016 Royalty Sale generated $1,830,000 in gross proceeds and occurred as part of the previously announced formal auction process for the overriding royalty interest. The Trust received a distribution of approximately $1,756.624, representing 99.99% of the net proceeds from the Royalty Sale of $1,756,800. Due to the Remaining Matters, the Trust must hold the net proceeds in a segregated account until the Court's final resolution of the Remaining Matters. The disposition of such net proceeds will be made in accordance with the final resolution of the Remaining Matters. In addition, the Trust may refrain from making any distribution of the net proceeds received from the 2016 Royalty Sale until the expiration of the audit period provided for in the conveyance document for the 2016 Royalty Sale, which expires on December 24, 2016.

As a result of the 2016 Royalty Sale, the Trust no longer owns any interest in the Royalty and therefore will not receive any further distributions of Net Proceeds. Because of the Remaining Matters in the Probate Proceeding, the Trust must hold the net proceeds from the 2016 Royalty Sale in a segregated account until the final resolution of the Remaining Matters. In addition, the Trust has set aside the distribution received from Cox Oil until the final resolution of the Remaining Matters. Distributions may be made from such segregated account for the payment of Trust expenses, which may include the payment of the ad litem's expenses, with the approval of the Court. Any final disposition of the remaining net proceeds to Unit holders will be made in accordance with the final resolution of the Remaining Matters. As discussed above, as of September 30, 2016, including the proceeds from the 2015 Note and subsequent cash advances by BONYM, the Trust's unrestricted cash was $22,230. Based upon currently estimated expenditures, inclusive of the costs and expenses of the Probate Proceeding, it is anticipated that the Trust's available cash will be depleted during the fourth quarter of 2016. Following the depletion of the Trust's available cash, the Trustees will endeavor to cause the Trust to pay the administrative costs of the Trust in accordance with the Trust Agreement. There are no assurances that the Trust will be able to continue to pay its administrative expenses.

The accompanying condensed financial statements have been prepared assuming that the Trust will continue as a going concern. Financial statements prepared on the going concern basis assume the realization of assets and the settlement of liabilities in the normal course of business. Because of the 2016 Royalty Sale, the Trust will not receive any further Net Proceeds from the Royalty Properties. The Trust currently holds the net proceeds from the 2016 Royalty Sale and remaining proceeds received as a result of the Cox Oil Sale, a portion of such proceeds having been used to pay certain expenses of the ad litem in the Probate Proceeding. The Trust will not make any distribution of these funds to Unit holders until it receives a subsequent order from the Court or the Remaining Matters are otherwise settled. In addition, the Trust may refrain from making any distribution of such proceeds until after the expiration of the audit period provided for in the conveyance document for the 2016 Royalty Sale, which expires on December 24, 2016. The lack of Net Proceeds and the inability to maintain adequate cash reserves raise substantial doubt about the Trust's ability to continue as a going concern. The condensed financial statements do not include any adjustments that might result from the outcome of this uncertainty. See Note 2 to the condensed financial statements.

Special Cost Escrow Account

The special cost escrow account is an account of the Working Interest Owners and it is described herein for informational purposes only. The Conveyance provides for the reserve of funds for estimated future "Special Costs" of plugging and abandoning wells, dismantling platforms and other costs of

abandoning the Royalty Properties, as well as for the estimated amount of future drilling projects and other capital expenditures on the Royalty Properties. Deposits into this account reduces current distributions and are placed in an escrow account and invested in short-term certificates of deposit. Such account is herein referred to as the "Special Cost Escrow" account. All of the Partnership's rights and obligations with respect to the Special Cost Escrow were assigned in connection with the Royalty Sales.

Three Months Ended September 30, 2016 and 2015

Royalty Trust Comparison

Royalty income was $0 and $713 for each of the three months ended ~~September~~March 3031, ~~2016~~2017 and ~~2015~~2016, respectively. As a result of the Royalty Sale, there were no gross proceeds for the underlying Royalty Properties attributable to the Trust for the production period of ~~May,~~November ~~June~~ and ~~July~~December 2016 and January 2017 attributable to the three months ~~ended~~ ~~September~~ended March 3031, ~~2016~~2017. Gross proceeds for the underlying Royalty Properties exceeded development and production costs by $~~326~~1,~~576~~094,037, or $~~195~~164,~~946~~105 attributable to the Trust, for the production ~~period~~ period of ~~May,~~November ~~June~~ and ~~July~~December 2015 and January 2016 attributable to the three months ended ~~September~~March 3031, ~~2015~~2016. ~~The~~For the three months ended March 31, 2016, the Net Proceeds were applied to reduce the accumulated excess cost carry forward, which represents the amount by which the aggregate development and production costs for the Royalty Properties since November 2008 have exceeded the related proceeds of the protection,. ~~and~~As as a result of such application, there was no ~~royalty~~ distributable income for the ~~quarter~~three months ended ~~September~~March 3031, ~~2015~~2016.

General and administrative expenses for the Trust were $~~153~~354,~~757~~794 for the three months ended ~~September~~March 3031, ~~2016~~2017 compared to $96142,~~765~~869 for the three months ended ~~September~~March 3031, ~~2015.~~ 2016. The increase is due, in part, to the ~~costs~~timing ~~associated~~of ~~with~~the recording of expenses and expenses incurred in the Probate Proceeding.

~~The~~For ~~reserve~~the ~~for~~three ~~future~~months ended March 31, 2017 and March 31, 2016, the Trust ~~expenses~~had ~~did~~undistributed ~~not~~net ~~change~~income ~~from~~of ~~December 31~~$0 and $164,105, ~~2015~~respectively, torepresenting ~~September~~the Trust's portion of the undistributed net income of $0 and $1,094,037 associated with the Royalty Properties for the three months ended March 3031, 2017 and 2016. The undistributed net income was applied to reduce the accumulated excess cost carry forward.

There was no distributable income for each of the three months ended September 30, 2016 and September 30, 2015 and therefore no distributions to Unit holders.

For the three months ended September 30, 2016 and September 30, 2015, the Trust had undistributed net income of $0 and $195,946, respectively, representing the Trust's portion of the undistributed net income of $0 and $1,306,304 associated with the Royalty Properties for the three months ended September 30, 2016 and 2015. The undistributed net income was applied to reduce the accumulated excess cost carry forward.

Underlying Properties Comparison

The following financial and operational information has been based on information previously provided to the Corporate Trustee by the Managing ~~General~~ General Partner. The Trustees had no control over these operations or internal controls relating to this information. The lack of revenues and production for the ~~third~~first quarter of ~~2016~~2017 are entirely attributable to the February 1, 2016 effective time for the 2016 Royalty Sale and, as a result, no additional disclosure on the 100% decrease in revenues and production in the ~~third~~first quarter of ~~2016~~2017 compared to the ~~third~~first quarter of ~~2015~~2016 is provided.

~~Volumes and dollar amounts discussed below represented amounts recorded by the Working Interest Owners unless otherwise specified.~~ 16

Natural Gas and Gas Products

Gas revenues decreased 100% to $0 in the third quarter of 2016 from $115,077 in the third quarter of 2015. Gas volumes during the third quarter of 2016 decreased 100% to 0 Mcf from 41,263 Mcf in the third quarter of 2015. The average price received for natural gas decreased 100% from an average price of $2.79 per Mcf in the third quarter of 2015 to $0 per Mcf in the third quarter of 2016, excluding the impact of the adjustments. Gas products revenue decreased 100% to $0 in the third quarter of 2016 from $17,858 in the third quarter of 2015. Gas products volumes during the third quarter of 2016 decreased 100% to 0 gallons compared to 47,820 gallons in the third quarter of 2015.

Crude Oil and Condensate

Crude oil and condensate revenues decreased 100% to $0 in the third quarter of 2016 from $2,109,957 in the third quarter of 2015. Oil volumes decreased 100% from 34,749 barrels in the third quarter of 2015 to 0 barrels in the third quarter of 2016. The average price received for crude oil and condensate production decreased 100% to $0 per barrel in the third quarter of 2016 from $60.72 per barrel in the third quarter of 2015, excluding the impact of the adjustments to Eugene Island 339 and Eugene Island 342.

Capital Expenditures

Capital expenditures decreased 100% to $0 in the third quarter of 2016 from $229 in the third quarter of 2015.

Production Expenses

Production expenses decreased 100% from $936,358 in the third quarter of 2015 to $0 in the third quarter of 2016.

Special Cost Escrow Account

In the third quarter of 2016, there were no funds released from or escrowed into the Special Cost Escrow account. As of September 30, 2016, $1,000 remained in the Special Cost Escrow account. The funds held in the Special Cost Escrow account were not reflected in the condensed financial statements of the Trust. All of the Partnership's rights and obligations with respect to the Special Cost Escrow were assigned in connection with the Royalty Sales.

Summary By Property

Listed below is a summary of operations of the principal Royalty Properties for the third quarter of 2016 as compared to operations for the third quarter of 2015 based on gross revenues generated during these periods combined. All decreases in revenues and production for the third quarter of 2016 are entirely attributable to the February 1, 2016 effective time for the 2016 Royalty Sale.

Eugene Island 339

Net crude oil revenues decreased from $501,115 in the third quarter of 2015 to $0 in the third quarter of 2016. Net crude oil production decreased from 8,518 barrels in the third quarter of 2015 to 0 barrels in the third quarter of 2016. Gas revenues decreased from $18,399 in the third quarter of

2015 to $0 in the third quarter of 2016. Gas production decreased from 5,919 Mcf in the third quarter of 2015 to 0 Mcf in the third quarter of 2016. Capital expenditures were $0 in the third quarter of 2015 and the third quarter of 2016. Operating expenses decreased from $44,781 in the third quarter of 2015 to $0 in the third quarter of 2016.

Ship Shoal 182/183

Net crude oil revenues decreased from $1,562,975 in the third quarter of 2015 to $0 in the third quarter of 2016. Net crude oil production decreased from 25,440 barrels in the third quarter of 2015 to 0 barrels in the third quarter of 2016. Gas revenues decreased from $93,909 in the third quarter of 2015 to $0 in the third quarter of 2016. Capital expenditures decreased from $231 in the third quarter of 2015 to $0 in the third quarter of 2016. Operating expenses decreased from $787,045 in the third quarter of 2015 to $0 in the third quarter of 2016.

South Timbalier 36/37

Net crude oil revenues decreased from $40,391 in the third quarter of 2015 to $0 for the same period in 2016. Gas revenues decreased from $2,727 in the third quarter of 2015 to $0 in the third quarter of 2016. Gas production decreased from 1,095 Mcf in the third quarter of 2015 to 0 Mcf in the third quarter of 2016. Capital expenditures were $0 in the third quarter of 2015 and 2016. Operating expenses decreased from $11,926 in the third quarter of 2015 to $0 in the third quarter of 2016.

Eugene Island 342

Net crude oil revenues decreased from $5,476 in the third quarter of 2015 compared to $0 in the third quarter of 2016. Net crude oil production decreased from 107 barrels in the third quarter of 2015 to 0 barrels in the third quarter of 2016. Gas revenues were $41 and gas production was 15 Mcf in the third quarter of 2015, compared to gas revenues of $0 and gas production of 0 Mcf in the third quarter of 2016. As the underlying interest in Eugene Island 342 is an overriding royalty interest, there were no capital or operating expenses recorded in the third quarter of 2016 and 2015.

Nine Months Ended September 30, 2016 and 2015

Royalty Trust Comparison

Royalty income was $117,142 and $0 for the nine months ended September 30, 2016 and 2015, respectively. Gross proceeds for the underlying Royalty Properties exceeded development and production costs by $1,156,741, or $173,511 attributable to the Trust, for the production period of November and December 2015 and January, February, March, April, May, June and July 2016 attributable to the nine months ended September 30, 2016 and by $4,261,214, or $639,183 attributable to the Trust for the production period of November and December 2014 and January, February, March, April, May, June and July 2015 attributable to the nine months ended September 30, 2015. The Net Proceeds were applied to reduce the accumulated excess cost carry forward, which represents the amount by which the aggregate development and production costs for the Royalty Properties since November 2008 have exceeded the related proceeds of the protection, and as a result there was no royalty income for the nine months ended September 30, 2016 and 2015.

General and administrative expenses for the Trust were $477,851 for the nine months ended September 30, 2016 compared to $334,255 for the nine months ended September 30, 2015. The increase is due, in part, to the costs associated with the Probate Proceeding.

The reserve for future Trust expenses did not change from December 31, 2015 to September 30, 2016 and remained at $0.

There was no distributable income for each of the nine months ended September 30, 2016 and September 30, 2015 and therefore no distributions to Unit holders.

For the nine months ended September 30, 2016 and September 30, 2015, the Trust had undistributed net income of $173,511 and $639,183, respectively, representing the Trust's portion of the undistributed net income of $1,094,037 and $4,261,214 associated with the Royalty Properties for the nine months ended September 30, 2016 and 2015. The undistributed net income was applied to reduce the accumulated excess cost carry forward.

Underlying Properties Comparison

The following financial and operational information has been based on information provided to the Corporate Trustee by the Managing General Partner. The Trustees had no control over these operations or internal controls relating to this information. Decreases in revenues and production for the nine months ended September 30, 2016 are all primarily attributable to the February 1, 2016 effective time for the 2016 Royalty Sale.

Volumes and dollar amounts discussed below represent amounts recorded by the Working Interest Owners unless otherwise specified.

Natural Gas and Gas Products

Gas revenues decreased ~~$458,394, or 85.0~~100%, to $~~81,116~~0 in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017 from $~~539~~81,~~510~~116 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016. Gas volumes decreased 100% to 0 Mcf during the first ~~nine~~quarter ~~months~~ of ~~2016~~2017 ~~decreased~~from ~~72.3% to~~ 43,878 Mcf ~~from 158,499 Mcf~~ in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016. ~~Excluding~~The ~~the impact of prior period adjustments, the~~ average price received for natural gas decreased ~~approximately 54.1~~100% ~~from~~to ~~an average price, excluding adjustments, of~~ $~~3.40~~0 per Mcf in the first ~~nine~~quarter ~~months~~ of ~~2015~~2017 tofrom an average price of $1.56 per Mcf in the first ~~nine~~quarter ~~months~~ of 2016., ~~Also~~excluding asthe aimpact ~~result~~ of the adjustments. Gas products revenue decreased 100%, ~~gas~~to $0 in the first quarter of 2017 from $23,137 in the first quarter of 2016. Gas products volumes during the first ~~nine~~quarter ~~months~~ of ~~2016~~2017 decreased ~~59.6~~100% to ~~62,956~~0 gallons, ~~compared~~from ~~to 155~~62,~~775~~956 gallons in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016.

Crude Oil and Condensate

Crude oil and condensate revenues decreased ~~$4,724,915, or 72.7~~100%, to $~~1,777,748~~0 in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017 from $61,~~502~~777,~~663~~748 in the first ~~nine~~ ~~months~~quarter of ~~2015~~2016. ~~Excluding~~Oil volumes decreased 100% to 0 barrels in the ~~impact~~first quarter of ~~prior~~2017 ~~period~~from ~~adjustments~~45,320 barrels in the first quarter of 2016. The average price received for crude oil and condensate production decreased ~~36.7~~100%, ~~or $22.79,~~ to $~~39.23~~0 per barrel in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017 from $6239.0214 per barrel in the first ~~nine~~quarter ~~months~~ of ~~2015. Oil volumes decreased 56.8% from 104~~2016,~~851~~ ~~barrels~~excluding in the ~~first~~impact ~~nine months~~ of ~~2015~~the adjustments to ~~45,320~~Eugene ~~barrels~~Island in339 ~~the~~and ~~first~~Eugene ~~nine~~Island ~~months of 2016~~342.

Capital Expenditures

Capital expenditures ~~decreased~~were ~~100% from~~ $~~933~~0 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2017 toand ~~$0 in the first nine months of~~ 2016.

Production Expenses

Production expenses decreased by ~~$2,052,137, or 72.2~~100%, ~~from~~to $~~2,841,709~~0 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2017 tofrom $~~779~~787,~~572~~964 in the first ~~nine~~quarter ~~months~~ of 2016.

Special Cost Escrow Account

In the first nine months of 2016, there were no funds released from or escrowed into the Special Cost Escrow account. As of September 30, 2016, $0 remained in the Special Cost Escrow account. The funds held in the Special Cost Escrow account were not reflected in the condensed financial statements of the Trust. The Special Cost Escrow account was set aside for estimated abandonment costs and future capital expenditures, as provided for in the Conveyance. For additional information relating to the Special Cost Escrow account, see "—Special Cost Escrow Account" below.

Summary By Property

Listed below is a summary of operations of the principal Royalty Properties for the first ~~nine~~quarter ~~months~~ of ~~2016~~2017 as compared to operations for the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 based on gross revenues generated during these periods combined. ~~Decreases~~All decreases in revenues and production for the ~~nine~~first ~~months~~quarter ~~ended~~of ~~September 30,~~2017 ~~2016~~ are ~~all~~entirely ~~primarily~~ attributable to the February 1, 2016 effective time for the 2016 Royalty Sale.

Eugene Island 339

~~Eugene~~Net ~~Island 339 net~~ crude oil revenues decreased from $1662,~~722,499~~064 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~662,064~~0 in the first ~~nine~~quarter ~~months~~ of 2017. The average crude oil price ~~2016~~received decreased from $36.83 ~~There~~per ~~was~~barrel ~~also~~in athe ~~decrease~~first quarter of 2016 to $0 per barrel in ~~net~~the first quarter of 2017. Net crude oil production decreased from 2717,~~778~~976 barrels in the first ~~nine~~quarter ~~months~~ of 2016 ~~2015~~ to ~~17,976~~0 barrels in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. Gas revenues decreased from $6358,~~853~~ 949 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~58,949~~0 in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. Gas production ~~increased~~decreased from 1727,~~471~~145 Mcf in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to ~~27,145~~0 Mcf in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. Capital expenditures were $0 in the first ~~nine~~quarter ~~months~~ of 2016 and ~~2015~~the first quarter of 2017. Operating expenses decreased from $~~103,567 in the first nine months of 2015 to $~~23,078 in the first ~~nine~~quarter ~~months~~ of 2016 ~~due in part~~ to ~~decreased~~$0 ~~maintenance costs~~ in the first ~~nine~~quarter ~~months~~ of ~~2016 as compared to the first nine months of 2015~~2017.

Ship Shoal 182/183

~~Ship~~Net ~~Shoal 182/183 net~~ crude oil revenues decreased from $41,~~901~~090,~~958~~667 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~1,090,667~~0 in the first ~~nine~~quarter ~~months~~ of ~~2016,~~ ~~due~~2017. inThe ~~part to a decrease in the~~ average crude oil price received decreased from $6340.6284 per barrel in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~40.84~~0 per barrel for the same period in ~~2016~~2017. ~~There~~Net ~~was also a decrease in net~~ crude oil production decreased from 77 26,~~053~~706 barrels in the first ~~nine~~quarter ~~months~~ of ~~2015~~ 2016 to ~~26,706~~0 barrels in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. Gas revenues decreased from $~~438~~20,~~666~~547 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~20,547~~0 in the first ~~nine~~quarter of 2017. Gas volumes decreased from 15,895 Mcf in the first ~~months~~quarter of 2016 to 0 Mcf in the first quarter of 2017. There was also a decrease in the average gas revenue price received from $31.3129 per Mcf in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~1.29~~0 per Mcf for the same period in ~~2016~~2017. Capital expenditures were $0 in the first quarter of 2016 and 2017. Operating expenses decreased from $1676,~~091~~682 in the first quarter of 2016 to $0 in the first quarter of 2017.

nine months of 2015 to $0 in the first nine months of 2016. Operating expenses decreased from $2,407,955 in the first nine months of 2015 to $676,682 for the same period in 2016.

South Timbalier 36/37

~~South~~Net ~~Timbalier 36/37~~ crude oil revenues decreased from $~~179~~20,~~409~~407 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~20,407~~0 for the same period in ~~2016~~2017. ~~due primarily~~Oil toproduction avolumes ~~decrease in the average crude oil price received~~ decreased from ~~$65.14~~516 ~~per~~barrels ~~barrel~~ in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to ~~$39.58~~0 ~~per~~barrels ~~barrel~~ in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. ~~There~~The ~~was~~average ~~also~~crude ~~a decrease in~~ oil ~~production~~price ~~volumes~~received decreased from ~~2,754~~$39.58 ~~barrels~~per barrel in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to ~~516~~$0 ~~barrels~~per barrel in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. Gas revenues decreased from $91,~~802~~553 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~1,553~~0 in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. ~~due~~Gas toproduction adecreased ~~decrease in the average natural gas price received~~ from ~~$3.11~~783 ~~per~~ Mcf in the first ~~nine~~quarter ~~months~~ of 2016 ~~2015~~ to ~~$1.98~~0 ~~per~~ Mcf in the first ~~nine~~quarter ~~months~~ of ~~2016~~ 2017. ~~There~~The ~~was~~average ~~also~~natural agas ~~decrease~~price inreceived ~~gas~~decreased ~~production~~ from ~~3,152~~$1.98 per Mcf in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to ~~783~~$0 per Mcf in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. Capital expenditures ~~decreased~~were ~~from a benefit of~~ $~~157 in the first nine months of 2015 to $~~0 in the first ~~nine~~quarter ~~months~~ of 2016 and 2017. Operating expenses decreased from $4010,~~482~~577 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~10,577~~0 in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017.

Eugene Island 342

Net crude oil revenues ~~increased~~decreased from ~~negative~~ $~~301~~4,~~203~~610 in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to $~~4,610~~0 in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. ~~This increase~~Net ~~is primarily due to a prior period adjustment in net~~ crude oil production decreased from ~~negative~~123 ~~2,733~~ barrels in the first ~~nine~~quarter ~~months~~ of ~~2015~~2016 to ~~123~~0 barrels in the first ~~nine~~quarter ~~months~~ of ~~2016~~2017. Gas revenues were $66 and gas production was 56 Mcf in the first ~~nine~~quarter ~~months~~ of 2016, compared to gas revenues of $~~27,188~~0 and gas production of ~~5,373~~0 Mcf in the first ~~nine~~quarter ~~months~~ of ~~2015~~2017. As the underlying interest in Eugene Island 342 is an overriding royalty interest, there were no capital or operating expenses recorded in the first ~~nine~~quarter ~~months~~ of 2017 and 2016. Royalty income was $0 and ~~2015~~$713 for the first quarter of 2017 and 2016, respectively.

Overview of Production, Prices and Royalty Income

The following schedule provides a summary of the volumes and weighted average prices for crude oil and condensate and natural gas recorded by the Working Interest Owners for the Royalty Properties, as well as the Working Interest Owners' calculations of the Net Proceeds and Royalties paid to the Trust during the periods indicated. The following information for the three ~~and nine~~ months ended

2518

~~ended September~~March 3031, 2016 ~~2015~~ includes the effect of the audit adjustments of Eugene Island 339 and Eugene Island 342.

	Royalty Properties Three Months Ended September 30,(1)						Royalty Properties Nine Months Ended September 30,(1)
	Royalty Properties Three Months Ended March 31,(1)
	2016			2015			2016			2015
	2017			2016
Crude oil and condensate (bbls)		—			3445,~~749~~320			~~45,320~~			~~104,851~~
Natural gas and gas products (Mcfe)		—			4943,~~233~~878			~~43,878~~			~~184,461~~
Crude oil and condensate average price, per bbl(2)	$	—		$	6039.7223		$	~~39.23~~		$	~~62.02~~
Natural gas average price, per Mcf (excluding gas products)(3)	$	—		$	21.7985		$	~~1.85~~		$	~~3.40~~
Crude oil and condensate revenues	$	—		$	21,~~109~~777,~~957~~748		$	~~1,777,748~~		$	~~6,502,663~~
Natural gas and gas products revenues		—			~~132~~104,~~935~~253			~~81,116~~			~~601,193~~
Production expenses		—			(~~936~~779,~~358~~572	)		~~(779,572~~	)		~~(2,841,709~~	)
Capital expenditures		—			~~(229~~—	)		—			~~(933~~	)
Interest
Undistributed net income(4)		—			(1,~~306~~094,~~304~~037	)		~~(1,094,037~~	)		~~(4,261,214~~	)
Refund of (provision for) Special Cost Escrow		—			—			—			—

Net Proceeds		—			—			—			—
Royalty interest		—	(5)		~~X15~~x15	%		—	~~(5)~~		~~X15~~	%

Partnership share		—			—			—			—
Trust interest		x99.99	%		x99.99	%		~~x99.99~~	%		~~x99.99~~	%

Trust share of Royalty Income(6)	$	—		$	—		$	—		$	—
Trust share of Royalty Income	$	—		$	—

(1)Amounts ~~were~~are based on production for the three- ~~and nine-~~month period ended ~~July~~January 31 of each year, respectively, and ~~included~~include the results of the adjustments for Eugene Island 339 and Eugene Island 342. (2)Excluding the adjustments, the average price for the three months ended ~~September~~March 3031, ~~2016~~2017 and ~~2015~~2016 was $0 and $~~60.75, respectively, and for the nine months ended September 30, 2016 and 2015 was $~~39.14 ~~and $62.10~~, respectively, per barrel. (3)Excluding the adjustments, the average price for the three months ended ~~September~~March 3031, ~~2016~~2017 and ~~2015~~2016 was $0 and $~~2.79, respectively, and for the nine months ended September 30, 2016 and 2015 was $~~1.56 ~~and $3.35~~, respectively, per Mcf. (4)Undistributed net loss ~~represented~~represents the amount of development and production costs associated with the Royalty that ~~exceeded~~exceed the proceeds of production from the ~~Royalty~~ Royalty Properties during the period. An undistributed net loss ~~was~~is carried forward and offset, in future periods, by positive proceeds earned by the related Working Interest Owner(s). Undistributed net income represents ~~represented~~ positive Net Proceeds, generated during the respective period, but not distributed by the Working Interest Owners. For the three months ended ~~September~~March 3031, 2016, the Trust had undistributed nonet income of $164,105, representing the Trust's portion of the aggregate undistributed net income of $1,094,037 associated with the Royalty Properties for the three months ended March 31, 2016. (5)As a result of the 2016 Royalty Sale, the Royalty interest was reduced from 15% to zero.

2619

(6)See "Trustee's Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources" and Note 4 to the Notes to the Condensed Financial Statements under Item 1 of Part I of this Form 10-Q for a discussion regarding uncertainty of distributions.

Critical Accounting Policies

Disclosure of critical accounting policies and the more significant judgments and estimates used in the preparation of the Trust's financial statements are included in Item 7 of the ~~2015~~2016 10-K. There have been no significant changes to the critical accounting policies during the three months ended ~~September~~March 3031, ~~2016~~2017.

New Accounting Pronouncements

There were no accounting pronouncements issued during the three months ended ~~September~~March 3031, ~~2016~~2017 applicable to the Trust or its condensed financial statements.

Off-Balance Sheet Arrangements

The Trust ~~had~~has no off-balance sheet arrangements. The Trust ~~had~~has not guaranteed the debt of any other party, nor ~~did~~does the Trust have any other arrangements or relationships with other entities that could ~~have~~ potentially ~~resulted~~result in unconsolidated debt, losses or contingent obligations.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

~~Prior~~There tohas ~~effective~~been ~~time~~no ofmaterial ~~the~~changes ~~2016 Royalty Sale, the only assets of and sources of income~~ to ~~the~~our ~~Trust were cash and the Trust's interest in the Partnership, which was the holder of the Royalty. As a result, the Trust was exposed to~~ market risk ~~associated~~previously ~~with~~disclosed ~~the Royalty from fluctuations~~ in ~~oil~~Part II, ~~and gas prices. See Note~~Item 27A of the ~~Notes~~ to2016 ~~Condensed Financial Statements~~10-K.

The Trust has in the past borrowed, and is expected to continue to borrow, money to pay expenses of the Trust. As a result, the Trust is exposed to interest rate market risk associated with the money borrowed to pay expenses.

Item 4. Controls and Procedures.

Evaluation of disclosure controls and procedures. The Corporate Trustee maintains disclosure controls and procedures designed to ensure that information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and regulations. Disclosure controls and procedures include controls and procedures designed to ensure that information required to be disclosed by the Trust is accumulated and communicated by Chevron, as the Managing General Partner of the Partnership, and the Working Interest Owners to the Corporate Trustee of the Trust, and its employees who participate in the preparation of the Trust's periodic reports as appropriate to allow timely decisions regarding required disclosure.

As ~~disclosed~~of in the ~~Trust's~~end ~~Quarterly~~of ~~Report~~the onperiod ~~Form 10-Q~~covered ~~for~~by ~~the~~this ~~quarter ended March 31~~report, ~~2016. Chevron notified~~ the Corporate Trustee ofcarried ~~errors~~out inan ~~the~~evaluation ~~working~~of ~~interest and net revenue interest used in calculating~~ the ~~net~~Trust's ~~reserves~~disclosure ~~attributable~~controls ~~to the Royalty Properties~~ and inprocedures. ~~preparing~~Michael ~~the~~J. ~~net~~Ulrich, ~~profits~~as ~~statements~~Trust ~~for~~Officer of the ~~Royalty~~Corporate ~~Properties~~Trustee, ~~and~~has ~~the~~concluded ~~Trust.~~that ~~The errors in~~ the ~~working~~ ~~interests~~disclosure controls and ~~net~~procedures ~~revenue~~of ~~interests have been corrected and~~ the ~~Corporate~~Trust ~~Trustee~~were ~~does~~effective ~~not~~as ~~anticipate~~of ~~any~~March 31, ~~future~~2017. ~~similar~~

27 Due to the previous contractual arrangements of (i) the Trust Agreement, (ii) the Partnership Agreement and (iii) the rights of the Partnership under the Conveyance regarding information furnished by the Working Interest Owners, the Trustees relied on (A) information provided by the Working Interest Owners, including historical operating data, plans for future operating and capital expenditures, reserve information and information relating to projected production, (B) information from the Managing General Partner of the Partnership, including information that is collected from the Working Interest Owners, and (C) conclusions and reports regarding reserves by the Trust's independent reserve engineers. See Item 1A. Risk Factors "—The Trustees and the Unit holders had no control over the operation or development of the Royalty Properties and had little influence over

issues affecting the Trust's ability to timely file or submit reports required under the Securities Exchange Act of 1934, as amended. As of the end of the period covered by this report, the Corporate Trustee carried out an evaluation of the Trust's disclosure controls and procedures. Michael J. Ulrich, as Trust Officer of the Corporate Trustee, has concluded that the disclosure controls and procedures of the Trust were effective as of September 30, 2016. 20

Due to the previous contractual arrangements of (i) the Trust Agreement, (ii) the Partnership Agreement and (iii) the rights of the Partnership under the Conveyance regarding information furnished by the Working Interest Owners, the Trustees relied on (A) information provided by the Working Interest Owners, including historical operating data, plans for future operating and capital expenditures, reserve information and information relating to projected production, (B) information from the Managing General Partner of the Partnership, including information that is collected from the Working Interest Owners, and (C) conclusions and reports regarding reserves by the Trust's independent reserve engineers. See Item 1A. Risk Factors "—The Trustees and the Unit holders had no control over the operation or development ~~of the Royalty Properties and had little influence over operation or development~~" and "The Trustees rely upon the Working Interest Owners and Managing General Partner for information regarding the Royalty Properties" in the ~~2015~~2016 Form 10-K for a description of certain risks relating to these arrangements and reliance on and applicable adjustments to operating information when reported by the Working Interest Owners to the Corporate Trustee and recorded in the Trust's results of operation.

Changes in Internal Control Over Financial Reporting. During the three months ended ~~September~~March 3031, ~~2016~~2017, there has been no change in the Trust's internal control over financial reporting that has materially affected, or is reasonably likely to materially affect, the Trust's internal control over financial reporting. The Corporate Trustee notes for purposes of clarification that it had no authority over, and makes no statement concerning, the internal control over financial reporting of the Working Interest Owners or the Managing General Partner of the Partnership.

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PART II—OTHER INFORMATION

Item 1. Legal Proceedings.

OnAs previously disclosed on July 10, 2014, the Trustees filed a Petition for Modification and Termination of the Trust (the "Petition") with the Probate Court of Travis County, Texas (the "Court"). The Petition requested that the Court modify the Trust Agreement to (1) allow for the termination of the Trust by a court order, and (2) allow the Trustees, as necessary to fulfill the purposes of the Trust and without Unit holder approval to (a) sell all or any portion of the Trust's interests in the Partnership or any other assets of the Trust, (b) exercise their rights to dissolve the Partnership, or (c) cause the Partnership to sell the Royalty. The ~~goals~~Trust incompleted ~~filing~~the ~~such~~process ~~probate~~of ~~proceeding~~serving (the ~~"Probate Proceeding")~~ ~~were~~Petition toon ~~permit~~ the ~~Trustees to direct the Partnership to sell the Royalty; to distribute the net proceeds resulting from such sale, after payment of the~~ Trust's ~~liabilities, to the~~ Unit holders; ~~and, to,~~in ~~thereafter~~connection ~~terminate~~with ~~the~~such ~~Partnership~~probate ~~and~~proceeding (the ~~Trust.~~"Probate ~~The Trust has completed the process of serving the Petition on the Trust's Unit holders~~Proceeding"). The Court appointed anGlenn M. Karisch, attorney ad litem (the "Ad Litem") to represent ~~any~~ any Unit holders that were not personally served. The ~~Court~~Ad ~~appointed~~Litem ~~attorney ad litem~~ filed a Counterclaim against the Trust on November 16, 2015 requesting (1) an order to sell all of the Royalty, and (2) an accounting of the general and administrative expenses of the Trust from 2008 through the present.

The Probate Proceeding was set for trial on January 15, 2016. Prior to trial, the ~~attorney~~Ad adLitem ~~litem~~ filed a Motion to Sever asking the Court to sever all matters related to the ~~requested~~ requested modification of the Trust and the sale of Trust assets, ~~as plead for, in part, in the petition originally filed by the Trustees and in the attorney ad litem's Counterclaim,~~ into a separate cause to proceed to trial. The ~~attorney~~Ad adLitem ~~litem~~ also filed a Motion for Continuance requesting that the Court continue the trial of all remaining matters, including the ~~attorney~~Ad ~~ad litem~~Litem's request for an accounting and the issues concerning the termination of the Trust, to a later date (the "Remaining Matters"). Prior to calling the case to trial, the Court granted the ~~attorney~~Ad ~~ad litem~~Litem's Motion to Sever and Motion for Continuance, severed the matters related to the modification of the Trust and the sale of Trust assets ("Severed Proceeding"), and continued the Remaining Matters to a later date. The Severed Proceeding has been assigned Cause No. C- 1- PB- 16- 000096 and is styled In re: TEL Offshore Trust.

The Severed Proceeding proceeded to trial before the Court on January 15, 2016. At trial, the Court entered a ~~final~~Final ~~judgment~~Judgment and Order granting the Trustees' request that the ~~Trust~~ Trust Agreement be modified to permit the Trustees to direct the Partnership to sell the remaining overriding royalty interest held by the Partnership as soon as reasonably possible and granting the ad ~~litem~~Ad Litem's request to sell all of the Royalty, notwithstanding any requirements of the Trust Agreement to the contrary. ~~Thereafter,~~The ~~the~~Partnership ~~Court~~completed ~~ordered that~~ the ~~Trustees~~sale ~~direct the Partnership to sell all~~ of the ~~Royalty~~remaining ~~owned~~overriding byroyalty ~~the Partnership~~ interest on ~~or before May 1, 2016. On April 25, 2016, the Court approved an extension of the May 1, 2016 deadline to~~ June 3024, 2016.

On August 17, 2016, the ~~attorney~~Ad adLitem ~~litem~~ filed a Second Amended Answer and First Amended Counterclaim seeking an accounting and asserting, among other causes of action, ~~that~~breach ~~the~~of ~~Trustees have breached their~~ fiduciary duties; tonegligence; ~~the~~gross ~~beneficiaries~~negligence; ofintentional ~~the~~conduct ~~Trust.~~and ~~The~~bad ~~Remaining~~faith; ~~Matters were originally set for trial on November 7, 2016. Trustees filed a motion for continuance of the Remaining Matters~~ and aforfeiture ~~hearing for such continuance occurred on September 14, 2016. At the hearing, the Court granted the Trustees' motion for continuance~~ of ~~the~~fees ~~Remaining Matters~~ and ~~scheduled~~ ~~the~~punitive ~~trial for June 12, 2017~~damages. ~~There~~The ~~can~~Ad beLitem nohas ~~assurances~~also asasserted toother ~~the~~allegations ~~outcome~~against of the ~~Remaining Matters and whether the Court will grant the requested relief, and if such relief is granted, when such actions will be completed~~Trustees.

29 The Remaining Matters were originally set for trial on November 7, 2016. The Trustees filed a motion for continuance of the Remaining Matters and a hearing for such continuance occurred on September 14, 2016. At the hearing, the Court granted the Trustees' motion for continuance of the Remaining Matters and scheduled the trial for June 12, 2017.

claims for breach of fiduciary duties and other claims against the Trustees on behalf of the beneficiaries. RNR Production Land and Cattle ("RNR") also filed its own petition on October 28, 2016, which asserted similar claims against the Trustees as the Ad Litem had asserted. Two other unitholders, Albert and Joyce Speisman ("Speismans" and, together with the Ad Litem and RNR, the "Plaintiffs") also filed a counterclaim on November 15, 2016, adopting the claims of the Realigned Petition.

the parties will enter into a formal compromise and settlement agreement reflecting the terms of the Mediation Settlement Agreement and providing for dismissal with prejudice of the Remaining Matters.

On May 5, 2017, the Ad Litem filed a Motion for Leave to Amend Petition to file its Third Amended Petition as Realigned Plaintiff, and the Corporate Trustee filed a Motion for Leave to File Its Amended Counterclaim for Modification and Termination of Trust as to Attorney Ad Litem, RNR, and the Speismans. The petitions request that the Trust Agreement be modified to (i) allow the Trust to be terminated on a date to be established by the Court, and (ii) establish a Trust termination date, which shall also serve as the record date, at which time the Trust's transfer agent will close the transfer books of the Trust and thereafter no further transfers or transactions in the Trust's units will be registered or effected. The Ad Litem also filed a Motion to Approve Allocation Agreement. The Allocation Agreement is an agreement among the Ad Litem, RNR and the Speismans that sets forth terms for the distribution of the QSF and provides that 20% of the QSF shall be distributed among unit holders as of a date in 2014 to be approved by the Court and the remainder will be distributed among unit holders as of the Trust termination date as approved by the Court. The Corporate Trustee is not a party to the Allocation Agreement.

On May 15, 2017, the Corporate Trustee, the Ad Litem, RNR and the Speismans entered into a Settlement Agreement (the "Corporate Trustee Settlement Agreement"). The Corporate Trustee Settlement Agreement requires a payment by the Corporate Trustee of $4 million into the QSF on a date (the "Settlement Payment Date") within five business days after (i) the approval of the settlement by the Court and the entry of a proposed final judgment (the "Proposed CT Final Judgment") dismissing with prejudice all claims against the Corporate Trustee, as more particularly described below, and (ii) the expiration of the time for appeal and exhaustion of all appeals. At the hearing held on May 15, 2017, the Court approved the settlement, the Corporate Trustee Settlement Agreement and the Proposed CT Final Judgment. The Corporate Trustee Settlement Agreement also requires the Corporate Trustee to transfer into the QSF all funds remaining in the segregated account on the Settlement Payment Date. Once the settlement payment and any remaining funds in the segregated account are paid to the QSF and the Corporate Trustee has performed certain other obligations under the Corporate Trustee Settlement Agreement, the Corporate Trustee shall have no further obligations or duties under the Trust Agreement and any Unit holder's sole rights by virtue of their status as a Unit holder or a former Unit holder shall be their right to receive any distribution from the QSF. The QSF will be used as the Court orders and approves, including the payment of the Plaintiff's attorneys' fees and expenses, the fees and expenses of the Administrator, and the remainder, if any, distributed to Unit holders according to the Allocation Agreement entered into among the Plaintiffs allocating the proceeds of the QSF, subject to the approval of the Court.

The Corporate Trustee Settlement Agreement provides that the Plaintiffs and all current and former Unit holders who were served by publication and did not answer or appear in the Remaining Matters that the Ad Litem was appointed to represent (the "AAL Parties") release all claims against the Corporate Trustee, as well as its agents, representatives, counsel, insurers, heirs, successors and assigns, except for any claims arising from debts or extensions of credit by and between the Corporate Trustee and the Plaintiffs, their agents, representatives, counsel, insurers, heirs, successors and assigns or any Unit holders, unrelated to the Trust or the Probate Proceeding. The Court has previously ruled that all damages payable by the Corporate Trustee shall be for the benefit of all Unit holders not just those who have sued in the Probate Proceeding. The Corporate Trustee Settlement Agreement provides that the Corporate Trustee is settling all such claims and all such claims are released by virtue of the

Corporate Trustee Settlement Agreement and the Proposed CT Final Judgment to be entered pursuant thereto. The Corporate Trustee, in return, releases all claims against the Ad Litem, RNR, the Speismans, their agents, representatives, counsel, insurers, heirs, successors and assigns, and all current and former Unit holders, except for any claims arising from any debts or extensions of credit by and between the Corporate Trustee and the Plaintiffs, their agents, representatives, counsel, insurers, heirs, successors and assigns or any Unit holders, unrelated to the Trust or the Probate Proceeding. The Proposed CT Final Judgment dismisses all claims released in the Corporate Trustee Settlement Agreement. The Corporate Trustee Settlement Agreement further provides that the Corporate Trustee releases any claims for the repayment of loans or other extensions of credit to the Trust by the Corporate Trustee or any affiliate thereof and further provides that the Corporate Trustee shall withdraw any application or claim for payment of funds out of the QSF or the segregated account maintained by the Trust.

The Corporate Trustee Settlement Agreement and the Proposed CT Final Judgment provide for certain modifications to the Trust Agreement, including the termination of the Trust. The Proposed CT Final Judgment provides that the Trust shall terminate at 5:00 p.m. Eastern Daylight Saving Time on June 30, 2017 (the "Record Date and Time"); provided such date will be delayed in the event an appeal is filed and may be delayed upon request of the Ad Litem or the Corporate Trustee if necessary. Upon the Record Date and Time, all rights of Unit holders in and under the Trust Agreement shall terminate and all Units and any beneficial interests therein shall cease to exist. The Proposed CT Final Judgment provides that as of the Record Date and Time each Unit holder shall be limited to its rights with respect to the QSF. The Proposed CT Final Judgment further provides that the Trust's transfer books will be closed and that trading of Units shall not be permitted after the Settlement Payment Date and the Trust's transfer agent will stop processing any Unit transfers as of the Record Date and Time.

The Corporate Trustee Settlement Agreement was conditioned upon Court approval. A hearing was held on May 15, 2017 before the Court to consider all pending motions for approval of the Corporate Trustee Settlement Agreement, the Proposed CT Final Judgment, the modification of the Trust Agreement and termination of the Trust, and the Allocation Agreement previously executed by the Ad Litem, RNR and the Speisman providing for the distribution of the QSF. At the hearing, the Court approved the Corporate Trustee Settlement Agreement, the Proposed CT Final Judgment, the modification of the Trust Agreement and the termination of the Trust. The Court did not approve the Allocation Agreement and it will be considered at a subsequent hearing.

Item 1A. Risk Factors.

~~There~~The ~~have~~terms ~~not~~of ~~been~~the ~~any~~settlement ~~material~~agreement ~~changes~~among ~~from~~ the ~~risk~~Corporate ~~factors~~Trustee ~~previously~~and ~~disclosed~~the plaintiffs in the Probate Proceeding provide for the transfer of the Trust's ~~response~~remaining cash to ~~Item 1A.~~a toqualified ~~Part 1 of~~settlement fund and the ~~2015~~subsequent ~~10-K~~termination of the Trust.

The Corporate Trustee Settlement Agreement and the proposed final judgment (the "Proposed CT Final Judgment") provide that the Corporate Trustee will pay the settlement amount and transfer the remaining funds in the segregated account into the TEL Offshore Qualified Settlement Fund (the "QSF"). The QSF is administered by a third party administrator previously appointed by the Probate Court of Travis County, Texas (the "Court"). The funds in the QSF will, subject to Court approval, be distributed pursuant to an Allocation Agreement executed among the plaintiffs. The Allocation Agreement provides that twenty percent (20%) of the funds in the QSF will be distributed, pursuant to

a claims process, to unit holders as of a date in 2014 to be approved by the Court and the remainder will be distributed, pursuant to a claims process, among unit holders as of the Trust termination date as approved by the Court. There are no assurances that the Allocation Agreement will be approved by the Court. While the settlement has been approved by the Court, if the effectiveness of the settlement is delayed by an appeal, the funds in the segregated account may continue to be reduced if the Court approves the payment of fees and expenses from the segregated account. In addition, the settlement payments from the Corporate Trustee and from the Individual Trustees are available for the payment of fees and expenses of the plaintiffs, which may reduce the funds available to the unit holders under the claims procedures established pursuant to the Allocation Agreement.

The Corporate Trustee Settlement Agreement and the Proposed CT Final Judgment also provide that the Trust shall be terminated as of a date established by the Court. The effective time for the termination of the Trust will be 5:00 p.m. Eastern Daylight Saving Time on June 30, 2017 (the "Record Date and Time") unless there is an appeal or other intervening event. Upon termination of the Trust, the Trust's transfer books will be closed and no further transfers of units will be permitted. From and after the Record Date and Time, all units shall cease to exist and all former unit holders shall be limited to their rights relative to the QSF.

Item 6. Exhibits.

(Asterisk indicates exhibit previously filed with the Securities and Exchange Commission and incorporated herein by reference.)

				SEC File or Registration Number	Exhibit Number
4(a)	*	—	Trust Agreement dated as of January 1, 1983, among Tenneco Offshore Company, Inc., Texas Commerce Bank National Association, as corporate trustee, and Horace C. Bailey, Joseph C. Broadus and F. Arnold Daum, as individual trustees (Exhibit 4(a) to Form 10-K for the year ended December 31, 1992 of TEL Offshore Trust)	0-06910	4(a)
4(b)	*	—	Agreement of General Partnership of TEL Offshore Trust Partnership between Tenneco Oil Company and the TEL Offshore Trust, dated January 1, 1983 (Exhibit 4(b) to Form 10-K for year ended December 31, 1992 of TEL Offshore Trust)	0-06910	4(b)
4(c)	*	—	Conveyance of Overriding Royalty Interests from Exploration I to the Partnership (Exhibit 4(c) to Form 10-K for year ended December 31, 1992 of TEL Offshore Trust)	0-06910	4(c)
4(d)	*	—	Amendments to TEL Offshore Trust Agreement, dated December 7, 1984 (Exhibit 4(d) to Form 10- K for year ended December 31, 1992 of TEL Offshore Trust)	0-06910	4(d)
4(e)	*	—	Amendment to the Agreement of General Partnership of TEL Offshore Trust Partnership, effective as of January 1, 1983 (Exhibit 4(e) to Form 10-K for the year ended December 31, 1992 of TEL Offshore Trust)	0-06910	4(e)
10(a)	*	—	Purchase Agreement, dated as of December 7, 1984 by and between Tenneco Oil Company and Tenneco Offshore II Company (Exhibit 10(a) to Form 10-K for year ended December 31, 1992 of TEL Offshore Trust)	0-06910	10(a)
31		—	Certification furnished pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
10(b)	*	—	Consent Agreement, dated November 16, 1988, between TEL Offshore Trust and Tenneco Oil Company (Exhibit 10(b) to Form 10-K for year ended December 31, 1988 of TEL Offshore Trust)	0-06910	10(b)
32		—	Certification furnished pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
99.1	*	—	Order Approving Settlement Agreement dated January 20, 2017 (Exhibit 99.1 to the Trust's Current Report on Form 8-K filed on January 27, 2017)	0-06910	99.1
99.2	*	—	Final Judgment as to Individual Trustees dated January 20, 2017 (Exhibit 99.2 to the Trust's Current Report on Form 8-K filed on January 27, 2017)	0-06910	99.2
99.3	*	—	Order Severing Final Judgment as to Individual Trustees dated January 20, 2017 (Exhibit 99.3 to the Trust's Current Report on Form 8-K filed on January 27, 2017)	0-06910	99.3
99.4	*	—	Mediation Settlement Agreement dated April 18, 2017 (Exhibit 99.1 to the Trust's Current Report on Form 8-K filed on April 25, 2017)	0-06910	99.1

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				SEC File or Registration Number	Exhibit Number
10(c)	*	—	Assignment and Assumption Agreement, dated November 17, 1988, between Tenneco Oil Company and TOC-Gulf of Mexico Inc. (Exhibit 10(c) to Form 10-K for year ended December 31, 1988 of TEL Offshore Trust)	0-06910	10(c)
10(d)	*	—	Gas Purchase and Sales Agreement Effective September 1, 1993 between Tennessee Gas Pipeline Company and Chevron U.S.A. Production Company (Exhibit 10(d) to Form 10-K for year ended December 31, 1993 of TEL Offshore Trust)	0-06910	10(d)
31		—	Certification furnished pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32		—	Certification furnished pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

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.


		TEL OFFSHORE TRUST
		By:		The Bank of New York Mellon Trust Company, N.A. Corporate Trustee
		By:		/s/ MICHAEL J. ULRICH Michael J. Ulrich Vice President

Date: ~~November~~May 1415, ~~2016~~2017

The Registrant, TEL Offshore Trust, has no principal executive officer, principal financial officer, board of directors or persons performing similar functions. Accordingly, no additional signatures are available and none have been provided.

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NOTE REGARDING FORWARD-LOOKING STATEMENTS
PART I—FINANCIAL INFORMATION

Item 1. Condensed Financial Statements.

TEL OFFSHORE TRUST CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS (UNAUDITED)
CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)
CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)
TEL OFFSHORE TRUST NOTES TO CONDENSED FINANCIAL STATEMENTS (UNAUDITED)

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

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

Item 4. Controls and Procedures.

PART II—OTHER INFORMATION

Item 1. Legal Proceedings.

Item 1A. Risk Factors.

Item 6. Exhibits .

SIGNATURES

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