BP Prudhoe Bay Royalty Trust 10-Q

BP PRUDHOE BAY ROYALTY TRUST

THE BANK OF NEW YORK,
as Trustee

/s/ Remo J. Reale

Remo J. Reale
Vice President

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549
_______________

FORM 10-Q


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

For the quarterly period ended September 30, 2004


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

For the transition period from ___to ___

Commission file number 1-10243

BP PRUDHOE BAY ROYALTY TRUST

(Exact Name of Registrant as Specified in Its Charter)


Delaware		13-6943724

(State or Other Jurisdiction of Incorporation or Organization)		(I.R.S. Employer Identification No.)


The Bank of New York, 101 Barclay Street, New York, NY		10286

(Address of Principal Executive Offices)	(Zip Code)

Registrant’s Telephone Number, Including Area Code: (212) 815-6908

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 o No þ

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act. Yes þ No o

As of November 5, 2004, 21,400,000 Units of Beneficial Interest were outstanding.

BP Prudhoe Bay Royalty Trust

Statements of Assets, Liabilities and Trust Corpus
(Prepared on a modified basis of cash receipts and disbursements)

(In thousands, except unit data)


	September 30,		December 31,
	2004		2003
Assets	(Unaudited)

Royalty Interest, net (Notes 1, 2, and 3)	$	12,553	$	14,060

Cash and cash equivalents (Note 2)		1,004		986


Total Assets	$	13,557	$	15,046


Liabilities and Trust Corpus

Accrued expenses	$	244	$	316
Trust Corpus (40,000,000 units of beneficial interest authorized, 21,400,000 units issued and outstanding)		13,313		14,730


Total Liabilities and Trust Corpus	$	13,557	$	15,046

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

BP Prudhoe Bay Royalty Trust

Statements of Cash Earnings and Distributions
(Prepared on a modified basis of cash receipts and disbursements)
(Unaudited)

(In thousands, except unit data)


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2004			2003			2004			2003
Royalty revenues	$	21,566		$	12,147		$	54,567		$	42,407
Interest income		2			2			7			8
Less: Trust administrative expenses		(212	)		(225	)		(752	)		(1,027	)

Cash earnings	$	21,356		$	11,924		$	53,822		$	41,388

Cash distributions	$	21,352		$	11,823		$	53,804		$	41,526

Cash distributions per unit	$	0.9978		$	0.5525		$	2.5142		$	1.9405

Units outstanding		21,400,000			21,400,000			21,400,000			21,400,00

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

BP Prudhoe Bay Royalty Trust

Statements of Changes in Trust Corpus
(Prepared on a modified basis of cash receipts and disbursements)
(Unaudited)

(In thousands)


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2004			2003			2004			2003
Trust Corpus at beginning of period	$	13,822		$	15,608		$	14,730		$	16,498
Cash earnings		21,356			11,924			53,822			41,388
Decrease (increase) in accrued expenses		(10	)		84			72			437
Cash distributions		(21,352	)		(11,823	)		(53,804	)		(41,526	)
Amortization of Royalty Interest		(503	)		(502	)		(1,507	)		(1,506	)


Trust Corpus at end of period	$	13,313		$	15,291		$	13,313		$	15,291

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

BP Prudhoe Bay Royalty Trust
Notes to Financial Statements (Unaudited)
(Prepared on a Modified Basis of Cash Receipts and Disbursements)
September 30, 2004

(1) Formation of the Trust and Organization

BP Prudhoe Bay Royalty Trust (the “Trust”), a grantor trust, was created as a Delaware business trust pursuant to a Trust Agreement dated February 28, 1989 among the Standard Oil Company (“Standard Oil”), BP Exploration (Alaska) Inc. (the “Company”), The Bank of New York (The “Trustee”) and The Bank of New York (Delaware), as co-trustee. Standard Oil and the Company are indirect wholly owned subsidiaries of the BP p.l.c. (“BP”).

Effective January 1, 2000, the Company and all other Prudhoe Bay working interest owners cross-assigned interests in the Prudhoe Bay Field pursuant to the Prudhoe Bay Unit Alignment Agreement. The Company retained all rights, obligations, and liabilities associated with the Trust. This transaction is not expected to have a material effect on the Trust’s operation.

On February 28, 1989, Standard Oil conveyed an overriding royalty interest (the “Royalty Interest”) to the Trust. The Trust was formed for the sole purpose of owning and administering the Royalty Interest. The Royalty Interest represents the right to receive, effective February 28, 1989, a per barrel royalty (the “Per Barrel Royalty”) of 16.4246% on the lesser of (a) the first 90,000 barrels of the average actual daily net production of oil and condensate per quarter or (b) the average actual daily net production of oil and condensate per quarter from the Company’s working interest in the Prudhoe Bay Field (the “Field”) as of February 28, 1989, located on the North Slope of Alaska. Trust Unit holders will remain subject at all times to the risk that production will be interrupted or discontinued or fall, on average, below 90,000 barrels per day in any quarter. BP has guaranteed the performance of the Company of its payment obligations with respect to the Royalty Interest.

The trustees of the Trust are The Bank of New York, a New York corporation authorized to do a banking business, and The Bank of New York (Delaware), a Delaware banking corporation. The Bank of New York (Delaware) serves as co-trustee in order to satisfy certain requirements of the Delaware Trust Act. The Bank of New York alone is able to exercise the rights and powers granted to the Trustee in the Trust Agreement.

The Per Barrel Royalty in effect for any day is equal to the price of West Texas Intermediate crude oil (the “WTI Price”) for that day less scheduled Chargeable Costs (adjusted in certain situations for inflation) and Production Taxes (based on statutory rates then in existence). For years subsequent to 2006, Chargeable Costs will be reduced up to a maximum amount of $1.20 per barrel in each year if additions to the Field’s proved reserves do not meet certain specific levels.

The Trust is passive, with the Trustee having only such powers as are necessary for the collection and distribution of revenues, the payment of Trust liabilities, and the protection of the Royalty Interest. The Trustee, subject to certain conditions, is obligated to establish cash

BP Prudhoe Bay Royalty Trust
Notes to Financial Statements (Unaudited)
(Prepared on a Modified Basis of Cash Receipts and Disbursements)
September 30, 2004

reserves and borrow funds to pay liabilities of the Trust when they become due. The Trustee may sell Trust properties only (a) as authorized by a vote of the Trust Unit Holders, (b) when necessary to provide for the payment of specific liabilities of the Trust then due (subject to certain conditions) or (c) upon termination of the Trust. Each Trust Unit issued and outstanding represents an equal undivided share of beneficial interest in the Trust. Royalty payments are received by the Trust and distributed to Trust Unit holders, net of Trust expenses, in the month succeeding the end of each calendar quarter. The Trust will terminate upon the first to occur of the following events:

a. On or prior to December 31, 2010: upon a vote of Trust Unit Holders of not less than 70% of the outstanding Trust Units.

b. After December 31, 2010: (i) upon a vote of Trust Unit Holders of not less than 60% of the outstanding Trust Units, or (ii) at such time the net revenues from the Royalty Interest for two successive years commencing after 2010 are less than $1,000,000 per year (unless the net revenues during such period are materially and adversely affected by certain events).

In order to ensure the Trust has the ability to pay future expenses, the Trust established a cash reserve account which the Trustee believes is sufficient to pay approximately one year’s current and expected liabilities and expenses of the Trust.

(2) Basis of Accounting

The financial statements of the Trust are prepared on a modified cash basis and reflect the Trust’s assets, liabilities, Corpus, earnings, and distributions, as follows:

a. Revenues are recorded when received (generally within 15 days of the end of the preceding quarter) and distributions to Trust Unit Holders are recorded when paid.

b. Trust expenses (which include accounting, engineering, legal, and other professional fees, trustees’ fees, and out-of-pocket expenses) are recorded on an accrual basis.

c. Amortization of the Royalty Interest is calculated based on the units of production method. Such amortization is charged directly to the Trust Corpus, and does not affect cash earnings. The daily rate for amortization per net equivalent barrel of oil for the three and nine months ended September 30, 2004 and 2003 was $0.37. The Trust evaluates impairment of the Royalty Interest by comparing the undiscounted cash flows expected to be realized from the Royalty Interest to the carrying value, pursuant to Statement of Financial Accounting Standards No. 144, “Accounting for the Impairment or Disposal of Long-Lived Assets” (“SFAS 144”). If the expected future undiscounted cash flows are less than the carrying value, the Trust recognizes an impairment loss for the difference between the carrying value and the estimated fair value of the Royalty Interest.

BP Prudhoe Bay Royalty Trust
Notes to Financial Statements (Unaudited)
(Prepared on a Modified Basis of Cash Receipts and Disbursements)
September 30, 2004

While these statements differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America, the modified cash basis of reporting revenues and distributions is considered to be the most meaningful because quarterly distributions to the Trust Unit Holders are based on net cash receipts. The accompanying modified cash basis financial statements contain all adjustments necessary to present fairly the assets, liabilities and Corpus of the Trust as of September 30, 2004 and December 31, 2003 and the modified cash earnings and distributions and changes in Trust Corpus for the three-month and nine-month periods ended September 30, 2004 and 2003. The adjustments are of a normal recurring nature and are, in the opinion of the Trustee, necessary to fairly present the results of operations.

As of September 30, 2004 and December 31, 2003, cash equivalents which represent the cash reserve consist of US treasury bills with an initial term of less than three months.

Estimates and assumptions are required to be made regarding assets, liabilities and changes in Trust Corpus resulting from operations when financial statements are prepared. Changes in the economic environment, financial markets and any other parameters used in determining these estimates could cause actual results to differ, and the differences could be material.

The financial statements should be read in conjunction with the financial statements and related notes in the Trust’s 2003 Annual Report on Form 10-K. The cash earnings and distributions for the interim period presented are not necessarily indicative of the results to be expected for the full year.

(3) Royalty Interest

The Royalty Interest is comprised of the following at September 30, 2004 and December 31, 2003 (in thousands):


	September 30,			December 31,
	2004			2003
Royalty Interest (at inception)	$	535,000		$	535,000
Less: Accumulated amortization		(348,929	)		(347,422	)
Impairment write-down		(173,518	)		(173,518	)


Balance, end of period	$	12,553		$	14,060

BP Prudhoe Bay Royalty Trust
Notes to Financial Statements (Unaudited)
(Prepared on a Modified Basis of Cash Receipts and Disbursements)
September 30, 2004

(4) Income Taxes

The Trust files its federal tax return as a grantor trust subject to the provisions of subpart E of Part I of Subchapter J of the Internal Revenue Code of 1986, as amended, rather than as an association taxable as a corporation. The Trust Unit Holders are treated as the owners of Trust income and Corpus, and the entire taxable income of the Trust will be reported by the Trust Unit Holders on their respective tax returns.

If the Trust were determined to be an association taxable as a corporation, it would be treated as an entity taxable as a corporation on the taxable income from the Royalty Interest, the Trust Unit Holders would be treated as shareholders, and distributions to Trust Unit Holders would not be deductible in computing the Trust’s tax liability as an association.

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

Cautionary Statement

The Trustee, its officers or its agents on behalf of the Trustee may, from time to time, make forward-looking statements (other than statements of historical fact). When used herein, the words “anticipates,” “expects,” “believes,” “intends” or “projects” and similar expressions are intended to identify forward-looking statements. To the extent that any forward-looking statements are made, the Trustee is unable to predict future changes in oil prices, oil production levels, economic activity, legislation and regulation, and certain changes in expenses of the Trust. In addition, the Trust’s future results of operations and other forward looking statements contained in this item and elsewhere in this report involve a number of risks and uncertainties. As a result of variations in such factors, actual results may differ materially from any forward looking statements. Some of these factors are described below. The Trustee disclaims any obligation to update forward looking statements and all such forward-looking statements in this document are expressly qualified in their entirety by the cautionary statements in this paragraph.

Liquidity and Capital Resources

The Trust is a passive entity, and the Trustee’s activities are limited to collecting and distributing the revenues from the Royalty Interest and paying liabilities and expenses of the Trust. Generally, the Trust has no source of liquidity and no capital resources other than the revenue attributable to the Royalty Interest that it receives from time to time. See the discussion under “THE ROYALTY INTEREST” for a description of the calculation of the Per Barrel Royalty, and the discussion under “THE PRUDHOE BAY UNIT — Reserve Estimates” and “INDEPENDENT OIL AND GAS CONSULTANTS’ REPORT” in Part I, Item 1 of the Trust’s Annual Report on Form 10-K for the fiscal year ended December 31, 2003, as amended (the “Annual Report”) for information concerning the estimated future net revenues of the Trust. However, the Trustee has a limited power to borrow, establish a cash reserve, or dispose of all or part of the Trust Estate, under limited circumstances pursuant to the terms of the Trust Agreement. See the discussion under “THE TRUST” in Part I, Item 1 of the Annual Report.

The Trustee has established a cash reserve of $1,000,000 to provide liquidity to the Trust during any future periods in which the Trust does not receive a distribution. This amount is equal to approximately one year’s expected liabilities and expenses of the Trust. Amounts set aside for the cash reserve are invested in U.S. government or agency securities secured by the full faith and credit of the United States. The Trustee will draw funds from the cash reserve account during any quarter in which the quarterly distribution received by the Trust does not exceed the liabilities and expenses of the Trust, and will replenish the reserve from future quarterly distributions, if any. The Trustee anticipates that it will keep the cash reserve in place until termination of the Trust.

As discussed under “CERTAIN TAX CONSIDERATIONS” in the Annual Report, amounts received by the Trust as quarterly distributions are income to the holders of the Units, (as will be any earning on investment of the cash reserve) and must be reported by the holders of the Units,

even if such amounts are used to repay borrowings or establish a cash reserve and are not received by the holders of the Units.

Results of Operations

Royalty revenues are generally received on the fifteenth day of the month following the end of the calendar quarter in which the related Royalty Production occurred (the “Quarterly Record Date”). The Trustee, to the extent possible, pays all expenses of the Trust for each quarter on the Quarterly Record Date on which the revenues for the quarter are received. For the statement of cash earnings and distributions, revenues and Trust expenses are recorded on a modified cash basis and, as a result, royalties paid to the Trust and distributions to Unit holders in the quarters ended September 30, 2004 and 2003 are attributable to the Company’s operations during the quarters ended June 30, 2004 and 2003, respectively.

The following table shows the factors for the quarters ended June 30, 2004 and 2003 which were employed to compute the Per Barrel Royalty received by the Trust during the quarters ended September 30, 2004 and 2003 (see Note 1 of Notes to Financial Statements in Part I, Item 1). The information in the table has been furnished by the Company.


	Quarter ended June 30,
	2004				2003
Average WTI Price			$	38.31			$	29.07
Chargeable Costs	$	12.00			$	11.75
Cost Adjustment Factor		1.4561				1.4129
Adjusted Chargeable Costs	$	17.47			$	16.60
Production Taxes	$	4.79			$	3.44

			$	22.26			$	20.04


Per Barrel Royalty			$	16.05			$	9.03

As long as the Company’s average daily net production from the Prudhoe Bay Unit exceeds 90,000 barrels, which the Company currently projects will continue until the year 2013, the only factors affecting the Trust’s revenues and distributions to Unit holders are changes in WTI Prices, scheduled annual increases in Chargeable Costs, changes in the Consumer Price Index, changes in Production Taxes and changes in the expenses of the Trust.

See the discussion under “THE ROYALTY INTEREST” in the Annual Report for a description of the calculation of the Per Barrel Royalty.

Quarter Ended September 30, 2004 Compared to Quarter Ended September 30, 2003

Trust royalty revenues increased by 78% in the quarter ended September 30, 2004 from the corresponding quarter of 2003. The Average WTI price of oil increased by 32% in the quarter ended September 30, 2004 from the quarter ended September 30, 2003. Because Adjusted Chargeable Costs and Production Taxes increased by 11% for the quarter ended September 30,

2004 from the quarter ended September 30, 2003, the period to period percentage increase in the per barrel royalty exceeded the increase in the Average WTI price of oil.

Nine Months Ended September 30, 2004 Compared to
Nine Months Ended September 30, 2003

Trust royalty revenues increased 29% in the nine months ended September 30, 2004 from the corresponding period in 2003. Trust administrative expenses have declined during the first nine months of 2004 from the expenses during the first nine months of 2003 by 27%, primarily due to a one-time $315,360 payment by the Trust during the first quarter of 2003 to BP America Inc., a subsidiary of BP, to reimburse BP America for annual fees paid by BP America to the New York Stock Exchange for listing the Units. Such annual listing fees are payable by the Trust under the terms of the Trust Agreement. The listing fees for the years 1990 through 1999, aggregating $315,360, had been invoiced by the New York Stock Exchange to BP America, which inadvertently paid them on behalf of the Trust and subsequently sought reimbursement when the error was discovered.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

See discussion above under Item 2 — Trustee’s Discussion and Analysis of Financial Condition and Results of Operations.

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 design and operation of the Trust’s disclosure controls and procedures pursuant to Exchange Act Rule 13a-15 and 15d-15. Based on that evaluation, the Trustee concluded that the Trust’s disclosure controls and procedures are effective in timely alerting the Trustee to material information relating to the Trust required to be included in the Trust’s periodic filings with the Securities and Exchange Commission. There has not been any change in the Trust’s internal controls over financial reporting identified in connection with the evaluation required by paragraph (d) of rule 13a-15 or Rule 15d-15 that occurred during the registrant’s last fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Trust’s internal control over financial reporting.

PART II
OTHER INFORMATION

Item 1. Legal Proceedings.

None.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

None.

Item 3. Defaults Upon Senior Securities.

None.

Item 4. Submission of Matters to a Vote of Security Holders.

None.

Item 5. Other Information.

(a) On October 15, 2004 the Trust received a cash distribution of $28,114,318 from the Company with respect to the quarter ended September 30, 2004. On October 18, 2004 the Trust distributed $27,897,502 (approximately $1.3036 per Unit), representing funds available to the Trustee net of Trust expenses, to Unit holders of record on October 14, 2004.

(b) Not applicable.

Item 6. Exhibits.

4.1 BP Prudhoe Bay Royalty Trust Agreement dated February 28, 1989 among The Standard Oil Company, BP Exploration (Alaska) Inc., The Bank of New York, Trustee, and F. James Hutchinson, Co-Trustee.

4.2 Overriding Royalty Conveyance dated February 27, 1989 between BP Exploration (Alaska) Inc. and The Standard Oil Company.

4.3 Trust Conveyance dated February 28, 1989 between The Standard Oil Company and BP Prudhoe Bay Royalty Trust.

4.4 Support Agreement dated as of February 28, 1989 among The British Petroleum Company p.l.c., BP Exploration (Alaska) Inc., The Standard Oil Company and BP Prudhoe Bay Royalty Trust.

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

32 Section 1350 Certification.

SIGNATURE

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.

Date: November 5, 2004

The registrant is a trust and has no officers or persons performing similar functions. No additional signatures are available and none have been provided.

INDEX TO EXHIBITS


Exhibit No.		Exhibit Description

*4.1		BP Prudhoe Bay Royalty Trust Agreement dated February 28, 1989 among The Standard Oil Company, BP Exploration (Alaska) Inc., The Bank of New York, Trustee, and F. James Hutchinson, Co-Trustee.

*4.2		Overriding Royalty Conveyance dated February 27, 1989 between BP Exploration (Alaska) Inc. and The Standard Oil Company.

*4.3		Trust Conveyance dated February 28, 1989 between The Standard Oil Company and BP Prudhoe Bay Royalty Trust.

*4.4		Support Agreement dated as of February 28, 1989 among The British Petroleum Company p.l.c., BP Exploration (Alaska) Inc., The standard Oil Company and BP Prudhoe Bay Royalty Trust.

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

32		Section 1350 Certification.

Incorporated by reference to the correspondingly numbered exhibit to the registrant’s Annual Report on Form 10-K for the fiscal year ended December 31, 1996 (Commission File No. 1-10243).

(1)		Formation of the Trust and Organization

		BP Prudhoe Bay Royalty Trust (the “Trust”), a grantor trust, was created as a Delaware business trust pursuant to a Trust Agreement dated February 28, 1989 among the Standard Oil Company (“Standard Oil”), BP Exploration (Alaska) Inc. (the “Company”), The Bank of New York (The “Trustee”) and The Bank of New York (Delaware), as co-trustee. Standard Oil and the Company are indirect wholly owned subsidiaries of the BP p.l.c. (“BP”).

		Effective January 1, 2000, the Company and all other Prudhoe Bay working interest owners cross-assigned interests in the Prudhoe Bay Field pursuant to the Prudhoe Bay Unit Alignment Agreement. The Company retained all rights, obligations, and liabilities associated with the Trust. This transaction is not expected to have a material effect on the Trust’s operation.

		On February 28, 1989, Standard Oil conveyed an overriding royalty interest (the “Royalty Interest”) to the Trust. The Trust was formed for the sole purpose of owning and administering the Royalty Interest. The Royalty Interest represents the right to receive, effective February 28, 1989, a per barrel royalty (the “Per Barrel Royalty”) of 16.4246% on the lesser of (a) the first 90,000 barrels of the average actual daily net production of oil and condensate per quarter or (b) the average actual daily net production of oil and condensate per quarter from the Company’s working interest in the Prudhoe Bay Field (the “Field”) as of February 28, 1989, located on the North Slope of Alaska. Trust Unit holders will remain subject at all times to the risk that production will be interrupted or discontinued or fall, on average, below 90,000 barrels per day in any quarter. BP has guaranteed the performance of the Company of its payment obligations with respect to the Royalty Interest.

		The trustees of the Trust are The Bank of New York, a New York corporation authorized to do a banking business, and The Bank of New York (Delaware), a Delaware banking corporation. The Bank of New York (Delaware) serves as co-trustee in order to satisfy certain requirements of the Delaware Trust Act. The Bank of New York alone is able to exercise the rights and powers granted to the Trustee in the Trust Agreement.

		The Per Barrel Royalty in effect for any day is equal to the price of West Texas Intermediate crude oil (the “WTI Price”) for that day less scheduled Chargeable Costs (adjusted in certain situations for inflation) and Production Taxes (based on statutory rates then in existence). For years subsequent to 2006, Chargeable Costs will be reduced up to a maximum amount of $1.20 per barrel in each year if additions to the Field’s proved reserves do not meet certain specific levels.

		The Trust is passive, with the Trustee having only such powers as are necessary for the collection and distribution of revenues, the payment of Trust liabilities, and the protection of the Royalty Interest. The Trustee, subject to certain conditions, is obligated to establish cash

	a.		On or prior to December 31, 2010: upon a vote of Trust Unit Holders of not less than 70% of the outstanding Trust Units.

	b.		After December 31, 2010: (i) upon a vote of Trust Unit Holders of not less than 60% of the outstanding Trust Units, or (ii) at such time the net revenues from the Royalty Interest for two successive years commencing after 2010 are less than $1,000,000 per year (unless the net revenues during such period are materially and adversely affected by certain events).

		In order to ensure the Trust has the ability to pay future expenses, the Trust established a cash reserve account which the Trustee believes is sufficient to pay approximately one year’s current and expected liabilities and expenses of the Trust.

(2)		Basis of Accounting

		The financial statements of the Trust are prepared on a modified cash basis and reflect the Trust’s assets, liabilities, Corpus, earnings, and distributions, as follows:

	a.		Revenues are recorded when received (generally within 15 days of the end of the preceding quarter) and distributions to Trust Unit Holders are recorded when paid.

	b.		Trust expenses (which include accounting, engineering, legal, and other professional fees, trustees’ fees, and out-of-pocket expenses) are recorded on an accrual basis.

	c.		Amortization of the Royalty Interest is calculated based on the units of production method. Such amortization is charged directly to the Trust Corpus, and does not affect cash earnings. The daily rate for amortization per net equivalent barrel of oil for the three and nine months ended September 30, 2004 and 2003 was $0.37. The Trust evaluates impairment of the Royalty Interest by comparing the undiscounted cash flows expected to be realized from the Royalty Interest to the carrying value, pursuant to Statement of Financial Accounting Standards No. 144, “Accounting for the Impairment or Disposal of Long-Lived Assets” (“SFAS 144”). If the expected future undiscounted cash flows are less than the carrying value, the Trust recognizes an impairment loss for the difference between the carrying value and the estimated fair value of the Royalty Interest.

		While these statements differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America, the modified cash basis of reporting revenues and distributions is considered to be the most meaningful because quarterly distributions to the Trust Unit Holders are based on net cash receipts. The accompanying modified cash basis financial statements contain all adjustments necessary to present fairly the assets, liabilities and Corpus of the Trust as of September 30, 2004 and December 31, 2003 and the modified cash earnings and distributions and changes in Trust Corpus for the three-month and nine-month periods ended September 30, 2004 and 2003. The adjustments are of a normal recurring nature and are, in the opinion of the Trustee, necessary to fairly present the results of operations.

		As of September 30, 2004 and December 31, 2003, cash equivalents which represent the cash reserve consist of US treasury bills with an initial term of less than three months.

		Estimates and assumptions are required to be made regarding assets, liabilities and changes in Trust Corpus resulting from operations when financial statements are prepared. Changes in the economic environment, financial markets and any other parameters used in determining these estimates could cause actual results to differ, and the differences could be material.

		The financial statements should be read in conjunction with the financial statements and related notes in the Trust’s 2003 Annual Report on Form 10-K. The cash earnings and distributions for the interim period presented are not necessarily indicative of the results to be expected for the full year.

(3)		Royalty Interest

		The Royalty Interest is comprised of the following at September 30, 2004 and December 31, 2003 (in thousands):

(4)		Income Taxes

		The Trust files its federal tax return as a grantor trust subject to the provisions of subpart E of Part I of Subchapter J of the Internal Revenue Code of 1986, as amended, rather than as an association taxable as a corporation. The Trust Unit Holders are treated as the owners of Trust income and Corpus, and the entire taxable income of the Trust will be reported by the Trust Unit Holders on their respective tax returns.

		If the Trust were determined to be an association taxable as a corporation, it would be treated as an entity taxable as a corporation on the taxable income from the Royalty Interest, the Trust Unit Holders would be treated as shareholders, and distributions to Trust Unit Holders would not be deductible in computing the Trust’s tax liability as an association.