Edgar Filing: TORCH ENERGY ROYALTY TRUST

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10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

Form 10-Q

(Mark One)

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2012

¨	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 1-12474

Torch Energy Royalty Trust

(Exact Name of Registrant as Specified in Its Charter)


Delaware		74-6411424
(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification Number)

Rodney Square North 1100 North Market Street, Wilmington, Delaware		19890
(Address of Principal Executive Offices)		(Zip Code)

302/636-6435

(Registrant’s telephone number, including area code)

Not Applicable

(Former name, former address and former fiscal year,

if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ¨ No x

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ¨ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act.

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

As of January 27, 2014, 8.6 million Units of Beneficial Interest of the Trust were outstanding.

TORCH ENERGY ROYALTY TRUST

PART 1 - FINANCIAL INFORMATION

Item I. Financial Statements

This document includes “forward looking statements” within the meaning of Section 27A of the Securities Act of 1993, as amended, and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical facts included in this document, including without limitation, statements under “Discussion and Analysis of Financial Condition and Results of Operations” regarding the financial position, reserve quantities and net present values of reserves of the Torch Energy Royalty Trust (“Trust”) and statements that include the words “believes”, “expects”, “anticipates”, “intends”, “estimates”, “projects”, “target”, “goal”, “plans”, “objectives”, “should” or similar expressions or variations are forward-looking statements. Torch Energy Advisors Incorporated (“Torch”) and the Trust can give no assurances that the assumptions upon which these statements are based will prove to be correct. Factors which could cause such forward looking statements not to be correct include, among others, the cautionary statements set forth in the Trust’s Annual Report on Form 10-K with the Securities Exchange Commission for the most recent fiscal year, cautionary statements contained in this report, the volatility of oil and natural gas prices, future production costs, future oil and natural gas production quantities, operating hazards, and environmental conditions.

Introduction

The financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. The Trust was formed effective October 1, 1993, pursuant to a trust agreement (“Trust Agreement”) among Wilmington Trust Company, not in its individual capacity but solely as trustee of the Trust (“Trustee”), Torch Royalty Company (“TRC”) and Velasco Gas Company, Ltd. (“Velasco”) as owners of certain oil and natural gas properties (“Underlying Properties”) and Torch Energy Advisors Incorporated (“Torch”) as grantor. TRC and Velasco created net profits interests (“Net Profits Interests”) which burden the Underlying Properties and conveyed such interests to Torch. The Trust was formed under the Delaware statutory trust act (formerly known as the Delaware business trust act). Torch conveyed the Net Profits Interests to the Trust in exchange for an aggregate of 8,600,000 units of beneficial interest (“Units”). Such Units were sold to the public through various underwriters in November 1993. The working interest owners of the Underlying Properties are TRC, Torch E&P Company, Samson Lone Star Limited Partnership and Constellation Energy Partners LLC (“Working Interest Owners”). On December 13, 2011, the Trust sold all of its Net Profits Interests, which burdened certain working interests owned by Constellation Energy Partners LLC, attributable to the Underlying Properties in the Robinson’s Bend Field. See Note 5 of the accompanying financial statements for additional information.

Certain information and footnote disclosures normally included in the annual financial statements have been omitted pursuant to such rules and regulations, although the Trustee believes that the disclosures are adequate to make the information presented not misleading. These financial statements should be read in conjunction with the December 31, 2011 financial statements and notes thereto included in the Trust’s applicable annual report on Form 10-K. All adjustments necessary to present fairly the assets, liabilities and trust corpus of the Trust as of March 31, 2012 and December 31, 2011, the distributable income (loss) and changes in trust corpus for the three-month periods ended March 31, 2012 and 2011 have been included. All such adjustments are of a normal recurring nature. The distributable income (loss) for such interim periods is not necessarily indicative of the distributable income (loss) for the full year.

TORCH ENERGY ROYALTY TRUST

The sole purpose of the Trust is to hold the Net Profits Interests, to receive payments from the Working Interest Owners, and to make payments to Unitholders. The Trust does not conduct any business activity and has no officers, directors or employees. The Trust and Trustee rely on third party service providers to perform administrative services for the Trust. Torch currently provides via a letter agreement the administrative services historically provided by Torch to the Trust through December 31, 2013 consistent with past practice and (ii) from December 31, 2013 to April 30, 2014 shall provide services to the Trust in support of any tax correspondence (tax booklet) and tax filings that might be necessary for the year ended December 31, 2013 consistent with past practice and other related services necessary to complete the wind down of the Trust that are also consistent with past practice. Subsequently, the inability of the Trust to hire qualified services providers to assist in the wind down and liquidation of the Trust may have a material adverse effect on the operations of the Trust.

The Trust has no officers, directors or employees. The Trust and Trustee rely solely on receiving accurate information, reports and other representations from Torch and other service providers to the Trust. In executing and submitting this report on behalf of the Trust and with respect to David A. Vanaskey in executing the certifications relating to this report, the Trustee and David A. Vanaskey have relied upon the accuracy of such reports, information and representations.

TORCH ENERGY ROYALTY TRUST

STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS

(In thousands)

ASSETS


	March 31, 2012		December 31, 2011
	(Unaudited)
Cash	$	1,931	$	2,383
Net profits interests in oil and natural gas properties (Net of accumulated amortization of $177,118 and $177,118 at March 31, 2012 and December 31, 2011, respectively		3,482		3,482

	$	5,413	$	5,865


LIABILITIES AND TRUST CORPUS

Trust expense payable	$	358	$	475
Trust corpus		5,055		5,390

	$	5,413	$	5,865

See notes to financial statements

TORCH ENERGY ROYALTY TRUST

STATEMENTS OF DISTRIBUTABLE INCOME (LOSS)

(In thousands, except per Unit amounts)

(Unaudited)


	Three Months Ended March 31,
	2012			2011
NNet profits income	$	—		$	466
NInfill well proceeds		—			—

		—			466
General and administrative expenses		335			406

Distributable income \ (loss)	$	(335	)	$	60

Distributable income \ (loss) per Unit (8,600 Units)	$	(0.04	)	$	0.01

Distributions per Unit	$	—		$	—

See notes to financial statements

TORCH ENERGY ROYALTY TRUST

STATEMENT OF CHANGES IN TRUST CORPUS

(In thousands)

(Unaudited)


	Three Months Ended March 31,
	2012			2011
Trust corpus, beginning of period	$	5,390		$	13,852
Amortization of Net Profits Interests		—			(380	)
Distributable income \ (loss)		(335	)		60
Distributions to Unitholders		—			—

Trust corpus, end of period	$	5,055		$	13,532

See notes to financial statements

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

1.	Nature of Operations

The Torch Energy Royalty Trust (“Trust”) was formed effective October 1, 1993, pursuant to a trust agreement (“Trust Agreement”) among Wilmington Trust Company, not in its individual capacity but solely as trustee of the Trust (“Trustee”), Torch Royalty Company (“TRC”) and Velasco Gas Company, Ltd. (“Velasco”) as owners of certain oil and natural gas properties (“Underlying Properties”) and Torch Energy Advisors Incorporated (“Torch”) as grantor. The Trust was formed under the Delaware statutory trust act (formerly known as the Delaware business trust act). TRC and Velasco created net profits interests (“Net Profits Interests”) which burden the Underlying Properties and conveyed such interests to Torch. Torch conveyed the Net Profits Interests to the Trust in exchange for an aggregate of 8,600,000 units of beneficial interest (“Units”). Such Units were sold to the public through various underwriters in November 1993. The working interest owners of the Underlying Properties were Torch Royalty Company, Torch E&P Company, Samson Lone Star Limited Partnership and Constellation Energy Partners LLC (“Working Interest Owners”). On December 13, 2011, the Trust sold all of its Net Profits Interests, which burdened certain working interests owned by Constellation Energy Partners LLC, attributable to the Underlying Properties in the Robinson’s Bend Field. See Note 5 for additional information concerning such sale.

The Net Profits Interests entitle the Trust to receive 95% of the Net Proceeds attributable to oil and gas produced and sold from wells (other than infill wells) on the Underlying Properties. The Net Profits Interests also entitle the Trust to 20% of the Net Proceeds of wells drilled on the Underlying Properties since the Trust’s establishment into formations in which the Trust has an interest, other than wells drilled to replace damaged or destroyed wells (“Infill Wells”).

The Underlying Properties constitute working interests in the Chalkley Field in Louisiana (“Chalkley Field”), the Robinson’s Bend Field in the Black Warrior Basin in Alabama (“Robinson’s Bend Field”), fields that produce from the Cotton Valley formations in Texas (“Cotton Valley Fields”) and fields that produce from the Austin Chalk formation in Texas (“Austin Chalk Fields”). The Underlying Properties represent interests in all productive formations from 100 feet below the deepest productive formation in each field to the surface when the Trust was formed. The Trust therefore has no interest in deeper productive formations.

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

The Trust received the affirmative vote of the Unitholders of more than 66 2/3% of the outstanding Units to terminate the Trust at the meeting of Unitholders held on January 29, 2008 (the “Termination Date”). Upon termination of the Trust, among other things, the Trustee is required to sell the Net Profits Interests. Specifically, pursuant to Section 9.03(e) of the Trust Agreement if the property of the Trust Estate (as defined in the Trust Agreement) has not been sold prior to the end of one calendar year following the termination date, the Trustee, thereafter, must cause such assets to be sold at public auction. See Note 5 for additional information concerning the liquidation of the Trust’s Net Profits Interests.

TRC and Velasco receive payments reflecting the proceeds of oil and natural gas sold and aggregate these payments, deduct applicable costs and make payments to the Trustee each quarter for the amounts due to the Trust. Prior to the Trust’s termination on January 29, 2008, Unitholders received quarterly cash distributions relating to oil and natural gas produced and sold from the Underlying Properties. Pursuant to Section 3.07 of the Trust Agreement, the Trustee established a cash reserve (“Cash Reserve”) in 2008 following the Trust’s termination. See Note 4 for additional information regarding cash distributions and the Cash Reserve. Because no additional properties will be contributed to the Trust, the assets of the Trust deplete over time and a portion of each cash distribution made by the Trust is analogous to a return of capital.

The only assets of the Trust, other than cash and temporary investments being held for the payment of actual, contingent and uncertain liabilities and for distribution to Unitholders, are the Net Profits Interests. Under the Trust Agreement, the Trustee receives the payments attributable to the Net Profits Interests and pays all expenses, liabilities and obligations of the Trust. The Trustee has the discretion to establish a cash reserve for the payment of any liability that is contingent or uncertain in amount or that otherwise is not currently due and payable. The Trustee is entitled to cause the Trust to borrow money to pay expenses, liabilities and obligations that cannot be paid out of cash held by the Trust. The Trustee is entitled to cause the Trust to borrow from any source, including from the entity serving as Trustee, provided that the entity serving as Trustee shall not be obligated to lend to the Trust. To secure payment of any such indebtedness (including any indebtedness to the Trustee), the Trustee is authorized to (i) mortgage and otherwise encumber the entire Trust estate or any portion thereof; (ii) carve out and convey production payments; (iii) include all terms, powers, remedies, covenants and provisions it deems necessary or advisable, including confession of judgment and the power of sale with or without judicial proceedings; and (iv) provide for the exercise of those and other remedies available to a secured lender in the event of a default on such loan. The terms of such indebtedness and security interest, if funds were loaned by the Trustee, must be similar to the terms which the Trustee would grant to a similarly situated commercial customer with whom it did not have a fiduciary relationship, and the Trustee shall be entitled to enforce its rights with respect to any such indebtedness and security interest as if it were not then serving as Trustee.

The Trustee is authorized and directed to sell and convey the Net Profits Interests without Unitholder approval in certain instances as described in the Trust Agreement, including upon termination of the Trust. The Trustee is empowered by the Trust Agreement to employ consultants, legal and financial advisors and agents (including Torch) and to make payments of all fees for services or expenses out of the assets of the Trust.

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

2.	Basis of Accounting, Significant Accounting Policies

The financial statements of the Trust are prepared on a modified cash basis and are not intended to present the financial position and results of operations in conformity with generally accepted accounting principles generally accepted in the United States of America (“GAAP”). Preparation of the Trust’s financial statements on such basis includes the following:

•

Revenues are recognized in the period in which amounts are received by the Trust. Therefore, revenues recognized during the three-month periods ended March 31, 2012 and 2011 are derived from oil and natural gas production sold during three-month periods ended December 31, 2011 and 2010, respectively. The Trust did not receive revenues from TRC with respect to production during the three-month period ended December 31, 2011 as a result of TRC recouping overpayments made to the Trust in 1994 and 1995 with respect to the Chalkley Field (the “Chalkley Gas Volume Adjustment”). See Note 4 for additional information regarding this adjustment.

•

General and administrative expenses are recognized on an accrual basis.

•

Amortization of the Net Profits Interests is calculated on a unit-of-production basis and charged directly to trust corpus.

•

Distributions to Unitholders are recorded when declared by the Trustee.

•

The Trust reviews the Net Profits Interests for impairment whenever events or changes in circumstances indicate the carrying amount of the Net Profits Interests may not be recoverable. Recoverability is measured by a comparison of the carrying amount of an asset to future net cash flows expected to be generated by the Net Profits Interests. If such asset is considered to be impaired, the impairment recognized is measured by the amount by which the carrying amount of the assets exceeds either the fair value or the estimated discounted cash flows of the assets, whichever is more readily measurable. At March 31, 2012 and 2011, no impairment was deemed necessary.

•

The financial statements of the Trust differ from financial statements prepared in accordance with GAAP because net profits income is not accrued in the period of production and amortization of the Net Profits Interests is not charged against operating results.

3.	Federal Income Taxes and Texas State Margin Tax

Tax counsel has advised the Trust and Trustee that, under current tax law, the Trust is classified as a grantor trust for federal income tax purposes and not an association taxable as a business entity. However, the opinion of tax counsel is not binding on the Internal Revenue Service. As a grantor trust, the Trust is not subject to federal income tax.

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

Because the Trust is treated as a grantor trust for federal income tax purposes and a Unitholder is treated as directly owning an interest in the Net Profits Interests, each Unitholder is taxed directly on such Unitholder’s pro rata share of income attributable to the Net Profits Interests consistent with the Unitholder’s method of accounting and without regard to the taxable year or accounting method employed by the Trust. Amounts payable with respect to the Net Profits Interests are paid to the Trust on the quarterly record date established for quarterly distributions in respect to each calendar quarter during the term of the Trust, and the income and deductions from such payments are allocated to the Unitholders of record on such date.

In May 2006, the State of Texas passed legislation to implement a margin tax at a rate of 1% to be imposed generally on federal gross revenues (up to 70%), as apportioned to Texas less certain costs and deductions, as specifically set forth in the new legislation. The effective date of the legislation was January 1, 2008, but the tax was generally imposed on revenues generated in 2007 and thereafter (earlier for certain fiscal year taxpayers). Entities subject to tax generally include trusts unless otherwise exempt and most other types of entities having limited liability protection. Trusts that meet certain statutory requirements are generally exempt from the margin tax as “passive entities.”

Since the Trust is exempt from the margin tax at the Trust level as a passive entity, each Unitholder that is a taxable entity would generally include its share of the Trust’s revenue in its margin tax computation. This revenue would be sourced to Texas under Texas Comptroller guidance that provides such income is sourced according to the principal place of business of the Trust, which is Texas.

4.	Distributions and Income Computations

Each quarter the amount of cash available for distribution to Unitholders (the “Quarterly Distribution Amount”) is equal to the excess, if any, of the cash received by the Trust, on the last day of the second month following the previous calendar quarter (or the next business day thereafter) ending prior to the dissolution of the Trust, from the Net Profits Interests then held by the Trust plus, with certain exceptions, any other cash receipts of the Trust during such quarter, subject to adjustments for changes made by the Trustee during such quarter in the Cash Reserve established for the payment of actual, contingent and uncertain liabilities of the Trust. Based on the payment procedures relating to the Net Profits Interests, cash received by the Trust on the last day of the second month of a particular quarter from the Net Profits Interests generally represents proceeds from the sale of oil and natural gas produced from the Underlying Properties during the preceding calendar quarter. The Quarterly Distribution Amount for each quarter is generally payable to Unitholders of record on the last day of the second month of the calendar quarter unless such day is not a business day, in which case the record date is the next business day thereafter. The Trust distributes the Quarterly Distribution Amount within approximately 10 days after the record date to each person who was a Unitholder of record on the associated record date.

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

During the three-month period ended December, 31, 2011, TRC computed the Chalkley Gas Volume Adjustment whereby TRC determined that it had overpaid the Trust $3.0 million (including $1.9 million of accrued interest as of December 31, 2011) in 1994 and 1995 with respect to TRC’s Underlying Property interests in the Chalkley Field. Neither the Trust nor Unitholders are obligated to return such overpayment to TRC; however, the Trust will receive no Net Proceeds with respect to TRC’s interests in the Underlying Properties of the Chalkley Field, the Cotton Valley Fields and the Austin Chalk Fields (“TRC Underlying Property Interests”) until future Net Proceeds from the TRC Underlying Property Interests, plus accrued interest, exceed the unrecouped balance of such overpayment. The Chalkley Gas Volume Adjustment was settled on August 30, 2013.

As a result of the Chalkley Gas Volume Adjustment, the Trust received no net profits income during the three-month period ended March 31, 2012 as a result of TRC withholding Net Proceeds from the Trust totaling $0.5 million. During the three-month period ended March 31, 2012, the Trust recognized no Net Proceeds pertaining to the Infill wells due to the timing of the Trust receiving such Infill Well cash receipts. During the three-month period ended March 31, 2012, the Trust made no cash distributions to Unitholders. As of March 31, 2012 and December 31, 2011, the Cash Reserve was $1.9 million and $2.4 million, respectively.

During the three-month period ended March 31, 2011 the Trust received cash payments totaling $0.5 million from the Working Interest Owners of the Underlying Properties which mainly pertained to net profits income attributable to production from the Underlying Properties during the three-month period ended December 31, 2010. Such amounts are classified as net profits income and Infill Well proceeds in the Trust’s statements of distributable income (loss) during the three-month period ended March 31, 2011. The Chalkley Gas Volume Adjustment did not impact Net Proceeds received by the Trust during the three-month period ended March 31, 2011. No cash distributions were made to Unitholders during the three-month period ended March 31, 2011.

5.	Termination and Liquidation of the Net Profits Interests

The Trust received the affirmative vote of the Unitholders of more than 66 2/3% of the outstanding Units to terminate the Trust at the meeting of Unitholders held on January 29, 2008, the Termination Date. Upon termination of the Trust, among other things, the Trustee is required to sell the Net Profits Interests. Specifically, pursuant to Section 9.03(e) of the Trust Agreement if the property of the Trust Estate (as defined in the Trust Agreement) has not been sold prior to the end of one calendar year following the termination date, the Trustee, thereafter, must cause such assets to be sold at public auction.

On August 4, 2011 the Trust entered into a material definitive agreement for advisory and marketing services with an effective date of August 1, 2011 with respect to the sale of the Net Profits Interests pursuant to an agreement with PLS, Inc., a Texas corporation. The Trust notified Robinson’s Bend Production II, LLC. (“RBP II”), a Delaware limited liability company and a subsidiary of Constellation Energy Partners, on November 3, 2011 that it was the successful bidder in the public auction of the sale of the Net Profits Interests attributable to the Robinson’s

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

Bend Field. On December 13, 2011, the Trust entered into a purchase and sale agreement by and between RBP II pursuant to which the Trust agreed to sell, and RBP II agreed to purchase, all of the Trust’s Net Profits Interests attributable to the Underlying Properties in the Robinson’s Bend Field for a purchase price of $1,000,000. The sale signed and closed simultaneously on December 13, 2011.

The Trustee anticipates it will continue to consult with the Trust’s and Trustee’s financial and legal advisors in the wind down of the Trust.

6.	Related Party Transactions

TRC and Velasco contracted to sell the oil and natural gas production from the Underlying Properties to Torch Energy Marketing, Inc. (“TEMI”), a subsidiary of Torch, under a purchase contract (“Purchase Contract”). Upon termination of the Trust, the Purchase Contract expired and the Working Interest Owners calculate the Net Proceeds owed to the Trust utilizing the same pricing mechanisms (including the sharing price and minimum price commitment mechanisms) as the expired Purchase Contract.

Marketing Arrangements and Price Sharing

In connection with the formation of the Trust, TRC, Velasco and TEMI entered into the Purchase Contract which expired upon termination of the Trust. Pursuant to the Purchase Contract, TEMI was obligated to purchase all net production attributable to the Underlying Properties for an index price for oil and natural gas (“Index Price”), less certain gathering, treating and transportation charges, which were calculated monthly. The Index Price equals 97% of the weighted average spot market prices of oil and natural gas (“Average Market Prices”) at the four locations where TEMI sold production.

The Purchase Contract also provided that TEMI pay a minimum price (“Minimum Price”) for natural gas production, adjusted annually for inflation. When TEMI paid a purchase price based on the Minimum Price it received price credits (“Price Credits”), equal to the difference between the Index Price and the Minimum Price, that it was entitled to deduct in determining the purchase price when the Index Price for natural gas exceeded the Minimum Price. In addition, if the Index Price for natural gas exceeded the sharing price, which was adjusted annually for inflation (“Sharing Price”), TEMI was entitled to deduct 50% of such excess (“Price Differential”) in determining the purchase price. TEMI had an annual option to discontinue the Minimum Price commitment. However, if TEMI discontinued the Minimum Price commitment, it would no longer be entitled to deduct the Price Differential in calculating the purchase price and would have forfeited all accrued Price Credits. As of the Termination Date, TEMI had no outstanding Price Credits and had not exercised its option to discontinue the Minimum Price commitment.

Upon the Trust’s termination, pursuant to each Conveyance, the Working Interest Owners utilized the same pricing mechanisms (including the Sharing Price and Minimum Price commitment mechanisms) as the expired Purchase Contract in calculating Net Proceeds due to the Trust. The Minimum Price per MMBtu was $2.05, $1.99 and $1.97 for 2012, 2011 and 2010

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

natural gas sales, respectively. The Sharing Price per MMBtu was $2.54, $2.46 and $2.43 for 2012, 2011 and 2010 natural gas sales, respectively. Pursuant to each Conveyance, the Working Interest Owners also have the same annual option to discontinue the Minimum Price commitment. As a result of the Sharing Price arrangement, Net Proceeds attributable to the Underlying Properties during the three-month periods ended March 31, 2012 and 2011 were reduced by $0.1 million and $0.4 million, respectively. As of March 31, 2012 and December 31, 2011, the Working Interest Owners had no outstanding Price Credits and had not exercised its right to discontinue the Minimum Price commitment.

Under each Conveyance, natural gas volumes are determined at the wellhead. Therefore, Net Proceeds do not include any amounts received in connection with extracting natural gas liquids from such production at natural gas processing or treating facilities.

Gathering, Treating and Transportation Arrangements

The Purchase Contract, which expired upon the Trust’s termination, entitled TEMI to deduct certain natural gas gathering, treating and transportation fees in calculating the purchase price for natural gas in the Robinson’s Bend, Austin Chalk and Cotton Valley Fields. The amounts that were deducted in calculating the purchase price for such natural gas were set forth in the Purchase Contract and were not affected by the actual costs incurred by TEMI to gather, treat and transport natural gas. Upon the Trust’s termination, pursuant to each Conveyance, the Working Interest Owners became entitled to deduct the same natural gas gathering, treating and transportation fees that had previously been deducted by TEMI pursuant to the Purchase Contract in calculating Net Proceeds due to the Trust.

For the Robinson’s Bend Field, a gathering, treating and transportation fee of $0.260 per MMBtu adjusted for inflation ($0.335 per MMBtu and $0.331 per MMBtu for such fees pertaining to 2011 and 2010 natural gas sales, respectively), plus fuel usage equal to 5% of revenues is deducting in computing Net Proceeds due to the Trust. Additionally, a gathering fee of $0.05 per MMBtu is deducted in calculating the purchase price for production from 73 of the 426 wells in the Robinson’s Bend Field. In computing Net Proceeds due to the Trust for the Austin Chalk Fields, $0.38 per MMBtu plus 17% of revenues are deducted as a fee to gather, treat and transport natural gas production. TEMI deducted from the purchase price for natural gas for production attributable to certain wells in the Cotton Valley Fields a transportation fee of $0.045 per MMBtu.

During the three-month periods ended March 31, 2012 and 2011, such fees deducted from the Net Proceeds calculations, attributable to production during each of the three-month periods ended December 31, 2011 and 2010, in the Robinson’s Bend, Austin Chalk and Cotton Valley Fields, totaled $0.03 million and $0.2 million, respectively. No amounts for gathering, treating or transportation are deducted in calculating the purchase price from the Chalkley Field.

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

Administrative Services Agreement

Torch provided accounting, bookkeeping, informational and other services to the Trust related to the Net Profits Interests pursuant to the Administrative Services Agreement effective October 1, 1993 and an oral arrangement after termination of the Administrative Services Agreement on January 29, 2008 through April 1, 2008. On November 7, 2008, an agreement was entered into between the Trust and Torch that engaged Torch to provide certain accounting services in connection with the Trust’s preparation and filing of the Trust’s Form 10-K for the year ended December 31, 2007.

To facilitate the winding down of the Trust, Torch currently provides certain accounting and other services for the Trust pursuant to an agreement with the Trust entered into on March 26, 2009. The initial term of the agreement expired on March 31, 2010 and was thereafter extended from year to year, up to the period ending August 30, 2013. Torch currently provides the Trust via letter agreement the administrative services historically provided by Torch to the Trust through December 31, 2013 consistent with past practice and (ii) from December 31, 2013 to April 30, 2014 shall provide services to the Trust in support of any tax correspondence (tax booklet) and tax filings that might be necessary for the year ended December 31, 2013 consistent with past practice and other related services necessary to complete the wind down of the Trust that are also consistent with past practice. Subsequently, the inability of the Trust to hire qualified service providers to assist in the wind down and liquidation of the Trust may have a material adverse effect on the operations of the Trust.

Services fees charged to the Trust by Torch during each of the three-month periods ended March 31, 2012 and 2011 totaled $0.1 million.

Operator Overhead Fees

A subsidiary of Torch operates certain oil and natural gas interests burdened by the Net Profits Interests. The Underlying Properties are charged, on the same basis as other third parties, for all customary expenses and costs reimbursements associated with these activities. Operator overhead fees deducted from the Net Proceeds computations for the Chalkley, Cotton Valley and Austin Chalk Fields totaled $55,000 and $58,000 during the three-month periods ended March 31, 2012 and 2011, respectively.

Compensation of the Trustee and Transfer Agent

The Trust Agreement provides that the Trustee be compensated for its administrative services, out of the Trust assets, in an annual amount of $80,000, plus an hourly charge for services in excess of a combined total of 250 hours annually at its standard rates. In accordance with provisions in the Trust Agreement, the Trustee may increase its compensation for its administrative services as a result of unusual or extraordinary services rendered by the Trustee.

Additionally, the Trustee receives a transfer agency fee of $5.00 annually per account (minimum of $15,000 annually), subject to change each December, beginning December 1994, based upon the change in the Producer’s Price Index as published by the Department of Labor, Bureau of Labor Statistics, plus $1.00 for each certificate issued.

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

Total administrative and transfer agent fees charged by the Trustee for services performed during the three-month periods ended March 31, 2012 and 2011 were $25,000 and $40,000, respectively.

7.	Trust Expense Payable

The Trust expense payable at March 31, 2012 and December 31, 2011 was $358,000 and $475,000, respectively. Such liability represents general and administrative expense accruals mainly pertaining to the Trust’s legal fees, accounting and audit fees, and administrative services fees.

8.	Subsequent Events

On January 24, 2013, the Trust received notice from NYSE Regulation, Inc. (“NYSE Regulation”) informing the Trust that NYSE Regulation has determined to commence proceedings to delist the Trust’s units from the New York Stock Exchange (“NYSE”), with trading of the units to be suspended prior to the opening of NYSE trading on January 30, 2013. NYSE Regulation informed the Trust that the delisting determination was based on the Trust’s delay in filing its Annual Report for the year ended December 31, 2011 on Form 10-K and subsequent Quarterly Reports for the fiscal quarters ending in 2012 with the Securities and Exchange Commission. The Trust had previously utilized the three-month cure period under Section 802.01C of the NYSE Listed Company Manual and a subsequent three-month extension of the filing date for the Annual Report to January 16, 2013 from NYSE Regulation, the Trust was unable to file the Annual Report by this extended deadline. NYSE Regulation declined the Trust’s request for further extension under Section 802.01C of the NYSE Listed Company Manual of the filing deadline. NYSE Regulation also noted that the average closing price of the Trust’s units had previously fallen below the NYSE’s continued listing minimum share price standard (Section 802.01E of the NYSE Listed Company Manual) of $1.00 over a consecutive 30 trading day period. Trading of the Units was suspended prior to the opening of NYSE trading on Wednesday, January 30, 2013. The Trust commenced trading on the Pink Sheets on that same day, under the symbol “TRRU”.

On August 30, 2013, the Trust simultaneously signed and closed a Purchase and Sale Agreement (“PSA”) by and among the Trust, TRC, Torch E&P Company, N.M.L. Inc., of Texas (formerly Torch Energy Services, Inc.), and Torch, pursuant to which the Trust and the Torch Energy Louisiana Royalty Trust sold all of its remaining net profits interests attributable to the underlying working interests in certain fields that produce from the Cotton Valley Fields, Austin Chalk Fields and Chalkley Field for a purchase price of $3,258,330. Pursuant to the PSA, TRC provided the Trust a release, including a release of claims with respect to TRC’s unrecouped balance pertaining to the Chalkley Gas Volume Adjustment. The unrecouped balance of $0.5 million consisted of the total amount claimed by TRC of $3.1 million minus Net Proceeds from the underlying properties withheld by TRC of $2.6 million. The PSA also provided TRC a

TORCH ENERGY ROYALTY TRUST

Notes to Financial Statements

release of claims with respect to the Trust Net Proceeds generated from TRC’s Underlying Property Interest attributable to oil and gas sales. The PSA also contains customary representations, warranties and covenants. The Trust no longer receives any proceeds from the Net Profits Interests for the Cotton Valley Fields, Austin Chalk Fields and the Chalkley Field as of May 1, 2013, the effective date of the PSA.

On December 4, 2013, the Trust announced a cash distribution of $3,390,639 or 39.426 cents per unit, payable on December 23, 2013 to Unitholders of record on December 13, 2013. On December 13, 2013, the Trust announced that the cash distribution which was announced on December 4, 2013 was adjusted downward by $360,000 due to additional expenses forecasted in the wind down and liquidation of the Trust. As a result, the previously announced applicable record date and the distribution date were adjusted accordingly. The revised distribution is $3,031,349 or 35.25 cents per Unit, payable on December 30, 2013 to Unitholders of record on December 23, 2013. This distribution mainly relates to the proceeds from the PSA. Immediately following the December 13, 2013 announcement, the Trust’s Cash Reserve, net of the $3,031,349 cash distribution payable on December 30, 2013, was approximately $510,000. To the extent that any of the Cash Reserve remains after the payment of all of the Trust’s expenses, the Trustee may make one or more additional cash distributions to the Unitholders of record; however, no assurance can be made that any such distributions will occur.

TORCH ENERGY ROYALTY TRUST

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

Results of Operations

Because a modified cash basis of accounting is utilized by the Trust, Net Proceeds attributable to the Underlying Properties for the three-month periods ended March 31, 2012 and 2011 is derived from actual oil and natural gas produced during the three-month periods ended December 31, 2011 and 2010, respectively.

The data set forth in the table below excludes the effect of the Chalkley Gas Volume Adjustment. See Notes 5 and 8 of the Trust’s accompanying financial statements for additional information concerning this adjustment.


	Three Months Ended March 31,
	2012(a)				2011
	Bbls of Oil		Mcf of Natural Gas		Bbls of Oil		Mcf of Natural Gas
Chalkley Field		438		118,366		529		145,360
Robinson’s Bend Field (b)		—		—		—		367,032
Cotton Valley Fields		345		97,542		402		106,883
Austin Chalk Fields		1,282		21,136		1,184		12,941

		2,065		237,044		2,115		632,216

(a)

Excludes the effect of the Chalkley Gas Volume Adjustment which reduced Net Proceeds paid to the Trust during the three-month period ended March 31, 2012 by $0.5 million. The Chalkley Gas Volume Adjustment did not affect Net Proceeds paid to the Trust during the three-month period ended March 31, 2011.

(b)

On December 13, 2011, the Trust sold its net profits interests with respect to the Robinson’s Bend Field to Robinson’s Bend Production II, LLC. See Note 5 of the Trust’s accompanying financial statements for additional information concerning this adjustment.

Three Months Ended March 31, 2012 Compared to Three Months Ended March 31, 2011

The Trust received no net profits income from the Trust during the three-month period ended March 31, 2012 as a result of the Chalkley Gas Volume Adjustment which recouped overpayments made to the Trust by TRC in 1994 and 1995. Neither the Trust nor Unitholders are obligated to return such overpayment to TRC; however, the Trust will receive no Net Proceeds with respect to TRC’s interests in the Underlying Properties of the Chalkley Field, the Cotton Valley Fields and the Austin Chalk Fields (“TRC Underlying Property Interests”) until future Net Proceeds from the TRC Underlying Property Interests, plus accrued interest, exceed the unrecouped balance of such overpayment. During the three-month period ended March 31, 2012, TRC withheld Net Proceeds from the Trust totaling $0.5 million. As of March 31, 2012, the unrecouped balance of the Chalkey Gas Volume Adjustment was $2.1 million. During the three-month period ended March 31, 2011, net profits income was $466,000. The Chalkley Gas

TORCH ENERGY ROYALTY TRUST

Volume Adjustment did not affect Net Proceeds paid to the Trust during the three-month period ended March 31, 2011. See Notes 4 and 8 of the Trust’s accompanying financial statements for additional information concerning this adjustment.

The Trust received no payments with respect to the Robinson’s Bend Field during the three-month period ended March 31, 2011. In calculating the Robinson’s Bend Field Net Proceeds pertaining to production during the three-month period ended March 31, 2011, costs and expenses exceeded gross revenues by approximately $0.8 million. The Trust was entitled to no payments with respect to the Robinson’s Bend Field until future proceeds exceed the sum of future costs and expenses and the cumulative excess of such costs and expenses, including interest (“Robinson’s Bend Deficit”). The Trust did not anticipate that the Net Proceeds attributable to the Robinson’s Bend Field, if any, would be significant in the future. As of March 31, 2011 (pertaining to production through March 31, 2011), the Robinson’s Bend Cumulative Deficit was approximately $7.0 million.

On December 13, 2011, the Trust entered into a purchase and sale agreement by and between Robinson’s Bend Production II, LLC (“RBP II”) pursuant to which the Trust agreed to sell, and RBP II agreed to purchase, all of the Trust’s Net Profits Interests attributable to the Underlying Properties in the Robinson’s Bend Field for a purchase price of $1,000,000. The sale signed and closed simultaneously on December 13, 2011. See Note 5 of the Trust’s accompanying financial statements for additional information.

Prior to the effect of the Chalkley Gas Volume Adjustment, natural gas production attributable to the Underlying Properties in the Chalkley, Cotton Valley and Austin Chalk Fields (excluding production generated from the Infill Wells) was 235,826 Mcf and 242,341 Mcf during the three- month periods ended March 31, 2012 and 2011, respectively. Natural gas production attributable to the Underlying Properties in the Robinson’s Bend Field (excluding production generated from the Infill Wells) was 348,652 Mcf during the three-month period ended March 31, 2011. There was no natural gas production attributable to the Underlying Properties in the Robinson’s Bend Field during the same period in 2012 as a result of the Trust selling its interests in such properties on December 13, 2011. Oil production attributable to the Underlying Properties for the three-month periods ended March 31, 2012 and 2011 was 1,808 Bbls and 2,115 Bbls, respectively. Oil production decreased during 2012 as a result of normal production declines.

During the three-month period ended March 31, 2012, the average price used to calculate Net Proceeds for natural gas, before gathering, treating and transportation deductions, was $2.79 per MMBtu as compared to $3.04 per MMBtu for the three-month period ended March 31, 2011. During the three-month period ended March 31, 2012, the average price used to calculate Net Proceeds for oil was $87.06 per Bbl as compared to $75.80 per Bbl for the three-month period ended March 31, 2011. Such average price calculations exclude the impact of the Chalkley Gas Volume Adjustment discussed in Notes 4 and 8 of the Trust accompanying financial statements.

Prior to the Trust’s termination on January 29, 2008, TEMI deducted the Price Differential and was committed to pay a Minimum Price for natural gas. When TEMI paid a purchase price for natural gas based on the Minimum Price, TEMI received Price Credits which it was entitled to deduct in determining the purchase price when the Index Price for natural gas exceeded the

TORCH ENERGY ROYALTY TRUST

Minimum Price. TEMI had not exercised its right to discontinue the Minimum Price commitment and had no outstanding Price Credits on the Termination Date. Additionally, if the Index Price for natural gas exceeded $2.10 per MMBtu, adjusted annually for inflation, TEMI deducted 50% of such excess in calculating the Net Proceeds payable to the Trust.

Upon the Trust’s termination, pursuant to each Conveyance, the Working Interest Owners used the same pricing mechanisms as the expired Purchase Contract (including the Sharing Price and Minimum Price commitment mechanisms) in calculating Net Proceeds due to the Trust. The Minimum Price per MMBtu was $2.05, $1.99 and $1.97 for 2012, 2011 and 2010 production, respectively. The Sharing Price per MMBtu was $2.54, $2.46 and $2.43 for 2012, 2011 and 2010 production, respectively. Pursuant to each Conveyance, the Working Interest Owners also have the same annual option to discontinue the Minimum Price commitment. As of March 31, 2012 and December 31, 2011, the Working Interest Owners had no outstanding Price Credits and had not exercised their right to discontinue the Minimum Price commitment. No Price Credits were deducted in calculating the purchase price related to net profits income during each of the three-month periods ended March 31, 2012 and 2011. The deduction of the Price Differential in connection with the Sharing Price mechanism reduced Net Proceeds paid to the Trust during the three-month periods ended March 31, 2012 and 2011 by $.02 million and $0.4 million, respectively.

During each of the three-month periods ended March 31, 2012 and 2011, the Trust recognized no Infill Well income pertaining to Infill Wells in the Cotton Valley Fields as a result of the timing of the receipts of such income by the Trust. Such Infill Wells are operated by Samson Lone Star Limited Partnership.

Prior to the effect of the Chalkley Gas Volume Adjustment, lease operating expenses and capital expenditures attributable to the Underlying Properties in the Chalkley, Cotton Valley and Austin Chalk Fields deducted in calculating Net Proceeds due to the Trust for the three-month periods ended March 31, 2012 and 2011 totaled $0.3 million and $0.4 million, respectively. With respect to the Robinsons’ Bend Field, lease operating expenses and capital expenditures of $1.6 million were deducted in calculating the Net Proceeds payable to the Trust from the Robinson’s Bend Field for the three-month period ended March 31, 2011. The Trust sold its interest in the Robinson’s Bend Field in December 2011 as disclosed above in this item.

General and administrative expenses amounted to $0.3 million and $0.4 million for the three-month periods ended March 31, 2012 and 2011, respectively. Such general and administrative expenses include costs pertaining to the administrative services provided by Torch and the Trustee, legal fees, accounting and audit fees, reserve report preparation fees, and Unitholder report printing fees.

Pursuant to the Trust Agreement, the Trustee established a cash reserve (“Cash Reserve”) following the Trust’s termination in 2008 for the payment of actual, contingent and uncertain liabilities associated with the liquidation and winding down of the Trust and the Trust’s arbitration. During the three-month period ended March 31, 2011, the Trust received cash payments totaling $0.5 million from the Working Interest Owners of the Underlying Properties pertaining to Net Proceeds from net profits income. All such receipts were allocated to the Trust’s Cash Reserve. The Trust received no cash payments from the Working Interest Owners during the three-month period ended March 31, 2012. The Cash Reserve as of March 31, 2012 and 2011 was $1.9 million and $2.4 million, respectively.

TORCH ENERGY ROYALTY TRUST

The foregoing resulted in a distributable loss of $0.3 million, or $.04 per Unit, for the three-month period ended March 31, 2012 as compared to distributable income of $0.06 million, or $0.01 per Unit, for the same period in 2011. During each of the three-month periods ended March 31, 2012 and 2011, the Trust made no cash distributions to Unitholders.

Net profits income received by the Trust during the three-month periods ended March 31, 2012 and 2011, derived from production sold during the three-month periods ended December 31, 2011 and 2010, respectively, was computed as shown in the following table (in thousands):


	Three Months Ended March 31, 2012 (a)									Three Months Ended March 31, 2011
	Chalkley, Cotton Valley and Austin Chalk Fields			Robinson’s Bend Field			Total			Chalkley, Cotton Valley and Austin Chalk Fields			Robinson’s Bend Field			Total
Oil and natural gas revenues	$	867		$	—		$	772		$	969		$	948		$	1,917


Direct operating expenses:
Lease operating expenses and property tax		282			—			341			398			1,709			2,107
Severance tax		70			—			61			66			61			127

		352			—			402			464			1,770			2,234

Net proceeds before capital expenditures		515			—			370			505			(822	)		(317	)
Capital expenditures		(6	)		—			1			14			2			16

Net proceeds		521			—			369			491			(824	)		(333	)
Net profits percentage		95	%		—	(b)		—			95	%		—	(b)		—

Net profits income		495			—			351			466			—			—
Chalkley Gas Volume Adj. (a)		(495	)					(351	)		—			—			—

Net profits income	$	—		$	—		$	—		$	466		$	—		$	466

(a)

The Chalkley Gas Volume Adjustment reduced net profits income during the three-month period ended March 31, 2012 by $0.5 million. See Notes 4 and 8 to the Trust’s accompanying financial statements for additional information.

(b)

With respect to the Robinson’s Bend Field, the Trust received no cash distributions during the three-month periods ended March 31, 2011. The Trust sold all of its net profits interests attributable to the Underlying Properties in the Robinson’s Bend Field on December 13, 2011. See Note 5 to the Trust’s accompanying financial statements for additional information.

Item 3. Quantitative and Qualitative Disclosures about Market Risk

The Trust is exposed to market risk, including adverse changes in commodity prices. The Trust’s assets constitute Net Profits Interests in the Underlying Properties. As a result, the Trust’s operating results can be significantly affected by fluctuations in commodity prices caused by changing market forces and the price received for production from the Underlying Properties.

TORCH ENERGY ROYALTY TRUST

All production from the Underlying Properties during the period from the inception of the Trust to the Trust’s termination on January 29, 2008 was sold pursuant to a Purchase Contract between TRC, Velasco, and TEMI. The Purchase Contract expired upon the Trust’s termination. Pursuant to the Purchase Contract, TEMI was obligated to purchase all net production attributable to the Underlying Properties for an Index Price, less certain other charges, which were calculated monthly. The Index Price calculation was based on market prices of oil and natural gas and therefore was subject to commodity price risk. The Purchase Contract also provided a Minimum Price paid by TEMI for natural gas. When TEMI paid a purchase price based on the Minimum Price, it received Price Credits equal to the difference between the Index Price and the Minimum Price that TEMI was entitled to deduct when the Index Price exceeded the Minimum Price. Additionally, if the Index Price exceeded the Sharing Price, TEMI was entitled to deduct such excess, the Price Differential. TEMI had the annual option to discontinue the Minimum Price commitment. However, if TEMI discontinued the Minimum Price commitment, it would no longer be entitled to deduct the Price Differential and would forfeit all accrued Price Credits. TEMI did not exercise its right to discontinue the Minimum Price commitment and had no outstanding Price Credits on the Termination Date.

Upon the Trust’s termination, pursuant to each Conveyance, the Working Interest Owners calculated Net Proceeds owed to the Trust utilizing the same pricing mechanisms (including the Sharing Price and Minimum Price commitment mechanisms) as the terminated Purchase Contract. The Minimum Price per MMBtu was adjusted annually for inflation and was $2.05, $1.99 and $1.97 for 2012, 2011 and 2010 natural gas sales, respectively. The Sharing Price per MMBtu was $2.54, $2.46 and $2.43 for 2012, 2011 and 2010 natural gas sales, respectively. Pursuant to each Conveyance, the Working Interest Owners also have the same annual option to discontinue the Minimum Price commitment. However, if the Working Interest Owners discontinue the Minimum Price commitment, they will no longer be entitled to deduct the Price Differential and will forfeit all accrued Price Credits. The Working Interest Owners had not exercised their option to discontinue the Minimum Price commitment and had no outstanding Price Credits as of March 31, 2012.

TORCH ENERGY ROYALTY TRUST

Item 4. Controls and Procedures

Evaluation of Disclosure Controls and Procedures.

The Trustee carried out an evaluation of the effectiveness of the design and operation of the Trust’s disclosure controls and procedures pursuant to Exchange Act Rules 13a-15 and 15d-15 as of the end of the period covered by this report. Based upon that evaluation, the Trustee concluded that the Trust’s disclosure controls and procedures are effective in timely alerting the Trustee to material information relating to the Trust required to be included in the Trust’s periodic filings with the SEC. In their evaluation of disclosure controls and procedures, the Trustee and Trust has relied, to the extent considered reasonable, on information provided by Torch and Watkins Meegan LLC, an accounting firm contracted by the Trust to perform certain Sarbanes-Oxley compliance for the Trust.

Changes in Internal Control over Financial Reporting.

There has not been any change in the Trust’s internal control over financial reporting during the three-month period ended March 31, 2012 that has materially affected, or is reasonably likely to materially affect, the Trust’s internal control over financial reporting. The Trust and Trustee rely on third party service providers to perform administrative services for the Trust. Torch provided accounting, bookkeeping, informational and other services to the Trust related to the Net Profits Interests pursuant to the Administrative Services Agreement effective October 1, 1993 and an oral arrangement after termination of the Administrative Services Agreement on January 29, 2008 through April 1, 2008. From November 7, 2008 through December 23, 2008, Torch provided certain accounting services in connection with the Trust’s preparation of its Form 10-K for the year ended December 31, 2007 pursuant to an agreement between the Trust and Torch dated November 7, 2008. To facilitate the winding down of the Trust, Torch currently provides certain accounting and other services for the Trust pursuant to an agreement with the Trust entered into on March 26, 2009. The initial term of the agreement expired on March 31, 2010 and was thereafter extended from year to year, up to the period ending August 30, 2013. Torch currently provides the Trust via letter agreement the administrative services historically provided by Torch to the Trust through December 31, 2013 consistent with past practice and (ii) from December 31, 2013 to April 30, 2014 shall provide services to the Trust in support of any tax correspondence (tax booklet) and tax filings that might be necessary for the year ended December 31, 2013 consistent with past practice and other related services necessary to complete the wind down of the Trust that are also consistent with past practice. Subsequently, the inability of the Trust to hire qualified services providers to assist in the wind down and liquidation of the Trust may have a material adverse effect on the operations of the Trust.

PART II. OTHER INFORMATION

ITEM 1.

Legal Proceedings

On October 16, 2008, Trust Venture Company, LLC and Wilmington Trust Company, solely in its capacity as Trustee for the Torch Energy Royalty Trust, (together, “Plaintiffs”) filed a petition against TRC, Torch E&P Company, and Constellation Energy Partners LLC (collectively, “Defendants”) in the District Court of Harris County, Texas. The petition sought to vacate the

TORCH ENERGY ROYALTY TRUST

arbitration award issued by the JAMS Panel in Defendants’ favor on July 18, 2008 in the arbitration captioned Torch Royalty Co., et al. v. Wilmington Trust Co., et al., JAMS Reference No. 13100017310. Defendants filed a motion to dismiss the Plaintiffs’ petition and to confirm the arbitration award. On or about December 10, 2008, the Court entered an Order dismissing the petition and granting the Defendants’ motion to confirm the arbitration award.

On December 22, 2008, the Trustee received a demand letter from Trust Venture Company, LLC with respect to certain enumerated costs - including administrative costs and costs for water gathering, treating and disposal - that are deducted by the working interest owners of certain of the Underlying Properties from the Net Profit Interests before remitting the Net Proceeds to the Trustee and the Trust. Trust Venture Company, LLC has concluded that the Trust has been overcharged (and continues to be overcharged) by the working interest owners of certain of the Underlying Properties and that these overcharges have damaged the Trust (and as a result, all of the Trust’s Unitholders). In addition, Trust Venture Company, LLC asserts that the working interest owners have failed to provide the required accountings as set forth in the Conveyances and that the Trust may request the court to require the working interest owners to provide such an accounting. Trust Venture Company, LLC requested that the Trustee either institute legal action against the working interest owners, or authorize Trust Venture Company, LLC to commence a derivative action against the current working interest owner of the Alabama property in accordance with, inter alia, Section 3816 of the Delaware Statutory Trust Act, codified at 12 Del. C. 3816(a), to recover all overcharges related to administrative costs, water gathering, treating and disposal costs and all overcharges reflected in the accounting. The Trustee responded on December 22, 2008 to Trust Venture Company, LLC with a request for additional information which it has now received. The Trustee carefully considered Trust Venture Company, LLC’s demand letter, and concluded, in the reasoned exercise of its business judgment, that it is in the best interest of the Trust and all Unitholders to authorize Trust Venture Company, LLC to commence a derivative action and provided its authorization as of December 30, 2008.

As disclosed by the Trust in its Annual Report on Form 10-K for the year ended December 31, 2007 (“2007 Annual Report”), Trust Venture intended to commence a derivative action against Constellation Energy Partners LLC, the working interest owner of certain oil and natural gas fields located in Alabama, in accordance with, inter alia, Section 3816 of the Delaware Statutory Trust Act, codified at 12 Del. C. 3816(a), to (i) recover any overcharges to the Trust by Constellation Energy Partners LLC related to administrative costs, water gathering, treating and disposal costs and severance taxes and (ii) require Constellation Energy Partners LLC to provide an accounting of its revenues and expenses as required under the Conveyance filed of record in Tuscaloosa County, Alabama. On December 30, 2008, Trust Venture Company, LLC filed and subsequently served a derivative lawsuit against Constellation Energy Partners LLC in Alabama state court alleging such overcharges, challenging the calculation of the Net Profits Interests under the Conveyances that were used to transfer the Net Profits Interests in each state, and demanding an accounting of Constellation Energy Partners LLC’s revenues and expenses. In response to the derivative lawsuit, on February 9, 2009, Constellation Energy Partners LLC filed in Alabama state court a motion to dismiss such lawsuit without prejudice in favor of arbitration in Texas on various grounds, including Trust Venture Company, LLC’s alleged lack of standing and Trust Venture’s alleged failure to comply with certain contractual agreements. The Alabama state court denied Constellation Energy Partners LLC’s motion to dismiss on February 25, 2009, and so the Alabama derivative action is proceeding against Constellation Energy Partners LLC.

TORCH ENERGY ROYALTY TRUST

On February 12, 2009, the Trustee received a certified copy of a demand for arbitration dated February 9, 2009 by Constellation Energy Partners LLC before JAMS in Texas (the “Demand Notice”) seeking a declaratory judgment that Constellation Energy Partners LLC (i) correctly calculated and paid the Net Profits Interests payments due to the Trust, (ii) correctly charged the Trust for certain well accounting services and severance taxes, and (iii) has complied with its contractual reporting requirements due to the Trust. In the Demand Notice, Constellation Energy Partners LLC claimed that, because the Trust authorized Trust Venture to file the derivative lawsuit, “there exists a judicable conflict between Constellation Energy Partners LLC and the Trust that is subject to resolution by arbitration.”

On February 12, 2009, Trust Venture Company, LLC filed an emergency motion in Alabama state court to stay the arbitration demanded by Constellation Energy Partners LLC until such time as the court issues a judgment as to the enforceability of the arbitration agreement made by and between the Trust and Constellation Energy Partners LLC. The court denied that motion on February 25, 2009. On March 9, 2009, the Trustee filed its own motion in the same Alabama state court seeking to intervene in the derivative action for the limited purpose of moving for a stay of the Texas arbitration until resolution of the derivative action. The Alabama state court heard oral argument on the Trustee’s motion on March 25, 2009, and on April 1, 2009, the Alabama state court denied the Trustee’s motion to stay the Texas arbitration and further denied Constellation Energy Partners LLC’s motion to stay the Alabama state court derivative action. Subsequently, the Trustee filed a motion to dismiss or stay the Texas arbitration with JAMS and the arbitration panel heard oral argument on April 10, 2009 and on April 13, 2009 granted the Trustee’s motion to stay the Texas arbitration proceedings pending the outcome of the Alabama derivative action. The arbitration panel subsequently entered an Order of Dismissal with respect to the Texas arbitration dated July 27, 2009. There can be no assurance as to the outcome or result of the Alabama derivative litigation or that Constellation Energy Partners LLC will not challenge the Order of Dismissal entered by the arbitration panel on July 27, 2009 or file other arbitration claims. On August 21, 2009, the Alabama state court added the Trust as a nominal plaintiff in the Alabama derivative action that is proceeding against Constellation Energy Partners LLC.

The Trust has also previously disclosed information regarding the termination of the Trust, the ongoing Alabama derivative litigation, the concluded Texas arbitration and other information regarding the Trust on its 2007, 2008, 2009 and 2010 Annual Report on Form 10-K filed with the SEC and its Current Reports on Form 8-K filed with the SEC. The Unitholders are urged to read the above mentioned and all other filings by the Trust with the SEC carefully and in their entirety.

On February 23, 2011, the Trust issued a press release and disclosed information regarding the ongoing Alabama derivative litigation on its Current Report on Form 8-K. In the press release, the Trust announced that it and the derivative unitholder plaintiff reached an agreement in principle with Constellation Energy Partners LLC to settle certain claims in the litigation, captioned Trust Venture Company, LLC v. Constellation Energy Partners LLC (CV-2008-900751), filed by the derivative plaintiff on the Trust’s behalf in the Circuit Court of Tuscaloosa County, Alabama (the “Settlement”).

TORCH ENERGY ROYALTY TRUST

As stated in the press release and the Notice of Pendency of Derivative Action, Proposed Settlement of Derivative Action, Settlement Hearing, and Right to Appear, in the form approved by the Court and attached to the Form 8-K filed with the SEC on February 23, 2011, subject to the approval of the Court, the derivative plaintiff (Trust Venture Company, LLC) and the Trust have agreed to settle the claims against Constellation Energy Partners LLC in the derivative action, and to enter into mutual, general releases with Constellation Energy Partners LLC in return for (i) a payment of $1,200,000 to the derivative plaintiff by Robinson’s Bend Production II (“RBP II”), which is a Delaware limited liability company and an affiliate of Constellation Energy Partners LLC, to reimburse the derivative plaintiff for the legal fees and expenses it incurred in prosecuting the derivative action, (ii) an irrevocable bid by RBP II of not less than $1,000,000 for its purchase from the Trust of the net overriding royalty interest (“Alabama NORRI”), when such Alabama NORRI is separately offered for sale by the Trust at public auction within 180 days of the effective date of the Settlement, with such bid amount to be deposited by RBP II in a third-party escrow account pending the public auction, and (iii) a third amendment to that certain Water Gathering and Disposal Agreement providing that, for a period of ten years commencing on the first day of the month following the effective date of the settlement, the charges for the gathering, separation, and disposal of water from oil and gas wells located in Tuscaloosa County, Alabama that are owned and operated by RBP II (“Wells”) shall be $0.53 per barrel of water. (RBP II currently charges $1.00 per barrel of water for the gathering, separation, and disposal of such water from the Wells).

The Alabama Circuit Court of Tuscaloosa County, Alabama convened a hearing on the settlement on April 11, 2011, at 2:00 p.m. CDT (the “Settlement Hearing”). At the Settlement Hearing, the Court determined whether or not (i) to approve the Settlement as memorialized in the proposed Settlement and Release Agreement with Constellation Energy Partners LLC, and (ii) to approve an Order ending this derivative action. On February 23, 2011, the Trust sent the Notice of Pendency of Derivative Action, Proposed Settlement of Derivative Action, Settlement Hearing, and Right to Appear to the Trust’s unitholders of record as of February 11, 2011, as required by the Settlement. On April 18, 2011, the Trust issued a press release and disclosed information on its Current Report on Form 8-K that the Alabama Circuit Court of Tuscaloosa County, Alabama approved in all respects the settlement as memorialized in the proposed Settlement and Release Agreement and ordered that the matter be dismissed, with prejudice, costs taxed as paid. In the Order and Final Judgment entered by the Court dated as of April 13, 2011, the Circuit Court acknowledged receiving the report from counsel for the trustee of the Trust that no objections to the proposed settlement in this matter had been received, and the Court confirmed after review that the Settlement and Release Agreement is fair, reasonable and adequate. The Settlement and Release Agreement became effective on June 13, 2011.

As previously disclosed on current Report Form 8-K filed on January 31, 2008, the Trust received the affirmative vote of the Unitholders of more than 66 2/3% of the outstanding units to terminate the Trust at the meeting of Unitholders held January 29, 2008. Pursuant to the Trust Agreement of the Trust, the “Termination Date” of the Trust is January 29, 2008.

Upon termination of the Trust, among other things, the Trustee is required to sell the Net Profits Interests. Specifically, pursuant to Section 9.03(e) of the Trust Agreement if the property of the Trust Estate (as defined in the Trust Agreement) has not been sold prior to the end of one calendar year following the termination date, the Trustee must cause such assets to be sold at

TORCH ENERGY ROYALTY TRUST

public auction. All of the Net Profits Interests have been sold and the Trust is wind-down operations. No assurances can be given by the Trustee with respect to the amount that will be distributed to Unitholders following the sales. Such distributions could be below the market value of the Units.

ITEM 1A.

Risk Factors

The Trust believes there have been no material changes to risk factors previously disclosed in our Annual Report on Form 10-K for the fiscal year ended December 31, 2011, filed with the SEC on April 22, 2011 (the “2011 Form 10-K”). You should carefully consider such risk factors as presented in the 2011 Form 10-K and other information set forth in this Quarterly Report on Form 10-Q, including our financial statements and the related notes.

ITEM 2.

Unregistered Sales of Equity Securities and Use of Proceeds

None.

ITEM 3.

Defaults upon Senior Securities

None.

ITEM 4.

(Removed and Reserved)

ITEM 5.

Other Information

None.

ITEM 6.

Exhibits

(a) Exhibits

4. Instruments of defining the rights of security holders, including indentures.

4.1

Form of Torch Energy Royalty Trust Agreement. *

4.2

Form of Louisiana Trust Agreement. *

4.3

Specimen Trust Unit Certificate. *

4.4

Designation of Ancillary Trustee. *

31.1

Certification pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1

Certification pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

Incorporated by reference from Registration Statements on Form S-1 of Torch Energy Advisors Incorporated (Registration No. 33-68688) dated November 16, 1993.

TORCH ENERGY ROYALTY TRUST

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.


TORCH ENERGY ROYALTY TRUST

By: Wilmington Trust Company, not in its individual capacity but solely as Trustee for the Trust

By:		/s/ David A. Vanaskey
		David A. Vanaskey
		Vice President

Date: February 3, 2014

(The Trust has no employees, directors or executive officers.)