UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

EASTERN AMERICAN NATURAL GAS TRUST

(Exact name of registrant as specified in its charter)

The Bank of New York
Care of BNY Midwest Trust Company
2 North Lasalle Street
Chicago, Illinois 60602

(Address of principal executive offices)

(Zip Code)

(312) 827-8500

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days.

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act).

PART I – FINANCIAL INFORMATION

ITEM 1.   Financial Statements

EASTERN AMERICAN NATURAL GAS TRUST

CONDENSED STATEMENTS OF DISTRIBUTABLE INCOME

(Unaudited)

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

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EASTERN AMERICAN NATURAL GAS TRUST

CONDENSED STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS

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

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EASTERN AMERICAN NATURAL GAS TRUST

CONDENSED STATEMENTS OF CHANGES IN TRUST CORPUS

(Unaudited)

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

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EASTERN AMERICAN NATURAL GAS TRUST

NOTES TO UNAUDITED CONDENSED FINANCIAL STATEMENTS

NOTE 1. Organization of the Trust

The Eastern American Natural Gas Trust (the “Trust”) was formed under the Delaware Business Trust Act pursuant to a Trust Agreement (the “Trust Agreement”) among Eastern American Energy Corporation (“Eastern American”), as grantor, Bank of Montreal Trust Company, as Trustee (“Trustee”), and Wilmington Trust Company, as Delaware Trustee (the “Delaware Trustee”).  Effective May 8, 2000, The Bank of New York acquired the corporate trust business of the then current Trustee and consequently is currently serving as Trustee.

The Trust was formed to acquire and hold net profits interests (the “Net Profits Interests”) created from the working interests owned by Eastern American in 650 producing gas wells and 65 proved development well locations (the “Development Wells”) in West Virginia and Pennsylvania (the “Underlying Properties”).

On March 15, 1993, 5,900,000 Depositary Units were issued in a public offering at an initial public offering price of $20.50 per Depositary Unit.  Each Depositary Unit consists of beneficial ownership of one unit of beneficial interest (“Trust Unit”) in the Trust and a $20 face amount beneficial ownership interest in a $1,000 face amount zero coupon United States Treasury Obligation (“Treasury Obligation”) maturing on May 15, 2013.  The financial statements of the Trust to which these notes relate do not incorporate information concerning the Treasury Obligations, the beneficial interest in which is held for the Unitholders by the Depositary.

The Net Profits Interests are passive in nature, and neither the Trustee nor the Delaware Trustee has management control or authority over, nor any responsibility relating to, the operation of the properties subject to the Net Profits Interests.  The Trust Agreement provides, among other things, that the Trust shall not engage in any business or commercial activity or acquire any asset other than the Net Profits Interests initially conveyed to the Trust; the Trustee may establish a reserve for payment of any liability that is contingent, uncertain in amount or is not currently due and payable; the Trustee is authorized to borrow funds required to pay liabilities of the Trust, provided that such borrowings are repaid in full prior to further distributions to Unitholders; and the Trustee will make quarterly cash distributions to Unitholders from funds of the Trust.

After the Trust was formed, 59 of the 65 Development Wells were drilled and completed. The remaining six Development Wells were not drilled. Clear title to two of the Development Wells could not be established, and they were excluded from the Trust in accordance with the conveyance transferring them to the Trust. Eastern American asserted the remaining four undrilled Development Wells, if drilled, would be too close to then existing wells on the property or an adjoining property, and thereafter settled its dispute with the Trust about drilling those four Development Wells by agreeing instead to pay the Trust annually for the annual volume of gas projected to be produced from those Development Wells as if they had been drilled.

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The Net Profits Interests initially consisted of a royalty interest (“Royalty NPI”) in 322 wells and a term interest (“Term NPI”) in the remaining wells and locations. As of September 30, 2004, the Trust held Net Profits Interests in 672 wells, consisting of Royalty NPI in 317 wells and Term NPI in the remaining wells. The Term NPI expire by their terms on May 15, 2013, or such earlier time as 41,683 MMcf of gas has been produced that is attributable to Eastern American’s net revenue interest in the properties burdened by the Term NPI. As of December 31, 2003, based on the Independent Petroleum Engineer’s Report, 19,548 MMcf of the maximum 41,683 MMcf has been produced.

Between May 15, 2012, and May 15, 2013 (the “Liquidation Date”), the Trustee is required to sell all the Royalty NPI and liquidate the Trust. Under the Trust Agreement, Eastern American has the right of first refusal to purchase any of the Royalty NPI the Trustee is required to sell after the Liquidation Date. If it exercises this right, Eastern American must pay the appraised Fair Value (as defined in the Trust Agreement) of the Royalty NPI, or the relevant third party offer price if a third party has offered to purchase the Royalty NPI. Unitholders of record on the relevant record dates will receive the net proceeds from selling the Royalty NPI in accordance with the Trust Agreement, and also will receive their respective share of the matured face amount of the Treasury Obligations held by the Depositary.

NOTE 2.  Basis of Presentation

The information furnished is based upon certain estimates of production for the periods presented and is therefore subject to adjustment in future periods to reflect actual production for the periods presented.  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 accompanying financial statements are unaudited interim financial statements, and should be read in conjunction with the audited financial statements and notes thereto included in the Trust’s Annual Report on Form 10-K, as amended, for the year ended December 31, 2003.

NOTE 3.  Trust Accounting Policies

The Trust serves as a pass-through entity, with items of depletion, interest income and expense, and income tax attributes being based upon the status and elections of Unitholders.  Thus, the Statements of Distributable Income show Distributable Income, defined as Trust income available for distribution to Unitholders subject to Trustees Cash Reserves described in Part I, Item 2 before application of those Unitholders’ additional expenses, if any, for depletion, interest expense, and income taxes.  The Trust uses the accrual basis to recognize revenue, with Royalty Income recognized as reserves are extracted from properties and sold.  Expenses are also presented on an accrual basis.  Actual cash receipts will vary from the accrual of revenues due to, among other reasons, the payment provisions of the gas purchase contract between the Trust and Eastern Marketing Corporation  (a subsidiary of Eastern American), which requires payment with respect

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to gas production for a calendar quarter to be made to the Trust on or before the tenth day of the third month following such quarter.

The Net Profits Interests are assessed annually to determine whether their net capitalized cost is impaired.  The Trust will determine if a writedown is necessary to its investment in the Net Profits Interests in gas properties to the extent that total capitalized costs, less accumulated amortization, exceed undiscounted future net revenues attributable to proved gas reserves of the Underlying Properties.  The Trust will then provide a writedown to the extent that the net capitalized costs exceed the discounted future net revenues attributable to proved gas reserves of the Underlying Properties.   Any such writedown would not reduce distributable income, although it would reduce Trust Corpus.

Amortization of the Net Profits Interests in Gas Properties is calculated on a units-of-production basis, whereby the Trust’s cost basis in the properties is divided by total Trust proved reserves to derive an amortization rate per reserve unit.  Such amortization does not reduce distributable income, rather it is charged directly to Trust Corpus.

The financial statements of the Trust differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America due to the following; i) certain cash reserves may be established for contingencies which were not accrued in the financial statements; ii) amortization of the Net Profits Interests in gas properties is charged directly to Trust Corpus; and iii) the sale of the Net Profits Interests is reflected in the Statements of Distributable Income as cash proceeds to the Trust.

NOTE 4. Income Taxes

The Trust is a grantor trust and is not required to pay federal or state income taxes.  Accordingly, no provision for federal or state income taxes has been made.  All income is taxed to the Unitholders of the Trust.

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ITEM 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations

Cautionary Statement

The Trust, the Trustee and Eastern American, its officers or its agents on behalf of the Trust 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, neither the Trust, the Trustee or Eastern American is able to predict future changes in gas prices, gas 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 Trust, the Trustee and Eastern American disclaim any obligations 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 and by the statements in the Annual Report on Form 10-K.

General

The Trust does not conduct any operations or activities.  The Trust’s purpose is, in general, to hold the Net Profits Interests, to distribute the cash proceeds to Unitholders which the Trust receives in respect of the Net Profits Interests (net of Trust expenses), and to perform certain administrative functions in respect of the Net Profits Interests and the Depositary Units.  Accordingly, the Trust derives substantially all of its income and cash flows from the Net Profits Interests.  The Trust has no source of liquidity or capital resources other than the cash flows from the Net Profits Interests.

The Net Profits Interests were created pursuant to conveyances (the “Conveyances”) from Eastern American to the Trust.  In connection therewith, Eastern American assigned its rights under a gas purchase contract (the “Gas Purchase Contract”) which obligates Eastern Marketing Corporation, a subsidiary of Eastern American, to purchase all of the natural gas produced from the Underlying Properties that is attributable to the Net Profits Interests.

The Conveyances and the Gas Purchase Contract entitle the Trust to receive an amount of cash for each calendar quarter equal to the Net Proceeds for such quarter.  “Net Proceeds” for any calendar quarter generally means an amount of cash equal to (a) 90% of a volume of gas equal to (i) the volume of gas produced during such quarter attributable to the Underlying Properties less (ii) a volume of gas equal to “Chargeable Costs” for such quarter, multiplied by (b) the applicable price for such quarter under the Gas Purchase Contract.  “Chargeable Costs” is that volume of gas which equates in value, determined by reference to the relevant sales price under the Gas Purchase Contract or the Conveyances, as applicable, to the sum of the “Operating Cost Charge”, “Capital Costs” and “Taxes”.

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The “Operating Cost Charge” for 2004 is based on an annual rate of $521,340, and for 2003 was an annual rate of $510,444.  As provided in the Conveyances, the Operating Cost Charge will fluctuate based on the lesser of (A) five percent (5%) or (B) a percentage, not less than zero percent (0%), equal to the percentage increase, if any, in the average weekly earnings of Crude Petroleum and Gas Production Workers for the last calendar year, as shown by the index of average weekly earnings of Crude Petroleum and Gas Production Workers, as published by the United States Department of Labor, Bureau of Labor Statistics, based on December-to-December comparison.  During 2003, the United States Department of Labor, Bureau of Labor Statistics converted all of its industry-based statistics to a different reporting system that was developed in cooperation with the United States’ North American Free Trade Agreement Partners, Canada and Mexico, in an effort to standardize and modernize reporting codes.  As a result of this conversion, the Crude Petroleum and Gas Production Workers index is no longer available for use in the annual calculation of overhead adjustment called for in the various Council of Petroleum Accountants Societies, or COPAS, model forms after March 2003.

Research by COPAS covering the past ten years indicated that by blending the Oil and Gas Extraction Index with the Professional and Technical Services Index, the results approximate the data from the old Crude Petroleum and Natural Gas Workers Index.  Accordingly, COPAS has calculated the percentage change in the simple average of the Oil and Extraction Index and the Professional and Technical Services Index, commencing in April 2004.  This “Overhead Adjustment Index” has been provided as a guidance to the industry as a replacement index for use in calculating the overhead adjustment.  The adjustment for the effective time period is 2.3%.  Since the Conveyance Documents do not specifically provide for a replacement index if the Crude Petroleum and Gas Production Workers Index was no longer published, Eastern American believes, and advised the Trustee, that the “Overhead Adjustment Index” as calculated by COPAS is a reasonable index to utilize since the industry is generally adopting the same as a replacement.  Eastern American, with the concurrence of the Trustee, will utilize this “Overhead Adjustment Index” to adjust the “Operating Cost Charge” so long as such index is published by COPAS.  The Operating Cost Charge was not increased as Development Wells were completed but is reduced for each well that is sold (free of the Net Profits Interests) or plugged and abandoned.  “Capital Costs” means Eastern American’s working interest share of capital costs for operations on the Underlying Properties, but only for items having a useful life of at least three years, and not including any capital costs incurred in drilling the Development Wells.  “Taxes” means ad valorem taxes, production and severance taxes, and other taxes imposed on the Trust’s interest in the Underlying Properties, or production therefrom.

Pursuant to the Gas Purchase Contract, Eastern Marketing is obligated to purchase such gas production at a purchase price per Mcf equal to the Index Price.  The Index Price for any quarter is determined solely by reference to the Variable Price component.  The Variable Price for any quarter is equal to the Henry Hub Average Spot Price (as defined) per MMBtu plus $0.30 per MMBtu, multiplied by 110% to effect a fixed adjustment for Btu content.  The Henry Hub Average Spot Price is defined as the price per MMBtu determined for any calendar quarter equal to the price obtained with respect to each of the three months in such quarter, in the manner specified below, and then taking the average of the prices determined for each of such three months.  The price determined for

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any month of such quarter is equal to the average of (i) the final settlement price per MMBtu for Henry Hub Gas Futures Contracts (as defined), as reported in The Wall Street Journal, for such contracts which expired in each of the five months prior to such month, (ii) the final settlement price per MMBtu for Henry Hub Gas Futures Contracts, as reported in The Wall Street Journal, for such contracts which expire during such month and (iii) the closing settlement price per MMBtu of Henry Hub Gas Futures Contracts determined as of the contract settlement date for such month, as reported in The Wall Street Journal, for such contracts which expire in each of the six months following such month.  A Henry Hub Gas Futures Contract is defined as a gas futures contract for gas to be delivered to the Henry Hub that is traded on the New York Mercantile Exchange.

Accordingly, the Index Price payable to the Trust for production may be higher or lower based on the fluctuations in natural gas futures prices during the relevant calculation period.  The price payable to the Trust will have a direct impact, positively or negatively, on the quarterly distributions payable by the Trust to its unit holders.

Eastern American had a disagreement with the Trust over Eastern American’s obligation to drill certain Development Wells that were closely offset by third parties.  The Trust agreed that in lieu of drilling these closely offset Development Wells that Eastern American could provide the Trust, on an annual basis commencing on April 1, 1997, and over the remaining life of the Trust, a volume of gas which is equal to the projected volumes of the wells as if they had been drilled.  These volumes have been estimated by Ryder Scott Company, independent petroleum engineers.  During the quarter ended September 30, 2004, an additional volume of 4,457 Mcf was delivered to the Trust, as compared to 4,822 Mcf for the quarter ended September 30, 2003.  These additional volumes fulfill Eastern American’s obligation to provide volumes for Development Wells that had been closely offset by third parties.

Eastern American has fulfilled its obligation with respect to the drilling of the Development Wells. Since the inception of the Trust, Eastern has drilled a total of 59 Development Wells, which are online and producing.  (See the Trust’s Form 10-K, as amended, for the fiscal year ended December 31, 2003 for a more complete description of the Development Wells.)

During the quarter ended March 31, 2003, a Coal Lessee contacted Eastern American and inquired as to whether it would sell the U.S. Steel Well # 26, which is a well in which the Trust owns a Net Profits Interests.  The Coal Lessee stated that the well would materially interfere with the Coal Lessee’s proposed mining operations.  Eastern American reviewed the Trust Agreement and production from this well to determine if it could cause the Trust to sell its Net Profits Interest in the well.  Upon review, it was discovered that the Net Profits Interests associated with the U.S. Steel #26 well accounted for less than 0.25% of the total production from the Underlying Properties for the prior twelve (12) month period.  Eastern American advised the Coal Lessee that it could sell this well.  Eastern American received $11,437 for the sale of the U.S Steel Well #26.  The effective date of the sale was March 1, 2003.  However, the transaction did not close until April 17, 2003.  Therefore, the Trust’s share of the proceeds of $10,293 was included in the Distributable Income of the Trust during the quarter ended June 30, 2003.

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During the quarter ended June 30, 2004, an oil and gas company contacted Eastern American and inquired as to whether it would sell certain assets situated in Centre County, Pennsylvania including the Horne #1, Horne #2 and Horne #15 wells (the Horne Underlying Properties), which are wells in which the Trust owns a Net Profits Interests.  Eastern American reviewed the Trust Agreement and certified to the Trustee that:  (i) the gross purchase price to be received by Eastern American for the sale of the Horne Underlying Properties in a single transaction or a series of related transactions is less than $500,000; (ii) the Assignee of the Horne Underlying Properties is not an Affiliate of Eastern American; (iii) the aggregate sale proceeds of $80,205 to be received by the Trust from Eastern American (the Trust’s Horne Sale Proceeds) represents the fair value to the Trust for Net Profits Interests to be released by the Trustee in connection with Eastern American’s sale of the Horne Underlying Properties; and (iv) the Trust’s Horne Sale Proceeds plus the aggregate sale proceeds received by the Trust pursuant to Section 3.02(b)(ii) of the Trust Agreement with respect to all other Net Profits Interests previously released by the Trustee pursuant to Section 3.02(b) during the most recently completed twelve calendar months does not exceed Five Hundred Thousand and 00/100 Dollars ($500,000).  Eastern American advised the oil and gas company that it could sell these wells.  The effective date of the sale was May 1, 2004.  The Trust’s share of the proceeds of $80,205 was included in the Distributable Income of the Trust during the quarter ending June 30, 2004.

Over the remaining life of the Trust, additional wells may be disposed of for similar reasons.

Critical Accounting Policies

The following is a summary of the critical accounting policies followed by the Trust.

Basis of Accounting:

The financial statements of the Trust differ from financial statements prepared in accordance with accounting principles generally accepted in the United States of America due to the following; i) certain cash reserves may be established for contingencies which were not accrued in the financial statements; ii) amortization of the Net Profits Interests in gas properties is charged directly to Trust Corpus; and iii) the sale of the Net Profits Interests is reflected in the Statements of Distributable Income as cash proceeds to the Trust.

Net Profits Interests in Gas Properties:

The Net Profits Interests in gas properties are periodically assessed to determine whether their net capitalized cost is impaired.  The Trust will determine if a writedown is necessary to its investment in the Net Profits Interests in gas properties to the extent that total capitalized costs, less accumulated amortization, exceed undiscounted future net revenues attributable to proved gas reserves of the Underlying Properties.  The Trust will then provide a writedown to the extent that the net capitalized costs exceed the discounted future net revenues attributable to proved gas reserves of the Underlying Properties.  Any such writedown would not reduce distributable income, although it would reduce Trust Corpus.

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Amortization of the Net Profits Interests in gas properties is calculated on a units-of-production basis, whereby the Trust’s cost basis in the properties is divided by total Trust proved reserves to derive an amortization rate per reserve unit.  Such amortization does not reduce distributable income, rather it is charged directly to Trust Corpus.  Revisions to estimated future units-of-production are treated on a prospective basis beginning on the date significant revisions are known.

The Net Profits Interest impairment test and the determination of amortization rates are dependent on estimates of proved gas reserves attributable to the Trust.  Numerous uncertainties are inherent in estimating reserve volumes and values, including economic and operating conditions, and such estimates are subject to change as additional information becomes available.

Liquidity and Capital Resources

The Trust has no source of liquidity or capital resources other than the distributions received from the Net Profits Interests.

In accordance with the provisions of the Conveyances, generally all revenues received by the Trust, net of Trust administrative and operating expenses and the amount of established reserves, are distributed currently to the Unitholders.

The Trust did not have any contractual obligations as of September 30, 2004.  At September 30, 2004, the Trust had accounts payable of $211,495 and distributions payable of $2,849,395.

Comparison of Results of Operations for Three Months Ended September 30, 2004 and Three Months Ended September 30, 2003

The Trust’s distributable income was $2,849,395 for the three months ended September 30, 2004 as compared to $3,014,259 for the three months ended September 30, 2003.  This decrease was due to a decrease in Royalty Income for the three months ended September 30, 2004 ($3,452,442) as compared to the three months ended September 30, 2003 ($3,521,454).  The decrease in Royalty Income was due to a decrease in production of gas attributable to the Net Profits Interests for the three months ended September 30, 2004 (485 Mmcf) as compared to the three months ended September 30, 2003 (552 Mmcf).  This decrease in production was offset by an increase in the price payable to the Trust under the Gas Purchase Contract as discussed below ($7.106 per Mcf for the three months ended September 30, 2004; $6.381 per Mcf for the three months ended September 30, 2003).  The decline in production is primarily attributable to natural production declines and the sale of wells.  Taxes on production and property were $232,004 for the three months ended September 30, 2004 as compared to $239,370 for the three months ended September 30, 2003. The decrease in taxes is due directly to the decrease in Royalty Income as discussed above.  Trust general and administrative expenses were $242,168 for the three months ended September 30, 2004 as compared to $140,679 for the three months ended September 30, 2003.  This increase in general and administrative expense was due primarily to an increase in legal fees of $79,716, due to additional

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filings, press releases, costs associated with the implementation of Section 404 of Sarbanes-Oxley Act of 2002 (“Sarbanes-Oxley”) and work associated in connection with a proxy solicitation to approve the selection of a successor trustee for the Trust.  Also, an increase in additional administrative expenses of $15,269 occurred due to additional costs associated with the implementation of Section 404 of Sarbanes-Oxley Act of 2002.

The price payable to the Trust for gas production attributable to the Net Profits Interests was $7.106 per Mcf for the three months ended September 30, 2004 and $6.381 per Mcf for the three months ended September 30, 2003.  The price per Mcf was higher for the three months ended September 30, 2004 than for the corresponding three month period ended September 30, 2003 due to an increase in the average spot market price for gas delivered at the Henry Hub near Henry, Louisiana ($6.160 per Dth for the three months ended September 30, 2004; $5.501 per Dth for the three months ended September 30, 2003).

Comparison of Results of Operations for Nine Months Ended September 30, 2004 and Nine Months Ended September 30, 2003

The Trust’s distributable income was $8,379,863 for the nine months ended September 30, 2004 as compared to $8,430,614 for the nine months ended September 30, 2003.  The Trust’s distributable amount was $8,279,863 for the nine months ended September 30, 2004 compared to $8,315,614 for the nine months ended September 30, 2003.  The difference in distributable income and distributable amount is due to the cash reserve established during the nine months ended September 30, 2003 to facilitate the payment of vendor invoices on a timely basis.  During the nine months ended September 30, 2004, the Trustee added an additional $100,000 to the reserve as compared to $115,000 for the nine months ended September 30, 2003.  The decrease in distributable income was due to a decrease in Royalty Income for the nine months ended September 30, 2004 ($10,024,331) as compared to the nine months ended September 30, 2003 ($10,165,525).  The decrease in Royalty Income was due to a decrease in production of gas attributable to the Net Profits Interests for the nine months ended September 30, 2004 (1,508 Mmcf) as compared to the nine months ended September 30, 2003 (1,635 Mmcf).  This decrease was offset by an increase in the average price payable to the Trust under the Gas Purchase Contract as discussed below ($6.645 per Mcf for the nine months ended September 30, 2004; $6.207 per Mcf for the nine months ended September 30, 2003).  The decline in production is primarily attributable to natural production declines and the sale of wells.  Taxes on production and property were $683,658 for the nine months ended September 30, 2004 as compared to $692,070 for the nine months ended September 30, 2003.  The decrease in taxes is due directly to the decrease in Royalty Income as discussed above.    The distributable income includes Cash Proceeds on Sale of Net Profits Interests of $80,205 for the nine months ended September 30, 2004, while $10,293 was recognized in the corresponding nine months of the prior year.  Amortization of Net Profits Interests in Gas Properties was $2,785,090 for the nine months ended September 30, 2004 as compared to $3,065,998 for the nine months ended September 30, 2003.  This decrease was primarily due to the decrease in production volumes.

The average price payable to the Trust for gas production attributable to the Net Profits Interests was $6.645 per Mcf for the nine months ended September 30, 2004 and $6.207 per Mcf for the nine

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months ended September 30, 2003.  The price per Mcf was higher for the nine months ended September 30, 2004 than for the corresponding nine month period ended September 30, 2003 due to an increase in the average spot market price for gas delivered at the Henry Hub near Henry, Louisiana ($5.741 per Dth for the nine months ended September 30, 2004; $5.342 per Dth for the nine months ended September 30, 2003).

Off-Balance Sheet Arrangements

The Trust does not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on the Trust’s financial condition, changes in financial condition, revenue or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors.

ITEM 3.  Quantitative and Qualitative Disclosures about Market Risk

The Trust does not engage in any operations, and does not utilize market risk sensitive instruments, either for trading purposes or for other than trading purposes.  As described elsewhere herein, the Depositary Units consist of beneficial ownership of one unit of beneficial interest in the Trust and a $20 face amount beneficial ownership interest in a $1,000 face amount zero coupon Treasury Obligation maturing on May 15, 2013.  High and low price information for the Treasury Obligations is included under Part II Item 5.  As described elsewhere herein, gas production attributable to the Net Profits Interest is sold to a wholly owned subsidiary of Eastern American pursuant to the Gas Purchase Contract described herein.

ITEM 4.  Controls and Procedures

Evaluation of Disclosure Controls and Procedures.  The Trustee maintains disclosure controls and procedures designed to ensure that information required to be disclosed by the Trust in the reports that it files or submits under the Securities Exchange Act of 1934, as amended, is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and regulations.  Disclosure controls and procedures include controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Trust is accumulated and communicated by several parties, including without limitation, the working interest owner, Eastern American Energy Corporation (“Eastern American”), and the independent reserve engineer to The Bank of New York, 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 September 30, 2004, the Trustee carried out an evaluation of the Trustee’s disclosure controls and procedures.  Patrick Tadie, a Vice President of the Trustee, has concluded that the controls and procedures are effective at the reasonable assurance level, while noting certain limitations on disclosure controls and procedures as set forth below.

Due to the contractual arrangements of (i) the Trust Agreement, and (ii) the rights of the Trustee under the Conveyances regarding information furnished by Eastern American, there are

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certain potential weaknesses that may limit the effectiveness of disclosure controls and procedures established by the Trustee or its employees and their ability to verify the accuracy of certain financial information.  The contractual limitations creating potential weaknesses in disclosure controls and procedures may be deemed to include:

•      Eastern American and its consolidated subsidiaries manage (i) historical operating data, including production volumes, marketing of products, operating and capital expenditures, environmental and other liabilities, the effects of regulatory changes and the number of producing wells and acreage, (ii) plans for future operating and capital expenditures and (iii) geological data relating to reserves.  While the Trustee requests material information for use in periodic reports as part of its disclosure controls and procedures, the Trustee does not manage this information, and relies entirely on Eastern American to provide accurate and timely information when requested for use in the Trust’s reports.

•      Under the terms of the Trust Agreement, the Trustee is entitled to, and in fact does, rely upon certain experts in good faith, including (i) the independent reserve engineer with respect to the annual reserve report, which includes projected production, operating expenses and capital expenses, and (ii) the independent auditors the Trustee has contracted with respect to the annual audit and quarterly reviews of financial data provided by Eastern American.  Other than contracting independent auditors and reviewing the financial and other information provided to the Trust by Eastern American on a quarterly basis, the Trustee makes no independent or direct verification of this financial or other information. While the Trustee has no reason to believe its reliance upon experts is unreasonable, this reliance on experts and restricted access to information may be viewed as a weakness.

The Trustee does not intend to expand its responsibilities beyond those permitted or required by the Trust Agreement and those required under applicable law.

Changes in Internal Controls

To the knowledge of the Trustee, there have been no significant changes in the Trust’s internal controls that could significantly affect the Trust’s internal controls subsequent to the date the Trustee completed its evaluation.  The Trustee notes for purposes of clarification that it has no authority over, and makes no statement concerning, the internal controls of Eastern American.

PART II – OTHER INFORMATION

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For the calendar quarter ended September 30, 2004, the high and low closing prices of the Treasury Obligations (which have $1,000 face principal amount), as quoted in the over-the-counter market for United States Treasury obligations were $704.20 and $660.00 respectively.  On September 30, 2004 the closing price of the Treasury Obligations, as quoted on such market, was $696.90.

The Trust provides Unitholders with the option to separate the related Treasury Obligation from the Trust Units.  Upon exercising this option, the Trustee transfers such Trust Units from the name of the Depositary to the name of the withdrawing Unitholder.  As of September 30, 2004, this option was exercised on 119,900 Trust Units.  (See the Trust’s 10-K, as amended, for the fiscal year ended December 31, 2003 for a more complete description of the Withdrawal of Trust Units and Restriction on Transfer.)

The Bank of New York has given notice of its intention to resign as Trustee and Depositary for the Eastern American Natural Gas Trust in accordance with (1) the Second Amended and Restated Trust Agreement of Eastern American Natural Gas Trust pursuant to which the Eastern American Natural Gas Trust was formed (the “Trust Agreement”) and (2) the Depositary Agreement (the “Depositary Agreement”) under which Trust Units and Treasury Obligations (as defined in the Trust Agreement) are held for Trust Unitholders. Proxy materials for the appointment of a successor trustee at a meeting of Trust Unitholders on November 30, 2004 were mailed to Trust Unitholders on or before October 5, 2004.  If Trust Unitholders approve the appointment of the successor trustee, the resignation of The Bank of New York and the appointment of the successor trustee will take effect on January 1, 2005.  The successor trustee will also replace The Bank of New York as depositary.

On May 14, 2004, the Trust filed an amended annual report on Form 10-K for the year ended December 31, 2003.  The amended annual report corrected the gas volume estimates of net proved reserves attributable to the Trust’s royalty and term net profits interests that were previously provided to the Trust and reported in the Trust’s annual report.  The Trust was informed by the independent petroleum consultant who provided the Trust with the gas reserve information reported in the Trust’s 2003 annual report that the information was incorrect.  The filing of the amended annual report followed the Trust’s receipt of corrected estimates from the independent petroleum consultant upon completion of that consultant’s review.

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ITEM 6.   Exhibits.

(a)

*      Incorporated by reference to the indicated exhibits to filings previously made by the registrant with the Securities and Exchange Commission.  All references are to the registrant’s Registration Statement on Form S-1, Registration No. 33-56336, except for Exhibit 3.1, which is incorporated by reference to the Registrant’s Annual report on Form 10-K for the year ended December 31, 1994.

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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.

Date:  November 8, 2004

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

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