UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q


þ		Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended ~~June~~September 30, 2010


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: 1-11608

WILLIAMS COAL SEAM GAS ROYALTY TRUST

(Exact name of registrant as specified in its charter)

Delaware (State or other jurisdiction of incorporation or organization) 75-6437433 (I.R.S. Employer Identification No.)


Delaware		75-6437433
(State or other jurisdiction		(I.R.S. Employer
of incorporation or		Identification No.)
organization)

Trust Division U.S. Trust, Bank of America Private Wealth Management 901 Main Street 17th Floor Dallas, Texas 75202 (Address of principal executive offices) (Zip code) (214) 209-2400 (Registrant’s telephone number, including area code)

(214) 209-2400 (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 þ 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 Regulations 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. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer o Accelerated filer o Non-accelerated filer þ Smaller reporting company o (Do not check if a smaller reporting company) ~~Smaller reporting company 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 þ

Number of units of beneficial interest outstanding at ~~August~~November 1615, 2010: 9,700,000

TABLE OF CONTENTS

PART I — FINANCIAL INFORMATION
	Item 1. Financial Statements
	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
	Items 1A through 5
	Item 1A. Risk Factors
	Items 2 through 5
	Item 6. Exhibits
SIGNATURES
EX-4.5
INDEX TO EXHIBITS
EX-3.2
EX-4.6
EX-10.10
EX-15.1
EX-31.1
EX-32.1

PART I — FINANCIAL INFORMATION

Item 1. Financial Statements.

The financial statements included herein have been prepared by Bank of America, N.A., as Trustee (the “Trustee”) of Williams Coal Seam Gas Royalty Trust (the “Trust”), pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in annual financial statements have been condensed or omitted pursuant to such rules and regulations, although the Trustee believes that the disclosures are adequate to make the information presented not misleading. It is suggested that these condensed financial statements and notes thereto 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, 2009 (the “2009 Annual Report”). The December 31, 2009 balance sheet is derived from the audited balance sheet of that date. In the opinion of the Trustee, all adjustments, consisting only of normal recurring adjustments, necessary to present fairly the assets, liabilities and trust corpus of the Trust as of ~~June~~September 30, 2010, ~~and~~ the distributable income for the three-month and ~~six~~nine-month periods ended ~~June~~September 30, 2010 and 2009, and the changes in trust corpus for the ~~six~~nine-month ~~periods~~ periods ended ~~June~~September 30, 2010 and 2009, have been included. The distributable income for such ~~interim~~ interim periods is not necessarily indicative of the distributable income for the full year.

The financial statements as of ~~June~~September 30, 2010, and for the three-month and ~~six~~nine-month ~~periods~~ periods ended ~~June~~September 30, 2010 and 2009 included herein have been reviewed by Ernst & Young LLP, an an independent registered public accounting firm, as stated in their report appearing herein.

Report of Independent Registered Public Accounting Firm

The Trustee
Williams Coal Seam Gas Royalty Trust

We have reviewed the condensed statement of assets, liabilities and trust corpus of the Williams Coal Seam Gas Royalty Trust as of ~~June~~September 30, 2010, and the related condensed statements of distributable income for the three-month and ~~six~~nine-month periods ended ~~June~~September 30, 2010 and 2009, ~~and~~ and the condensed statements of changes in trust corpus for the ~~six~~nine-month periods ended ~~June~~ September 30, 2010 and 2009. These financial statements are the responsibility of the Trustee’s management.

We conducted our review in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board, the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

As described in Note 2 to the financial statements, these financial statements have been prepared on a modified cash basis of accounting, which is a comprehensive basis of accounting other than U.S. generally accepted accounting principles.

Based on our review, we are not aware of any material modifications that should be made to the condensed financial statements referred to above for them to be in conformity with the basis of accounting described in Note 2.

We have previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the statement of assets, liabilities and trust corpus of the Williams Coal Seam Gas Royalty Trust as of December 31, 2009, and the related statements of distributable income and changes in trust corpus for the year then ended not provided herein, and in our report dated March 31, 2010, we expressed an unqualified opinion on those financial statements and included explanatory paragraphs regarding the Williams Coal Seam Gas Royalty Trust’s ability to continue as a going concern and regarding the Trust’s change in its reserve estimates and related disclosures as a result of adopting new oil and gas reserve estimation and disclosure requirements. In our opinion, the information set forth in the accompanying condensed statement of assets, liabilities and trust corpus as of December 31, 2009, is fairly stated, in all material respects, in relation to the statement of assets, liabilities and trust corpus from which it has been derived.

/s/ Ernst & Young LLP

Tulsa, Oklahoma ~~August~~November 1617, 2010

WILLIAMS COAL SEAM GAS ROYALTY TRUST

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

	June 30,		December 31,
	September 30,		December 31,
	2010		2009
	(Unaudited)
ASSETS
Current Assets — cash and cash equivalents	$	~~166~~148,~~226~~199	$	52,195
Royalty interests in oil and gas properties (less accumulated amortization of $134,882,068 at June 30, 2010 and $134,091,719 at December 31, 2009) (Note 2)		3,684,596		4,474,945
Royalty interests in oil and gas properties (less accumulated amortization of $135,534,569 at September 30, 2010 and $134,091,719 at December 31, 2009) (Note 2)		3,032,095		4,474,945
TOTAL ASSETS	$	3,~~850~~180,~~822~~294	$	4,527,140
LIABILITIES AND TRUST CORPUS
Current Liabilities:
Accounts payable	$	3029,~~907~~739	$	116,341
Trust corpus — 9,700,000 units of beneficial interest authorized and outstanding (Note 2)		3,~~819~~150,~~915~~555		4,410,799
TOTAL LIABILITIES AND TRUST CORPUS	$	3,~~850~~180,~~822~~294	$	4,527,140

The accompanying notes are an integral part of these financial statements. See accountants’ review report.

WILLIAMS COAL SEAM GAS ROYALTY TRUST

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)

	THREE MONTHS			THREE MONTHS
	ENDED			ENDED
	June 30, 2010			June 30, 2009
	September 30, 2010			September 30, 2009
Royalty income (Notes 2, 4 and 7)	$	407,607		$	931,608
Royalty income (Notes 2, 4 and 6)	$	1,483,027		$	77,767
Interest income		50206			~~180~~42
Total		~~407~~1,~~657~~483,233			~~931~~77,~~788~~809
General and administrative expenses (Note 4)		(~~174~~217,~~670~~014	)		(~~266~~182,~~079~~005	)
Distributable income	$	232,987		$	655,709
Distributable income (expenses in excess of income)	$	1,266,219		$	(104,196	)
Distributable income per unit (9,700,000 units) (Note 2)	$	0.0213		$	(.0701	)

The accompanying notes are an integral part of these financial statements. See accountants’ review report.

WILLIAMS COAL SEAM GAS ROYALTY TRUST

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME (UNAUDITED)

	SIX MONTHS			SIX MONTHS
	NINE MONTHS			NINE MONTHS
	ENDED			ENDED
	June 30, 2010			June 30, 2009
	September 30, 2010			September 30, 2009
Royalty income (Notes 2, 4 and 7)	$	1,172,185		$	2,325,261
Royalty income (Notes 2, 4 and 6)	$	2,655,212		$	2,403,029
Interest income		~~117~~323			~~799~~841
Total		12,~~172~~655,~~302~~535			2,~~326~~403,~~060~~870
General and administrative expenses (Note 4)		(~~700~~917,~~539~~553	)		(~~638~~820,~~367~~886	)
Distributable income	$	~~471~~1,~~763~~737,982		$	1,~~687~~582,~~693~~984
Distributable income per unit (9,700,000 units) (Note 2)	$	0.0518		$	0.1716

The accompanying notes are an integral part of these financial statements. See accountants’ review report.

WILLIAMS COAL SEAM GAS ROYALTY TRUST

CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS (UNAUDITED)

	SIX MONTHS			SIX MONTHS
	NINE MONTHS			NINE MONTHS
	ENDED			ENDED
	June 30, 2010			June 30, 2009
	September 30, 2010			September 30, 2009
Trust corpus, beginning of period	$	4,410,799		$	5,592,220
Amortization of royalty interests (Note 2)		(~~790~~1,~~349~~442,850	)		(~~656~~736,~~315~~649	)
Distributable income		~~471~~1,~~763~~737,982			1,~~687~~582,~~693~~984
Distributions to Unitholders (Note 5)		(~~272~~1,~~298~~555,376	)		(1,736,104	)
Trust corpus, end of period	$	3,~~819~~150,~~915~~555		$	4,~~887~~702,~~494~~451
Distributions per unit (9,700,000 units) (Note 5)	$	0.0316		$	0.18

The accompanying notes are an integral part of these financial statements. See accountants’ review report.

WILLIAMS COAL SEAM GAS ROYALTY TRUST

NOTES TO FINANCIAL STATEMENTS (UNAUDITED)

1. TRUST ORGANIZATION AND PROVISIONS

Williams Coal Seam Gas Royalty Trust (the “Trust”) was formed as a Delaware business trust pursuant to the terms of the Trust Agreement of Williams Coal Seam Gas Royalty Trust (as amended, the “Trust Agreement”) entered into effective as of December 1, 1992, by and among Williams Production Company, a Delaware corporation (“WPC”), as trustor; The Williams Companies, Inc., a Delaware corporation (“Williams”), as sponsor; Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), a national banking association (the “Trustee”); and ~~The~~BNY ~~Bank of New York~~ Mellon Trust ~~Company,~~of ~~N.A.~~ Delaware (as successor to Chemical Bank Delaware), a Delaware banking corporation (the “Delaware Trustee”) (the “Trustee” and the “Delaware Trustee” are sometimes referred to collectively as the “Trustees”). The Trustees are independent financial institutions. In 2007 the Bank of America private wealth management group officially became known as “U.S. Trust, Bank of America Private Wealth Management.” The legal entity that serves as Trustee of the Trust did not change, and references in this report on Form 10-Q to U.S. Trust, Bank of America Private Wealth ~~Management~~ Management shall describe the legal entity Bank of America, N.A.

The Trust was formed to acquire and hold certain net profits interests (the “Royalty Interests”) in proved natural gas properties located in the San Juan Basin of New Mexico and Colorado (the “Underlying Properties”) owned by WPC. The Trust was initially created effective as of December 1, 1992, with a $100 contribution by WPC. On January 21, 1993, the Royalty Interests were conveyed to the Trust by WPC pursuant to the Net Profits Conveyance (the “Conveyance”) entered into effective as of October 1, 1992, by and among WPC, Williams, the Trustee and the Delaware Trustee, in consideration for all the 9,700,000 authorized units of beneficial interest in the Trust (“Units”). WPC transferred its Units by dividend to its parent, Williams, which sold an aggregate of 5,980,000 Units to the public through various underwriters in January and February 1993 (the “Public Offering”). Subsequently, Williams sold to the public an additional 151,209 Units. During the second quarter of 1995, Williams transferred its remaining Units to Williams Holdings of Delaware, Inc. (“WHD”), a separate holding company for Williams’ non-regulated businesses. Effective July 31, 1999, WHD was merged into Williams, and by operation of the merger, Williams assumed all assets, liabilities and obligations of WHD, including without limitation, ownership of WHD’s Units. Effective August 11, 2000, Williams sold its Units to Quatro Finale IV LLC, a Delaware limited liability company (“QFIV”), in a privately negotiated transaction. Williams retained the voting rights and retained a “call” option on the transferred Units, and QFIV was granted a “put” option on the Units. Through a series of exercises of its call option, Williams reacquired an aggregate of 3,568,791 Units from December 2001 through June 2003. Williams has informed the Trustee that it has subsequently sold 2,779,500 of these Units through ~~August~~ November 1, 2010 and owned a remaining 789,291 Units as of such date.

Effective May 1, 1997, WPC sold the Underlying Properties subject to and burdened by the Royalty Interests to Quatro Finale LLC, an unaffiliated Delaware limited liability company. Ownership of the Underlying Properties reverted back to WPC effective February 1, 2001, pursuant to the terms of the May 1, 1997 transaction. Pursuant to a Purchase and Sale Agreement dated March 14, 2001 (the “2001 Transaction Agreement”), and effective March 1, 2001, WPC sold the Underlying Properties subject to and burdened by the Royalty Interests to Quatro Finale V LLC, an unaffiliated Delaware limited liability company. The sale of the Underlying Properties iswas expressly permitted under the Trust Agreement. Effective January 1, 2003, ownership of the Underlying Properties once again reverted back to WPC after it exercised its right to repurchase interests in the Underlying Properties from Quatro Finale V LLC pursuant to the 2001 Transaction Agreement. Unless otherwise dictated by context, references herein to WPC with respect to the ownership of the Underlying Properties for any period from May 1, 1997 through February 1, 2001, and for the period from March 1, 2001 through December 31, 2002, shall be deemed to refer to Quatro Finale.

The Trustee has the power to collect and distribute the proceeds received by the Trust and to pay Trust liabilities and expenses. The Delaware Trustee has only such powers as are set forth in the Trust Agreement and is not empowered to otherwise manage or take part in the business of the Trust. The Royalty Interests are passive in nature, and neither the Delaware Trustee nor the Trustee has any control over or any responsibility relating to the operation of the Underlying Properties.

~~The~~Prior to the sale of the Trust’s assets described in Note 2 below, the only assets of the Trust, other than cash and cash equivalents being held for the payment of expenses and liabilities and for distribution to Unitholders, ~~are~~were the Royalty Interests. The Royalty Interests ~~consist~~ consisted primarily of a net profits interest (the “NPI”) in the Underlying Properties. The NPI generally entitled ~~entitles~~ the Trust to receive 60 percent of the NPI Net Proceeds, as defined below, attributable to (i) gas produced and sold from WPC’s net revenue interests (working interests less lease burdens) in the properties in which WPC has a working interest (the “WI Properties”) and (ii) the revenue stream received by WPC attributable to its 35 percent net profits interest in 5,348 gross acres in La Plata County, Colorado (the “Farmout Properties”). “NPI Net Proceeds” consists generally of the aggregate proceeds attributable to WPC’s net revenue interest, based on the sale at the wellhead of gas produced from the WI Properties and the revenue stream received by WPC from its 35 percent net profits interest in the Farmout Properties, less certain taxes and costs.

The Royalty Interests also include a 20 percent interest in WPC’s Infill Net Proceeds from the sale of production since well spacing rules have been effectively modified and additional wells are drilled on producing drilling blocks on the WI Properties (the “Infill Wells”) during the term of the Trust. “Infill Net Proceeds” consists generally of the aggregate proceeds, after payout, based on the price at the wellhead, of gas produced from WPC’s net revenue interest in any Infill Wells less certain taxes and costs.

On October 15, 2002, the New Mexico Oil and Gas Commission (NMOCD) revised the field rules for the Basin Fruitland Coal (Gas) Pool to allow optional second (infill) wells on the standard 320 acre spacing unit in certain designated areas of the pool (the non-fairway wells). On July 17, 2003, the NMOCD further modified the field rules for the Basin Fruitland Coal (Gas) Pool to allow these infill wells on the standard 320 acre spacing unit in all areas of the

pool. The WI Properties contain 442 infill locations designated as proved locations according to U.S. Securities and Exchange Commission (“SEC”) guidelines. As of ~~June~~September 30, 2010, all of these infill locations represent proved developed producing reserves, while there are no economical proved undeveloped locations.

WPC has informed the Trustee that the Infill Wells reached payout in the aggregate during 2008. However, during 2009, WPC informed the Trustee that due to the net deficit realized by the Infill Wells during the third and fourth quarters of 2009, the Infill Net Profit Costs exceeded the Infill Net Profit Gross Proceeds. The Trust was not liable for such excess costs, and such excess costs constituted Excess Infill Net Profits Costs until recovered by WPC from the distribution received by the Trust during the first quarter of 2010. The complete definitions of Infill Net Proceeds, Infill Net Profit Costs, Excess Infill Net Profit Costs, and Infill Net Profit Gross Proceeds are set forth in the Conveyance.

2. BASIS OF ACCOUNTING

The Trust terminated effective March 1, 2010 (the “Termination Date”), pursuant to the terms of the Trust Agreement. Accordingly, there exists substantial doubt about the Trust’s ability to continue as a going concern. Cancellation of the Trust will occur ~~on or~~ following the Termination ~~Date~~ Date when ~~all~~the ~~Trust~~net ~~assets~~proceeds ~~have~~from ~~been~~the ~~sold~~sale ~~and~~of the ~~net~~Trust’s ~~proceeds~~assets ~~therefrom~~have been distributed to holders of ~~Units~~ Units in the Trust (“Unitholders”).

The Trust Agreement required termination of the Trust in the event that when a computation is performed as of each December 31, the net present value (discounted at 10 percent) of the estimated future net revenues (calculated in accordance with criteria established by the SEC) for proved reserves attributable to the Royalty Interests but using the average monthly Blanco Hub Spot Price for the past calendar year less certain gathering costs, is equal to or less than $30 million. The net present value of the estimated future net revenues computed as described above by the independent petroleum engineers as of December 31, 2009 was approximately $8.4 million. The results of this computation triggered an early termination of the Trust. Because the Trust’s computed net present value fell below the $30 million stipulated threshold as of December 31, 2009 the Trust terminated effective March 1, 2010. The accompanying financial statements have been prepared on a going concern basis and do not include any adjustments, costs and expenses or other matters that might result from the outcome of this termination. All of these adjustments, costs and expenses resulting from the outcome of this termination are not presently known; however, they could be significant.

Following termination of the Trust, the Trustee will continue to act as Trustee of the Trust until ~~all Trust assets are sold and~~ the net proceeds from ~~such~~the ~~sales~~sale ~~distributed~~of ~~to Unitholders. The Trustee will use best efforts to sell~~ the Trust’s assets inhave ~~accordance~~been ~~with~~distributed ~~the~~to ~~procedures set forth in the Trust Agreement~~Unitholders.

The Trust ~~has~~ retained Albrecht & Associates, Inc., an investment banking firm (the “Advisor”), on behalf of the Trust who ~~will~~assisted ~~assist~~ the Trustee in selling the remaining Royalty Interests owned by the Trust (the “Remaining Royalty Interests”). WPC had the right, but not the obligation, to make a cash offer to purchase all the Remaining Royalty Interests following termination of the Trust as described in the following paragraph.

WPC had the right, within 60 days of the Termination Date, to make a cash offer to purchase all of the Remaining Royalty Interests then held by the Trust. An offer was not made by WPC during this 60 day period. Under the terms of the Trust Agreement, the Trustee ~~has~~ used Best Efforts (as defined in the Trust Agreement), assisted by the Advisor to obtain offers for the Remaining Royalty Interests. At the end of a 120-day period following the Termination Date, the Trustee notified ~~WPC~~ WPC of the highest offer (net of any commissions or other fees payable by the Trust), acceptable to ~~the~~ the Trustee (which must be an all-cash offer), received during such period (the “Highest Acceptable Offer”). WPC then had the exclusive right, but not the obligation, to purchase all Remaining Royalty Interests for a cash purchase price equal to 105 percent of the Highest Acceptable Offer. WPC had originally notified the Trustee that it ~~will~~would not be exercising its right to purchase all Remaining Royalty Interests pursuant to such ~~provisions~~provision of the Trust Agreement with respect to the Highest Acceptable Offer; however, during contractual negotiations with the bidder providing the Highest Acceptable Offer, the bidder requested certain revisions to its offer. As a result, the Trustee directed the Advisor to request updated bids from previous bidders to confirm which offer continued to be the Highest Acceptable Offer. Following receipt of updated bids and the re-determination of the Highest Acceptable Offer, WPC exercised its right under the Trust Agreement to purchase all Remaining Royalty Interests with respect to the re-determined Highest Acceptable Offer. WPC purchased the Remaining Royalty Interests for a cash purchase price of $23.1 million which was equal to 105 percent of the re-determined Highest Acceptable Offer. The effective date of the sale of the Remaining Royalty Interests was September 1, 2010 and the sale closed on October 27, 2010. See Note 4.

~~The~~Because ~~Trustee~~a isdefinitive incontract ~~the~~for ~~process~~sale of ~~assisting~~the ~~with~~Remaining Royalty Interests was not entered into prior to the ~~due~~150th ~~diligence~~day ~~process~~following ~~and~~the ~~negotiating~~Termination Date, according to the ~~terms~~ ofTrust aAgreement, all ~~potential~~net ~~sale~~proceeds of production attributable to the Remaining Royalty Interests following the Termination Date and before the September 1, ~~but~~2010 noeffective ~~definitive~~date ~~agreement~~of ~~has~~the ~~been executed~~sale ~~and~~of nothe ~~assurances~~Trust’s ~~can~~assets will be ~~made~~distributed as to ~~when~~the orUnitholders. ifAll ~~such~~proceeds ~~sale~~of ~~will~~production ~~occur~~following orthe Termination Date attributable to the ~~ultimate~~Remaining ~~net~~Royalty Interests were deposited into a non-interest bearing ~~proceeds~~account ~~that~~until ~~will~~distributed bein ~~derived~~accordance ~~therefrom~~with the Trust Agreement.

~~Because~~After areceipt ~~definitive~~of ~~contract~~royalty ~~for~~income ~~sale~~in ofMay 2010, the ~~Remaining~~Trust ~~Royalty~~withheld ~~Interests~~in ~~was~~cash ~~not~~and ~~entered~~cash ~~into~~equivalents ~~prior~~$300,000 tofor ~~the~~anticipated ~~150th~~general ~~day~~and ~~following~~administrative ~~the~~expenses, ~~Termination~~including ~~Date,~~expenses ~~according~~relating to ~~the Trust Agreement,~~this ~~all~~termination ~~net~~process ~~proceeds~~some of ~~production~~which ~~attributable~~have tobeen ~~the~~incurred ~~Remaining~~through September 30, ~~Royalty Interests following the~~2010. ~~Termination~~The ~~Date~~Trustee ~~and~~intends ~~until a sale of the Remaining Royalty Interests will be distributed~~ to ~~the Unitholders.~~withhold ~~All~~an ~~proceeds~~additional of$700,000 ~~production~~from ~~following~~ the ~~Termination~~distribution ~~Date attributable~~ to ~~the Remaining~~be ~~Royalty~~made ~~Interests have been deposited into a non-interest bearing account until they are distributed~~ in ~~accordance~~November ~~with the Trust Agreement~~2010.

~~After~~The ~~receipt~~financial statements of ~~royalty~~the ~~income~~Trust inare ~~May 2010,~~prepared ~~the~~on ~~Trust~~a ~~withheld~~modified in cash basis and ~~cash~~are ~~equivalents~~not ~~$300,000~~intended ~~for~~to ~~anticipated~~present ~~general~~financial position and ~~administrative~~results ~~expenses,~~of ~~including~~operations ~~expenses~~in ~~relating~~conformity towith ~~this~~United States Generally Accepted Accounting Principles (“GAAP”). The financial statements do not include any adjustments that might result from execution of the plan for termination ~~process~~or ~~some~~liquidation of ~~which~~the Trust’s assets, with the exception of the portion of the expenses of the liquidation or termination that have been incurred ~~through~~to ~~June 30, 2010~~date. Preparation of the Trust’s financial statements on the modified cash basis on a going concern basis includes the following:

The Trustee may accept an offer for all or a part (but not more than six parts) of the Remaining Royalty Interests as it deems to be in the best interests of the Trust and Unitholders and may continue, for up to one calendar year after the Termination Date, to attempt to locate a buyer or buyers of the Remaining Royalty Interests in order to sell such interests in an orderly fashion not involving a public auction. If any Remaining Royalty Interests have not been sold or a definitive agreement for sale has not been entered into by the end of such calendar year, the Trustee is required to sell the Remaining Royalty Interests at public auction to the highest cash bidder, which sale may be to WPC or any of its affiliates. Notice of such sale by auction shall be mailed at least 30 days prior to such sale to each Unitholder at his address as it appears on the ownership ledger of the Trustee.

The financial statements of the Trust are prepared on a modified cash basis and are not intended to present financial position and results of operations in conformity with United States Generally Accepted Accounting Principles (“GAAP”). The financial statements do not include any adjustments that might result from execution of the plan for termination or liquidation of the Trust’s assets. Preparation of the Trust’s financial statements on the modified cash basis on a going concern basis includes the following:

	•		Revenues are recognized in the period in which amounts are received by the Trust. Routine general and administrative expenses are recognized on an accrual basis.

	•		Amortization of the Royalty 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 (See Note 5).

	•		Loss contingencies are recognized in the period in which amounts are paid by the Trust.

The financial statements of the Trust differ from financial statements prepared in accordance with GAAP. For example, royalty income is not accrued in the period of production, amortization of the Royalty Interests is not charged against operating results, and loss contingencies are not charged to operating results until paid. This comprehensive basis of accounting other than GAAP corresponds to the accounting permitted for royalty trusts by the SEC, as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts.

3. FEDERAL AND STATE INCOME TAXES

The Trust is a grantor trust for Federal income tax purposes. As a grantor trust, the Trust is not required to pay Federal income taxes. Accordingly, no provision for income taxes has been made in these financial statements.

Because the Trust is treated as a grantor trust, and because a Unitholder is treated as directly owning an interest in the Royalty Interests, each Unitholder is taxed directly on his per Unit pro rata share of income attributable to the Royalty Interests consistent with the Unitholder’s method of accounting and without regard to the taxable year or accounting method employed by the Trust.

Some Trust Units are held by middlemen, as such term is broadly defined in U.S. Treasury Regulations (and includes custodians, nominees, certain joint owners, and brokers holding an interest for a custodian in a street name, referred to herein collectively as “middlemen”). Therefore, the Trustee considers the Trust to be a widely held fixed investment trust (“WHFIT”) for U.S. Federal income tax purposes. U.S. Trust, Bank of America Private Wealth Management, EIN 56-0906609, 901 Main Street, 17^th Floor, Dallas, Texas 75202, telephone number (214) 209-2400, is the representative of the Trust that will provide tax information in accordance with applicable U.S. Treasury Regulations governing the information reporting requirements of the Trust as a WHFIT. Notwithstanding the foregoing, the middlemen holding Trust Units on behalf of the Unitholders, and not the Trustee of the Trust, are solely responsible for complying with the information reporting requirements under the U.S. Treasury Regulations with respect to such Trust Units, including the issuance of IRS Form 1099 and certain written tax statements. Unitholders whose Trust Units are held by middlemen should consult with such middlemen regarding the information that will be reported to them by the middlemen with respect to the Trust Units.

In connection with the termination of the Trust and the resulting cancellation of the Trust pursuant to the provisions of the Trust Agreement, the Trust will not incur any Federal income tax liability at the Trust level as a result of the sale of the Remaining Royalty Interests or payment to Unitholders of the net proceeds ~~form~~from such sale. However, for Federal income tax purposes, the sale of the Remaining Royalty Interests will be taxable to the Unitholders. Each Unitholder will recognize gain or loss on such sale measured by the difference between the Unitholder’s share of the amount realized from the sale of the Remaining Royalty Interests and such Unitholder’s adjusted basis in his or her Units. The amount realized from the sale of the Remaining Royalty Interests will be allocated to Unitholders in the same manner as the Trustee allocates the income received by the Trust.

Prior to determining the gain or loss resulting from the sale of the Remaining Royalty Interests ~~following the cancellation of the Trust~~, each Unitholder should reduce his tax basis (but not below zero) in the Remaining Royalty Interests (and, correspondingly, his Units) by (1) the amount of depletion allowable with respect to the Remaining Royalty Interests through the date of the cancellation, and (2) by the amount of any return of capital, including returns of capital resulting from a reduction to the cash reserve maintained by the Trust during a quarterly period.

Assuming a Unitholder holds his or her Units as a capital asset, gain or loss from the sale of the Remaining Royalty Interests will be treated as a capital gain or loss. If the Units have been held for more than one year, the gain or loss will constitute a long-term capital gain or loss; otherwise, the gain or loss will constitute a short-term capital gain or loss. Notwithstanding the foregoing, a Unitholder must, ~~upon the sale of the Remaining Royalty Interests,~~ treat as ordinary income his or her depletion recapture amount, which is an amount equal to the lesser of (i) the gain on the sale of the Remaining Royalty Interests or (ii) the sum of the prior depletion deductions taken with respect to the Remaining Royalty Interests (but not in excess of the initial basis of such Units allocated to the Remaining Royalty Interests).

~~Following~~The ~~the termination of the~~ Trust, ~~the Trust~~ Agreement provides that any purchaser of the Remaining Royalty Interests, regardless of the date of closing of the purchase, shall generally be entitled to net proceeds of production attributable to the Remaining Royalty Interests after the Termination Date and until a sale of the Remaining Royalty Interests and neither the Trust nor the Unitholders shall be entitled to any such proceeds (the “Purchaser Allocation Proceeds”). However, because a definitive agreement for sale of all the Remaining Royalty Interests was not entered into prior to the 150th day following the Termination Date, the Purchaser Allocation Proceeds, and all amounts thereafter payable to the Trust until athe September 1, 2010 effective date of the sale of the Remaining ~~Royalty~~ Royalty Interests, will be distributed instead to the Unitholders in accordance with the provisions of the Trust Agreement.

The proceeds from the sale of the Remaining Royalty Interests, less liabilities and expenses of the Trust and amounts used for cash reserves, will be distributed, together with any interest expected to be earned thereon, to Unitholders of record on the record date established for such distribution. NoSee ~~assurances~~Note can be given as to the amount, or timing, or distributions, if any, to Unitholders of the Trust, as such amount and timing would depend in part on the amount of expenses ultimately payable by the Trust and when such expenses become payable and the net sales price of the Remaining Royalty Interests and when the sale of the Remaining Royalty Interests occurs6.

13 The sale of the Remaining Royalty Interests may be a taxable event to the Unitholders for state tax purposes. Unitholders should consult their own tax advisors regarding the state tax

The sale of the Remaining Royalty Interests following the termination of the Trust may be taxable events to the Unitholders for state tax purposes. Unitholders should consult their own tax advisors regarding the state tax consequences of the sale of the Remaining Royalty Interests following the termination of the Trust.

Each Unitholder should consult his tax advisor regarding Trust tax compliance matters, including tax consequences resulting from the termination of the Trust on the Termination Date and the sale of the Remaining Royalty Interests.

4. RELATED PARTY TRANSACTIONS

~~Williams~~On ~~provides~~October 27, ~~accounting~~210, ~~bookkeeping and informational services to~~ the Trust ~~in accordance~~entered ~~with~~into ana ~~Administrative~~Purchase ~~Services~~and Sale Agreement ~~effective~~with ~~December 1,~~WPC ~~1992.~~pursuant ~~The fee is~~to ~~$50,000~~which ~~per~~it ~~quarter,~~sold ~~escalating 3 percent each October 1 commencing October 1, 1993. For~~ the ~~three and~~Royalty ~~six~~Interests of ~~month periods ended June 30, 2010,~~ the ~~administration~~Trust ~~fee~~to ~~included~~WPC infor ~~general~~a ~~and administrative~~cash ~~expenses~~purchase ~~was~~price ~~$82,642~~of ~~and~~ $~~165~~23,~~285~~100,000. ~~respectively,~~Pursuant ~~as compared~~ to the ~~$80,235~~Purchase and ~~$160~~Sale Agreement,~~471 for~~ the ~~comparable~~effective ~~period~~date inof ~~2009.~~the ~~Substantially~~sale ~~all~~of ~~production~~assets ~~from~~was ~~the~~September 1, WI2010. The ~~Properties~~closing isof ~~sold~~the ~~to a~~sale ~~Williams’~~occurred ~~subsidiary.~~simultaneously ~~Additionally,~~with ~~all~~the ~~royalty~~execution ~~income~~of isthe ~~received from Williams~~agreement.

~~The interests of~~ Williams ~~and~~provides ~~its~~accounting, ~~affiliates~~bookkeeping and ~~the~~informational ~~interests~~services ofto the Trust ~~and the~~in ~~Unitholders~~accordance with ~~respect~~an toAdministrative ~~the~~Services ~~Underlying~~Agreement ~~Properties~~effective ~~could at times be different. As a working interest owner in the WI Properties~~December 1, ~~WPC could have interests that conflict with the interests of the Trust and Unitholders~~1992. ~~For~~The ~~example,~~fee ~~such conflicts could be due to a number of factors~~is ~~including~~$50,000 ~~but~~per ~~not limited to~~quarter, ~~future~~escalating ~~budgetary~~3 percent ~~considerations~~each ~~and~~October ~~the~~1 ~~absence~~commencing ~~of any contractual obligation on the part of WPC to spend for development of the WI Properties~~October 1, ~~except as noted herein~~1993. ~~Such~~For ~~decisions may have~~ the ~~effect of changing the amount or timing of future~~three ~~distributions to Unitholders. WPC’s interests may also conflict with those of the Trust~~ and ~~Unitholders~~ innine ~~situations~~month ~~involving~~periods ~~the~~ended sale or abandonment of Underlying Properties or the purchase or sale of the Remaining Royalty Interests. WPC has the right at any time to sell any of the Underlying Properties subject to the Royalty Interests andSeptember 30, ~~under certain circumstances~~2010, ~~may abandon any of~~ the WIadministration ~~Properties.~~fee ~~Such~~included ~~sales or abandonment may not be~~ in ~~the~~general ~~best interests of~~and ~~the~~administrative ~~Trust.~~expenses ~~Williams’~~was ~~interest~~$82,642 ~~could conflict with those of the Trust~~ and ~~Unitholders~~$247,927, ~~to the extent the interests of WPX Gas Resources (hereinafter defined)~~respectively, ~~under~~as ~~the~~compared ~~Gas~~to ~~Purchase Contract~~$80,235 ~~or Williams Field Services Company~~ and ~~WPX Gas Resources~~$240, ~~under the Gas Gathering Contract, differ~~706 ~~from~~for the ~~interests~~comparable ofperiod ~~the~~in ~~Trust and the Unitholders or a potential purchaser of any Remaining Royalty Interests~~2009. ~~Except~~Substantially ~~for~~all ~~amendments~~production tofrom the ~~Gas~~WI ~~Gathering~~Properties ~~Contract~~is orsold ~~Gas Purchase Contract~~to ~~that must be approved by the vote of~~ a ~~majority~~Williams’ ofsubsidiary. ~~the~~Additionally, ~~Unitholders~~all ~~present~~royalty atincome ~~a meeting at which a quorum~~ is ~~present~~received iffrom ~~such amendment would materially adversely affect Trust revenues, no mechanism or procedure has been included to resolve potential conflicts of interest between the Trust,~~ Williams~~, WPC or their affiliates~~.

~~During~~The ~~2009~~interests ~~WPC~~of ~~notified~~Williams and its affiliates and the interests of the Trust ~~that~~and ~~royalty~~the Unitholders ~~income~~with ~~for~~respect to the ~~second~~Underlying ~~quarter~~Properties ~~2009~~could ~~includes~~at antimes be different. As a working ~~overpayment~~interest ofowner ~~approximately~~in ~~$766~~the WI Properties,~~000.~~ InWPC ~~connection~~could ~~with~~have ~~assisting~~had interests that conflict with the interests of the Trust and Unitholders. For example, such conflicts could have been due ~~diligence~~to ~~process~~a number of ~~for~~factors including, but not limited to, future budgetary considerations and the ~~potential~~absence ~~sale~~of any contractual obligation on the part of WPC to spend for development of the ~~Remaining~~WI ~~Royalty~~Properties, ~~Interests~~except ~~with~~as noted herein. Such decisions may have had the ~~party~~effect ~~that~~of ~~provided~~changing the ~~Highest~~amount or timing of ~~Acceptable~~distributions ~~Offer,~~to Unitholders. WPC’s ~~notified~~interests may have also conflicted with those of the Trust and Unitholders in the purchase or sale of the ~~discovery~~Remaining Royalty Interests. Williams’ interest could have conflicted with those of ~~certain~~the ~~errors~~Trust ~~related~~and Unitholders to the extent the interests of WPX Gas ~~accounting~~Resources ~~for~~(hereinafter defined), under the ~~Underlying~~Gas ~~Properties~~Purchase ~~that~~Contract, ~~had~~or ~~impacted~~Williams ~~royalty~~Field ~~income~~Services Company ~~receipts~~and ofWPX Gas Resources, under the ~~Trust over~~Gas Gathering Contract, differed from the ~~course~~interests of the Trust ~~last~~and ~~five~~the ~~years~~Unitholders or a potential purchaser of any Remaining Royalty Interests. ~~WPC~~Except ~~informed~~for amendments to the ~~Trust~~Gas Gathering Contract or Gas Purchase Contract that must be approved by the ~~net~~vote of ~~effect~~a majority of the Unitholders present at a meeting at which a quorum is present if such amendment would materially adversely affect Trust revenues, no mechanism or procedure was included to resolve potential conflicts of interest between the Trust, Williams, WPC or their affiliates.

14 During 2009 WPC notified the Trust that royalty income for the second quarter 2009 included an overpayment of approximately $766,000. In connection with assisting with the due diligence process for the potential sale of the Remaining Royalty Interests, WPC notified the Trust of the discovery of certain errors related to the accounting for the Underlying Properties

that had impacted royalty income receipts of the Trust over the course of the last five years. WPC informed the Trust that the net effect of these errors is a cumulative overpayment to the Trust of approximately $1,067,000. Williams waived any right to seek recoupment of the amounts of these overpayments or reduce any future payments of royalty income to the Trust by the amounts of these overpayments.

5. DISTRIBUTIONS TO UNITHOLDERS

For production through the March 1, 2010 Termination Date, the Trustee determined for each quarter the amount of cash available for distribution to Unitholders. Such amount (the “Quarterly Distribution Amount”) was an amount equal to the excess, if any, of the cash received by the Trust, on or prior to the last day of the month following the end of each calendar quarter from the Royalty Interests, plus, with certain exceptions, any other cash receipts of the Trust during such quarter, over the liabilities of the Trust paid or accrued during such quarter, subject to adjustments for changes made by the Trustee during such quarter in any cash reserves established for the payment of contingent or future obligations of the Trust.

The Trustee distributed the Quarterly Distribution Amount within 60 days after the end of each calendar quarter to each person who was a Unitholder of record on the associated record date (i.e., the 45th day following the end of each calendar quarter or if such day is not a business day, the next business day thereafter), together with interest estimated to be earned on such amount from the date of receipt thereof by the Trustee to the payment date.

Because a definitive contract for the sale of the Remaining Royalty Interests was not entered into prior to the 150th day following the Termination Date, the Trust and the Unitholders, and not WPC, as the buyer of the Remaining Royalty Interests, are generally entitled to net proceeds of production attributable to the Remaining Royalty Interests following the ~~Termination~~ Termination Date and until athe September 1, 2010 effective date of the sale of the Remaining Royalty Interests (Note 2).

6. SUBSEQUENT EVENTS

Subsequent to ~~June~~September 30, 2010, the Trust ~~declared~~sold the ~~following~~assets of the Trust in connection with the termination of the Trust, resulting in a special liquidating distribution:. See Notes 2 and 4.

Quarterly
Record	Payment	Distribution
Date	Date	per Unit
August 4, 2010	August 27, 2010	$.132276

Subsequent to September 30, 2010, the Trust declared the following distributions:

The distribution per unit was $.132276 attributable to production for the months of March, April, May and June, 2010 (except for the Farmout Properties for which production for the months of March through May was included), following the Termination Date (payable in the third quarter of 2010) as compared to $0.0111 attributable to the months of January and February, 2010 (except for the Farmout Properties for which production for the months of December 2009 to February 2010 was included), prior to the Termination Date (paid in the second quarter of 2010). The increase in distributions is mainly the result of non-recurring items impacting second quarter royalty income including a retroactive unit expansion adjustment that


Type of	Record	Payment	Distribution
Distribution	Date	Date	per Unit
Quarterly Distribution	November 15, 2010	November 29, 2010	$	.034323

Special Liquidating Distribution	November 15, 2010	November 29, 2010	$	2.381443

~~reduced~~ The ~~royalty~~quarterly ~~income~~distribution byper ~~approximately $807,000~~unit ~~and~~was ~~including~~$.034323 ~~only~~attributable ~~the~~to ~~months of~~ production ~~preceding~~for the ~~Termination~~months ~~Date being included~~of inJuly ~~the~~and ~~royalty~~August, ~~income~~2010 ~~received~~(payable ~~during~~in the ~~second~~fourth quarter of 2010) as ~~discussed~~compared into ~~Note~~a 2$. ~~The Trust~~132276 ~~withheld~~distribution inattributable ~~cash~~to ~~and~~the ~~cash~~second ~~equivalents~~quarter of ~~$200,000~~2010 (production for ~~anticipated~~the ~~general~~months ~~and~~of ~~administrative expenses,~~March ~~including~~through ~~expenses~~June ~~relating~~2010). toThe ~~the~~decrease ~~termination~~in ~~process~~distributions inis mainly the ~~first~~result ~~quarter~~of including ~~all~~only ofthe ~~which has~~two ~~been~~months ~~incurred~~of atproduction ~~June~~preceding September 301, 2010 ~~and~~in anthe ~~additional~~royalty ~~$300,000~~income received ~~for~~during ~~anticipated~~the ~~general~~fourth ~~and administrative~~quarter ~~expenses,~~of ~~including~~2010 ~~expenses~~as ~~relating~~discussed toin ~~the~~Note 2. ~~termination~~The ~~process~~Trustee inintends ~~the~~to ~~second quarter~~withhold an additional $700,000 ~~some~~from ofthe ~~which~~distribution ~~has~~to ~~been~~be ~~incurred~~made atin ~~June 30,~~November 2010.

The special liquidating distribution represents the proceeds from the sale of the Remaining Royalty Interests to WPC for a cash purchase price of $23,100,000, ~~less~~to ~~liabilities~~Unitholders ~~and~~of ~~expenses~~record on ofNovember 15, 2010, the record date established for such distribution. The record date was also the date the Trust’s Unit transfer books were closed and ~~amounts~~the ~~used~~New ~~for~~York Stock ~~cash~~Exchange ~~reserves,~~suspended ~~will~~trading beof ~~distributed,~~the ~~together~~Units ~~with~~at ~~any~~the ~~interest~~close of business on such date. To the ~~expected~~extent tothat bethe ~~earned~~cash ~~thereon,~~reserve toexceeds ~~Unitholders~~the actual liabilities and expenses of ~~record~~the onTrust, the Trustee will make one or more distributions to Unitholders of record ~~date~~as ~~established~~of ~~for~~November 15, ~~such distribution~~2010. No assurances can be given as to the amount, or timing, orof distributions, if any, to Unitholders of the Trust, as such amount, if any, and timing ~~would~~ depend in part on the amount of liabilities and expenses ultimately payable by the Trust and when such ~~expenses~~liabilities ~~become payable~~ and ~~the~~expenses ~~net~~become ~~sales price of the Remaining Royalty Interests and when the sale of the Remaining Royalty Interests occurs~~payable.

7. CONTINGENCIES

Prior to August 1, 2010, WPX Gas Resources Company (“WPX Gas Resources,” as successor in interest to Williams Gas Marketing Company), purchased natural gas produced from the WI Properties (except for certain small volumes) at the wellhead under the terms of a gas purchase contract dated October 1, 1992, as amended (the “Gas Purchase Contract”). The Gas Purchase Contract provided for a pricing mechanism during an initial 5-year period, which expired on December 31, 1997, and continued for one or more consecutive additional 1-year terms unless and until WPX Gas Resources exercised its annual option, exercisable 15 days prior to the end of each contract year, to discontinue purchasing gas under the pricing mechanism of the Gas Purchase Contract and instead purchase gas at a monthly market-based price. WPX Gas Resources did not exercise this option, and therefore the pricing mechanism continued to remain in effect through the expiration of the Gas Purchase Contract on August 1, 2010. The terms for the purchase of natural gas produced from the WI Properties (except for certain small volumes related to the Farmout Properties, which were not affected by the Gas Purchase Contract expiration) subsequent to the expiration date are currently being negotiated.

Under the pricing mechanism of the Gas Purchase Contract, when the market price was less than $1.70 per MMBtu (the “Minimum Purchase Price”), the Trust was paid the Minimum Purchase Price for the gas and an account (the “Price Credit Account”) was maintained to identify the accrued and unrecouped amount of payments made to the Trust in excess of the market price. Any amounts in the Price Credit Account were subject to future recoupment when the market price exceeded the Minimum Purchase Price. As of June 30, 2010, there were no remaining unrecouped price credits in the Price Credit Account.

While the terms of the Gas Purchase Agreement pricing mechanism remained in place and no balance existed in the Price Credit Account, when the market price for natural gas exceeded $1.94 per MMBtu (as was the case during the first six months of 2010), the Trust

received only 50 percent of the excess of the market price over the $1.94 price per MMBtu before reduction for gathering, processing and certain other costs.

In 2008, WPC notified the Trust that certain royalty matters were currently being litigated by a federal regulatory agency and another producer. WPC learned that this case was decided unfavorably to the producer in October 2009. Neither WPC nor the Trust was a party to the litigation; however, given the similarities to the Trust’s Underlying Properties, WPC and the Royalty Interests will more than likely be impacted as well. WPC is currently evaluating the negative impact to the Trust’s NPI. In addition, there are other cases pending against other producers on related issues that could potentially have a significant negative impact to future royalty income with respect to the Royalty Interests, natural gas reserves and reserve value.

The majority of the production attributable to the Trust is within Federal Units. Unit participating areas are formed by pooling production from the participating area. Entitlement to the pooled production is based on each party’s acreage in the participating area divided by the total participating acreage. Wells drilled outside the participating area may create an enlargement to the participating area and a revision of the Unit ownership entitlement. The Bureau of Land Management (“BLM”) must approve Unit participating area expansions. The effective date for Unit expansions is retroactive to the date the well creating the expansion was tested. WPC notified the Trust that the second quarter 2010 royalty distribution to the Trust was negatively impacted by approximately $807,000 for a unit expansion adjustment it processed during the period.

The royalty income presented in the accompanying statements of distributable income is on an entitlement basis and reflects WPC’s estimated impact of the most recent BLM participating area approvals through June 30, 2010.

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

Termination and Liquidation of the Trust

With respect to the Trust termination provisions as outlined in the Trust Agreement, the net present value of the estimated future net revenues computed in accordance with the Trust Agreement, using an average 2009 index price of $3.25, by the independent petroleum engineers as of December 31, 2009 was approximately $8.4 million (which assumed continuation of the Gas Purchase Contract with WPX through 2012). The results of this computation have triggered an early termination of the Trust. Because the Trust’s computed net present value fell below the $30 million stipulated threshold as of December 31, 2009, the Trust terminated effective March 1, 2010 (the “Termination Date”).

Following termination, the Trustee and the Delaware Trustee will continue to act as trustees of the Trust until ~~all remaining Trust assets have been sold and~~ the net proceeds from ~~such~~the ~~sales, if~~sale ~~any,~~of the Trust’s assets are distributed to Unitholders.

Upon the termination of the Trust, the Trustee ~~will~~used ~~use~~ Best Efforts (as defined in the Trust Agreement) to sell ~~any~~the remaining Royalty Interests for cash pursuant to the procedures described in the Trust Agreement. The Trustee ~~has~~ retained Albrecht & Associates, Inc., an investment banking ~~firm~~ firm (the “Advisor”), on behalf of the Trust who ~~has~~assisted ~~and~~the ~~will~~Trustee ~~continue~~in selling the remaining Royalty Interests then owned by the Trust (the “Remaining Royalty Interests”). WPC had the right, but not the obligation to make a cash offer, to purchase all Remaining Royalty Interests following termination of the Trust as described in the following paragraph.

~~assist~~ WPC had the ~~Trustee~~right, inwithin 60 days of the Termination Date, to make a cash offer to ~~selling~~purchase all of the ~~remaining~~Remaining Royalty Interests then ~~owned~~held by the Trust. An offer was not made by WPC during this 60 day period. Under the terms of the Trust Agreement, the Trustee used Best Efforts (as defined in the “Trust Agreement), assisted by the Advisor to obtain offers for the Remaining Royalty Interests. At the end of a 120-day period following the Termination Date, the Trustee notified WPC of the highest offer (net of any commissions or other fees payable by the Trust), acceptable to the Trustee (which must be an all-cash offer), received during such period (the “Highest Acceptable Offer”). WPC then had the exclusive right, but not the obligation, to purchase ~~make~~all Remaining Royalty Interests for a cash purchase price equal to 105 percent of the Highest Acceptable Offer. WPC had originally notified the Trustee that it would not be exercising its right to purchase all Remaining Royalty Interests pursuant to such provision of the Trust Agreement with respect to the Highest Acceptable Offer; however, during contractual negotiations with the bidder providing the Highest Acceptable Offer, the bidder requested certain revisions to its offer. As a result, the Trustee directed the Advisor to request updated bids from previous bidders to confirm which offer continued to be the Highest Acceptable Offer. Following receipt of updated bids and the re-determination of the Highest Acceptable Offer, WPC exercised its right under the Trust Agreement to purchase all Remaining Royalty Interests with respect to the re-determined Highest Acceptable Offer. WPC purchased the Remaining Royalty Interests ~~following~~for ~~termination~~a cash purchase price of $23.1 million which was equal to 105 percent of the ~~Trust~~re-determined asHighest Acceptable ~~described~~Offer. inThe effective date of the ~~following~~sale of the Remaining Royalty Interests was September ~~paragraph~~1, 2010 and the sale closed on October 27, 2010. See Note 4.

~~WPC~~Because ~~had the right, within 60 days following the Termination Date, to make~~ a ~~cash~~definitive ~~offer~~contract ~~to purchase~~for ~~all~~sale of the Remaining Royalty Interests ~~then held by the Trust. An offer~~ was not ~~made~~entered byinto ~~WPC~~prior ~~during~~to ~~this~~the 60 150th day ~~period.~~following ~~Under~~ the ~~terms~~Termination ofDate, the Trust ~~Agreement,~~and the ~~Trustee~~Unitholders, ~~has~~and ~~used~~not ~~Best~~the ~~Efforts~~buyer ~~(as~~of ~~defined in~~ the ~~Trust~~Remaining ~~Agreement)~~Royalty Interests, ~~assisted~~are bygenerally ~~the~~entitled ~~Advisor~~ to ~~obtain~~net ~~offers~~proceeds ~~for~~of ~~the~~production ~~Remaining~~attributable ~~Royalty~~to ~~Interests. At~~ the ~~end~~Remaining ofRoyalty aInterests ~~120-day period~~ following the Termination Date, ~~the Trustee~~and ~~notified~~before ~~WPC of~~ the September 1, ~~highest~~2010 ~~offer~~effective ~~(net~~date of ~~any commissions or other fees payable by~~ the ~~Trust),~~ ~~acceptable~~sale toof the ~~Trustee~~Trust’s ~~(which~~assets ~~must be an all-cash offer), received during such period~~ (~~the~~Note ~~“Highest Acceptable Offer”~~2). Therefore, WPC ~~then~~will distribute ~~had~~to the ~~exclusive~~Trust ~~right,~~the ~~but~~net ~~not~~proceeds ~~the~~from ~~obligation,~~production attributable to ~~purchase~~ ~~all~~the Remaining Royalty Interests for athis ~~cash~~period. ~~purchase~~All ~~price~~proceeds ~~equal~~of toproduction ~~105 percent~~following of the ~~Highest~~ ~~Acceptable~~Termination ~~Offer.~~Date ~~WPC~~attributable to ~~notified~~ the ~~Trustee~~Remaining ~~that~~Royalty itInterests ~~will~~were ~~not~~deposited beinto ~~exercising~~a ~~its~~non-interest ~~right~~bearing toaccount until ~~purchase~~distributed ~~all~~in ~~Remaining~~accordance ~~Royalty~~with ~~Interests pursuant to such provisions of~~ the Trust Agreement.

~~The~~On November 5, 2010, the Trustee isannounced ina ~~the~~special ~~process~~liquidating ofdistribution ~~assisting~~per ~~with~~Unit ~~the~~of $2.381443. ~~due~~This ~~diligence~~special ~~process~~liquidating ~~and~~distribution ~~negotiating~~represents the ~~terms~~ ofproceeds afrom ~~potential~~the sale of the Remaining Royalty Interests to WPC for a cash purchase price of $23,100,000, ~~but~~to noUnitholders ~~definitive~~of record ~~agreement~~on ~~has~~November 15, ~~been~~2010, the record date established for such distribution. The record date ~~executed~~was also the date the Trust’s Unit transfer books were closed and nothe New York Stock Exchange suspended trading at the close of business on such date. To the extent that the cash reserve exceeds the actual liabilities and expenses of the Trust, the Trustee will make one or more distributions to Unitholders of record as of November 15, 2010. No assurances can be ~~made~~given as to ~~when~~the amount, or timing, of distributions, if any, to Unitholders of the Trust, as such ~~sale~~amount, ~~will~~if ~~occur~~any, orand timing depend in part on the ~~ultimate~~amount ~~net~~of liabilities ~~proceeds~~owed ~~that~~and ~~will~~expenses beultimately ~~derived~~payable ~~therefrom~~by the Trust and when such liabilities and expenses become payable.

Because a definitive contract for sale of the Remaining Royalty Interests was not entered into prior to the 150th day following the Termination Date, the Trust and the Unitholders, and not the buyer of the Remaining Royalty Interests, will generally be entitled to net proceeds of production attributable to the Remaining Royalty Interests following the Termination Date and until a sale of the Remaining Royalty Interests (Note 2). Therefore, WPC will distribute to the Trust the net proceeds from production attributable to the Remaining Royalty Interests for this period. All proceeds of production following the Termination Date attributable to the Remaining Royalty Interests have been deposited into a non-interest bearing account until they are distributed in accordance with the Trust Agreement.

The Trustee may accept any offer for all or any part (not more than six parts) of the Remaining Royalty Interests as it deems to be in the best interests of the Trust and Unitholders and may continue, for up to one calendar year after the Termination Date, to attempt to locate a buyer or buyers of the Remaining Royalty Interests in order to sell such interests in an orderly fashion not involving a public auction. If any Remaining Royalty Interests have not been sold or a definitive agreement for sale has not been entered into by the end of such calendar year, the Trustee is required to sell the Remaining Royalty Interests at public auction to the highest cash bidder, which sale may be to WPC or any of its affiliates. Notice of such sale by auction shall be mailed at least 30 days prior to such sale to each Unitholder at his address as it appears on the ownership ledger of the Trustee.

The sale of the Remaining Royalty Interests following the termination of the Trust will be taxable events to the Unitholders for Federal income tax purposes. Generally, a Unitholder will realize gain or loss equal to the difference between the amount realized on the sale of the Remaining Royalty Interests upon termination of the Trust and his adjusted basis in such Units. Gain or loss realized by a Unitholder who is not a dealer with respect to such Units and who has a holding period for the Units of more than one year will be treated as long-term capital gain or

The sale of the Remaining Royalty Interests following the termination of the Trust will be a taxable event to the Unitholders for Federal income tax purposes. Generally, a Unitholder will realize gain or loss equal to the difference between the amount realized on the sale of the Remaining Royalty Interests and his adjusted basis in such Units. Gain or loss realized by a Unitholder who is not a dealer with respect to such Units and who has a holding period for the Units of more than one year will be treated as long-term capital gain or loss except to the extent of any depletion recapture amount, which must be treated as ordinary income. State tax consequences may also result to Unitholders ~~upon the termination of the Trust~~ and the sale of the Remaining Royalty Interests. Each Unitholder should consult his own tax advisor regarding Trust tax compliance matters, including Federal and state tax implications concerning the sale of the Remaining Royalty Interests ~~following the termination of the Trust~~ (Note 3).

Distributable Income

Prior to the termination of the Trust, when excess cash was available, the Trust made quarterly cash distributions to Unitholders. The only assets of the Trust, other than cash and cash equivalents being held for the payment of expenses and liabilities and for distribution to Unitholders, are the Royalty Interests. The Royalty Interests owned by the Trust burden the Underlying Properties, which are owned by WPC and not the Trust.

Distributable income of the Trust generally consists of the excess of royalty income plus interest income over the general and administrative expenses of the Trust. Upon receipt by the Trust, royalty income iswas invested in short-term investments in accordance with the Trust Agreement until its subsequent distribution to Unitholders. Currently, funds ~~are~~awaiting distribution are invested in Bank of America money market accounts which are backed by the good faith of Bank of America, N.A., but are not insured by the Federal Deposit Insurance Corporation (“FDIC”). The Trust does not lend money and has limited ability to borrow money, which the Trustee believes limits the Trust’s risk from the current tightening of credit markets. ~~The Trust’s future royalty income, however, may be subject~~ to risks relating to the creditworthiness of the operators of the Underlying Properties and WPX Gas Resources and other purchasers of the natural gas produced from the Underlying Properties, as well as risks associated with fluctuations in the price of natural gas. Additional risks are described in “Item 1A – Risk Factors” of the 2009 Annual Report.

The amount of distributable income of the Trust for any quarter may ~~differ~~have differed from the amount of cash available for distribution to Unitholders in such quarter due to differences in the ~~treatment~~ treatment of the expenses of the Trust in the determination of those amounts. The financial statements of the Trust are prepared on a modified cash basis pursuant to which general and ~~administrative~~ administrative expenses of the Trust are recognized when incurred whereas royalty income is recognized when received. Consequently, the reported distributable income of the Trust for any quarter is determined by deducting from the income received by the Trust the amount of expenses incurred by the Trust during such quarter. The amount of cash available for distribution to Unitholders, however, is determined in accordance with the provisions of the Trust Agreement and reflects the deduction from the income actually received by the Trust of the amount of expenses actually paid or accrued by the Trust and adjustments for changes in reserves for unpaid liabilities. See Notes 5 and 6 to the financial statements of the Trust appearing elsewhere in this report on Form 10-Q for additional information regarding the determination of the amount of cash available for distribution to Unitholders.

Three Months and ~~Six~~Nine Months Ended ~~June~~September 30, 2010 Compared to Three Months and ~~Six~~Nine Months ~~Ended~~ ~~June~~Ended September 30, 2009

For the quarter ended ~~June~~September 30, 2010, royalty income received by the Trust amounted to $~~407~~1,~~607~~ 483,027 as compared to $~~931~~77,~~608~~767 received for the same quarter in 2009. ~~Royalty~~The ~~income~~increase ~~would~~in ~~have been~~royalty ~~$165,792~~income ~~for~~is ~~the~~due ~~quarter~~to ~~ended~~higher ~~June 30,~~natural ~~2009,~~gas ifprices ~~the~~and ~~Trust~~due ~~had~~to ~~not~~receiving ~~received~~four anmonths ~~overpayment from WPC~~ of ~~$765,816.~~production ~~Production~~in ~~volumes~~the ~~are~~2010 ~~affected~~period by(versus ~~changes~~normally inreceiving ~~sales~~3 ~~prices~~months ~~for~~of ~~natural~~production), ~~gas~~favorably ~~produced and~~impacting ~~costs~~the ~~that~~gross ~~are~~proceeds ~~deducted~~(before inroyalties, ~~calculating~~taxes, ~~the~~and ~~NPI~~operating ~~Net~~expenses, ~~Proceeds.~~which ~~Production~~are ~~related~~included toin ~~the~~ royalty income) ~~received~~earned by the ~~Trust~~properties. inFor the ~~second~~2009 ~~quarter~~period, ofroyalty ~~2010~~income was ~~462,627~~near ~~MMBtu~~break-even ~~(exclusive~~as ofgross ~~the impact~~proceeds ofwere ~~the~~only ~~retroactive~~slightly ~~unit~~higher ~~expansion~~than ~~adjustment~~the ~~described~~expenses ~~below)~~included asin ~~compared~~royalty ~~to 473~~income,~~556~~ ~~MMBtu for~~due to the ~~second~~relatively ~~quarter~~steady ~~2009.~~level ~~Excluding the impact~~ of ~~WPC’s~~operating ~~overpayment~~expenses, ~~error~~which inare ~~the~~not ~~second~~impacted ~~quarter of~~by ~~2009,~~changes ~~the increase~~ in ~~royalty~~natural ~~income~~gas ~~received~~prices. isProduction volumes ~~primarily~~are ~~resulting~~affected ~~from~~by ~~significant~~changes ~~increases~~ in sales prices ~~realized~~ for ~~the~~natural ~~months~~gas ofproduced ~~January~~ and ~~February 2010~~costs ~~compared~~that ~~with~~are deducted ~~those~~ in calculating the ~~prior year.~~NPI ~~These~~Net ~~significant~~Proceeds. ~~price~~Production ~~increases~~related ~~were~~to ~~substantially~~the ~~offset by a retroactive unit expansion adjustment, which reduced~~ royalty income inreceived ~~2010~~ by ~~approximately $807,000 and a reduction in~~ ~~proceeds related to~~ the ~~lack~~Trust ofin ~~inclusion of~~ the ~~production~~third ~~month~~quarter of ~~March~~ 2010, ~~which~~ was ~~received following~~827,563 ~~the~~MMBtu ~~Termination~~as ~~Date.~~compared ~~General~~to ~~and~~153,226 ~~administrative~~MMBtu ~~expenses~~ for the ~~quarter ended June 30,~~ ~~2010 were lower compared to the~~ same quarter in 2009 ~~due to the elimination of various on-going services as a result of the impending liquidation of the Trust~~.

Royalty income for the ~~six~~nine months ended ~~June~~September 30, 2010 was $12,~~172~~655,~~185~~212 as compared to $2,~~325~~403,~~261~~ 029 for the same period in 2009. Royalty income for the ~~six~~nine month period ended ~~June~~ September 30, 2009 would have been $1,~~559~~637,~~445~~213 if the Trust had not ~~for~~received ~~the~~an overpayment byfrom WPC of $765,816. Williams informed the Trust that it waived any right to seek repayment of such amount. Production related to the royalty income received by the Trust for the ~~six~~nine months ended ~~June~~ September 30, 2010 was 1,~~002~~830,~~835~~ 398 MMBtu ~~(exclusive of the impact of the retroactive unit expansion adjustment)~~ as compared to 1,~~128~~282,~~876~~103 MMBtu for the ~~six~~ nine months ended ~~June~~ September 30, 2009. ~~Excluding~~The ~~the~~increase ~~impact of WPC’s overpayment error~~ in ~~the second quarter of 2009, the decrease in~~ royalty income ~~received~~ is ~~primarily~~attributable ~~resulting~~to ~~from~~higher ~~the~~gas ~~$807,000 retroactive unit expansion adjustment, which reduced royalty income for the first half of 2010 partially offset by price increases between the comparative periods~~prices.

General and administrative expenses for the ~~six~~nine month period ended ~~June~~September 30, 2010 ~~increased~~, increased $6296,~~172~~667 or 1011 percent compared to the same period in 2009 due to costs incurred related to the termination of the Trust.

Because the Trust incurs administrative expenses throughout a quarter but receives its royalty income only once in a quarter, the Trustee established in the first quarter of 1993 a cash reserve for the payment of expenses and liabilities of the Trust. The Trustee thereafter has adjusted the amount of such reserve in certain quarters as required for the payment of the Trust’s expenses and liabilities, in accordance with the provisions of the Trust Agreement. The Trustee ~~has~~will ~~maintained~~maintain ~~for~~ ~~the foreseeable future~~ a cash reserve ~~that~~for ~~will~~the bepayment ~~reduced~~of by Trust expenses in ~~excess~~connection ofwith the ~~royalty~~winding ~~income.~~down ~~After~~of ~~receipt~~the ofTrust. ~~royalty~~To ~~income~~the inextent ~~May 2010,~~that the ~~Trust~~cash ~~withheld~~reserve inexceeds ~~cash~~the ~~and~~actual ~~cash~~liabilities and ~~equivalents~~expenses anof ~~additional~~the ~~$300~~Trust,~~000~~ ~~for~~the ~~anticipated~~Trustee ~~general~~will ~~and~~make ~~administrative~~one ~~expenses,~~or ~~including expenses~~more ~~relating~~distributions to ~~the~~Unitholders ~~termination~~of ~~process~~record as of November 15, ~~some~~2010. ofNo ~~which~~assurances ~~had~~can ~~been~~be ~~incurred~~given atas ~~June 30~~to the amount, ~~2010.~~or Astiming, of distributions, if ~~discussed~~any, into ~~Note~~Unitholders 2of the Trust, ~~because~~as asuch ~~definitive~~amount, ~~contract~~if ~~for~~any, ~~sale~~and oftiming ~~the~~depend ~~Remaining~~in ~~Royalty~~part ~~Interests~~on ~~was~~the amount of ~~not~~liabilities ~~entered~~owed ~~into~~and ~~prior~~expenses toultimately payable by the ~~150th~~Trust ~~day~~and ~~following~~when ~~the~~such liabilities and expenses become payable.

20 Royalty income received by the Trust in a given calendar quarter will generally reflect the sum of (i) net proceeds from the sale of gas produced from the WI Properties during the preceding calendar quarter, plus (ii) cash received by WPC with respect to the Farmout Properties either (a) during the preceding calendar quarter or (b) if received in sufficient time to be paid to the Trust, in the month immediately following such calendar quarter. Accordingly, the royalty income included in distributable income for the quarter ended September 30, 2010, was based generally on production volumes as shown in the table below and natural gas prices for the months of March 2010 through June 2010 (Note 2). Due to delays associated with the receipt of income related to the Farmout Properties, the Trust's royalty income for the third quarter of 2010 reflects estimated production volumes shown in the table below from the Farmout Properties for the months of March 2010 through May 2010. The production volumes included in the table below are for production attributable to net profits of the Underlying Properties, and not for production attributable to the Trust’s Royalty Interests.

Termination Date, the Trust and the Unitholders, and not the buyers of the Remaining Royalty interests, are generally entitled to net proceeds of production attributable to the Remaining Royalty Interests following the Termination Date and until a sale of the Remaining Royalty Interests.


	Three Months		Three Months
	Ended		Ended
	June 30, 2010		June 30, 2009
Production (MMBtu) (1)
WI Properties		985,514		13,813	(2)
Farmout Properties		195,085		238,672
Infill Properties		596,018	$	8,676	(4)

Blanco Hub Spot Price ($/MMBtu) (3)	$	3.98	$	2.59

Net Wellhead Price WI Properties ($/MMBtu) (3)	$	1.95	$	. 76

Royalty income received by the Trust in a given calendar quarter will generally reflect the sum of (i) net proceeds from the sale of gas produced from the WI Properties during the preceding calendar quarter, plus (ii) cash received by WPC with respect to the Farmout Properties either (a) during the preceding calendar quarter or (b) if received in sufficient time to be paid to the Trust, in the month immediately following such calendar quarter. Accordingly, the royalty income included in distributable income for the quarter ended June 30, 2010, was based generally on production volumes as shown in the table below and natural gas prices for the months of January 2010 and February 2010 (Note 2). Due to delays associated with the receipt of income related to the Farmout Properties, the Trust’s royalty income for the second quarter of 2010 reflects estimated production volumes shown in the table below from the Farmout Properties for the months of December 2009 through February 2010. The production volumes included in the table below are for production attributable to net profits of the Underlying Properties, and not for production attributable to the Trust’s Royalty Interests.


(1)		Million British Thermal Units.

(2)		The WI Properties realized a net deficit from the Net Profits Interest for the three month period ended June 30, 2009; therefore, no production quantities related to that period are presented. The production quantity above is comprised entirely of favorable retroactive adjustments of 13,813 MMBtu.

(3)		Simple average of estimates for the months included in the period presented.


(4)		There was no distribution from the Infill Properties for the three month period ended June 30, 2009 as described in Note 1 to the financial statements of the Trust. The production quantity above reflects favorable retroactive adjustments of 8,676 MMBtu.

	Three Months			Three Months
	Ended			Ended
	March 31, 2010			March 31, 2009
Production (MMBtu) (1)
WI Properties		494,670	(2)		517,461	(3)
Farmout Properties		188,621			216,729
Infill Properties		263,264			165,212
Blanco Hub Spot Price ($/MMBtu) (4)	$	5.52		$	3.54
Net Wellhead Price WI Properties ($/MMBtu) (4)	$	2.80	(2)	$	1.80	(5)

Production from the WI Properties is generally sold by WPC to WPX Gas Resources pursuant to the Gas Purchase Contract that, prior to terminating on August 1, 2010, provided certain protections for WPC and Unitholders by providing that WPX Gas Resources would purchase gas from WPC at a minimum purchase price of $1.70 even when the applicable index price (which is equal to 97% of the Blanco Hub Spot Price) fell below $1.70 per MMBtu, provided that WPX Gas Resources was entitled to accrue price credits in the amount of any excess of the minimum price so paid over the applicable index price. When the applicable index price exceeded $1.70 per MMBtu, WPX Gas Resources was entitled to recoup any price credits previously accrued. When the applicable index price was greater than $1.94 per MMBtu, the Gas Purchase Contract protected and benefited WPX Gas Resources by allowing it to purchase gas from WPC at a contract price equal to $1.94 per MMBtu plus only 50 percent of the difference between the applicable index price and $1.94 per MMBtu. The Gas Purchase Contract also provided that the price paid for gas by WPX Gas Resources was reduced by the amount of gathering, processing and certain other costs paid by WPX Gas Resources. See “Item 2 Properties — The Royalty Interests — Gas Purchase Contract” in the 2009 Annual Report for detailed information about the Gas Purchase Contract and its impact on Trust income.

(1)		Million British Thermal Units.
(2)		Excludes the impact of the retroactive unit expansion adjustment described in Note 7.
(3)		Includes unfavorable retroactive adjustments of (38,339) MMBtu.
(4)		Simple average of estimates for the months included in the period presented.
(5)		Reflects a prior year overpayment by WPC of $765,816 which Williams has waived any right to recoup.

The initial five-year term of the pricing provision (“Primary Term”) of the Gas Purchase Contract expired on December 31, 1997. Following the expiration of the Primary Term, the

Production from the WI Properties is generally sold by WPC to WPX Gas Resources pursuant to the Gas Purchase Contract that provides certain protections for WPC and Unitholders by providing that WPX Gas Resources will purchase gas from WPC at a minimum purchase price of $1.70 even when the applicable index price (which is equal to 97% of the Blanco Hub Spot Price) falls below $1.70 per MMBtu, provided that WPX Gas Resources is entitled to

~~accrue~~pricing provision ~~price~~continued ~~credits~~to remain in ~~the~~effect ~~amount~~for ofone ~~any~~or ~~excess~~more ofconsecutive ~~the~~additional ~~minimum~~one-year ~~price~~terms ~~so paid over the~~(each ~~applicable~~such ~~index~~term ~~price.~~a ~~When~~“Contract ~~the~~Year”) ~~applicable~~unless ~~index~~and ~~price~~until ~~exceeds~~WPX ~~$1.70~~Gas ~~per~~Resources ~~MMBtu,~~exercised ~~WPX~~its ~~Gas~~annual ~~Resources~~option, isexercisable ~~entitled~~15 days prior to ~~recoup~~the ~~any~~end ~~price~~of ~~credits~~each ~~previously~~Contract ~~accrued.~~Year, ~~When~~to ~~the~~discontinue ~~applicable~~purchasing ~~index~~gas ~~price~~from isWPC ~~greater~~under ~~than~~the ~~$1.94~~pricing ~~per~~provision ~~MMBtu,~~of the Gas Purchase Contract ~~protects~~ and ~~benefits~~instead ~~WPX~~purchase ~~Gas~~gas ~~Resources~~at bya monthly ~~allowing~~price itequal to ~~purchase~~the ~~gas~~index ~~from~~price ~~WPC~~of at97% aof ~~contract~~the ~~price~~Blanco ~~equal~~Hub toSpot $1Price.94 ~~per~~WPX ~~MMBtu~~did ~~plus~~not ~~only~~exercise 50this ~~percent~~option, and the pricing mechanism of the ~~difference~~Primary ~~between~~Term continued to remain in effect through the expiration ~~applicable~~of ~~index~~the ~~price~~Gas ~~and~~Purchase ~~$1.94~~Agreement ~~per~~on ~~MMBtu~~August 1, 2010. The ~~Gas~~terms ~~Purchase Contract~~for ~~also~~the ~~provides~~purchase ~~that~~of natural gas produced from the ~~price~~WI ~~paid~~Properties (except for ~~gas~~certain bysmall ~~WPX~~volumes ~~Gas~~related ~~Resources~~to isthe ~~reduced~~Farmout Properties, which were not affected by the ~~amount~~Gas ofPurchase Contract expiration) from the expiration ~~gathering,~~date ~~processing~~through ~~and~~the ~~certain~~September 1, ~~other~~2010 ~~costs~~effective ~~paid~~date byof ~~WPX~~the ~~Gas~~sale ~~Resources.~~of ~~See~~the ~~“Item 2~~Trust’s ~~Properties~~assets —were governed ~~The~~by ~~Royalty~~a ~~Interests~~new — Gas Purchase ~~Contract”~~Agreement indated ~~the~~effective ~~2009~~as ~~Annual~~of ~~Report~~August 1, 2010, which provides for ~~detailed~~an ~~information~~index ~~about~~price equal to 97% of the posted index price published in Inside FERC’s Gas ~~Purchase~~Market ~~Contract~~Report ~~and~~for ~~its~~“El Paso ~~impact~~Natural onGas ~~Trust~~Company, ~~income~~San Juan.”

~~The~~For ~~initial~~the ~~five-year~~nine ~~term~~months ofended ~~the~~September 30, ~~pricing~~2010, ~~provision~~which ~~(“Primary~~is ~~Term”)~~based ofon ~~the~~production ~~Gas~~volumes ~~Purchase~~and natural ~~Contract~~gas ~~expired~~prices onthrough ~~December~~the August 311, ~~1997.~~2010 ~~Following the~~ expiration date of the ~~Primary~~Gas ~~Term~~Purchase Agreement, the ~~pricing~~Blanco Hub ~~provision~~Spot ~~continued~~Price towas ~~remain~~above in$2.00 ~~effect~~per ~~for~~MMBtu, ~~one~~and ortherefore ~~more~~the ~~consecutive~~applicable ~~additional~~index ~~one-year~~price ~~terms~~under ~~(each~~the Gas ~~such~~Purchase ~~term a “~~Contract, ~~Year”)~~which ~~unless~~is ~~and~~equal ~~until~~to ~~WPX~~97% ~~Gas~~of ~~Resources~~the ~~exercised~~Blanco ~~its~~Hub ~~annual~~Spot ~~option~~Price, ~~exercisable~~ ~~15 days~~was ~~prior~~above to$1.94 ~~the~~per ~~end~~MMBtu through ofsuch ~~each~~period. ~~Contract~~In ~~Year~~general, ~~to discontinue purchasing gas from WPC~~ under the ~~pricing provision of the~~ Gas Purchase Contract, ~~and~~the ~~instead~~Trust ~~purchase~~only ~~gas~~receives ~~at a monthly~~the ~~price~~benefit ~~equal~~of to50 percent ~~the~~of ~~index~~any ~~price~~amount ofby ~~97%~~which of the ~~Blanco~~applicable ~~Hub~~index ~~Spot~~price ~~Price~~exceeds $1.94 ~~WPX~~per ~~did not exercise this~~MMBtu. ~~option~~Consequently, ~~and~~pursuant to the ~~pricing~~terms ~~mechanism~~ of the ~~Primary~~Gas ~~Term~~Purchase ~~continued~~Contract, toWPX ~~remain~~Gas inResources ~~effect~~paid ~~through~~WPC ~~the~~an ~~expiration~~amount offor ~~the~~gas ~~Gas~~purchased ~~Purchase~~equal ~~Agreement~~to ~~on August~~ $1~~, 2010~~.94 ~~The~~per ~~terms~~MMBtu, ~~for~~less the ~~purchase~~costs ofpaid ~~natural gas~~by ~~produced~~WPX ~~from~~Gas ~~the~~Resources WIto gather ~~Properties~~and ~~(except~~process ~~for~~such ~~certain~~gas ~~small~~and ~~volumes~~deliver ~~related~~it to ~~the~~specified ~~Farmout Properties,~~delivery ~~which~~points ~~were~~plus ~~not~~50 percent ~~affected~~of by the excess ~~Gas~~of ~~Purchase~~the ~~Contract~~applicable ~~expiration)~~index ~~subsequent~~price toover ~~the expiration~~$1.94 ~~date~~per ~~are currently being negotiated~~MMBtu.

For the six months ended June 30, 2010, which is based on production volumes and natural gas prices through the March 1, 2010 Termination Date, the Blanco Hub Spot Price was above $2.00 per MMBtu, and therefore the applicable index price under the Gas Purchase Contract, which is equal to 97% of the Blanco Hub Spot Price, was above $1.94 per MMBtu through such period. In general, under the Gas Purchase Contract, the Trust only receives the benefit of 50 percent of any amount by which the applicable index price exceeds $1.94 per MMBtu. Consequently, pursuant to the terms of the Gas Purchase Contract, WPX Gas Resources paid WPC an amount for gas purchased equal to $1.94 per MMBtu, less the costs paid by WPX Gas Resources to gather and process such gas and deliver it to specified delivery points plus 50 percent of the excess of the applicable index price over $1.94 per MMBtu. The Blanco Hub Spot Price remained above $2.00 per MMBtu in July 2010.

The information in this report on Form 10-Q concerning production and prices relating to the Underlying Properties is based on information prepared and furnished by WPC to the Trustee. The Trustee has no control over and no responsibility relating to the operation of the Underlying Properties.

Forward-Looking Statements

This report on 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, which are intended to be covered by the safe harbor created thereby. All statements other than statements of historical fact included in this report on Form 10-Q, including, without limitation, statements contained in this “Trustee’s Discussion and Analysis of Financial Condition and Results of Operations” regarding the Trust’s financial position and industry conditions and any distribution of sale proceeds from the Remaining Royalty Interests upon termination of the Trust, are forward-looking statements. Although the Trustee believes that the expectations reflected in such forward-looking statements are reasonable, it can give no assurance that such expectations will prove to have been correct.

thereby. All statements other than statements of historical fact included in this report on Form 10-Q, including, without limitation, statements contained in this “Trustee’s Discussion and Analysis of Financial Condition and Results of Operations” regarding the Trust’s financial position and industry conditions and any sale of the Remaining Royalty Interests upon termination of the Trust, are forward-looking statements. Although the Trustee believes that the expectations reflected in such forward-looking statements are reasonable, it can give no assurance that such expectations will prove to have been correct.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

The only assets of and sources of income to the Trust are the Royalty Interests, which, prior to the termination of the Trust, generally entitled the Trust to receive a share of the net profits from natural gas production from the Underlying Properties. Consequently, the Trust’s financial results are significantly affected by fluctuations in natural gas prices and the Trust has commodity price risk exposure associated with the natural gas markets in the United States. The Trust does not engage in any hedging activities to manage its price risk associated with natural gas production from the Underlying Properties. The Royalty Interests do not entitle the Trust to control or influence the operation of the Underlying Properties or the sale of gas produced therefrom. Natural gas produced from the WI Properties, which comprises the majority of production attributable to the Royalty Interests, was sold by WPC pursuant to the terms of the Gas Purchase Contract which expired August 1, 2010. and a new Gas Purchase Agreement effective August 1, 2010. Although the Trust was not a party to the Gas Purchase Contract, the Gas Purchase Contract significantly impacted revenues to the Trust. Although the original Gas Purchase Contract mitigated the risk to the Trust of low gas prices, it also limited the ability of the Trust to benefit from the effects of higher gas prices, particularly to the extent a balance existed in the Price Credit Account. See “Item 2 Properties — The Royalty Interests — Gas Purchase Contract” in the 2009 Annual Report for detailed information about the original Gas Purchase Contract and its impact on the Trust and Unitholders.

Upon receipt by the Trust, royalty income is invested in short term investments in accordance with the Trust Agreement until its subsequent distribution to Unitholders. Currently, funds are invested in Bank of America money market accounts which are backed by the good faith and credit of Bank of America, N.A., but are not insured by the FDIC. Each Unitholder should independently assess the creditworthiness of Bank of America, N.A. For more information about the credit rating of Bank of America, N.A., please refer to its periodic filings with the SEC. The Trust does not lend money and has limited ability to borrow money, which the Trustee believes limits the Trust’s risk from the current tightening of credit markets. ~~The Trust’s future royalty income, however,~~ may be subject to risks relating to the creditworthiness of the operators of the Underlying Properties and WPX Gas Resources and other purchasers of the natural gas produced from the Underlying Properties, as well as risks associated with fluctuations in the price of natural gas.

~~The~~Prior to suspension of trading as of the close of business on November 15, 2010, the market prices of the Units ~~are~~were determined by the buyers and sellers on the New York Stock Exchange. The Trust does not make market on any Units and is not in any position to advise any Unitholder on any market position. Unitholders should be aware that any position of the market concerning the Units is beyond the Trust’s control and on any given day, various market conditions will affect the market of the Units. See Note 6 regarding suspension or termination of trading of the Units on the New York Stock Exchange as of the record date for the distribution of net sales proceeds from the sale of the Trust’s assets.

23 Other than the Trust’s ability to periodically borrow money as necessary to pay expenses, liabilities and obligations of the Trust that cannot be paid out of cash held by the Trust, the Trust is prohibited from engaging in borrowing transactions. The amount of any such borrowings is unlikely to be material to the Trust. The Trust periodically holds short-term investments acquired with funds held by the Trust pending distribution to Unitholders and funds held in reserve for the payment of Trust expenses and liabilities. Because of the short-term nature of these borrowings and investments and certain limitations upon the types of such investments that may be held by the Trust, the Trustee believes that the Trust is not subject to any material

The assets of the Trust are passive in nature, and other than the Trust’s ability to periodically borrow money as necessary to pay expenses, liabilities and obligations of the Trust that cannot be paid out of cash held by the Trust, the Trust is prohibited from engaging in borrowing transactions. The amount of any such borrowings is unlikely to be material to the Trust. The Trust periodically holds short-term investments acquired with funds held by the Trust pending distribution to Unitholders and funds held in reserve for the payment of Trust expenses and liabilities. Because of the short-term nature of these borrowings and investments and certain limitations upon the types of such investments that may be held by the Trust, the Trustee believes that the Trust is not subject to any material interest rate risk. The Trust does not engage in transactions in foreign currencies that could expose the Trust or Unitholders to any foreign currency related market risk.

Item 4. Controls and Procedures.

The Trust maintains a set of disclosure controls and procedures designed to ensure that information required to be disclosed by the Trust in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms. In addition, the disclosure controls and procedures are designed to ensure that the information required to be disclosed by the Trust is accumulated and communicated to the Trustee to allow timely decisions regarding required disclosure. As of the end of the period covered by this report on Form 10-Q, 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 Rule 13a-15 and 15d-15. Based upon that evaluation, the Trustee concluded that the Trust’s disclosure controls and procedures are effective in recording, processing, summarizing and reporting, on a timely basis, information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 and are effective in ensuring that information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934 is accumulated and communicated to the Trustee to allow timely decisions regarding required disclosure. In its evaluation of disclosure controls and procedures, the Trustee has relied, to the extent considered reasonable, on information provided by WPC. There has not been any change in the Trust’s internal control over financial reporting during the period covered by this report on Form 10-Q that has materially affected, or is reasonably likely to materially affect, the Trust’s internal control over financial reporting.

PART II — OTHER INFORMATION

Item 1. Legal Proceedings.

Not applicable.

~~Items~~ Item 1A. ~~through~~Risk 5Factors.

Except as set forth below, there has been no material changes in the risk factors disclosed in Part I, Item 1A of the Trust’s 2009 Report for the year ended December 31, 2009.

The Trust terminated on March 1, 2010, has sold its remaining Royalty Interests and no further Trust distributions are anticipated following distribution of the net sales proceeds (Note 6).

The Trust’s computed net present value of the estimated future net revenues for proved reserves attributable to the Royalty Interests computed in accordance with the Trust Agreement, using an average 2009 index price of $3.25, by the independent petroleum engineers as of December 31, 2009, was approximately $8.4 million. The results of this computation triggered an early termination of the Trust as of March 1, 2010 in accordance with the terms of the Trust Agreement. In accordance with the Trust Agreement, the Trustee sold all of the assets of the Trust and will distribute proceeds from the Royalty Interest through the September 1, 2010

effective date of the sale of the Trust’s assets, as well as the net sales proceeds from the sale of the assets on October 27, 2010 to Unitholders of record on November 15, 2010. Following such distributions, no additional distributions are anticipated. The Trustee has retained a cash reserve to pay the Trust’s liabilities and expenses in connection with the winding up of the Trust. To the extent that the cash reserve exceeds the actual liabilities and expenses of the Trust, the Trustee will make one or more distributions to Unitholders of record as of November 15, 2010; however, no assurances can be made as to the amount, or timing, of distributions, or whether any such distributions will ever be made. See Notes 2 and 6.

The Trust will no longer be a reporting company and its Units will no longer trade on the New York Stock Exchange.

November 15, 2010 was the date the Trust’s Unit transfer books closed and the New York Stock Exchange suspended trading of the Units at the close of business on such date. The Trust will thereafter deregister the Units with the Securities and Exchange Commission and will cease to be a reporting company.

Items 2 through 5.

Not applicable.

Item 6. Exhibits.

The exhibits listed below are filed as part of this report on Form 10-Q:


EXHIBIT
NUMBER		EXHIBIT
3.2 —		Certificate of Amendment to Certificate of Trust of Williams Coal Seam Gas Royalty Trust dated as of October 21, 2010.

4.1 —		Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of December 1, 1992, by and among Williams Production Company, The Williams Companies, Inc. and Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), as trustees (filed as Exhibit 4.1 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).

4.2 —		First Amendment to the Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of December 15, 1992, by and among Williams Production Company, The Williams Companies, Inc., Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.) (filed as Exhibit 4.2 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).

EXHIBIT
NUMBER		EXHIBIT
4.1—		Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of December 1, 1992, by and among Williams Production Company, The Williams Companies, Inc. and Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), as trustees (filed as Exhibit 4.1 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.3 —		Second Amendment to the Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of January 12, 1993, by and among Williams Production Company, The Williams Companies, Inc., Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.) (filed as Exhibit 4.3 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.2—		First Amendment to the Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of December 15, 1992, by and among Williams Production Company, The Williams Companies, Inc., Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.) (filed as Exhibit 4.2 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.4 —		Net Profits Conveyance effective as of October 1, 1992, by and among Williams Production Company, The Williams Companies, Inc., and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), and Chemical Bank Delaware (filed as Exhibit 4.4 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.3—		Second Amendment to the Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of January 12, 1993, by and among Williams Production Company, The Williams Companies, Inc., Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.) (filed as Exhibit 4.3 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.5 —		Supplemental Net Profits Conveyance dated as of May 19, 2010 by and between Williams Production Company LLC and Bank of America, N.A. as successor Trustee of the Williams Coal Seam Gas Royalty Trust. (filed as Exhibit 4.5 to the Registrant’s Form 10-Q for the six months ended June 30, 2010 and incorporated herein by reference).
4.4—		Net Profits Conveyance effective as of October 1, 1992, by and among Williams Production Company, The Williams Companies, Inc., and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), and Chemical Bank Delaware (filed as Exhibit 4.4 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.6 —		Amendment to Net Profits Conveyance dated as of October 27, 2010 by and between Williams Production Company, LLC and Bank of America, N.A.
4.5—		Supplemental Net Profits Conveyance dated as of May 19, 2010 by and between Williams Production Company LLC and Bank of America, N.A. as successor Trustee of the Williams Coal Seam Gas Royalty Trust.
10.10 —		Gas Purchase Agreement effective as of August 1, 2010 between WPX Gas Resources Company and Williams Production, LLC
15.1 —		Letter regarding unaudited interim financial information dated August 16, 2010, from the independent Registered Public Accounting Firm which acknowledges awareness of the use in a registration statement of a report on unaudited interim financial information.
10.11 —		Purchase and Sale Agreement dated as of October 27, 2010 by and between Williams Coal Seam Gas Royalty Trust and Williams Production Company, LLC (filed as Exhibit 10.1 to the Registrant’s Form 8-K dated October 29, 2010 and incorporated herein by reference).
15.1 —		Letter regarding unaudited interim financial information dated November 17, 2010, from the independent Registered Public Accounting Firm which acknowledges awareness of the use in a registration statement of a report on unaudited interim financial information.

EXHIBIT
NUMBER		EXHIBIT
31.1 —		Certification by Ron E. Hooper, Senior Vice President and Administrator of Bank of America, Trustee of Williams Coal Seam Gas Royalty Trust, dated ~~August~~November 1617, 2010, and submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1 —		Certificate by Bank of America, Trustee of Williams Coal Seam Gas Royalty Trust, dated ~~August~~November 1617, 2010, and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350).

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.


	WILLIAMS COAL SEAM GAS ROYALTY TRUST By: BANK OF AMERICA, N.A., Trustee
	By:	/s/ RON E. HOOPER
		Ron E. Hooper
		Senior Vice President and Administrator

(The Trust has no directors or executive officers.)

Date: ~~August~~ November 1617, 2010

INDEX TO EXHIBITS

EXHIBIT NUMBER		EXHIBIT
4.1—		Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of December 1, 1992, by and among Williams Production Company, The Williams Companies, Inc. and Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), as trustees (filed as Exhibit 4.1 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
3.2 —		Certificate of Amendment to Certificate of Trust of Williams Coal Seam Gas Royalty Trust dated as of October 21, 2010.
4.2—		First Amendment to the Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of December 15, 1992, by and among Williams Production Company, The Williams Companies, Inc., Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.) (filed as Exhibit 4.2 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.1 —		Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of December 1, 1992, by and among Williams Production Company, The Williams Companies, Inc. and Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), as trustees (filed as Exhibit 4.1 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.3—		Second Amendment to the Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of January 12, 1993, by and among Williams Production Company, The Williams Companies, Inc., Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.) (filed as Exhibit 4.3 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.2 —		First Amendment to the Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of December 15, 1992, by and among Williams Production Company, The Williams Companies, Inc., Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.) (filed as Exhibit 4.2 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.4—		Net Profits Conveyance effective as of October 1, 1992, by and among Williams Production Company, The Williams Companies, Inc., and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), and Chemical Bank Delaware (filed as Exhibit 4.4 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.3 —		Second Amendment to the Trust Agreement of Williams Coal Seam Gas Royalty Trust effective as of January 12, 1993, by and among Williams Production Company, The Williams Companies, Inc., Chemical Bank Delaware and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.) (filed as Exhibit 4.3 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).
4.5 —		Supplemental Net Profits Conveyance dated as of May 19, 2010 by and between Williams Production Company LLC and Bank of America, N.A. as successor Trustee of the Williams Coal Seam Gas Royalty Trust.
4.4 —		Net Profits Conveyance effective as of October 1, 1992, by and among Williams Production Company, The Williams Companies, Inc., and Bank of America, N.A. (as successor to NationsBank of Texas, N.A.), and Chemical Bank Delaware (filed as Exhibit 4.4 to the Registrant’s Form 10-K for the year ended December 31, 1992 and incorporated herein by reference).

EXHIBIT NUMBER		EXHIBIT
15.1 —		Letter regarding unaudited interim financial information dated August 16, 2010, from the independent Registered Public Accounting Firm which acknowledges awareness of the use in a registration statement of a report on unaudited interim financial information.
4.5 —		Supplemental Net Profits Conveyance dated as of May 19, 2010 by and between Williams Production Company LLC and Bank of America, N.A. as successor Trustee of the Williams Coal Seam Gas Royalty Trust. (filed as Exhibit 4.5 to the Registrant’s Form 10-Q for the six months ended June 30, 2010 and incorporated herein by reference).
31.1 —		Certification by Ron E. Hooper, Senior Vice President and Administrator of Bank of America, Trustee of Williams Coal Seam Gas Royalty Trust, dated August 16, 2010, and submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
4.6 —		Amendment to Net Profits Conveyance dated as of October 27, 2010 by and between Williams Production Company, LLC and Bank of America, N.A.
32.1 —		Certificate by Bank of America, Trustee of Williams Coal Seam Gas Royalty Trust, dated August 16, 2010, and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350).
10.10 —		Gas Purchase Agreement effective as of August 1, 2010 between WPX Gas Resources Company and Williams Production Company, LLC
10.11 —		Purchase and Sale Agreement dated as of October 27, 2010 by and between Williams Coal Seam Gas Royalty Trust and Williams Production Company, LLC (filed as Exhibit 10.1 to the Registrant’s Form 8-K dated October 29, 2010 and incorporated herein by reference).
15.1 —		Letter regarding unaudited interim financial information dated November 17, 2010, from the independent Registered Public Accounting Firm which acknowledges awareness of the use in registration statement of a report on unaudited interim financial information.
31.1 —		Certification by Ron E. Hooper, Senior Vice President and Administrator of Bank of America, Trustee of Williams Coal Seam Gas Royalty Trust, dated November 17, 2010, and submitted pursuant to Rule 13a-14(a)/15d-14(a) and pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1 —		Certificate by Bank of America, Trustee of Williams Coal Seam Gas Royalty Trust, dated November 17, 2010, and submitted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (18 U.S.C. Section 1350).

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