Edgar Filing: CROSS TIMBERS ROYALTY TRUST

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Form 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

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

For the quarterly period ended June 30, 2013

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

Commission File Number: 1-10982

Cross Timbers Royalty Trust

(Exact name of registrant as specified in its charter)


Texas		75-6415930
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)

U.S. Trust, Bank of America Private Wealth Management P.O. Box 830650, Dallas, Texas		75283-0650
(Address of principal executive offices)		(Zip Code)

(877) 228-5084

(Registrant’s telephone number, including area code)

NONE

(Former name, former address and former fiscal year, if change since last report)

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

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

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, 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 (check one):

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

Indicate the number of units of beneficial interest outstanding, as of the latest practicable date:

Outstanding as of July 1, 2013

6,000,000

CROSS TIMBERS ROYALTY TRUST

FORM 10-Q FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2013

TABLE OF CONTENTS


	Page
Glossary of Terms		3

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements		4

Report of Independent Registered Public Accounting Firm		5

Condensed Statements of Assets, Liabilities and Trust Corpus at June 30, 2013 and December 31, 2012		6

Condensed Statements of Distributable Income for the Three and Six Months Ended June 30, 2013 and 2012		7

Condensed Statements of Changes in Trust Corpus for the Three and Six Months Ended June 30, 2013 and 2012		8

Notes to Condensed Financial Statements		9

Item 2. Trustee’s Discussion and Analysis		13

Item 3. Quantitative and Qualitative Disclosures about Market Risk		18

Item 4. Controls and Procedures		18

PART II. OTHER INFORMATION

Item 1A. Risk Factors		19

Item 6. Exhibits		19

Signatures		20

CROSS TIMBERS ROYALTY TRUST

GLOSSARY OF TERMS

The following are definitions of significant terms used in this Form 10-Q:


Bbl		Barrel (of oil)

Mcf		Thousand cubic feet (of natural gas)

MMBtu		One million British Thermal Units, a common energy measurement

net proceeds		Gross proceeds received by XTO Energy from sale of production from the underlying properties, less applicable costs, as defined in the net profits interest conveyances.

net profits income		Net proceeds multiplied by the applicable net profits percentage of 75% or 90%, which is paid to the trust by XTO Energy. “Net profits income” is referred to as “royalty income” for income tax purposes.

net profits interest		An interest in an oil and gas property measured by net profits from the sale of production, rather than a specific portion of production. The following defined net profits interests were conveyed to the trust from the underlying properties:

		90% net profits interests—interests that entitle the trust to receive 90% of the net proceeds from the underlying properties that are royalty or overriding royalty interests in Texas, Oklahoma and New Mexico.

		75% net profits interests—interests that entitle the trust to receive 75% of the net proceeds from the underlying properties that are working interests in Texas and Oklahoma.

royalty interest (and overriding royalty interest)		A nonoperating interest in an oil and gas property that provides the owner a specified share of production without any production expense or development costs.

underlying properties		XTO Energy’s interest in certain oil and gas properties from which the net profits interests were conveyed. The underlying properties include royalty and overriding royalty interests in producing and nonproducing properties in Texas, Oklahoma and New Mexico, and working interests in producing properties located in Texas and Oklahoma.

working interest		An operating interest in an oil and gas property that provides the owner a specified share of production that is subject to all production expense and development costs.

CROSS TIMBERS ROYALTY TRUST

PART I—FINANCIAL INFORMATION

Item 1.

Financial Statements.

The condensed financial statements included herein are presented, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and footnote disclosures normally included in annual financial statements have been condensed or omitted pursuant to such rules and regulations, although the trustee believes that the disclosures are adequate to make the information presented not misleading. These condensed financial statements should be read in conjunction with the financial statements and the notes thereto included in the trust’s latest Annual Report on Form 10-K. In the opinion of the trustee, all adjustments, consisting only of normal recurring adjustments, necessary to present fairly the assets, liabilities and trust corpus of the Cross Timbers Royalty Trust at June 30, 2013, and the distributable income and changes in trust corpus for the three- and six-month periods ended June 30, 2013 and 2012, have been included. Distributable income for such interim periods is not necessarily indicative of distributable income for the full year. The condensed financial statements as of June 30, 2013, and for the three-month and six-month periods ended June 30, 2013 and 2012 have been subjected to a review by PricewaterhouseCoopers LLP, the Trust’s independent registered public accounting firm, whose report is included herein.

Report of Independent Registered Public Accounting Firm

To the Unitholders of Cross Timbers Royalty Trust and

Bank of America, N.A., Trustee:

We have reviewed the accompanying condensed statement of assets, liabilities and trust corpus of Cross Timbers Royalty Trust (the “Trust”) as of June 30, 2013, and the related condensed statements of distributable income and changes in trust corpus for the three-month and six-month periods ended June 30, 2013 and 2012. These interim financial statements are the responsibility of the Trustee.

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

As described in Note 1, these financial statements were prepared on the modified cash basis of accounting, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America.

Based on our review, we are not aware of any material modifications that should be made to the accompanying condensed interim financial statements for them to be in conformity with the basis of accounting described in Note 1.

We previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the statement of assets, liabilities and trust corpus as of December 31, 2012, and the related statements of distributable income and changes in trust corpus for the year then ended (not presented herein), and in our report dated March 8, 2013, we expressed an unqualified opinion on those financial statements. In our opinion, the information set forth in the accompanying condensed statement of assets, liabilities and trust corpus as of December 31, 2012 is fairly stated in all material respects in relation to the statement of assets, liabilities and trust corpus from which it has been derived.

PricewaterhouseCoopers LLP

Dallas, TX

August 6, 2013

CROSS TIMBERS ROYALTY TRUST

Condensed Statements of Assets, Liabilities and Trust Corpus


	June 30,		December 31,
	2013		2012
	(Unaudited)
ASSETS
Cash and short-term investments	$	1,195,010	$	1,307,815
Interest to be received		22		23
Net profits interests in oil and gas properties—net (Note 1)		12,206,851		12,532,729

	$	13,401,883	$	13,840,567

LIABILITIES AND TRUST CORPUS
Distribution payable to unitholders	$	1,195,032	$	1,307,838
Trust corpus (6,000,000 units of beneficial interest authorized and outstanding)		12,206,851		12,532,729

	$	13,401,883	$	13,840,567

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

CROSS TIMBERS ROYALTY TRUST

Condensed Statements of Distributable Income (Unaudited)


	Three Months Ended				Six Months Ended
	June 30				June 30
	2013		2012		2013		2012
Net profits income	$	3,225,021	$	3,961,296	$	6,017,619	$	8,338,276
Interest income		56		76		117		162

Total income		3,225,077		3,961,372		6,017,736		8,338,438
Administration expense		127,847		138,130		261,030		265,972

Distributable income	$	3,097,230	$	3,823,242	$	5,756,706	$	8,072,466

Distributable income per unit (6,000,000 units)	$	0.516205	$	0.637207	$	0.959451	$	1.345411

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

CROSS TIMBERS ROYALTY TRUST

Condensed Statements of Changes in Trust Corpus (Unaudited)


	Three Months Ended						Six Months Ended
	June 30						June 30
	2013			2012			2013			2012
Trust corpus, beginning of period	$	12,381,750		$	13,188,818		$	12,532,729		$	13,415,740
Amortization of net profits interests		(174,899	)		(213,413	)		(325,878	)		(440,335	)
Distributable income		3,097,230			3,823,242			5,756,706			8,072,466
Distributions declared		(3,097,230	)		(3,823,242	)		(5,756,706	)		(8,072,466	)

Trust corpus, end of period	$	12,206,851		$	12,975,405		$	12,206,851		$	12,975,405

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

CROSS TIMBERS ROYALTY TRUST

Notes to Condensed Financial Statements (Unaudited)

1.	Basis of Accounting

The financial statements of Cross Timbers Royalty Trust are prepared on the following basis and are not intended to present financial position and results of operations in conformity with U.S. generally accepted accounting principles (“GAAP”):

•

Net profits income recorded for a month is the amount computed and paid by XTO Energy Inc., the owner of the underlying properties, to Bank of America, N.A., as trustee for the trust. XTO Energy is a wholly owned subsidiary of Exxon Mobil Corporation. Net profits income consists of net proceeds received by XTO Energy from the underlying properties in the prior month, multiplied by net profit percentages of 90% for the 90% net profits interests, and 75% for the 75% net profits interests.

Costs deducted in the calculation of net proceeds for the 90% net profits interests generally include applicable taxes, transportation, marketing and legal costs, and do not include production expense or development costs. For the 75% net profits interests, costs deducted in the calculation of net proceeds include production expense, development costs, applicable taxes, transportation, marketing and legal costs, operating charges and other costs.

•

Net profits income is computed separately for each of five conveyances under which the net profits interests were conveyed to the trust. If monthly costs exceed revenues for any conveyance, such excess costs must be recovered, with accrued interest, from future net proceeds of that conveyance and cannot reduce net proceeds from the other conveyances.

•

Interest income, interest to be received and distribution payable to unitholders include interest to be earned on net profits income from the monthly record date (last business day of the month) through the date of the next distribution to unitholders.

•

Trust expenses are recorded based on liabilities paid and cash reserves established by the trustee for liabilities and contingencies.

•

Distributions to unitholders are recorded when declared by the trustee.

•

The trustee routinely reviews the Trust’s net profits interests in oil and gas properties for impairment whenever events or circumstances indicate that the carrying amount of an asset may not be recoverable. If an impairment event occurs and it is determined that the carrying value of the Trust’s net profits interests may not be recoverable, an impairment will be recognized as measured by the amount by which the carrying amount of the net profits interests exceeds the fair value of these assets, which would likely be measured by discounting projected cash flows. There is no impairment of the assets as of June 30, 2013.

The financial statements of the trust differ from those prepared in conformity with U.S. GAAP because revenues are recognized when received rather than accrued in the month of production, expenses are recognized when paid rather than when incurred, and certain cash reserves may be established by the trustee for contingencies which would not be recorded under U.S. GAAP. This comprehensive basis of accounting other than U.S. GAAP corresponds to the accounting permitted for royalty trusts by the U.S. Securities and Exchange Commission, as specified by Staff Accounting Bulletin Topic 12:E, Financial Statements of Royalty Trusts.

Most accounting pronouncements apply to entities whose financial statements are prepared in accordance with U.S. GAAP, directing such entities to accrue or defer revenues and expenses in a period other than when such revenues were received or expenses were paid. Because the trust’s financial statements are prepared on the modified cash basis, as described above, most accounting pronouncements are not applicable to the trust’s financial statements.

The initial carrying value of the net profits interests of $61,100,449 represents XTO Energy’s historical net book value for the interests on February 12, 1991, the creation date of the trust. Amortization of the net profits interests is calculated on a unit-of-production basis and is charged directly to trust corpus. Accumulated amortization was $48,893,598 as of June 30, 2013 and $48,567,720 as of December 31, 2012.

2.	Federal Income Taxes

For federal income tax purposes, the trust constitutes a fixed investment trust that is taxed as a grantor trust. A grantor trust is not subject to tax at the trust level. The unitholders are considered to own the trust’s income and principal as though no trust were in existence. The income of the trust is deemed to have been received or accrued by each unitholder at the time such income is received or accrued by the trust and not when distributed by the trust.

Because the trust is a grantor trust for federal tax purposes, each unitholder is taxed directly on his proportionate share of income, deductions and credits of the trust consistent with each such unitholder’s taxable year and method of accounting and without regard to the taxable year or method of accounting employed by the trust. The income of the trust consists primarily of a specified share of the net profits from the sale of oil and natural gas produced from the underlying properties. During the first six months of 2013, the trust incurred administration expenses and earned interest income on funds held for distribution and for the cash reserve maintained for the payment of contingent and future obligations of the trust.

The net profits interests constitute “economic interests” in oil and gas properties for federal tax purposes. Each unitholder is entitled to amortize the cost of the units through cost depletion over the life of the net profits interests or, if greater, through percentage depletion equal to 15 percent of gross income. Unlike cost depletion, percentage depletion is not limited to a unitholder’s depletable tax basis in the units. Rather, a unitholder is entitled to a percentage depletion deduction as long as the applicable underlying properties generate gross income. Unitholders may compute both percentage depletion and cost depletion from each property and claim the larger amount as a deduction on their income tax returns.

If a taxpayer disposes of any “Section 1254 property” (certain oil, gas, geothermal or other mineral property), and the adjusted basis of such property includes adjustments for depletion deductions under Section 611 of the Internal Revenue Code (the “Code”), the taxpayer generally must recapture the amount deducted for depletion as ordinary income (to the extent of gain realized on the disposition of the property). This depletion recapture rule applies to any disposition of property that was placed in service by the taxpayer after December 31, 1986. Detailed rules set forth in Sections 1.1254-1 through 1.1254-6 of the U.S. Treasury Regulations govern dispositions of property after March 13, 1995. The Internal Revenue Service likely will take the position that a unitholder must recapture depletion upon the disposition of a unit.

Interest and net profits income attributable to ownership of units and any gain on the sale thereof are considered portfolio income, and not income from a “passive activity,” to the extent a unitholder acquires and holds units as an investment and not in the ordinary course of a trade or business. Therefore, interest and net profits income attributable to ownership of units generally may not be offset by losses from any passive activities.

Individuals may incur expenses in connection with the acquisition or maintenance of trust units. These expenses may be deductible as “miscellaneous itemized deductions” only to the extent that such expenses exceed 2 percent of the individual’s adjusted gross income.

Under current law, the highest marginal U.S. federal income tax rate applicable to ordinary income of individuals is 39.6%, and the highest marginal U.S. federal income tax rate applicable to long-term capital gains (generally, gains from the sale or exchange of certain investment assets held for more than one year) and qualified dividends of individuals is 20%. Such marginal tax rates may be effectively increased by up to 1.2% due to the phaseout of personal exemptions and the limitations on itemized deductions. The highest marginal U.S. federal income tax rate applicable to corporations is 35%, and such rate applies to both ordinary income and capital gains.

Section 1411 of the Code imposes a 3.8% Medicare tax on certain investment income earned by individuals, estates, and trusts for taxable years beginning after December 31, 2012. For these purposes, investment income generally will include a unitholder’s allocable share of the trust’s interest and royalty income plus the gain recognized from a sale of trust units. In the case of an individual, the tax is imposed on the lesser of (i) the individual’s net investment income from all investments, or (ii) the amount by which the individual’s modified adjusted gross income exceeds specified threshold levels depending on such individual’s federal income tax filing status. In the case of an estate or trust, the tax is imposed on the lesser of (i) undistributed net investment income, or (ii) the excess adjusted gross income over the dollar amount at which the highest income tax bracket applicable to an estate or trust begins.

Some trust units are held by middlemen, as such term is broadly defined in U.S. Treasury Regulations (and includes custodians, nominees, certain joint owners, and brokers holding an interest for a customer in street name, collectively referred to herein as “middlemen”). Therefore, the trustee considers the trust to be a non-mortgage widely held fixed investment trust (“WHFIT”) for U.S. federal income tax purposes. U.S. Trust, Bank of America Private Wealth Management, EIN: 56-0906609, Post Office Box 830650, Dallas, Texas, 75283-0650, telephone number 1-877-228-5084, email address trustee@crosstimberstrust.com, 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. Tax information is also posted by the trustee at www.crosstimberstrust.com. Notwithstanding the foregoing, the middlemen holding trust units on behalf of unitholders, and not the trustee of the trust, are solely responsible for complying with the information reporting requirements under the U.S. Treasury Regulations with respect to such trust units, including the issuance of IRS Forms 1099 and certain written tax statements. Unitholders whose trust units are held by middlemen should consult with such middlemen regarding the information that will be reported to them by the middlemen with respect to the trust units.

Unitholders should consult their tax advisors regarding trust tax compliance matters.

3.	State Taxes

All revenues from the trust are from sources within Texas, Oklahoma or New Mexico. Because it distributes all of its net income to unitholders, the trust has not been taxed at the trust level in New Mexico or Oklahoma. While the trust has not owed tax, the trustee is required to file a return with Oklahoma reflecting the income and deductions of the trust attributable to properties located in that state, along with a schedule that includes information regarding distributions to unitholders. Texas does not impose a state income tax, so no part of the trust’s income will be subject to income tax at the trust level in Texas. Oklahoma and New Mexico tax the income of nonresidents from real property located within those states, and the trust has been advised by counsel that those states will each tax nonresidents on income from the net profits interests located in those states. Oklahoma and New Mexico also impose a corporate income tax that may apply to unitholders organized as corporations (subject to certain exceptions for S corporations and limited liability companies, depending on their treatment for federal tax purposes).

Texas imposes a franchise tax at a rate of 1% on gross revenues less certain deductions, as specifically set forth in the Texas franchise tax statutes. Entities subject to tax generally include trusts and most other types of entities that provide limited liability protection, unless otherwise exempt. Trusts that receive at least 90% of their federal gross income from designated passive sources, including royalties from mineral properties and other non-operated mineral interest income, and do not receive more than 10% of their income from operating an active trade or business, generally are exempt from the Texas franchise tax as “passive entities.” The trust has been and expects to continue to be exempt from Texas franchise tax as a passive entity. Because the trust should be exempt from Texas franchise tax at the trust level as a passive entity, each unitholder that is considered a taxable entity under the Texas franchise tax will generally be required to include its Texas portion of trust revenues in its own Texas franchise tax computation. This revenue is sourced to Texas under provisions of the Texas Administrative Code providing that such income is sourced according to the principal place of business of the trust, which is Texas.

Each unitholder should consult his or her own tax advisor regarding state tax requirements, if any, applicable to such person’s ownership of trust units.

4.	Contingencies

Several states have enacted legislation requiring state income tax withholding from nonresident recipients of oil and gas proceeds. After consultation with its tax counsel, the trustee believes that it is not required to withhold on payments made to the unitholders. However, regulations are subject to change by the various states, which could change this conclusion. Should amounts be withheld on payments made to the trust or the unitholders, distributions to the unitholders would be reduced by the required amount, subject to the filing of a claim for refund by the trust or unitholders for such amount.

5.	Excess Costs

in February 2013 and May 2013 and increased oil prices in June 2013 led to the partial recovery of excess costs, plus accrued interest, of $54,849 ($41,137 net to the trust) in February 2013 and $155,974 ($116,980 net to the trust) in May and June 2013 on properties underlying the Texas working interest. Remaining excess costs totaled $41,040 ($30,780 net to the trust) for the period ended June 30, 2013.

Item 2.

Trustee’s Discussion and Analysis.

The following discussion should be read in conjunction with the trustee’s discussion and analysis contained in the trust’s 2012 Annual Report on Form 10-K, as well as the condensed financial statements and notes thereto included in this Quarterly Report on Form 10-Q. The trust’s Annual Report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all amendments to those reports are available on the trust’s web site at www.crosstimberstrust.com.

Distributable Income

Quarter

For the quarter ended June 30, 2013, net profits income was $3,225,021 compared to $3,961,296 for second quarter 2012. This 19% decrease in net profits income is the result of lower oil prices ($0.5 million), decreased gas production ($0.4 million) and increased development costs ($0.3 million), partially offset by increased oil production ($0.4 million). See “Net Profits Income” on following page.

After considering interest income of $56 and administration expense of $127,847, distributable income for the quarter ended June 30, 2013 was $3,097,230, or $0.516205 per unit of beneficial interest. Administrative expense for the quarter decreased $10,283 from the prior year quarter. For second quarter 2012, distributable income was $3,823,242, or $0.637207 per unit. Distributions to unitholders for the quarter ended June 30, 2013 were:


			Distribution
Record Date	Payment Date		per Unit
April 30, 2013		May 14, 2013	$	0.135290
May 31, 2013		June 14, 2013		0.181743
June 28, 2013		July 15, 2013		0.199172

			$	0.516205

Six Months

For the six months ended June 30, 2013, net profits income was $6,017,619 compared to $8,338,276 for the same 2012 period. This 28% decrease in net profits income is the result of lower oil and gas prices ($1.7 million), increased development costs ($0.7 million) and decreased gas production ($0.4 million), partially offset by decreased taxes, transportation and other costs ($0.4 million). See “Net Profits Income” below.

After considering interest income of $117 and administration expense of $261,030, distributable income for the six months ended June 30, 2013 was $5,756,706, or $0.959451 per unit of beneficial interest. Administrative expense for the six months ended June 30, 2013 decreased $4,942 from the prior year six-month period. For the six months ended June 30, 2012, distributable income was $8,072,466, or $1.345411 per unit.

Net Profits Income

Net profits income is recorded when received by the trust, which is the month following receipt by XTO Energy and generally two months after oil production and three months after gas production. Net profits income is generally affected by three major factors:

•

oil and gas sales volumes,

•

oil and gas sales prices, and

•

costs deducted in the calculation of net profits income.

Because properties underlying the 90% net profits interests are royalty and overriding royalty interests, the calculation of net profits income from these interests only includes deductions for production and property taxes, legal costs, and marketing and transportation charges. In addition to these costs, the calculation of net profits income from the 75% net profits interests includes deductions for production expense and development costs since the related underlying properties are working interests.

The following is a summary of the calculation of net profits income received by the trust:


	Three Months							Six Months
	Ended June 30 *(a)*				Increase			Ended June 30 *(a)*					Increase
	2013		2012		(Decrease)			2013			2012		(Decrease)
Sales Volumes
Oil (Bbls) (b)
Underlying properties		51,786		46,417		12	%		97,959			95,802		2	%
Average per day		582		516		13	%		541			526		3	%
Net profits interests		21,106		22,725		(7	%)		37,214			48,440		(23	%)
Gas (Mcf) (b)
Underlying properties		359,322		430,245		(16	%)		763,661			834,993		(9	%)
Average per day		3,992		4,728		(16	%)		4,196			4,563		(8	%)
Net profits interests		313,852		382,106		(18	%)		663,881			742,358		(11	%)
Average Sales Prices
Oil (per Bbl)	$	84.65	$	97.27		(13	%)	$	81.93		$	95.28		(14	%)
Gas (per Mcf)	$	6.12	$	6.20		(1	%)	$	5.94		$	6.79		(13	%)
Revenues
Oil sales	$	4,383,424	$	4,514,726		(3	%)	$	8,026,251		$	9,127,862		(12	%)
Gas sales		2,199,236		2,668,248		(18	%)		4,534,111			5,666,480		(20	%)

Total Revenues		6,582,660		7,182,974		(8	%)		12,560,362			14,794,342		(15	%)

Costs
Taxes, transportation and other		761,669		926,770		(18	%)		1,454,863			1,895,972		(23	%)
Production expense (c)		1,344,215		1,270,288		6	%		2,896,313			2,716,425		7	%
Development costs		717,609		381,521		88	%		1,373,245			487,350		182	%
Excess costs (d)		52,411		—		—			(41,040	)		—		—

Total Costs		2,875,904		2,578,579		12	%		5,683,381			5,099,747		11	%

Net Proceeds	$	3,706,756	$	4,604,395		(19	%)	$	6,876,981		$	9,694,595		(29	%)

Net Profits Income	$	3,225,021	$	3,961,296		(19	%)	$	6,017,619		$	8,338,276		(28	%)

(a)

Because of the interval between time of production and receipt of royalty income by the trust, (1) oil and gas sales for the quarter ended June 30 generally represent oil production for the period February through April and gas production for the period January through March and (2) oil and gas sales for the six-months ended June 30 generally represent oil production for the period November through April and gas production for the period October through March.

(b)

Oil and gas sales volumes are allocated to the net profits interests based upon a formula that considers oil and gas prices and the total amount of production expense and development costs. As product prices change, the trust’s share of the production volumes is impacted as the quantity of production to cover expenses in reaching the net profits break-even level changes inversely with price. As such, the underlying property production volume changes may not correlate with the trust’s net profit share of those volumes in any given period. Therefore, comparative discussion of oil and gas sales volumes is based on the underlying properties.

(c)

Production expense is primarily from seven working interest properties in the 75% net profits interest. Six of these properties are not operated by XTO Energy or ExxonMobil. Production expense includes an overhead charge which is deducted and retained by the operator. As of June 30, 2013, this charge was $35,947 per month (including monthly overhead charges of $5,135 which ExxonMobil deducts as operator of the Hewitt Unit) and is subject to adjustment each May based on an oil and gas industry index.

(d)

See Note 5 to Condensed Financial Statements.

The following are explanations of significant variances on the underlying properties from second quarter 2012 to second quarter 2013 and from the first six months of 2012 to the comparable period in 2013:

Sales Volumes

Oil

Oil sales volumes increased 12% for second quarter 2013 and 2% for the six-month period as compared with the same 2012 periods primarily because of the timing of cash receipts, partially offset by natural production decline.

Gas

Gas sales volumes decreased 16% for second quarter 2013 as compared with the same 2012 period primarily because of the timing of cash receipts and natural production decline. Gas sales volumes decreased 9% for the first six months of 2013 as compared with the same 2012 period primarily because of the timing of cash receipts and natural production decline, partially offset by increased production from new wells and workovers.

The estimated rate of natural production decline on the underlying oil and gas properties is approximately 6% to 8% a year.

Sales Prices

Oil

The average oil price decreased 13% to $84.65 per Bbl for the second quarter and 14% to $81.93 per Bbl for the six-month period. Oil prices are expected to remain volatile. The second quarter 2013 oil price is primarily related to production from February through April 2013, when the average NYMEX price was $93.50 per Bbl. The average NYMEX price for May and June 2013 was $95.22 per Bbl. At July 22, 2013, the average NYMEX futures price for the following twelve months was $100.73 per Bbl.

Gas

Gas prices for the second quarter decreased 1% to $6.12 per Mcf and for the six-month period decreased 13% to $5.94 per Mcf. Natural gas prices are affected by the level of North American production, weather, crude oil and natural gas liquids prices, the U.S. economy, storage levels and import levels of liquefied natural gas. Natural gas prices are expected to remain volatile. The second quarter 2013 gas price is primarily related to production from January through March 2013, when the average NYMEX price was $3.34 per MMBtu. The average NYMEX price for April through June 2013 was $4.09 per MMBtu. At July 22, 2013, the average NYMEX futures price for the following twelve months was $3.86 per MMBtu.

Costs

Taxes, Transportation and Other

Taxes, transportation and other decreased 18% for the second quarter primarily because of decreased gas production taxes and other deductions related to lower gas revenues. Taxes, transportation and other decreased 23% for the six-month period primarily because of decreased oil and gas production taxes and other deductions related to lower oil and gas revenues.

Production Expense

Production expense increased 6% for the second quarter primarily because of increased non-operated overhead and power and fuel costs. Production expense increased 7% for the six-month period primarily because of increased non-operated overhead, power and fuel, and outside operated costs, partially offset by decreased repairs and maintenance costs.

Development Costs

Development costs increased 88% for the second quarter and 182% for the six-month period primarily because of the timing of expenditures and increased activity and costs related to non-operated Texas and Oklahoma oil properties underlying the 75% net profits interest.

Excess Costs

Lower oil prices in January 2013 and increased costs related to the timing of cash expenditures in January and March 2013 caused costs to exceed revenues by a total of $148,300 ($111,225 net to the trust) in January and March 2013 on properties underlying the Texas working interest. XTO advised the trustee that increased costs related to the timing of cash expenditures caused costs to exceed revenues by a total of $103,563 ($77,672 net to the trust) in April 2013 on properties underlying the Texas working interest. However, these excess costs did not reduce net proceeds from the remaining conveyances. Decreased costs in February 2013 and May 2013 and increased oil prices in June 2013 led to the partial recovery of excess costs, plus accrued interest, of $54,849 ($41,137 net to the trust) in February 2013 and $155,974 ($116,980 net to the trust) in May and June 2013 on properties underlying the Texas working interest. Remaining excess costs totaled $41,040 ($30,780 net to the trust) for the period ended June 30, 2013.

Contingencies

Forward-Looking Statements

Statements in this report relating to future plans, predictions, events or conditions are forward-looking statements. All statements other than statements of historical fact included in this Form 10-Q including, without limitation, statements regarding the net profits interests, underlying properties, development activities, development, production and other costs and expenses, oil and gas prices and differentials to NYMEX prices,

distributions to unitholders and industry and market conditions, are forward-looking statements that are subject to risks and uncertainties which are detailed in Part I, Item 1A of the trust’s Annual Report on Form 10-K for the year ended December 31, 2012, which is incorporated by this reference as though fully set forth herein. XTO Energy and the trustee assume no duty to update these statements as of any future date.

Item 3.

Quantitative and Qualitative Disclosures about Market Risk.

There have been no material changes in the trust’s market risks from the information disclosed in Part II, Item 7A of the trust’s Annual Report on Form 10-K for the year ended December 31, 2012.

Item 4.

Controls and Procedures.

As of the end of the period covered by this report, the trustee carried out an evaluation of the effectiveness of the trust’s disclosure controls and procedures pursuant to Exchange Act Rules 13a-15 and 15d-15. Based upon that evaluation, the trustee concluded that the trust’s disclosure controls and procedures are effective in recording, processing, summarizing and reporting, on a timely basis, information required to be disclosed by the trust in the reports that it files or submits under the Securities Exchange Act of 1934 and are effective in ensuring that information required to be disclosed by the trust in the reports that it files or submits under the Securities Exchange Act of 1934 is accumulated and communicated to the trustee to allow timely decisions regarding required disclosure. In its evaluation of disclosure controls and procedures, the trustee has relied, to the extent considered reasonable, on information provided by XTO Energy. There has not been any change in the trust’s internal control over financial reporting during the period covered by this report that has materially affected, or is reasonably likely to materially affect, the trust’s internal control over financial reporting.

PART II—OTHER INFORMATION

Item 1.

Not applicable.

Item 1A.

Risk Factors.

There have been no material changes in the risk factors disclosed under Part I, Item 1A of the trust’s Annual Report on Form 10-K for the year ended December 31, 2012.

Items 2 through 5.

Not applicable.

Item 6.

Exhibits.

(a) Exhibits.


Exhibit Number and Description

(31)		Rule 13a-14(a)/15d-14(a) Certification

(32)		Section 1350 Certification

(99)		Items 1A, 7 and 7A to the Annual Report on Form 10-K for Cross Timbers Royalty Trust filed with the Securities and Exchange Commission on March 8, 2013 (incorporated herein by reference)

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.


	CROSS TIMBERS ROYALTY TRUST
	By BANK OF AMERICA, N.A., TRUSTEE

	By	/s/ NANCY G. WILLIS
		Nancy G. Willis
		Vice President

	EXXON MOBIL CORPORATION

Date: August 6, 2013	By	/s/ BETH E. CASTEEL
		Beth E. Casteel
		Vice President—Upstream Business Services

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