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, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

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

As of May 15, 2018—1,863,590 Units of Beneficial Interest were outstanding in Mesa Royalty Trust.

This Form 10-Q includes "forward-looking statements" about Mesa Royalty Trust (the "Trust") and other matters discussed herein that are subject to risks and uncertainties that are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995 and Section 21E of the Securities Exchange Act of 1934, as amended (the "Exchange Act"). All statements other than statements of historical fact included in this document, including, without limitation, statements under "Trustee's Discussion and Analysis of Financial Condition and Results of Operations," including the Trust's or any Working Interest Owner's (as defined in "Note 1—Trust Organization and Provisions") future financial position, status in any insolvency proceeding, business strategy, budgets, projected costs and plans and objectives for future operations, information regarding target distributions, statements pertaining to future development activities and costs, statements regarding the number of development wells to be completed in future periods, and information regarding production and reserve growth, are forward-looking statements. Actual outcomes and results may differ materially from those projected. Forward-looking statements are generally accompanied by words such as "estimate," "project," "predict," "believe," "expect," "anticipate," "potential," "could," "may," "can," "foresee," "plan," "goal," "assume," "target," "should," "intend" or other words that convey the uncertainty of future events or outcomes. These statements are based on certain assumptions made by the Trust in light of its experience and perception of historical trends, current conditions and expected future developments, as well as other factors we believe are appropriate under the circumstances. The Trustee (as defined herein) relies on the Working Interest Owners for information regarding the Subject Interests (as defined in "Note 1—Trust Organization and Provisions"), the Royalty (as defined in "Note 1—Trust Organization and Provisions"), and the Working Interest Owners themselves.

Although the Working Interest Owners have advised the Trust that they believe that the expectations reflected in the forward-looking statements contained herein are reasonable, no assurance can be given that such expectations will prove to be correct. However, whether actual results and developments will conform with such expectations and predictions is subject to a number of risks and uncertainties, including the risk factors discussed in Item 1A of Part I of the Trust's Annual Report on Form 10-K for the year ended December 31, 2017, and those set forth from time to time in the Trust's filings with the Securities and Exchange Commission (the "SEC"), which could affect the future results of the energy industry in general, and the Trust and Working Interest Owners in particular, and could cause those results to differ materially from those expressed in such forward-looking statements. The actual results or developments anticipated may not be realized or, even if substantially realized, they may not have the expected consequences to or effects on the Working Interest Owners' businesses and the Trust. Such statements are not guarantees of future performance and actual results or developments may differ materially from those projected in such forward-looking statements. The Trust undertakes no obligation to publicly update or revise any forward-looking statements, except as required by applicable law.

	March 31, 2018			December 31, 2017

	(Unaudited)
ASSETS
Cash and short-term investments	$	1,755,089		$	1,801,613
Net overriding royalty interest in oil and gas properties		42,498,034			42,498,034
Accumulated amortization		(40,590,364	)		(40,519,773	)

Total assets	$	3,662,759		$	3,779,874



LIABILITIES AND TRUST CORPUS
Distributions payable	$	699,364		$	681,942
Trust corpus (1,863,590 units of beneficial interest authorized, issued and outstanding)		2,963,395			3,097,932

Total liabilities and trust corpus	$	3,662,759		$	3,779,874

The Trust, created under the laws of the State of Texas, maintains its offices at the office of the Trustee, The Bank of New York Mellon Trust Company, N.A., (the "Trustee"), 601 Travis Street, Floor 16, Houston, Texas 77002. The telephone number of the Trust is 713-483-6020. The Bank of New York Mellon Trust Company, N.A., is the successor Trustee from JPMorgan Chase Bank, N.A., which is the successor by mergers to the originally named Trustee, Texas Commerce Bank National Association. The Trust has no employees. Administrative functions of the Trust are performed by the Trustee. The Trustee maintains a website for the Trust that makes available, free of charge, filings by the Trust with the Securities and Exchange Commission ("SEC") and other information. Any reports filed with the SEC are accessible through our website as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. The Trust's website is http://mtr.investorhq.businesswire.com/.

Trust Corpus Description. The Mesa Royalty Trust (the "Trust") was created on November 1, 1979, and is now governed by the Mesa Royalty Trust Indenture (as amended, the "Trust Indenture"). Through a series of conveyances, assignments, and acquisitions, the Trust currently owns an overriding royalty interest (the "Royalty") equal to 11.44% of 90% of the Net Proceeds (as defined in the Conveyance and described below) attributable to the specified interest in certain producing oil and gas properties located in the:

Trust Corpus Conveyance History. On November 1, 1979, Mesa Petroleum Co., predecessor to Mesa Limited Partnership ("MLP"), which was the predecessor to MESA Inc., conveyed to the Trust the Royalty equal to 90% of the Net Proceeds (as defined in the Conveyance and described below) attributable to the specified interests in properties conveyed by the assignor on that date (the "Subject Interests"). The Subject Interests consisted of interests in the Royalty Properties described above. The Royalty is evidenced by counterparts of an Overriding Royalty Conveyance, dated as of November 1, 1979 (the "Conveyance"). In 1985, the Trust Indenture was amended and the Trust conveyed to an affiliate of Mesa Petroleum Co. 88.5571% of the original Royalty (such transfer, the "1985 Assignment"). The effect of the 1985 Assignment was an overall reduction of approximately 88.56% in the size of the Trust. As a result, the Trust is now entitled to receive 11.44% of 90% of the Net Proceeds attributable to each month.

Hugoton Royalty Properties. Until August 7, 1997, MESA Inc. operated the Hugoton Royalty Properties through Mesa Operating Co., a wholly owned subsidiary of MESA Inc. On August 7, 1997, MESA Inc. merged with and into Pioneer Natural Resources Company ("Pioneer"), formerly a wholly owned subsidiary of MESA Inc., and Parker & Parsley Petroleum Company merged with and into Pioneer Natural Resources USA, Inc. (successor to Mesa Operating Co.), a wholly owned subsidiary of Pioneer ("PNR") (collectively, the mergers are referred to herein as the "Merger"). Subsequent to the Merger, the Hugoton Royalty Properties were operated by PNR until December 31, 2014, at which point Linn Energy Holdings, LLC, a subsidiary of Linn Energy, LLC ("Old Linn") took over as operator. Pursuant to the bankruptcy proceedings and court-approved plans of reorganization involving Old Linn, which are described in detail below, Linn Energy, Inc. (together with its subsidiaries, "Linn") became the operator of the Hugoton Royalty Properties on February 28, 2017. Linn currently operates the Hugoton Royalty Properties. On April 18, 2018, Linn announced its Board of Directors' decision to separate Linn into two stand-alone public companies, which is expected to take place during the third quarter of 2018. The Trustee is in discussions with Linn regarding the impact of the separation plan.

San Juan Basin—Colorado Properties. On April 30, 1991, MLP sold to Conoco, Inc. ("ConocoPhillips") its interests in the San Juan Basin Royalty Properties (the "San Juan Basin Sale"). The Trust's interest in the San Juan Basin Royalty Properties was conveyed from PNR's working interest in 31,328 net producing acres in northwestern New Mexico and southwestern Colorado. ConocoPhillips sold the portion of its interests in the San Juan Basin—Colorado Properties to MarkWest Energy Partners, Ltd. (effective January 1, 1993) and Red Willow Production Company ("Red Willow") (effective April 1, 1992). On October 26, 1994, MarkWest Energy Partners, Ltd. sold substantially all of its interest in the San Juan Basin—Colorado Properties to BP Amoco Company ("BP"), a subsidiary of BP p.l.c. BP and Red Willow currently operate the San Juan Basin—Colorado Properties.

San Juan Basin—New Mexico Properties. Starting from the date of the San Juan Basin Sale and ending on July 31, 2017, ConocoPhillips operated substantially all of the San Juan Basin—New Mexico Properties, except an immaterial number of properties assigned to XTO Energy, Inc. ("XTO") effective January 1, 2005. On July 31, 2017, ConocoPhillips sold its San Juan Basin assets to Hilcorp San Juan LP ("Hilcorp"), an affiliate of Hilcorp Energy Company. Hilcorp currently operates the San Juan Basin—New Mexico Properties. Effective September 2017, following Hilcorp's acquisition of Conoco's interests in the San Juan—New Mexico Properties, Hilcorp continued to make an estimated payment of Net Proceeds to the Trust each month consistent with the monthly amount previously paid by ConocoPhillips. These estimated payments remain subject to reconciliation with respect to actual revenue, costs and net proceeds and the effects of pricing during the months after Hilcorp has completed its transition as owner of the San Juan—New Mexico Properties. The reconciliation and true-up of the estimated payments for this transition period may affect the Trust's future receipt of Net Proceeds from Hilcorp.

As used in this report, Linn refers to the current operator of the Hugoton Royalty Properties, Hilcorp refers to the current operator of the San Juan Basin—New Mexico Properties, and BP and Red Willow refers to the current co-operators of certain tracts of land included in the San Juan Basin—Colorado Properties, unless otherwise indicated. The Royalty Properties are required to be operated by the Working Interest Owners (as defined below) in accordance with reasonable and prudent business judgment and good oil and gas field practices. Each Working Interest Owner has the right to abandon any well or lease if, in its opinion, such well or lease ceases to produce or is not capable of producing oil, gas or other minerals in commercial quantities. Each Working Interest Owner markets the production on terms deemed by it to be the best reasonably obtainable in the circumstances. See "Contracts" under Part I, Item 1 of the Trust's Annual Report on Form 10-K for the year ended December 31, 2017.

The Trustee has no power or authority to exercise any control over the operation of the Royalty Properties or the marketing of production therefrom.

Trustee and Terms of Trust Indenture. Effective October 2, 2006, the Trustee succeeded JP Morgan Chase Bank, N.A. as Trustee of the Trust. The Trust is a passive entity whose purposes are limited to: (1) converting the Royalty to cash, either by retaining it and collecting the proceeds of production (until production has ceased or the Royalty is otherwise terminated) or by selling or otherwise disposing of the Royalties; and (2) distributing such cash, net of amounts for payments of liabilities to the Trust, to the unitholders. The Trust has no sources of liquidity or capital resources other than the revenues, if any, attributable to the Royalties and interest on cash held by the Trustee as a reserve for liabilities or for distribution. The terms of the Trust Indenture provide, among other things, that:

Trustee's Fees. Pursuant to the Trust Indenture, the Trust pays the Trustee fees for its services each quarter and the Working Interest Owners partially reimburse the Trust for the fees paid in connection with the Trustee's services. The net amount of these reimbursements is included in the general and administrative expenses of the Trust. For the quarter ended March 31, 2018, the Trustee was due $118,750 for its services. The Trust paid $108,288 of this amount to the Trustee, and $10,462 was allocated to offset against interest due to the Trust under the Trust Indenture. The Trust Indenture requires that cash being held by the Trustee earn interest at 1.5% below the prime rate, which would have yielded the Trust a 3.00% annualized return from January 1, 2018 through March 21, 2018 and a 3.25% annualized return from March 22, 2018 through March 31, 2018. However, due to the current interest rate environment, the Trustee was unable to obtain an account in which such an interest rate was available. In the event such an interest rate is unavailable in the future, the Trustee intends to allocate certain of its fees due to the Trust to meet the minimum interest rate payable under the Trust Indenture. In future periods the Trustee will continue to allocate a portion of the fees earned for its services to the Trust until the remaining $11,568 of interest due to the Trust is fully offset.

The Working Interest Owners partially reimburse the Trust each quarter for amounts paid in connection with the Trustee's services. For the quarter ended March 31, 2018, the Trustee's fees were $108,288 and the Working Interest Owners reimbursed a sum of $95,897 to the Trustee, which was the same amount reimbursed for the quarter ended March 31, 2017.

Linn Energy, LLC Reorganization. On May 11, 2016, Old Linn, LinnCo, LLC ("LinnCo"), an affiliate of Old Linn, and certain of Old Linn's direct and indirect subsidiaries (collectively with Old Linn and LinnCo, the "Debtors"), filed voluntary petitions for reorganization under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court for the Southern District of Texas (the "Court"). The Debtors' Chapter 11 cases were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16-60040.

On January 27, 2017, the Court entered the Order Confirming (I) Amended Joint Chapter 11 Plan of Reorganization of Linn Energy, LLC and its Debtor Affiliates Other Than Linn Acquisition Company, LLC and Berry Petroleum Company, LLC and (II) Amended Joint Chapter 11 Plan of Reorganization of Linn Acquisition Company, LLC and Berry Petroleum Company, LLC, which approved and confirmed the Amended Joint Chapter 11 Plan of Reorganization of Linn Energy, LLC and Its Debtor Affiliates Other Than Linn Acquisition Company, LLC and Berry Petroleum Company, LLC (the "Plan"). The Plan became effective on February 28, 2017 (the "Effective Date").

Pursuant to the Plan, on the Effective Date, all assets of Old Linn (other than equity interests in Linn Acquisition Company, LLC and Berry Petroleum Company, LLC) were conveyed to Linn

Energy, Inc. (or a subsidiary thereof), and LinnCo, LLC and Linn Energy, LLC were wound down and liquidated. Subsequent to the effectiveness of the Plan, Linn is now the reorganized successor to Old Linn. Under the Plan Supplement, as amended, filed with the Court, the Debtors assumed all executory contracts and unexpired leases with the Trust and Mesa Operating Limited Partnership as the counterparty. Furthermore, pursuant to the Plan, the royalty interests in the Hugoton Royalty Properties owned by the Trust shall be preserved and remain in full force and effect in accordance with the terms of the granting instruments or other governing documents.

Discussion of Net Proceeds. The Conveyance provides for a monthly computation of Net Proceeds. Net Proceeds is defined in the Conveyance as the "Gross Proceeds" received by the Working Interest Owners during a particular period, minus certain production and capital costs for such period. "Gross Proceeds" is defined in the Conveyance as the amount received by the Working Interest Owners from the sale of "Subject Minerals", subject to certain adjustments. "Subject Minerals" means all oil, gas and other minerals, whether similar or dissimilar, in and under, and which may be produced, saved and sold from, and which accrue and are attributable to, the Subject Interests from and after November 1, 1979. "Production costs" means, generally, costs incurred on an accrual basis by the Working Interest Owners in operating the Royalty Properties, including capital and non-capital costs. If production and capital costs exceed Gross Proceeds for any month, the excess, plus interest thereon at 120% of the prime rate of Bank of America, is recovered out of future Gross Proceeds prior to the making of further payment to the Trust. The Trust, however, is generally not liable for any operating costs or other costs or liabilities attributable to the Royalty Properties or minerals produced therefrom. The Trust is not obligated to return any Royalty income received in any period.

The Working Interest Owners are required to maintain books and records sufficient to determine the amounts payable under the Royalty. Additionally, in the event of a controversy between a Working Interest Owner and any purchaser as to the correct sales price for any production, amounts received by such Working Interest Owner and promptly deposited by it with an escrow agent are not considered to have been received by such Working Interest Owner, and, therefore, are not subject to being payable with respect to the Royalty until the controversy is resolved; but all amounts thereafter paid to such Working Interest Owner by the escrow agent will be considered amounts received from the sale of production. Similarly, operating costs include any amounts a Working Interest Owner is required to pay whether as a refund, interest or penalty to any purchaser because the amount initially received by such Working Interest Owner as the sales price was in excess of that permitted by the terms of any applicable contract, statute, regulation, order, decree or other obligation. Within 30 days following the close of each calendar quarter, the Working Interest Owners are required to deliver to the Trustee a statement of the computation of Net Proceeds attributable to such quarter.

The brief discussions of the Trust Indenture and the Conveyance contained herein are qualified in their entirety by reference to the Trust Indenture and the Conveyance themselves, which are exhibits to

the Trust's Annual Report on Form 10-K for the year ended December 31, 2017 and are available upon request from the Trustee.

The accompanying unaudited financial information has been prepared by the Trustee in accordance with the instructions to Form 10-Q. The preparation of the financial statements requires estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent liabilities at the date of the financial statements and the reported amounts of income and expenses during the reporting period. Actual results could differ from those estimates. 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 Annual Report on Form 10-K for the year ended December 31, 2017. 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.

In accordance with the Conveyance, the Working Interest Owners are obligated to calculate and pay the Trust each month an amount equal to 90% of the Net Proceeds (as defined in the Conveyance) attributable to the month.

This basis for reporting distributable income is considered to be the most meaningful because distributions to the unitholders for a month are based on net cash receipts for such month. However, these statements differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America because, under such principles, royalty income for a month would be based on net proceeds from production 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.

There are no pending legal proceedings to which the Trust is a named party. The Trustee has been advised by Linn, Hilcorp, and BP that the Trust may be subject to litigation in the ordinary course of business for certain matters that include the Royalty Properties. While each of the Working Interest Owners has advised the Trustee that it does not currently believe any of the pending litigation will have a material adverse effect net to the Trust, in the event such matters were adjudicated or settled in a material amount and charges were made against Royalty income, such charges could have a material impact on future Royalty income.

In a technical advice memorandum dated February 26, 1982, the Internal Revenue Service (the "IRS") advised the Dallas District Director that the Trust is classifiable as a grantor trust and not as an association taxable as a corporation. As a grantor trust, the Trust incurs no federal income tax liability and each unitholder is subject to tax on the unitholder's pro rata share of the income and expense of the Trust as if the unitholder were the direct owner of a pro rata share of the Trust's assets. In addition, there is no state tax liability for the period.

The U.S. Tax Cuts and Job Act (the "2017 Tax Act") was enacted on December 22, 2017. The 2017 Tax Act is comprehensive legislation that contains substantial changes to U.S. taxation. The Trust does not expect the new tax law to have any significant impact due to the Trust being classified as a grantor trust for U.S. income tax purposes. However, unitholders should consult with their personal tax advisors to determine how the 2017 Tax Act impacts any items of income or deduction received from the Trust.

For taxable years beginning after December 31, 2012, individuals, estates, and trusts with income above certain thresholds are subject under Section 1411 of the Internal Revenue Code to an additional 3.8% tax—also known as the "net investment income tax"—on their net investment income. Grantor trusts such as the Trust are not subject to the 3.8% tax; however, the unitholders may be subject to the

tax. For these purposes, investment income would generally include certain income derived from investments, such as the royalty income derived from the units and gain realized by a unitholder from a sale of units.

The Trustee assumes that some Trust units are held by a middleman, 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 street name). Therefore, the Trustee considers the Trust to be a non-mortgage widely held fixed investment trust ("WHFIT") for U.S. federal income tax purposes. The Bank of New York Mellon Trust Company, N.A., 601 Travis Street, Floor 16, Houston, Texas 77002, telephone number 713-483-6020, 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 units on behalf of unitholders, and not the Trustee of the Trust, are solely responsible for complying with the information reporting requirements under the Treasury Regulations with respect to such units, including the issuance of IRS Forms 1099 and certain written tax statements. Unitholders whose 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 units.

Excess production costs result when costs, charges, and expenses attributable to a working interest property exceed the revenue received from the sale of oil, gas, and other hydrocarbons produced from such property. The excess production costs must be recovered by the Working Interest Owners before any distribution of Royalty income from the properties will be made to the Trust. Red Willow made a $147 distribution to the Trust during the first quarter of 2017 without recovering the excess production costs. The $147 distribution was returned to Red Willow in the second quarter of 2017.

During 2011, the Trustee, acting pursuant to the Trust Indenture, withheld $1.0 million for future unknown contingent liabilities and expenses (such cumulative withholding being the "Contingent

Reserve"). The Trustee reserves the right to determine whether or not to release cash reserves in future periods with respect to any reimbursement expenses. At any given time, the Contingent Reserve is included in cash and short term investments.

For the three months ended March 31, 2018, the Trustee increased the Contingent Reserve by $55,725 of royalty income received from BP in March 2018 after the distribution to unitholders had been announced for the month of March 2018, which royalty income was included in the April 2018 distribution to unitholders. For the three months ended March 31, 2018, the Trustee decreased the Contingent Reserve by (1) $49,211 of royalty income received from BP in December 2017 after the distribution to unitholders had been announced for the month of December 2017, which royalty income was included in the January 2018 distribution to unitholders and (2) $70,460 of December 2017 expenses that were included in the distribution calculation for December 2017, but not paid by the Trust until January 2018.

As of March 31, 2018, the value of the Contingent Reserve was $1,055,725, which is included in cash and short-term investments. The effect on distributable income per unit of adjustments to the Contingent Reserve is as follows:

	Three Months Ended March 31,

	2018			2017
Distributable Income Before Reserve for Contingent Liabilities and Expenses	$	635,418		$	871,646
Increase in the Contingent Reserve		(55,725	)		(82,244	)
Withdrawal from the Contingent Reserve		119,671			—

Distributable income Available for Distribution	$	699,364		$	789,402



Distributable income Available for Distribution per unit	$	0.3753		$	0.4236



Units outstanding		1,863,590			1,863,590

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

The following review of Mesa Royalty Trust's (the "Trust") financial condition and results of operations should be read in conjunction with the financial statements and notes thereto. The discussion of net production attributable to the Hugoton and San Juan Basin Royalty Properties (as each is defined below) represents production volumes that are to a large extent hypothetical as the Trust does not own and is not entitled to any specific production volumes. Any discussion of "actual" production volumes represents the hydrocarbons that were produced from the properties in which the Trust has an overriding royalty interest.

The Trust was created on November 1, 1979, and is now governed by the Mesa Royalty Trust Indenture (as amended, the "Trust Indenture"). Through a series of conveyances, assignments, and acquisitions, the Trust currently owns an overriding royalty interest (the "Royalty") equal to 11.44% of 90% of the Net Proceeds (as defined and described in an Overriding Royalty Conveyance dated as of November 1, 1979 (the "Conveyance")) attributable to the specified interest in certain producing oil and gas properties located in the:

Pursuant to past conveyances and bankruptcy proceedings, Linn Energy, Inc.("Linn"), Hilcorp San Juan LP ("Hilcorp"), XTO Energy, Inc. ("XTO"), BP Amoco Company ("BP"), and Red Willow Production Company ("Red Willow") are the operators of certain portions of the Hugoton Royalty Properties and San Juan Basin Royalty Properties (each of Linn, Hilcorp, XTO, BP, and Red Willow being a "Working Interest Owner", and together, the "Working Interest Owners"). As used in this report, Linn refers to the current operator of the Hugoton Royalty Properties, Hilcorp refers to the current operator of the San Juan Basin—New Mexico Properties, and BP and Red Willow refers to the currents co-operators of certain tracts of land included in the San Juan Basin—Colorado Properties, unless otherwise indicated.

Any discussion of "actual" production volumes represents the hydrocarbons that were produced from the properties in which the Trust has an overriding royalty interest. See Note 7 to the financial statements in the Trust's Annual Report on Form 10-K for the year ended December 31, 2017.

The Trust is a passive entity whose purposes are limited to: (1) converting the Royalties to cash, either by retaining them and collecting the proceeds of production (until production has ceased or the Royalties are otherwise terminated) or by selling or otherwise disposing of the Royalties; and (2) distributing such cash, net of amounts for payments of liabilities to the Trust, to the unitholders. The Trust has no sources of liquidity or capital resources other than the revenues, if any, attributable to the Royalties and interest on cash held by the Trustee as a reserve for liabilities or for distribution. The Trust does not undertake or control any capital projects or make capital expenditures. While the Trust's Royalty income is net of capital expenditures, these capital expenditures are controlled and paid by the Working Interests Owners, and the Trust receives Royalty income net of these expenses. In addition, the Trust does not have any off-balance sheet arrangements or other contingent obligations.

This Form 10-Q includes "forward-looking statements" about the Trust and other matters discussed herein that are subject to risks and uncertainties that are intended to qualify for the safe harbor from liability established by the Private Securities Litigation Reform Act of 1995 and Section 21E of the Securities Exchange Act of 1934, as amended. All statements other than statements of historical fact included in this document, including, without limitation, statements under "Trustee's Discussion and Analysis of Financial Condition and Results of Operations," including the Trust's or any Working Interest Owner's future financial position, status in any insolvency proceeding, business strategy, budgets, projected costs and plans and objectives for future operations, information regarding target distributions, statements pertaining to future development activities and costs, statements regarding the number of development wells to be completed in future periods, and information regarding production and reserve growth, are forward-looking statements. Actual outcomes and results may differ materially from those projected. Forward-looking statements are generally accompanied by words such as "estimate," "project," "predict," "believe," "expect," "anticipate," "potential," "could," "may," "can," "foresee," "plan," "goal," "assume," "target," "should," "intend" or other words that convey the uncertainty of future events or outcomes. These statements are based on certain assumptions made by the Trust in light of its experience and perception of historical trends, current conditions and expected future developments, as well as other factors we believe are appropriate under the circumstances. The Trustee relies on the Working Interest Owners for information regarding the Subject Interests (as defined herein in "Note 1—Trust Organization and Provisions"), the Royalty, and the Working Interest Owners themselves.

Royalty income is computed after deducting the Trust's proportionate share of capital costs, operating costs and interest on any cost carryforward from the Trust's proportionate share of "Gross Proceeds," as defined in the Conveyance. The following summary illustrates the net effect of the components of the actual Royalty computation for the periods indicated.

	Three Months Ended March 31,

	2018									2017
	Natural Gas			Natural Gas Liquids			Oil and Condensate			Natural Gas			Natural Gas Liquids			Oil and Condensate
The Trust's proportionate share of Gross Proceeds(1)(5)	$	881,118		$	328,695		$	6,075		$	990,241		$	264,054		$	11,447
Less the Trust's proportionate share of:
Capital costs recovered		(2,854	)		(1,352	)		(23	)		(3,950	)		(1,420	)		(88	)
Operating costs		(321,243	)		(135,955	)		(2,288	)		(258,061	)		(76,403	)		(4,865	)

Net proceeds(2)	$	557,021		$	191,388		$	3,764		$	728,230		$	186,231		$	6,494



Royalty income(2)	$	552,703		$	191,166		$	3,749		$	725,773		$	186,272		$	6,494



Average sales price	$	2.23		$	20.67		$	37.58		$	2.69		$	19.40		$	37.45



Average production costs(3)	$	1.31		$	14.84		$	23.16		$	0.97		$	8.11		$	28.56

(1): Gross Proceeds from natural gas liquids attributable to each of the Hugoton and San Juan Basin Royalty Properties are net of a volumetric in-kind processing fee retained by Linn and Hilcorp, respectively.
(2): Royalty income is computed after deducting the Trust's proportionate share of capital costs, operating costs and interest on any cost carryforward from the Trust's proportionate share of Gross Proceeds. As a result of excess production costs incurred in one monthly operating period and then recovered in a subsequent monthly operating period, the Royalty income paid to the Trust may not agree to the Trust's royalty interest in the Net Proceeds (as defined in the Conveyance). The excess production costs must be recovered by the Working Interest Owners before any distribution of Royalty income will be made to the Trust.

San Juan Basin—New Mexico Properties. Excess production costs in the amount of $5,529 and $3,735 as of March 31, 2018 and 2017, respectively, were related to the San Juan Basin—New Mexico Properties operated by XTO. The Trust recovered prior period excess production costs of $541 related to the San Juan Basin—Colorado Properties operated by XTO during the

three months ended March 31, 2018. Excess production costs related to the San Juan Basin—New Mexico Properties operated by XTO were approximately $144 for the three months ended March 31, 2017.

San Juan Basin—Colorado Properties. Excess production costs related to the San Juan Basin—Colorado Properties operated by BP and Red Willow were approximately $0 and $11,929, respectively, as of March 31, 2018. Excess production costs related to the San Juan Basin—Colorado Properties operated by BP and Red Willow were approximately $0 and $13,832, respectively as of March 31, 2017.

Excess production costs related to the San Juan Basin—Colorado Properties operated by BP were approximately $0 and $0 for the three months ended March 31, 2018 and 2017, respectively. The Trust recovered prior period excess production costs of $4,015 related to the San Juan Basin—Colorado Properties operated by Red Willow during the quarter ended March 31, 2018. Excess production costs related to the San Juan Basin—Colorado Properties operated by Red Willow were approximately $1,300 for the three months ended March 31, 2017. The Trust recovered prior period excess production costs of $3,860 related to the San Juan Basin—Colorado properties operated by BP during the quarter ended March 31, 2017. Red Willow made a $147 distribution to the Trust during the first quarter of 2017 without recovering the excess production costs. The $147 distribution was returned to Red Willow in the second quarter of 2017.

(3): Average production costs attributable to the Royalty are calculated as stated capital costs plus operating costs, divided by stated net production volumes attributable to the Royalty paid. As noted above in footnote (2), production costs may be incurred in one operating period and then recovered in a subsequent operating period, which may cause Royalty income paid to the Trust not to agree to the Trust's Royalty interest in the Net Proceeds.
(4): Net production volumes attributable to the Royalty are determined by dividing Royalty income by the average sales price received. Any differences noted are due to rounding.
(5): Effective September 2017, following Hilcorp's acquisition of Conoco, Inc.'s ("ConocoPhillips") interests in the San Juan—New Mexico Properties, Hilcorp continued to make an estimated payment of Net Proceeds to the Trust each month consistent with the monthly amount previously paid by ConocoPhillips. These estimated payments remain subject to reconciliation with respect to actual revenue, costs and net proceeds and the effects of pricing during the prior months after Hilcorp has completed its transition as owner of the San Juan—New Mexico Properties. The reconciliation and true-up of the estimated payments for this transition period may affect the Trust's future receipt of Net Proceeds from Hilcorp.

Royalty Income. The Trust's Royalty income was $747,618 for the quarter ended March 31, 2018, a decrease of approximately 19% as compared to $918,539 for the quarter ended March 31, 2017. The decrease was primarily a result of lower natural gas prices, decreased net production of natural gas, natural gas liquids and oil and condensate and an increase in operating expenses, offset in part by higher natural gas liquids and oil and condensate prices and lower capital expenditures in the quarter ended March 31, 2018, as compared to the quarter ended March 31, 2017. The Trust's Interest income for the quarters ended March 31, 2018 and 2017 was $4,557 and $1,357, respectively. In accordance with the Trust Indenture and as explained below, interest on cash on hand was paid at a rate equivalent to a 3.00% annualized return from January 1, 2018 through March 21, 2018 and a 3.25% annualized return from March 22, 2018 through March 31, 2018

General and Administrative Expense. General and administrative expense was $116,757 and $48,250 for the three months ended March 31, 2018 and 2017, respectively. The Trustee's fees are included in general and administrative expense. The increase for the three months ended March 31, 2018 as compared to March 31, 2017 was primarily a result of general and administrative expenses in the amount of $70,460 for December 2017 being paid by the Trust in January 2018. If the Trust had paid such expenses in December 2017, general and administrative expenses for the three months ended March 31, 2018 would have been $46,297.

For the quarter ended March 31, 2018, the Trustee was due $118,750 for its services. The Trust paid $108,288 of this amount to the Trustee, and $10,462 was allocated to offset against interest due to the Trust under the Trust Indenture. The Trust Indenture requires that cash being held by the Trustee earn interest at 1.5% below the prime rate, which would have yielded the Trust a 3.00% annualized return from January 1, 2018 through March 21, 2018 and a 3.25% annualized return from March 22, 2018 through March 31, 2018. However, due to the current interest rate environment, the Trustee was unable to obtain an account in which such an interest rate was available. In the event such an interest rate is unavailable in the future, the Trustee intends to allocate certain of its fees due to the Trust to meet the minimum interest rate payable under the Trust Indenture. In future periods the Trustee will continue to allocate a portion of the fees earned for its services to the Trust until the remaining $11,568 of interest due to the Trust is fully offset.

Unreimbursed Expenses and the Contingent Reserve. The Working Interest Owners partially reimburse the Trust each quarter for amounts paid in connection with the Trustee's services. For the quarter ended March 31, 2018, the Trustee's fees were $108,288 and the Working Interest Owners reimbursed a sum of $95,897 to the Trustee, which was the same amount reimbursed for the quarter ended March 31, 2017.

During 2011, the Trustee, acting pursuant to the Trust Indenture, withheld $1.0 million for future unknown contingent liabilities and expenses (such cumulative withholding being the "Contingent Reserve"). The Trustee reserves the right to determine whether or not to release cash reserves in future periods with respect to any reimbursement expenses. At any given time, the Contingent Reserve is included in cash and short term investments. As of March 31, 2018, there were $0 of unreimbursed expenses. For the three months ended March 31, 2018, the Trustee increased the Contingent Reserve by $55,725 of royalty income received from BP in March 2018 after the distribution to unitholders had been announced for the month of March 2018, which royalty income was included in the April 2018 distribution to unitholders. For the three months ended March 31, 2018, the Trustee decreased the Contingent Reserve by (1) $49,211 of royalty income received from BP in December 2017 after the distribution to unitholders had been announced for the month of December 2017, which royalty income was included in the January 2018 distribution to unitholders and (2) $70,460 of December 2017 expenses that were included in the distribution calculation for December 2017, but not paid by the Trust until January 2018. As of March 31, 2018, the Contingent Reserve was $1,055,725, which is included in cash and short-term investments.

Distributable Income Available for Distribution. The portion of the Trust's distributable income available for distribution each period includes the Royalty income received from the Working Interest Owners during such period, plus interest income earned to the date of distribution (if any) and increases or withdrawals from the Contingent Reserve (if any). Distributable income available for distribution for the quarter ended March 31, 2018 was $699,364, representing $0.3753 per unit, compared to $789,402, representing $0.4236 per unit, for the quarter ended March 31, 2017. Based on 1,863,590 units outstanding for the quarters ended March 31, 2018 and 2017, respectively, the per unit distributions for each month in such periods were as follows:

Natural gas and natural gas liquids production attributable to the Hugoton Royalty Properties accounted for approximately 41% of the Royalty income of the Trust during the first quarter of 2018.

Royalty Income. Royalty income attributable to the Hugoton Royalty Properties decreased to $309,303 in the first quarter of 2018 from $409,670 in the first quarter of 2017 primarily due to decreases in natural gas prices, decreased net natural gas and natural gas liquids production volumes and higher operating costs, offset in part by an increase in natural gas liquids prices from the Hugoton Royalty Properties in the first quarter of 2018 compared to the first quarter of 2017.

Operating Costs and Capital Expenditures. Operating costs were $241,671 in the first quarter of 2018, an increase of approximately 266% as compared to $66,028 in the first quarter of 2017, primarily due to timing of ad valorem tax payments and an increase in transportation charges during the first quarter of 2018. Capital expenditures attributable to the Hugoton Royalty Properties were $2,411 in the first quarter of 2018, as compared to $1,254 in the first quarter of 2017.

Average Sales Price. Average sales prices per Mcf of natural gas and barrel ("Bbl") for natural gas liquids for the Hugoton Royalty Properties is directly dependent on the prices Linn realizes for natural gas sold under short-term and multi-month contracts at market clearing prices to multiple purchasers. Overall market prices received for natural gas from Hugoton Royalty Properties were lower for the three months ended March 31, 2018 as compared to the three months ended March 31, 2017.

Linn Energy Reorganization. On May 11, 2016, Linn Energy, LLC ("Old Linn"), LinnCo, LLC ("LinnCo"), an affiliate of Old Linn, and certain of Old Linn's direct and indirect subsidiaries (collectively with Old Linn and LinnCo, the "Debtors"), filed voluntary petitions for reorganization under Chapter 11 of the United States Bankruptcy Code in the United States Bankruptcy Court for the Southern District of Texas (the "Court"). The Debtors' Chapter 11 cases were administered jointly under the caption In re Linn Energy, LLC, et al., Case No. 16-60040.

Pursuant to the Plan, on the Effective Date, all assets of Old Linn (other than equity interests in Linn Acquisition Company, LLC and Berry Petroleum Company, LLC) were conveyed to Linn Energy, Inc. (or a subsidiary thereof), and LinnCo, LLC and Linn Energy, LLC were wound down and liquidated. Subsequent to the effectiveness of the Plan, Linn Energy, Inc. is now the reorganized successor to Old Linn. Under the Plan Supplement, as amended, filed with the Court, the Debtors assumed all executory contracts and unexpired leases with the Trust and Mesa Operating Limited Partnership as the counterparty. Furthermore, pursuant to the Plan, the royalty interests in the Hugoton Royalty Properties owned by the Trust shall be preserved and remain in full force and effect in accordance with the terms of the granting instruments or other governing documents.

On April 18, 2018, Linn announced its Board of Directors' decision to separate Linn into two stand-alone public companies, which is expected to take place during the third quarter of 2018. The Trustee is in discussions with Linn regarding the impact of the separation plan.

Royalty income from the San Juan Basin Royalty Properties is calculated and paid to the Trust on a state-by-state basis depending upon whether the property is situated in Colorado or New Mexico. A majority of the Royalty income from the San Juan Basin Royalty Properties is attributable to the San Juan Basin—New Mexico Properties. Substantially all of the natural gas produced from the San Juan Basin Royalty Properties is currently being sold on the spot market.

Royalty Income. Royalty income from the San Juan Basin—Colorado Royalty Properties was $146,866 during the first quarter of 2018, compared to $204,845 during the first quarter of 2017. This decrease in Royalty income was due primarily to lower market prices and lower net production volumes for natural gas in the first quarter of 2018 compared to the first quarter of 2017.

Operating Costs. Operating costs on these properties were $34,985 in the first quarter of 2018, as compared to $35,412 in the first quarter of 2017.

Royalty Income. Royalty income from the San Juan Basin—New Mexico Properties was $291,449 during the first quarter of 2018 as compared with Royalty income of $304,025 during the first quarter of 2017. This decrease in Royalty income was due primarily to a decrease in natural gas and natural gas liquids prices and decreased net production volumes of oil and condensate for the first quarter of 2018 compared to the first quarter of 2017, offset in part by increased net production volumes of natural gas and natural gas liquids and a decrease in operating costs and capital expenditures during the first quarter of 2018 compared to the first quarter of 2017.

Operating Costs and Capital Expenditures. Operating costs were $182,830 in the first quarter of 2018, a decrease of approximately 23% as compared to $237,889 in the first quarter of 2017 due

primarily to maintenance expense reductions in the third quarter of 2017 that continue to be used by Hilcorp as estimates for the current quarter. Capital expenditures on these properties were $1,817 in the first quarter of 2018, a decrease of approximately 57% as compared to $4,205 in the first quarter of 2017.

Effective September 2017, following Hilcorp's acquisition of ConocoPhillips' interests in the San Juan—New Mexico Properties, Hilcorp continued to make an estimated payment of Net Proceeds to the Trust each month consistent with the monthly amount previously paid by ConocoPhillips. These estimated payments remain subject to reconciliation with respect to actual revenue, costs and net proceeds, and the effects of pricing during the prior months after Hilcorp has completed its transition as owner of the San Juan—New Mexico Properties. The reconciliation and true-up of the estimated payments for this transition period may affect the Trust's future receipt of Net Proceeds from Hilcorp.

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", 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 in the reports that it files or submits under the Exchange Act is accumulated and communicated by the Working Interest Owners to The Bank of New York Mellon Trust Company, N.A., 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 Trustee's disclosure controls and procedures. The officer acting on behalf of the Trustee concluded that the Trust's disclosure controls and procedures were effective.

Due to the contractual arrangements of (i) the Trust Indenture and (ii) the rights of the Trust under the Conveyance regarding information furnished by the Working Interest Owners, the Trustee relies on information provided by the Working Interest Owners, including (i) the status of litigation, (ii) historical operating data, plans for future operating and capital expenditures and reserve information, (iii) information relating to projected production, and (iv) conclusions regarding reserves by their internal reserve engineers or other experts in good faith. See Part I Item 1A. "Risk Factors—Trust unitholders and the Trustee have no control over the operation or development of the Royalty Properties and have little influence over operation or development" and "The Trustee relies upon the Working Interest Owners for information regarding the Royalty Properties" in the Trust's Annual Report on Form 10-K for the year ended December 31, 2017 for a description of certain risks relating to these arrangements and reliance, including filings such as this filing outside the time periods specified notwithstanding effective disclosure controls and procedures of the Trustee regarding information under its control.

The officer acting on behalf of the Trustee has not conducted a separate evaluation of the disclosure controls and procedures with respect to information furnished by the Working Interest Owners. The Trustee notes that it is conducting an ongoing review of certain information and calculations by the Working Interest Owners, along with an outside joint venture auditor. See "Management's Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources" under Item 7 in the Trust's Annual Report on Form 10-K for the year ended December 31, 2017 for information concerning controls and procedures with respect to the Royalty.

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.

There are no pending legal proceedings to which the Trust is a named party. The Trustee has been advised by Linn, Hilcorp and BP that the Trust may be subject to litigation in the ordinary course of business for certain matters that include the Royalty Properties. While each of the Working Interest Owners has advised the Trustee that it does not currently believe any of the pending litigation will have a material adverse effect net to the Trust, in the event such matters were adjudicated or settled in a material amount and charges were made against Royalty income, such charges could have a material impact on future Royalty income.

For a discussion of the Trust's potential risks and uncertainties, please see "Risk Factors" in Item 1A to Part 1 of the Trust's Annual Report on Form 10-K for the year ended December 31, 2017. During the quarter ended March 31, 2018, there was no material change in such risk factors.

(Asterisk indicates exhibit previously filed with the Securities and Exchange Commission and incorporated herein by reference. The Bank of New York Mellon Trust Company, N.A. is the successor trustee to JPMorgan Chase Bank, N.A. JPMorgan Chase Bank, N.A. was formerly known as The Chase Manhattan Bank and was successor by mergers to the originally named Trustee, Texas Commerce Bank National Association).

			SEC File or Registration Number	Exhibit Number

4(a	)	*Mesa Royalty Trust Indenture between Mesa Petroleum Co. and Texas Commerce Bank National Association, as Trustee, dated November 1, 1979	2-65217	1(a)

4(b	)	*Form of Overriding Royalty Conveyance between Mesa Petroleum Co. and Texas Commerce Bank, as Trustee, dated November 1, 1979	2-65217	1(b)

4(c	)	*First Amendment to the Mesa Royalty Trust Indenture dated as of March 14, 1985 (Exhibit 4(c) to Form 10-K for year ended December 31, 1984 of Mesa Royalty Trust)	1-7884	4(c)

4(d	)	*Form of Assignment of Overriding Royalty Interest, effective April 1, 1985, from Texas Commerce Bank National Association, as Trustee, to MTR Holding Co. (Exhibit 4(d) to Form 10-K for year ended December 31, 1984 of Mesa Royalty Trust)	1-7884	4(d)

4(e	)	*Purchase and Sale Agreement, dated March 25, 1991, by and among Mesa Limited Partnership, Mesa Operating Limited Partnership and ConocoPhillips, as amended on April 30, 1991 (Exhibit 4(e) to Form 10-K for year ended December 31, 1991 of Mesa Royalty Trust)	1-7884	4(e)

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.

The Registrant, Mesa Royalty 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.


ý		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Quarterly Period ended March 31, 2018
o		TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Transition Period from to


Texas (State or other jurisdiction of Incorporation or Organization)		76-6284806 (I.R.S. Employer Identification No.)
The Bank of New York Mellon Trust Company, N.A., Trustee 601 Travis Street, Floor 16 Houston, Texas (Address of Principal Executive Offices)		77002 (Zip Code)


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

	Three Months Ended March 31,

	2018			2017
Trust corpus, beginning of period	$	3,097,932		$	3,439,339
Distributable income		635,418			871,646
Distributions to unitholders		(699,364	)		(789,402	)
Amortization of net overriding royalty interest		(70,591	)		(145,198	)

Trust corpus, end of period	$	2,963,395		$	3,376,385

	As of March 31, 2018		As of December 31, 2017

San Juan Basin—Colorado Properties—Red Willow	$	11,929	$	15,944
San Juan Basin—New Mexico Properties—XTO		5,529		6,070

Total	$	17,458	$	22,014

	Three Months Ended March 31,

	2018			2017
Royalty income	$	747,618		$	918,539
Interest income		4,557			1,357
General and administrative expense		(116,757	)		(48,250	)

Distributable income	$	635,418		$	871,646



Distributable income per unit	$	0.3410		$	0.4677



Units outstanding		1,863,590			1,863,590



Net production volumes attributable to the Royalty paid(4)	247,901	9,250	100	269,476	9,601	173

	2018		2017

January	$	0.1479	$	0.1572
February		0.1115		0.1133
March		0.1159		0.1531

	$	0.3753	$	0.4236

	Three Months Ended March 31,

	2018		2017
Royalty income attributable to Hugoton Royalty Properties	$	309,303	$	409,670
Operating costs attributable to Hugoton Royalty Properties	$	241,671	$	66,028
Capital expenditures attributable to Hugoton Royalty Properties	$	2,411	$	1,254



Actual production volumes attributable to the Royalty paid for Hugoton Royalty Properties	100,334	7,161	—	96,653	5,567	—



Net production volumes attributable to the Royalty paid for Hugoton Royalty Properties	56,078	3,997	—	82,568	4,846	—

	Three Months Ended March 31,

	2018		2017
Royalty income attributable to San Juan Basin—Colorado Properties	$	146,866	$	204,845
Operating costs attributable to San Juan Basin—Colorado Properties	$	34,985	$	35,412



Actual production volumes attributable to the Royalty paid for San Juan Basin—Colorado Properties	117,636	—	—	121,865	—	—



Net production volumes attributable to the Royalty paid for San Juan Basin—Colorado Properties	92,916	—	—	102,467	—	—



Actual production volumes attributable to the Royalty paid for San Juan Basin—New Mexico Properties	161,986	11,151	162	151,933	11,600	306



Net production volumes attributable to the Royalty paid for San Juan Basin—New Mexico Properties	98,907	5,254	100	84,442	4,755	173

Exhibit Number					SEC File or Registration Number		Exhibit Number

	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


		Mesa Royalty Trust
		By:		The Bank of New York Mellon Trust Company, N.A., as Trustee
		By:		/s/ ELAINA RODGERS Elaina Rodgers Vice President & Trust Officer