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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

FORM 10-Q


ý		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED MARCH 31, 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 1-8432

MESA OFFSHORE TRUST
(Exact name of Registrant as Specified in its Charter)


Texas (State of Incorporation or Organization)		76-6004065 (I.R.S. Employer Identification No.)
JPMorgan Chase Bank, N.A., Trustee Institutional Trust Services 919 Congress Avenue Austin, Texas (Address of Principal Executive Offices)		78701 (Zip Code)
1-800-852-1422 (Registrant's Telephone Number, Including Area Code)

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. 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 ý (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 Act). Yes o No ý

As of May 14, 2010, 71,980,216 Units of Beneficial Interest were outstanding in Mesa Offshore Trust.

PART I—FINANCIAL INFORMATION

Item 1. Financial Statements.

MESA OFFSHORE TRUST
STATEMENTS OF DISTRIBUTABLE INCOME
(Unaudited)

		Three Months Ended March 31,

		2010			2009
Royalty income		$	81,589		$	112,567
Settlement proceeds			19,001,230			—
Interest income			627			21
Plaintiff attorney fees			(7,750,000	)		—
General and administrative expenses			(2,960,132	)		(112,588	)

	Distributable income	$	8,373,314		$	—

	Distributable income per unit	$	0.1163		$	—

STATEMENT OF ASSETS, LIABILITIES AND TRUST CORPUS

		March 31, 2010			December 31, 2009

		(Unaudited)
ASSETS
Cash and short-term investments		$	2,454,747		$	302,164
Net overriding royalty interest in oil and gas properties			380,905,000			380,905,000
Less: accumulated amortization			(380,905,000	)		(380,905,000	)

	Total assets	$	2,454,747		$	302,164

LIABILITIES AND TRUST CORPUS
Reserve for trust expenses		$	2,454,747		$	302,164
Trust expense payable			—			75,055
Interest payable			—			480,443
Advances payable—JPMorgan			—			599,718
Note payable—JPMorgan			—			5,000,000
Trust corpus (71,980,216 units of beneficial interest authorized and outstanding)			—			(6,155,216	)

	Total liabilities and trust corpus	$	2,454,747		$	302,164

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

MESA OFFSHORE TRUST
STATEMENTS OF CHANGES IN TRUST CORPUS
(Unaudited)

		Three Months Ended March 31,

		2010			2009
Trust corpus, beginning of period		$	(6,155,216	)	$	(4,055,744	)
	Trust expenses payable		75,055			176,973
	Interest payable		480,443			(50,877	)
	Advances payable—JPMorgan		599,718			—
	Note payable—JPMorgan		5,000,000			(878,518	)

Trust corpus, end of period		$	—		$	(4,808,166	)

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

MESA OFFSHORE TRUST
NOTES TO FINANCIAL STATEMENTS
(Unaudited)

Note 1—Trust Organization

The Trust

The Mesa Offshore Trust (the "Trust") was created effective December 1, 1982. On that date, Mesa Petroleum Co., predecessor to Mesa Limited Partnership, which was the predecessor to MESA Inc., transferred to the Trust a 99.99% interest in the Mesa Offshore Royalty Partnership (the "Partnership"). The Trust is an independent trust administered by JPMorgan Chase Bank, N.A., as trustee (the "Trustee"). JPMorgan Chase Bank, N.A., was formerly known as The Chase Manhattan Bank and is the successor by mergers to the original name of the Trustee, Texas Commerce Bank National Association.

JPMorgan Chase & Co. and The Bank of New York Company ("BNY") announced in April 2006 an agreement pursuant to which BNY would acquire a portion of JPMorgan Chase & Co.'s corporate trust business in exchange for BNY's consumer small business and middle market banking business. This transaction did not include any transfer by JPMorgan of its obligations as Trustee of this Trust.

The Partnership

The Partnership was created to receive and hold a net overriding royalty interest (the "Royalty") in ten producing and non-producing oil and gas properties located in federal waters offshore Louisiana and Texas (the "Royalty Properties"). Mesa Petroleum Co. created the Royalty out of its working interest in the Royalty Properties and transferred it to the Partnership. Until August 7, 1997, MESA Inc. owned and operated its assets through Mesa Operating Co. ("Mesa"), the operator and the managing general partner of the Royalty Properties. On August 7, 1997, MESA, Inc. merged with and into Pioneer Natural Resources Company ("PNRC"), formerly a wholly owned subsidiary of MESA, Inc., and Parker & Parsley Petroleum Company merged with and into Pioneer Natural Resources USA, Inc. ("PNR") (successor to Mesa), a wholly owned subsidiary of PNRC (collectively, the mergers are referred to herein as the "Merger"). Subsequent to the Merger, PNR owns and operates its assets through PNRC, and is also the managing general partner of the Partnership. The Partnership is owned 99.99% by the Trust and 0.01% by PNR. PNR serves as the managing general partner of the Partnership. PNR receives no compensation for serving as managing general partner other than the income it receives attributable to its interest in the Partnership.

Note 2—Status of the Trust, Legal Proceedings, and Timing of Liquidation

Status of the Trust, Timing of Liquidation and Legal Proceedings

The Trust Indenture provides that the Trust will liquidate if the total amount of cash per year received by the Trust falls below certain levels for each of three successive years. As a result of insufficient production on Royalty Properties nearing the end of their estimated productive lives, Royalty income received by the Trust in 2002, 2003 and 2004 fell below the Termination Threshold prescribed by the Trust Indenture.

Pursuant to the Final Settlement Agreement described below, the Trustee directed the sale or other final disposition of the properties owned by the Partnership as part of the termination and

liquidation of the Trust. As part of the liquidation and termination of the Trust, the Trustee set February 22, 2010 as the record date for unit holders entitled to payments of any final liquidating distributions. The Trustee also announced, and on March 24, 2010 paid, an initial liquidating distribution of $0.116238 per unit. The Trustee will make one or more final liquidating distributions to unit holders of any funds remaining after all Trust liabilities have been satisfied.

Pioneer has informed the Trustee that it expects to commence plugging and abandonment of the Partnership's remaining property on the Brazos A-39 Block during the third quarter of 2010, pending the availability of the required lift boat needed to do the work. The Trustee expects to make a final liquidating distribution as promptly as practicable after such date, if there are any remaining proceeds after all of the Trust's liabilities have been paid by the Trustee.

On April 11, 2005, MOSH Holding, L.P. ("MOSH") filed an Original Petition in the District Court of Travis County, Texas, 250th Judicial District, against PNRC; PNR; Woodside Energy (USA), Inc. ("Woodside"); and JPMorgan, as Trustee of the Mesa Offshore Trust (Case No. GN501113) (the "Lawsuit"). The Lawsuit was subsequently transferred to the 334th Judicial District of Harris County, Texas (the "Court"). MOSH's Original Petition alleged Pioneer and Woodside were liable for various actions, including (1) a wrongful farmout by Pioneer to Woodside of the Brazos A-39 Lease, (2) a wrongful delay by Pioneer in producing the Brazos A-39 Lease and the Midway #5 well drilled thereon, (3) fraudulent accounting practices by Pioneer, (4) breach of fiduciary duty by Pioneer, (5) aiding and abetting breach of fiduciary duty by Woodside, (6) misapplication of Trust property by Pioneer, (7) conspiracy to misapply fiduciary property by Woodside and Pioneer, (8) common law fraud by Pioneer, (9) gross negligence by Pioneer, and (10) breach of the conveyance agreement by Pioneer. As described below, MOSH later added claims against the Trustee for (1) an accounting, and (2) an alleged breach of fiduciary duty. The remedies MOSH sought included (a) reconstruing the Trust Indenture to determine that the Trust is not terminated because there has or should have been production that would have generated revenues to extend the life of the Trust, (b) requiring the Trustee to pursue certain claims, or to allow MOSH to pursue such claims, (c) setting aside any farmouts by Pioneer in which there have been conveyances to an alleged affiliate of Pioneer, (d) the removal of JPMorgan as Trustee, (e) the return or forfeiture of compensation to JPMorgan, (f) monetary damages against Pioneer, Woodside and JPMorgan, and (g) unspecified exemplary damages against all defendants.

MOSH's Original Petition did not contain any claims against the Trustee, except to enjoin the Trustee from terminating the Trust during the pendency of the Lawsuit. In April 2005, the Trustee entered into an agreement with MOSH whereby the Trustee would not sell the Trust assets without first giving MOSH sixty-days written notice. This agreement allowed MOSH time to obtain documents and discovery from Pioneer and Woodside, and allowed the Trustee time to investigate the claims asserted by MOSH against Pioneer and Woodside to determine if they had any merit and, most importantly, whether the claims would benefit the Trust. During the six month period between April and October 2005, the Trustee conducted an independent investigation including: numerous meetings and discussions with the parties; reviewing the relevant documents with the Trustee's counsel; employing independent reservoir engineers to evaluate the reserves in which the Trust has an interest; engaging independent joint venture auditors to examine the accounting records of the operator, Pioneer, relating to revenues and expenses allocated to the Partnership's interests; and obtaining from both MOSH and Pioneer their respective legal analyses of the challenged farmout.

Throughout 2005, the parties also anticipated that the Midway #5 well on the Brazos A-39 Lease that is the primary subject of the Lawsuit would go into production. Given the discrepancy between the reserves claimed by MOSH and those projected by Pioneer for the Midway #5 well, actual production results would significantly impact the Trustee's assessment of whether the Trust was better off with the cost-free override created by the Pioneer-Woodside Farmout, or the prior cost-burdened net profits interest that MOSH sought to restore through the Lawsuit. Unfortunately, Hurricane Katrina struck the Gulf of Mexico in August 2005 and delayed the commencement of production until 2006.

Faced with this post-Katrina situation in the fall of 2005, the Trustee urged all the parties to consent to a bifurcated trial of the farmout issue on an expedited basis. The Trustee proposed to MOSH that if the Court determined that the farmout was not valid and that restoring the net profits interest would benefit the Trust, then the Trust would reimburse MOSH's reasonable attorneys' fees, up to $100,000, and the Trustee would allow MOSH's counsel to represent the Trust in prosecuting the damages portion of the case. Conversely, if MOSH were to lose on the expedited determination of the farmout issue, and in the absence of more evidence to support any ancillary claims, then MOSH would dismiss the other claims and would not be reimbursed, and the Trustee would move forward to terminate the Trust.

Although the Trustee, Pioneer, and Woodside all agreed to an expedited trial of the farmout issues, MOSH balked. Contrary to the assertions of MOSH and the Intervenor Plaintiffs, the Trustee never agreed that the claims asserted by MOSH against Pioneer and Woodside "had merit"—the Trustee simply stated that the farmout issue might merit immediate adjudication at that time to determine if MOSH was legally correct.

When MOSH refused to agree to an expedited and bifurcated trial as proposed by the Trustee, the Trustee informed MOSH that the Trustee's investigation of MOSH's allegations beyond the farmout issues failed to convince the Trustee that pursuing those claims and incurring the related legal fees and expenses would benefit the Trust. Moreover, the Trustee informed MOSH that the Trustee's independent joint venture auditors and reservoir engineers had not found any evidence to support any of MOSH's damage allegations. Therefore, the Trustee informed MOSH that the Trustee's investigation indicated that the Trust was better off with the post-farmout cost-free overriding royalty interest than the pre-farmout cost-burdened net profits interest, so the funding of MOSH's efforts to set aside the farmout with Trust funds would not be in the best interest of the Trust.

It was at this point, in November 2005, in the midst of the Trustee's negotiations with MOSH to obtain an agreed resolution of MOSH's claims, that MOSH alleged for the first time that the Trustee had a conflict of interest because of JPMorgan's long-standing lending relationship with Pioneer. Although it is clear under the Trust Indenture, the Texas Trust Act, and relevant case law that JPMorgan is not precluded, by holding the position of Trustee, from pursuing commercial banking activities not involving Trust funds, MOSH amended its petition and asserted claims against the Trustee on November 28, 2005.

Although it responded that MOSH's claims against the Trustee were meritless, to avoid any further assertion that the Trustee could not impartially evaluate MOSH's claims, on November 30, 2005, JPMorgan announced its intention to resign as Trustee, effective January 31, 2006. On December 13, 2005, the lawsuit was transferred to the 334th Judicial District Court of Harris County, Texas. At a hearing on January 27, 2006 in the Harris County Court, the Court denied MOSH's motion for a temporary injunction to remove JPMorgan as Trustee and appoint a principal of MOSH, Timothy Roberson, as a temporary Trustee. At the Court's suggestion, JPMorgan agreed to continue as Trustee,

until such time as a substitute trustee was found that fulfilled the qualifications of Trustee stated in the Trust Indenture. Since that hearing, none of the parties ever identified a willing qualified successor Trustee that was not also a lender under one of Pioneer's credit facilities (which status MOSH contended was an alleged conflict of interest).

On December 8, 2006, Dagger-Spine Hedgehog Corporation ("Dagger-Spine") filed a petition to intervene in the Lawsuit as a Plaintiff, alleging claims virtually identical to MOSH. Another group of unit holders, led by Keith A. Wiegand, (together with Dagger-Spine, the "Intervenors") also filed on March 9, 2007 a petition to intervene as plaintiffs in the Lawsuit, incorporating and adopting the same claims asserted by MOSH. MOSH and the Intervenors are referred to hereinafter as the "Plaintiffs."

In 2006, after the Court denied MOSH's attempt to remove JPMorgan as Trustee, the parties pursued formal discovery in the Lawsuit. During this period, the Trustee continued to evaluate the merits of the alleged claims against Pioneer and Woodside. A central allegation by MOSH and the Intervenors was that Pioneer and Woodside delayed the commencement of production from the well drilled pursuant to the Pioneer-Woodside Farmout—the Midway #5 well on the Brazos A-39 Lease. However, Woodside and Pioneer witnesses gave sworn testimony in depositions about the commercial and technical reasons for the delays in bringing the well on line. The well commenced production in April 2006. After production began, the Trustee instructed its independent petroleum reserve engineers to evaluate how the production results and projected future production from the well might affect the value of the Trust's interests. The Trustee's independent engineers determined that the initial production data from the well did not warrant a material change in prior assessments of the value of the Trust's assets.

Pioneer subsequently reported to the Trustee that production from the well was suspended in July 2006 due to mercury contamination identified at downstream facilities where the production from the well was commingled with production from other wells. An updated evaluation from the Trustee's independent petroleum reserve engineers estimated that revenues from future production likely would not exceed the costs of drilling and completing the well. This confirmed to the Trustee that, if the Partnership's interest in the underlying lease had remained, or was, a cost-burdened net profits interest, instead of the cost-free overriding royalty interest the Partnership held as a result of the Pioneer-Woodside Farmout, the Partnership would not have received, or would not receive, any payments from this production, and the Trust accordingly would not have received any associated distributions. Further, the production data did not support reserves of the size asserted by the Plaintiffs. The well resumed production in February 2007, but the well was shut in again on April 18, 2007 due to an increase in hydrogen sulfide content coincidental with an increase in water production. Pioneer implemented a hydrogen sulfide contingency plan, which was required and approved by the MMS, including the installation of the necessary alarm and safety systems. The well was shut in October 4, 2008 after discovery of corrosion in the production separator on the host platform. A replacement production separator was installed on the host platform. The well was returned to production on March 19, 2009, but was subsequently shut in again on September 2, 2009, and has been off production ever since. The lease expired 180 days after last production and reverted to the federal government.

Given its conclusion that the Trust was better off with the post-farmout override, and hoping to the end this litigation and liquidate the Trust per the Trust Indenture, the Trustee reached a conditional settlement on January 26, 2007 with Pioneer and Woodside of the claims asserted by the Plaintiffs against Pioneer and Woodside. The conditional settlement was set forth in the Mutual Release and Settlement Agreement dated as of January 26, 2007 (the "Pioneer/Woodside Settlement Agreement").

The Trustee filed a motion for approval of the Pioneer/Woodside Settlement Agreement with the Court on January 30, 2007. The Trustee believed that the Pioneer/Woodside Settlement Agreement was in the best interest of the unit holders, but the Plaintiffs opposed it, and on June 19, 2007, the Court issued an Order denying the Trustee's motion to approve the Pioneer/Woodside Settlement Agreement.

In June and July 2007, Pioneer and Woodside filed motions with the Court that argued that the claims against them did not have merit as a matter of law. Pioneer's motion included an argument that the Plaintiffs did not have the legal right to sue Pioneer because the claims belonged to the Trust, not the beneficiaries of the Trust. On October 19, 2007, the Trustee offered to assign to the Plaintiffs the Trust's claims against Pioneer and Woodside, but the Plaintiffs rejected that offer. Through their counsel, the Plaintiffs and the Trustee also began negotiating a resolution of the claims pending between them, and on October 26, 2007, the Trustee and the Plaintiffs informed the Court of an agreement in principle to settle.

On December 3, 2007, the Trustee entered into a Settlement Agreement and Release with the Plaintiffs and additional Trust unit holders (the "Plaintiffs' Settlement Agreement"). Also on December 3, 2007, the Trustee and the Plaintiffs filed a Joint Motion for Approval of Settlement Agreement (the "Joint Motion"). In response to the Joint Motion, on December 21, 2007, Pioneer filed cross-claims against the Trustee seeking declaratory and injunctive relief to prevent certain aspects of the proposed settlement between the Trustee and the Plaintiffs. On January 14, 2008, the Trustee filed an answer to Pioneer's cross-claims, in which the Trustee denied the cross-claims in their entirety, stated that they were baseless, and set forth numerous affirmative defenses. On January 22, 2008, the Court issued an Order denying the Joint Motion. As a result, the conditions precedent to the Plaintiffs' Settlement Agreement could not be satisfied, and the Plaintiffs' Settlement Agreement became null and void. In addition to denying the Joint Motion, the Court also considered and denied in the same Order (i) the application by the Plaintiffs for the appointment of a temporary trustee and (ii) Pioneer's application for a temporary restraining order. As a result of the Court's denial of the Joint Motion, and the Court's denial of the Plaintiffs' application for the appointment of a temporary trustee, JPMorgan elected not to resign in order to avoid a vacancy, and continues to serve as Trustee.

On April 28, 2008, the Court issued a Docket Control Order, setting the trial date for December 8, 2008. On July 3, 2008, the Plaintiffs filed a Third Amended Petition, seeking, among other things, to add claims against the Partnership (through its partners Pioneer and the Trustee) and JPMorgan in an individual capacity. By order dated July 3, 2008, the Court denied Pioneer's pending motions for summary judgment, including Pioneer's challenge to Plaintiffs' standing. Pioneer then filed a petition for writ of mandamus to the Houston Fourteenth Court of Appeals on July 22, 2008, seeking to reverse the trial courts' ruling on standing. On September 25, 2008, the Houston Fourteenth Court of Appeals denied Pioneer's petition for writ of mandamus, and Pioneer filed a petition for writ of mandamus with the Supreme Court of Texas on October 1, 2008. On October 24, 2008, the group of unit holders led by Keith A. Wiegand filed a Motion for Non-Suit Without Prejudice, and the Court granted the motion on October 24, 2008. Thus, all references herein to "Plaintiffs" after the date of October 24, 2008 include only MOSH and Dagger-Spine. At a hearing before the Court on October 31, 2008, the Plaintiffs agreed to postpone the trial again, and the trial was scheduled for April 13, 2009. The Supreme Court of Texas denied Pioneer's petition for writ of mandamus on November 21, 2008.

By notice dated February 6, 2009, which the Trustee mailed to all unit holders of record on February 10, 2009, the Trustee announced again that the Termination Threshold had been met and that, as a result, it had instructed Pioneer to sell the oil and gas assets of the Partnership at public

auction on March 18, 2009. In addition, the Trustee announced that the sale would include all of Pioneer's interests in Brazos Block A-39. On March 3, 9, and 12, respectively, unit holders Gordon Stamper, Robert Miles, and Keith Wiegand—formerly part of the group of Intervenors led by Keith Wiegand (collectively, the "Individual Intervenors")—filed pro se motions with the Court to intervene in the Lawsuit. At the public auction on March 18, 2009, no bids were submitted for the Partnership assets, in the face of the pending litigation. On March 25, 2009, Plaintiffs filed their Fourth Amended Original Petition, Application for Temporary Restraining Order, Temporary Injunction, Show Cause Order, and Permanent Injunction. On April 15, 2009 and May 9, 2009, respectively, unit holders Michael Brown and Benjamin Ginter filed additional interventions (collectively, along with other individuals previously defined as such, the "Individual Intervenors").

On May 18, 2009, the Trustee, on behalf of the Trust, entered into a Final Settlement Agreement with (1) the Plaintiffs, both in their individual capacities and as claimed representatives of the Trust and/or the unit holders, (2) Pioneer and (3) Woodside. The terms of the Final Settlement Agreement included the following: (a) Pioneer would pay to the Trust $13 million and would sell and contribute to the Trust any proceeds from the sale of all of its interests in the Brazos Block A-39 (the "Pioneer Settlement Interests"); (b) Trustee would pay to the Trust $5 million and would release all claims for and forgive repayment of the existing $5 million Demand Promissory Note (the "Credit Facility") provided by JPMorgan, as lender, to the Trust; and (c) Woodside would pay to the Trust $1 million. Notwithstanding certain other releases, the Trustee will be permitted to use the remaining balance available under the Credit Facility and any other Trust income to pay Trust liabilities and expenses as permitted under the Trust Indenture prior to the final distribution of any net settlement proceeds. These liabilities and expenses include any out-of-pocket costs incurred for effecting the sale of assets in the Liquidation Process and for any other fees and expenses relating to the administration of the Trust after April 27, 2009. As provided in the Final Settlement Agreement, each of the parties agreed to release any and all claims against the other parties that are, or could have been, asserted in the Lawsuit, including any claims for reimbursement of attorneys' fees or costs, except as provided for under the Final Settlement Agreement.

On June 15, 2009, a group of unit holders, most of whom were part of the former group led by Keith A. Wiegand that had previously voluntarily non-suited their claims, submitted a filing to the Court, seeking to delay certain issues from being heard at the June 18, 2009 settlement hearing. This group of unit holders is referred to herein as the "2009 Unit Holder Group." On June 18, 2009 and July 23, 2009, the Court held evidentiary hearings on the fairness of the Final Settlement Agreement. The purpose of these hearings was for the Court to determine whether the Final Settlement Agreement should be approved as being in the best interests of the Trust and its unit holders/beneficiaries. The Individual Intervenors, the 2009 Unit Holder Group, and all other objectors were afforded the opportunity to participate in the hearings.

The Court considered all of the papers filed, the evidence presented, and arguments both for and against the Final Settlement Agreement, and, on August 6, 2009, approved the Final Settlement Agreement and denied all objections thereto. In its Findings of Fact and Conclusions of Law With Respect to Final Settlement Agreement ("Findings of Fact and Conclusions of Law"), the Court ruled that all claims that were raised (or that could have been raised) against the defendants in the Lawsuit were owned by the Trust and/or the Partnership; the Plaintiffs pursued the claims asserted in the Lawsuit on behalf of the Trust and/or the Partnership; the Plaintiffs and the Trustee had the authority to prosecute, resolve, settle and release all released claims on behalf of the Trust, the Partnership and the Plaintiffs; and the settlement was in the best interest of the Trust and its unit holders. The Court

also entered findings that full and proper notice of the Lawsuit, the Final Settlement Agreement, and the settlement fairness hearing was provided to all unit holders and that all unit holders were given the opportunity to obtain the related documents and express any objections they may have had regarding the Final Settlement Agreement. The Court considered these unit holder objections in entering the Findings of Fact and Conclusions of Law, and denied all of them.

The initial judgment by the Court was interlocutory, meaning that it was not yet final, because, while the Court found that all unit holders were fully and properly notified of the Final Settlement Agreement and the related hearing, the Court indicated in its Findings of Fact and Conclusions of Law that it did not appear that the Individual Intervenors were provided notice that the motions to strike their petitions in intervention, filed by Pioneer, would be considered by the Court at the same time as the settlement agreement. Therefore, although the Court denied all of the Individual Intervenors' objections to the settlement, the Court also wanted to consider the related motions to strike their petitions in intervention before entering a final judgment in the Lawsuit.

On July 10, 2009, the Trustee mailed a notice to all unit holders of record, announcing that the Termination Threshold had been met and that, in accordance with the Trust Indenture and Final Settlement Agreement, it had instructed Pioneer to sell the oil and gas assets of the Partnership at public auction on August 12, 2009 through The Oil & Gas Asset Clearinghouse. However, given the interlocutory nature of the Court's August 6, 2009 judgment, the settling parties agreed to postpone the public auction until after the Court entered final judgment.

On September 14, 2009, the Court signed its Final Judgment, resolving all parties and all claims in the Lawsuit. This Final Judgment granted the defendants' motion for summary judgment and motion to dismiss claims of Intervenors Keith Wiegand, Robert Miles, Gordon Stamper, Michael Brown, and Benjamin Ginter. Robert Miles non-suited his intervention prior to argument on these motions. The Final Judgment also denied the motion for sanctions filed by Gordon Stamper, and adopted and incorporated the August 6, 2009 Findings of Fact and Conclusions of Law. Thus, there are no longer any issues remaining before the Court, all objections to the Final Settlement Agreement are overruled and denied, all pending petitions in interventions are dismissed, and all related intervenors' claims are dismissed. Additionally, all other claims by parties to the Lawsuit, to the extent not otherwise addressed by the Final Judgment, are dismissed with prejudice. On October 19, 2009, Gordon Stamper filed a petition for writ of mandamus in the Houston Fourteenth Court of Appeals, related to a September 10, 2009 order denying his motion to recuse the Judge presiding over the Lawsuit. The Houston Fourteenth Court of Appeals denied his petition for writ of mandamus in an opinion dated November 3, 2009. Also on November 3, 2009, Gordon Stamper filed a "Motion to Appeal" in the Court, and this Motion was assigned to the Houston Fourteenth Court of Appeals. On December 3, 2009, the Court of Appeals issued a memorandum opinion dismissing the appeal, and the appeal became effective on February 1, 2010.

Given the entry of the Final Judgment, the Trustee directed Pioneer to sell the assets of the Mesa Offshore Royalty Partnership (the "Partnership assets") (along with the Pioneer Settlement Interests), consistent with the terms contained in the Final Settlement Agreement, and as approved by the Court in the Final Judgment, at public auction on November 11, 2009 through The Oil & Gas Asset Clearinghouse. Notice of the public auction was mailed to the unit holders of record at least thirty days before the sale.

At the public auction, the Partnership assets and the assets contributed to the Trust by Pioneer for sale pursuant to its tender letter of October 10, 2008 (hereafter referred to as "Pioneer Settlement

Interests") were offered in two lots: (1) the West Delta 61 Lot; and (2) the Brazos A-39 Lot (together, the "Sales Lots"). There was no right of first refusal as previously considered, and the two lots were offered for sale to the highest bidder(s). The highest bidder for the West Delta 61 Lot was Emerald Energy, with a purchase price of $700,000. The Brazos A-39 Lot, including interests owned by the Partnership and assets contributed to the Trust by Pioneer for sale pursuant to a tender letter, did not receive any bids. Since this liquidation process did not result in the sale of Pioneer's interests in Brazos Block A-39, by letter dated January 11, 2010, Pioneer Natural Resources informed the Trust that Pioneer proposed to its co-working interest owner in the Brazos A-39 #5 well, Woodside, that the well, platform and related facilities should be abandoned pursuant to an operating agreement governing the property. Woodside agreed to this by election dated January 8, 2010. As a result, the Brazos A-39 lease lapsed and reverted to the U.S. government in early March 2010, and all of the interests in the lease held by each of Pioneer, Woodside and the Partnership have been extinguished. Production from the Brazos A-39 #5 well was relied upon to maintain the Brazos A-39 lease, but the well was shut in by a pipeline purchaser on September 2, 2009 because the production does not meet pipeline specifications. The lease expired 180 days after last production. Based on these events, Pioneer had previously informed the Trustee that it was moving forward with the final accounting relating to the termination, liquidation and wind-up of the Partnership in accordance with the Final Settlement Agreement and the Partnership's First Amended and Restated Articles of General Partnership. The Trustee is still awaiting such action by Pioneer in order to move forward to conclude the final termination of the Trust. Pioneer expects to commence that process during the third quarter 2010 pending the availability of the required lift boat needed to do the work.

Based on the sale or abandonment by the Partnership of all of the overriding royalty and other interests conveyed to the Partnership pursuant to the Conveyance, and based on the Settlement Agreement becoming final and non-appealable on February 1, 2010, the Trust terminated at such effective time in accordance with Section 9.02 of the Trust Indenture and with the Settlement Agreement. The Trustee closed the Trust's unit transfer books and no further unit transfers were recognized after the close of business on February 22, 2010, the record date for the Trust's liquidating distributions. Although the Trust cannot control trading, trading of the Trust's common units on the OTC Bulletin Board should have also ceased. There were 71,980,216 units of beneficial interest in the Trust outstanding as of the close of business on February 22, 2010. The Trustee made its first liquidating distribution of approximately $8,373,000 ($0.116328 per unit) on March 24, 2010, to unit holders of record as of February 22, 2010.

The Trustee has held in reserve amounts sufficient to cover estimated expenses associated with the winding up and termination of the Trust. Also, in accordance with the Court's Final Judgment, counsel for the Plaintiffs, together with the 2009 Unit Holder Group, have been awarded total attorneys' fees and expenses of $7,750,000, which the Trustee also paid and deducted on March 24, 2010. In addition, JPMorgan made a payment to the Trust in the amount of $5 million, and released all claims for payment and forgave repayment of all obligations (including principal and accrued and unpaid interest thereon) under the existing $5 million Demand Promissory Note in accordance with the terms of the Final Settlement Agreement effective March 24, 2010. Amounts remaining after the completion of the termination of the Trust, if any, will be paid to unit holders as of the February 22, 2010 record date in one or more final liquidating distributions.

The Trustee will continue to act as Trustee and exercise its powers for the purpose of liquidating and winding up the affairs of the Trust at its termination until its duties have been fully performed and the Trust estate is finally distributed. In accordance with the Trust Indenture, the Trustee will as

promptly as possible distribute the remaining assets in the Trust estate, if any, after paying, satisfying and discharging all of the liabilities of the Trust, or, when necessary, setting up reserves in such amounts as the Trustee in its discretion deems appropriate for contingent liabilities.

The final liquidating distribution to unit holders will be an amount net of funds required to satisfy all Trust liabilities.

Note 3—Going Concern

The accompanying financial statements have been prepared assuming that the Trust will continue as a going concern. The Trust Indenture provides that the Trust will liquidate if the total amount of cash per year received by the Trust falls below certain levels for each of three successive years. As a result of insufficient production on Royalty Properties nearing the end of their estimated productive lives, Royalty income received by the Trust in 2002, 2003, and 2004 fell below the Termination Threshold prescribed by the Trust Indenture. In 2005, the Trustee began procedures to liquidate the Trust assets and during 2009, the remaining properties in which the Trust had an interest were either sold or were in process of being plugged and abandoned.

During the two years ended December 31, 2009, the Trust incurred general and administrative expenses which exceeded Royalty and interest income and its available cash reserves, due to expenses incurred in connection with the ongoing litigation. As such, the Trustee was required to borrow money in accordance with the Trust Indenture to fund Trust expenses. The Trustee entered into a Demand Promissory Note with JPMorgan on September 28, 2007, which was amended on December 3, 2007, for demand loans that may be advanced from time to time in the principal amount of up to $3.0 million. The amendment provided for, among other provisions, an extension of the stated maturity date of the Loans made pursuant to the Demand Promissory Note and the Amended and Restated Note until the earlier of (1) December 31, 2009, (2) 31 days after the Trust's receipt of any settlement proceeds, recovery or judgment in connection with the Lawsuit, (3) final liquidation of the Trust's assets, or (4) the Settlement Agreement was not approved by the Court.

On January 22, 2008, the court in which the lawsuit was pending issued an Order denying the Joint Motion for approval of the Settlement Agreement. According to the terms of the Amended Promissory Note, the note matured on this date as a result of the denial, and all portions of the outstanding principal under this note together with accrued and unpaid interest became due, in full. However, on August 25, 2008, in connection with the execution of the Second Amended and Restated Promissory Note, the definition of "Maturity Date" was amended to delete the test relating to the failure of the Court to approve the prior Settlement Agreement. As a result, the due date of the Demand Promissory Note was not accelerated described above, however, the maturity date remained (1) December 31, 2009, (2) 31 days after the Trust's receipt of settlement proceeds, recovery or judgment in connection with the Lawsuit or (3) final liquidation of the Trust's assets.

On January 28, 2009, the Trustee executed and delivered to JPMorgan a Third Amended and Restated Promissory Note, dated as of January 12, 2009, increasing the principal amount available for borrowing, subject to the terms of such note, to $5 million. As of December 31, 2009, there was outstanding $5.0 million under the Demand Promissory Note together with $480,443 of accrued and unpaid interest expense. The Demand Promissory Note was cancelled effective March 24, 2010. The Trustee has retained reserve amounts deemed by it necessary to cover estimated expenses associated with the winding up and termination of the Trust. Amounts remaining after the completion of the

termination of the Trust, if any, will be paid to unit holders as of the February 22, 2010 record date in one or more final liquidating distributions.

Note 4—Net Overriding Royalty Interest

The instruments conveying the Royalty to the Partnership provide that PNR calculate and pay to the Partnership each month an amount equal to 90% of aggregate net proceeds for the preceding month. Generally, net proceeds means the excess of the amounts received by PNR from sales of its share of oil and gas from the Royalty Properties (gross proceeds) over the operating and capital costs incurred. Costs exceeding gross proceeds for any month are recovered by PNR, with interest thereon at the prime rate of the Bank of America plus one-half percent, out of future gross proceeds prior to making further royalty payments to the Partnership.

Amortization of the Royalty, which is calculated on the basis of current royalty income in relation to estimated future royalty income, is charged directly to trust corpus since such amounts do not affect distributable income.

The Net Overriding Royalty Interest is reviewed for impairment whenever events or changes in circumstances indicate that its carrying amount may not be recoverable. If circumstances require the Net Overriding Royalty Interest to be tested for possible impairment, the Trust first compares undiscounted cash flows expected to be generated by the Net Overriding Royalty Interest to its carrying value. If the carrying value of the Net Overriding Royalty Interest is not recoverable on an undiscounted cash flow basis, an impairment is recognized to the extent that the carrying value exceeds its fair value. The fair value of the Net Overriding Royalty Interest is measured using valuation techniques consistent with the income approach, converting future cash flows to a single discounted amount.

An impairment related to the Net Overriding Royalty was recorded in 2009 as a result of the termination of the Trust and the related sale of the West Delta 61 Lot and abandonment of the Brazos A-39 Lot. The remaining carrying value of the Net Overriding Royalty of $2,937 was written off. This resulted in a full write down of the asset, which was included in the amortization of royalty interest in the Trust Corpus, as this amount does not affect cash earnings.

On March 24, 2010, the Trustee paid an initial liquidating distribution of $0.116238 per unit. The Trustee does not anticipate receiving any additional proceeds related to the Royalty interests.

Note 5—Basis of Presentation

The accompanying unaudited financial information has been prepared by the Trustee in accordance with the instructions to Form 10-Q. JPMorgan was formerly known as The Chase Manhattan Bank and is the successor by mergers to the original name of the Trustee, Texas Commerce Bank National Association. The Trustee believes such information includes all the disclosures necessary to make the information presented not misleading. The information furnished reflects all adjustments which are, in the opinion of the Trustee, necessary for a fair presentation of the results for the interim periods presented. The financial information should be read in conjunction with the financial statements and notes thereto included in the Trust's 2009 Annual Report on Form 10-K.

The financial statements of the Trust are prepared on the following basis:

(a) Royalty income recorded for a month is the Trust's interest in the amount computed and paid by the working interest owner to the Partnership for such month rather than either the value of a portion of the oil and gas produced by the working interest owner for such month or the amount subsequently determined to be 90% of the net proceeds for such month;

(b) Interest income, interest receivable and distributions payable to unit holders include interest to be earned on short-term investments from the financial statement date through the next date of distribution; and

(c) Trust general and administrative expenses, net of reimbursements, are recorded in the month they accrue and are recoupable from Royalty income. Trust expenses payable and the note payable are reported as a reduction in Trust Corpus.

This basis for reporting distributable income is considered to be the most meaningful because distributions to the unit holders for a month are based on net cash receipts for such month. However, it will differ from the basis used for financial statements prepared in accordance with accounting principles generally accepted in the United States because, under such accounting principles, Royalty income for a month would be based on net proceeds from sales for such month without regard to when calculated or received, general and administrative expenses would be recorded in the month they accrue and interest income for a month would be calculated only through the end of such month, and accounting principles generally accepted in the United States would require a liquidation basis of accounting.

The preparation of the financial statements requires estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates. The Trust considers all highly liquid investments with a maturity of three months or less to be cash equivalents. Subsequent events were evaluated through the issuance date of the financial statements.

The instruments conveying the Royalty provide that the working interest owner calculate and pay the Partnership each month an amount equal to 90% of the net proceeds for the preceding month. Generally, net proceeds means the excess of the amounts received by the working interest owner from sales of oil and gas from the Royalty Properties plus other cash receipts over operating and capital costs incurred.

During the first quarter of 2010, the Trust received $81,589 in Royalty income and settlement proceeds of $19,001,230. Such Royalty income and settlement proceeds were used to pay (i) a portion of the first liquidating distribution made during the quarter, (ii) plaintiff fees in accordance with the Final Settlement Agreement, and (iii) other general and administrative expenses. In addition, $2,152,583 of these proceeds were also reserved by the Trustee for estimated future expenses of the Trust, including costs associated with winding up the Trust prior to a final liquidating distribution. During the three months ended March 31, 2010, the Trust had distributable income of $8,373,314.

Below is a summary of general and administrative expenses and the adjustments made to the reserve for Trust expenses:

	Three Months Ended March 31,

	2010		2009
General and administrative costs incurred during the period	$	807,549	$	702,596
Expenses paid by JPMorgan for prior period		—		270,595
(Deductions from) additions to reserve for Trust expenses		2,152,583		111,537
Total expenses paid by JPMorgan during current period		—		(878,518	)
Unpaid trust expenses		—		(93,622	)

General and administrative costs as reported	$	2,960,132	$	112,588

Note 6—JPMorgan Demand Promissory Note

On September 28, 2007, the Trust entered into a Demand Promissory Note agreement with JPMorgan in order to cover portions of its operating expenses. The lender approved an uncommitted line of credit to the Trust in a principal amount not to exceed $3 million. As part of the agreement, JPMorgan agreed to pay the expenses on behalf of the Trust. JPMorgan could decline to fund any request of the Trust for borrowings at anytime, for any reason, including the event that JPMorgan had reason to believe that the Trust would not be able to satisfy its obligation to repay the Demand Loans. Interest on the note was calculated at a rate per annum equal to Prime Rate plus two percent (2%), paid annually. The Demand Promissory Note was secured by a pledge of the Trust Estate, as that term is defined in the Trust Indenture, including without limitation the 99.99% general partnership interest in the Mesa Offshore Royalty Partnership owned by the Trust, pursuant to a Pledge Agreement dated September 29, 2007, as amended by the First Amendment to Pledge Agreement dated as of December 3, 2007, executed by the Trust for the benefit of the Lender. The Trust could borrow amounts under this Note until the earlier of such time as JPMorgan made demand for payment in full or December 31, 2008.

On December 3, 2007, JPMorgan, individually and as lender, entered into an Amended and Restated Promissory Note with the Trust as borrower, to amend the Demand Promissory Note to provide for, among other provisions, an extension of the stated maturity date of the Loans made pursuant to the Demand Promissory Note and the Amended and Restated Note until the earlier of (1) December 31, 2009, (2) 31 days after the Trust's receipt of any settlement proceeds, recovery or judgment in connection with the Lawsuit, (3) final liquidation of the Trust's assets, or (4) the Settlement Agreement was not approved by the Court. Additionally, the amendment provided that the Trust may continue to obtain loans under the note until the maturity date, as long as the amount borrowed did not exceed $3 million and the loan was not in default. The amendment also provided that interest expense shall be due and payable on the maturity date.

On August 25, 2008, the Trustee executed an amended and restated Demand Note that, among other things, increased the aggregate principal amount available for borrowing to $4.0 million and amended the definition of "Maturity Date" to delete the text relating to the failure of the Court to approve the prior Settlement Agreement.

On January 28, 2009, the Trustee executed and delivered to the lender a Third Amended and Restated Promissory Note, dated as of January 12, 2009, increasing the principal amount available for

borrowing, subject to the terms of such note, to $5 million. On January 28, 2009, the Trust and JPMorgan also entered into a Third Amendment to Pledge Agreement, dated as of January 12, 2009, amending the definition of "Collateral" from the Second Amendment to the Pledge Agreement dated June 25, 2008 to include (1) all issued and outstanding general partnership interests by the Trust in the Partnership, together with any cash or property received in exchange or in substitution for such interests (collectively, the "Pledged Assets"), and any distributions received on such Pledged Assets or cash or property received upon any conversion or in exchange for such Pledged Assets; (2) all Additional Collateral (as defined therein) owned by the Trust; (3) all deposit accounts in the name of the Trust; (4) any consideration received or due to the Trust; and (5) all proceeds of any and all of the foregoing.

Interest was payable at a base rate offered by JPMorgan as announced publicly at its principal office as its prime commercial lending rate, plus 2%.

Effective March 24, 2010, JPMorgan released all claims for payment and forgave repayment of all obligations (including principal and accrued and unpaid interest thereon) under the existing Demand Promissory Note in accordance with the terms of the Final Settlement Agreement.

Note 7—Distributions to Unit holders

Under the terms of the Trust Indenture, the Trustee must distribute to the unit holders all cash receipts, after paying liabilities and providing for cash reserves as determined necessary by the Trustee.

The amounts distributed are determined on a monthly basis and are payable to unit holders of record as of the last business day of each month. However, cash distributions are made quarterly in January, April, July and October, and include interest earned from the monthly record dates to the dates of distribution.

On March 24, 2010, the Trustee paid an initial liquidating distribution of $0.116238 per unit. The Trustee does not anticipate receiving any additional proceeds related to the Royalty interests.

Note 8—Federal Income Taxes

The Trustee reports on the basis that the Trust is a grantor trust. Based on its previous audit policy, the Internal Revenue Service (the "IRS") is expected to concur with such action. No IRS ruling has been received or requested with respect to the Trust, however, and no court case has been decided involving identical facts and circumstances. It is possible, therefore, that the IRS would assert upon audit that the Trust is taxable as a corporation and that a court might agree with such assertion.

As a grantor trust, the Trust will incur no federal income tax liability. In addition, it will incur little or no federal income tax liability if it is held to be a non-grantor trust. If the Trust were held to be taxable as a corporation, it would have to pay tax on its net taxable income at the corporate rate. In addition, there is no state tax liability for the period.

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

The following review of the Trust's financial condition and results of operations should be read in conjunction with the financial statements and notes thereto.

Note Regarding Forward-Looking Statements

This Form 10-Q includes "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical facts included in this Form 10-Q, including without limitation the statements under "Management's Discussion and Analysis of Financial Condition and Results of Operations" are forward-looking statements. Although Pioneer has advised the Trust that it believes that the expectations reflected in such forward-looking statements are reasonable, no assurance can be given that such expectations will prove to have been correct. Important factors that could cause actual results to differ materially from expectations ("Cautionary Statements") are disclosed in this Form 10-Q, including, without limitation, in conjunction with the forward-looking statements included in this Form 10-Q and in the Trust's Form 10-K for the year ended 2009, including under Item 1A. "Risk Factors". All subsequent written and oral forward-looking statements attributable to the Trust or persons acting on its behalf are expressly qualified in their entirety by the Cautionary Statements.

Financial Review

The amount of cash distributed by the Trust is dependent on, among other things, the sales prices and quantities of gas, crude oil, condensate and natural gas liquids produced from the Royalty Properties and the quantities sold. Substantial uncertainties exist with regard to future gas and oil prices, which are subject to fluctuations due to the regional supply and demand for natural gas and oil, production levels and other activities of the Organization of the Petroleum Exporting Countries ("OPEC") and other oil and gas producers, weather, storage levels, industrial growth, conservation measures, competition and other variables.

Below is a summary of Royalty income received on the Trust properties for the three months ended March 31, 2010 and 2009:

	Three Months Ended March 31,

	2010			2009
Gross proceeds @ 90%	$	108,137		$	71,789
Operating expenditures @ 90%		(47,987	)		(3,078	)
Expense reserve @ 90%		0			0
Capital expenditures @ 90%		—			—

Net proceeds (deficit)		60,150			68,711
Increase (decrease) in deficit		21,447			0

Net proceeds after deficit recovery(1)		81,597			68,711
Royalty Income (99.99%)	$	81,589		$	112,567

(1): Net proceeds in the amount of $43,867 related to 2008 were not received by the Trust until January 2009; therefore, royalty income was recorded for this amount in the three months ended March 31, 2009.

Below is a summary of distributable income for the three months ended March 31, 2010 and 2009:

	Three Months Ended March 31,

	2010			2009
Royalty income	$	81,589		$	112,567
Settlement proceeds		19,001,230			—
Interest income		627			21
Plaintiff attorney fees		(7,750,000	)		—
General and administrative expenses		(2,960,132	)		(112,588	)

Distributable income	$	8,373,314		$	—
Distributable income per unit	$	.1163		$	—
Accumulated deficit (as of end of period)	$	—		$	—

During the first quarter of 2010, the Trust received $81,589 in Royalty income and settlement proceeds of $19,001,230, compared to only Royalty income of $112,567 during the first quarter of 2009. During the first quarter of 2010, the Trust had distributable income of $8,373,314, compared to no distributable income during the first quarter of 2009. Settlement proceeds of $19,001,230 and Royalty income of $81,589 were used to pay $807,549 of the Trust's general and administrative expenses for the three months ended March 31, 2010.

On September 28, 2007 the Trust entered into a Demand Promissory Note with JPMorgan which was amended on December 3, 2007, August 25, 2008 and January 12, 2009, in which loans were advanced by the lender from time to time not to exceed $5.0 million. This Demand Promissory Note was used to pay any unpaid administrative expenses related to the operation of the Trust. Effective March 24, 2010, JPMorgan released all claims for payment and forgave repayment of all obligations

(including principal and accrued and unpaid interest thereon) under the existing Demand Promissory Note in accordance with the terms of the Final Settlement Agreement. The Trustee has held in reserve amounts sufficient to cover estimated expenses associated with the winding up and termination of the Trust. Amounts remaining after the completion of the termination of the Trust, if any, will be paid to unit holders of record as of February 22, 2010 in one or more liquidating distributions.

Below is a summary of general and administrative expenses and the adjustments made to the reserve for Trust expenses:

	Three Months Ended March 31,

	2010		2009
General and administrative costs incurred during the period	$	807,549	$	702,596
Expenses paid by JPMorgan for prior period		—		270,595
(Deductions from) additions to reserve for Trust expenses		2,152,583		111,537
Total expenses paid by JPMorgan during current period		—		(878,518	)
Unpaid trust expenses		—		(93,622	)

General and administrative costs as reported	$	2,960,132	$	112,588

General and administrative expenses of the Trust incurred during the first quarter of 2010 increased $104,953 to $807,549 as compared to $702,596 for the same period in 2009. The increase in general and administrative expenses in 2010 is primarily due to expenditures related to the Trust's termination.

Operational Review

Below is an operational review of the Brazos A-39 and West Delta 61 properties:

Brazos A-7 and A-39

The Trustee has been informed that Pioneer expects to commence plugging and abandoning of the Partnership's remaining property in the Brazos A-39 Block during the third quarter of 2010 pending the availability of the required lift boat needed to do the work. The Trustee did not receive net proceeds from the Brazos A-39 during the first quarter of 2010. Reference is made to Item 1., Financial Statements, Note 2—Status of Trust, Legal Proceedings and Timing of Liquidation.

West Delta 61 and Other

	Three Months Ended March 31,

	2010			2009
Gross proceeds @ 90%	$	108,137		$	68,420
Operating expenditures @ 90%		(47,987	)		—
Capital expenditures @ 90%		—			—

Net proceeds (deficit)	$	60,150		$	68,420

The West Delta 61 property was sold at public auction on November 11, 2009 through The Oil & Gas Asset Clearinghouse. Reference is made to Item 1., Financial Statements, Note 2—Status of Trust, Legal Proceedings and Timing of Liquidation. The gross proceeds of $108,137 and expenses of $47,987 recognized for the West Delta property during the first quarter of 2010 represent proceeds and expenditures for the production period from July 2009 to November 2009.

Capital Expenditures

PNR does not anticipate any future capital expenditures on the Royalty Properties other than plugging and abandonment costs for which the Trust has no direct liability.

Termination of the Trust

Pursuant to the Final Settlement Agreement described below, the Trustee directed the sale or other final disposition of the properties owned by the Partnership as part of the termination and liquidation of the Trust. As part of the liquidation and termination of the Trust, the Trustee set February 22, 2010 as the record date for unit holders entitled to payments of any final liquidating distributions. The Trustee also announced, and on March 24, 2010 paid, an initial liquidating distribution of $0.116238 per unit. The Trustee will make one or more final liquidating distributions to unit holders of any funds remaining after all Trust liabilities have been satisfied.

Assets and Liabilities in the Process of Liquidation

As a result of the triggering of the Termination Threshold effective January 1, 2005, the Trust is in the process of terminating and winding up. Reference is made to Item 1., Financial Statements, Note 2—Status of Trust, Legal Proceedings and Timing of Liquidation. As of March 31, 2010, the Trust's only remaining asset is a cash balance of $2,454,747.

Liquidity and Capital Resources

Historically, the Trust's primary sources of liquidity have been the Royalty income received from the Partnership's share of the net proceeds from the Royalty Properties and borrowings under the Demand Promissory Note. Reference is made to Note 9 in the Notes to Financial Statement included in the Form 10-K for the year ended December 31, 2009 and Note 6 in the Notes to Financial Statements contained in Part I, Item 1 herein. However, as a result of triggering the Termination Threshold effective January 1, 2005, the Trust is in the process of terminating and winding up. At a public auction held on November 11, 2009 through The Oil & Gas Asset Clearinghouse, the West Delta 61 property was sold to the highest bidder, Emerald Energy, with a purchase price of $700,000. The Brazos A-39 property, including interests owned by the Partnership and assets contributed to the Trust by Pioneer for sale pursuant to a tender letter, did not receive any bids. Pioneer has informed the Trustee that it expects to commence plugging and abandonment of the Brazos A-39 property during the third quarter of 2010 pending the availability of the required lift boat needed to do the work. As a result of the termination of the Trust and the related sale of the West Delta 61 Lot and abandonment

of the Brazos A-39 Lot, the Trustee does not anticipate receiving any additional proceeds from the Royalty interests and, therefore, does not anticipate that the Trust will make any additional distributions to unit holders prior to one or more final liquidating distributions.

As part of the liquidation and termination of the Trust, the Trustee set February 22, 2010 as the record date for unit holders entitled to payments of any final liquidating distributions. The Trustee also announced, and on March 24, 2010 paid, an initial liquidating distribution of $0.116238 per unit. The Trustee will make one or more final liquidating distributions to unit holders of any funds remaining after all Trust liabilities have been satisfied.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures. The Trustee maintains disclosure controls and procedures designed to ensure that information required to be disclosed by the Trust in the reports that it files or submits under the Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and regulations. Disclosure controls and procedures include controls and procedures designed to ensure that information required to be disclosed by the Trust is accumulated and communicated by PNR, as the managing general partner of the Partnership, and the working interest owners to JPMorgan, as Trustee of the Trust, and its employees who participate in the preparation of the Trust's periodic reports as appropriate to allow timely decisions regarding required disclosure.

As of the end of the period covered by this report, the trust officer acting on behalf of the Trustee responsible for the administration of the Trust conducted an evaluation of the Trust's disclosure controls and procedures. The officer acting on behalf of the Trustee concluded that the Trust's controls and procedures are effective.

Due to the contractual arrangements of (i) the Trust Indenture, (ii) the Partnership Agreement and (iii) the rights of the Partnership under the Conveyance regarding information furnished by the working interest owners, the Trustee relies on: (A) information provided by the working interest owners, including (i) the status of litigation, (ii) historical operating data, plans for future operating and capital expenditures, reserve information, as well as (iii) information relating to projected production; (B) information provided by the managing general partner of the Partnership that is collected by the managing general partner from the working interest owners; and (C) conclusions regarding reserves by reserve engineers or other experts in good faith. See Item 1A. Risk Factors "—The Trustee relies upon the working interest owners and managing general partner for information regarding the Royalty Properties" in the Trust's Annual Report on Form 10-K for the year ended 2009 for a description of certain risks relating to these arrangements and reliance.

Changes in Internal Control over Financial Reporting. In connection with the evaluation by the Trustee of changes in internal control over financial reporting of the Trust that occurred during the Trust's last fiscal quarter, no change in the Trust's internal control over financial reporting was identified that has materially affected, or is reasonably likely to materially affect, the Trust's internal control over financial reporting. The Trustee notes for purposes of clarification that it has no authority over, has not evaluated and makes no statement concerning, the internal control over financial reporting of the working interest owners or the managing general partner of the Partnership.

PART II

Item 1. Legal Proceedings.

Please read Note 2 to the Notes to Financial Statements contained in Item I, Part 1 contained herein.

Item 1A. Risk Factors.

There have not been any material changes from the risk factors previously disclosued in Item 1A to Part I of the Trust's Annual Report on Form 10-K for the year ended December 31, 2009.

Item 6. Exhibits

(Asterisk indicates exhibit previously filed with the Securities and Exchange Commission and incorporated herein by reference. JPMorgan was formerly known as The Chase Manhattan Bank and is successor by mergers to the original name of the Trustee, Texas Commerce Bank National Association).

				Exhibit Number

4	(a)*	Mesa Offshore Trust Indenture between Mesa Petroleum Co. and Texas Commerce Bank National Association, as Trustee, dated December 15, 1982	2-79673	10(gg)
4	(b)*	Overriding Royalty Conveyance between Mesa Petroleum Co. and Mesa Offshore Royalty Partnership, dated December 15, 1982	2-79673	10(hh)
4	(c)*	Partnership Agreement between Mesa Offshore Management Co. and Texas Commerce Bank National Association, as Trustee, dated December 15, 1982	2-79673	10(ii)
4	(d)*	Amendment to Partnership Agreement between Mesa Offshore Management Co., Texas Commerce Bank National Association, as Trustee, and Mesa Operating Limited Partnership, dated December 27, 1985 (Exhibit 4(d) to Form 10-K for year ended December 31, 1992 of Mesa Offshore Trust)	1-8432	4(d)
4	(e)*	Amendment to Partnership Agreement between Texas Commerce Bank National Association, as Trustee and Mesa Operating dated as of January 5, 1994 (Exhibit 4(e) to Form 10-K for year ended December 31, 1993 of Mesa Offshore Trust)	1-8432	4(e)
31		Certification furnished pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32		Certification furnished pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.


	MESA OFFSHORE TRUST
	By:	/s/ JPMORGAN CHASE BANK, N.A., as Trustee
	By:	/s/ MIKE ULRICH Mike Ulrich Vice President The Bank of New York Trust Company, N.A., as attorney-in-fact for the Trustee
Date: May 17, 2010

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

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PART I—FINANCIAL INFORMATION

Item 1. Financial Statements.

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

Item 4. Controls and Procedures.

PART II

Item 1. Legal Proceedings.

Item 1A. Risk Factors.

Item 6. Exhibits

SIGNATURES

MESA OFFSHORE TRUST 10-Q