UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(MARK ONE)
[X] QUARTERLY REPORT UNDER SECTION 13 OR 15 (D)
OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE QUARTERLY PERIOD ENDED JUNE 30, 1999
OR
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (D)
OF THE SECURITIES EXCHANGE ACT OR 1934
[ ] FOR THE TRANSITION PERIOD FROM __________ TO __________
Commission File Number 1-11748
EASTERN AMERICAN NATURAL GAS TRUST
(Exact name of registrant as specified in its charter)
Delaware 36-7034603
(State or other jurisdiction (I.R.S. Employer
of incorporation or organization) Identification No.)
BANK OF MONTREAL TRUST COMPANY
C/O HARRIS TRUST AND SAVINGS BANK
311 W. MONROE STREET, 12TH FLOOR
CHICAGO, ILLINOIS 60606
(Address of principal executive offices)
(Zip Code)
(312) 461-4662
(Registrant's telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
the preceding 12 months (or for such shorter period that the registrant was
required to file such reports) and (2) has been subject to such filing
requirements for the past 90 days.
Yes [X] No [ ]
<PAGE>
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
EASTERN AMERICAN NATURAL GAS TRUST
STATEMENTS OF DISTRIBUTABLE INCOME
(UNAUDITED)
<TABLE>
<CAPTION>
SIX MONTHS ENDED THREE MONTHS ENDED
JUNE 30 JUNE 30
-------------------------- -------------------------
1999 1998 1999 1998
----------- ----------- ---------- --------
<S> <C> <C> <C> <C>
Royalty Income .............................. $ 4,590,717 $ 5,217,923 $ 2,229,264 $ 2,471,379
Operating Expenses:
Taxes on production and property ......... 310,273 359,468 150,185 170,115
Operating cost charges ................... 247,538 237,630 123,769 118,439
----------- ----------- ----------- -----------
Total Operating Expenses ................. 557,811 597,098 237,769 288,554
----------- ----------- ----------- -----------
Net Proceeds to the Trust ................... 4,032,906 4,620,825 1,955,310 2,182,825
General and Administrative Expenses ......... (278,757) (255,622) (119,054) (118,341)
Interest Income ............................. 2,980 3,654 1,491 2,073
Cash Proceeds on Sale of Net Profits Interest 282,944 838,474 93,658 396,310
----------- ----------- ----------- -----------
Distributable Income ..................... $ 4,040,073 $ 5,207,331 $ 1,931,405 $ 2,462,867
=========== =========== =========== ===========
Distributable Income Per Unit(5,900,000)
units authorized and Outstanding): ....... $ 0.6848 $ 0.8826 $ 0.3274 $ 0.4174
=========== =========== =========== ===========
</TABLE>
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE FINANCIAL STATEMENTS.
2
<PAGE>
EASTERN AMERICAN NATURAL GAS TRUST
STATEMENTS OF ASSETS, LIABILITIES AND TRUST CORPUS
<TABLE>
<CAPTION>
JUNE 30, 1999 DECEMBER 31, 1998
--------------- -------------------
(UNAUDITED)
<S> <C> <C>
Assets:
Cash ...................................... $ 1,491 $ 1,483
Net Proceeds Receivable ................... 2,048,968 2,187,489
Net Profits Interests in Gas Properties ... 93,162,180 93,162,180
Accumulated Amortization .................. (37,151,971) (34,341,682)
------------ ------------
Total Assets ........................... $ 58,060,668 $ 61,009,470
============ ============
Liabilities and Trust Corpus:
Trust General and Administrative
Expenses Payable ....................... $ 119,054 $ 115,930
Distributions Payable ..................... 1,931,405 2,073,042
Trust Corpus (5,900,000 Trust Units
authorized and outstanding) ............ 56,010,209 58,820,498
------------ ------------
Total Liabilities and Trust Corpus ..... $ 58,060,668 $ 61,009,470
============ ============
</TABLE>
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE FINANCIAL STATEMENTS.
3
<PAGE>
EASTERN AMERICAN NATURAL GAS TRUST
STATEMENTS OF CHANGES IN TRUST CORPUS
(UNAUDITED)
SIX MONTHS SIX MONTHS
ENDED ENDED
JUNE 30, 1999 JUNE 30, 1998
-------------- --------------
Trust Corpus, Beginning of Period .......... $ 58,820,498 $ 64,315,517
Distributable Income ....................... 4,040,073 5,207,331
Distributions Declared to Unitholders ...... (4,040,073) (5,207,331)
Amortization of Net Profits Interests in
Gas Properties .......................... (2,810,289) (2,777,962)
------------ ------------
Trust Corpus, End of Period ............... $ 56,010,209 $ 61,537,555
============ ============
THE ACCOMPANYING NOTES ARE AN INTEGRAL PART OF THESE FINANCIAL STATEMENTS.
4
<PAGE>
EASTERN AMERICAN NATURAL GAS TRUST
NOTES TO UNAUDITED 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"). 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 in West Virginia and
Pennsylvania (the "Underlying Properties"). The Net Profits Interests consisted
of a royalty interest in 322 wells and a term interest in the remaining wells
and locations. Prior to or on May 15, 2013, the Trustee is required to sell the
royalty interests and liquidate the Trust.
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 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 which is
contingent, uncertain in amount or that 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.
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
for the year ended December 31, 1998.
5
<PAGE>
EASTERN AMERICAN NATURAL GAS TRUST
NOTES TO UNAUDITED FINANCIAL STATEMENTS - (CONTINUED)
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 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 recorded as income 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 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.
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.
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 reserves to derive an amortization rate per reserve unit.
Such amortization does not reduce distributable income, but does reduce Trust
Corpus.
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.
6
<PAGE>
ITEM 2. Management's Discussion and Analysis of Financial Condition and Results
of Operations
Year 2000
The Year 2000 problem refers to the inability of certain computer and other
information technology systems to properly process date and time information
after December 31, 1999. The problem was caused, in part, by the programming
practice of using two digits rather than four to represent the year in a date.
The consequence of the Year 2000 problem, in general, is that information
technology and embedded processing systems are at risk of malfunction after
December 31, 1999, and potentially at dates prior to December 31, 1999.
The Trust is a passive legal entity, and neither owns nor directly uses any
computer systems, accounting systems or other assets that might have embedded
Year 2000 problems, and consequently will not incur any costs or expense to
prevent any such problems. However, the Trust is dependent on Eastern American
and its systems for the calculation of amounts payable to the Trust and for the
actual payment of such amounts. Eastern American has informed the Trustee that
Eastern American has substantially completed its Year 2000 assessment of its key
business information systems and is taking the necessary steps to ensure its
systems will be compliant by the year 2000. According to Eastern American, it is
simultaneously modifying its present operating and applications systems to
eliminate Year 2000 problems (which Eastern American expects to complete by
August 31, 1999), and implementing a new integrated application software package
(which it expects to be operational by September 30, 1999). For further
information regarding Eastern American's Year 2000 issues and the status of its
Year 2000 compliance program, reference is hereby made to the most recent
reports filed by Energy Corporation of America with the Securities and Exchange
Commission pursuant to the Securities and Exchange Act of 1934, as amended.
Eastern Marketing purchases and resells gas from the properties in which the
Trust has an interest to a variety of purchasers, and consequently is dependent
upon those purchasers to perform their obligations to pay for gas purchased.
Eastern American is also dependent upon the various pipeline systems that
transport gas produced from the wellheads to the purchasers. A failure of the
transportation system or of purchasers of a material portion of such gas to make
payment for such gas could have a material adverse effect on the Trust. Eastern
American has informed the Trustee that Eastern American is in the process of
soliciting information regarding Year 2000 readiness from the companies Eastern
American considers material to its business. Based on information received thus
far, Eastern American is not aware of any third-party Year 2000 problem that is
reasonably likely to be material to the Trust. Although Eastern American is in
the process of requesting this information, Eastern American does not have the
ability to require responses to such requests or to independently verify their
accuracy. Year 2000 related failures by Eastern American's customers or vendors
could have a material adverse effect on the Trust.
7
<PAGE>
In addition, the Trust is dependent on the Trustee for the maintenance of
records reflecting the ownership of the Units and for the payment to the
Unitholders of quarterly distributions received from Eastern American. The
Trustee has informed the Trust that its "systems and other date sensitive assets
have been updated to manage the Year 2000 date issue seamlessly, and the
[Trustee] anticipates that the transition will be a non-event for its
customers." For further information regarding the Trustee's Year 2000 issues and
the status of its Year 2000 compliance program, reference is hereby made to the
most recent reports filed by Harris Bankcorp, Inc. with the Securities and
Exchange Commission pursuant to the Securities and Exchange Act of 1934, as
amended.
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 to Unitholders
cash 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 which 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". The "Operating Cost Charge" for 1998 was based on an annual rate of
$476,764, and for 1999 this annual rate is $496,656. In subsequent years, the
Operating Cost Charge will escalate, based on increases in the index of average
weekly earnings of Crude Petroleum and Gas Production Workers (published by the
United States Department of Labor, Bureau of Labor Statistics), but not more
than 5% per year. The Operating Cost Charge was not increased as Development
Wells were completed but will be 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.
8
<PAGE>
Pursuant to the Gas Purchase Contract, Eastern Marketing Corporation is
obligated to purchase such gas production, on a quarterly basis, at a purchase
price per Mcf, subject to certain adjustments, equal to the greater of the Index
Price or the Floor Price for gas produced during the seven-year period ending
December 31, 1999 (the "Primary Term") and at a purchase price per Mcf equal to
the Index Price thereafter. The Floor Price was $2.84 per Mcf for 1998 and shall
be $3.09 per Mcf for 1999, in each case subject to adjustment under certain
circumstances. The Index Price for any quarter during the Primary Term will be a
weighted average price determined by reference to the fixed price ("Fixed
Price") component, which will be given a 66 2/3% weight, and a variable price
("Variable Price") component, which will be given a 33 1/3% weight. Following
the Primary Term, the Index Price will be determined solely by reference to the
Variable Price. The Fixed Price was equal to $3.39 per Mcf for 1998, and
escalates at 5% for each year thereafter through December 31, 1999 at which time
the "Primary Term" expires and the "Fixed Price" terminates. The fixed price for
1999 is $3.56 per Mcf. The Variable Price is equal to the Henry Hub Average Spot
Price (as defined) plus $.30 per MMBtu, multiplied by 110% to effect a fixed
adjustment for Btu content. The Henry Hub Average Spot Price for any quarter is
a price per MMBtu based on a 12-month average settlement price of the gas
futures contracts for gas delivered to the Henry Hub (Henry, Louisiana).
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 June 30, 1999, an
additional volume of 7,820 Mcf was delivered to the Trust as compared to 9,935
Mcf for the quarter ended June 30, 1998. 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 for the fiscal year ended December 31, 1998 for a more complete
description of the Development Wells.)
During the quarter ended June 30, 1999, one (1) well in which the Trust
owns a Net Profits Interest was required to be plugged and abandoned by the coal
lessee of the property upon which the well was drilled since the well interfered
with proposed mining operations. The coal lessee has the right to cause this
well to be plugged and abandoned pursuant to an agreement entered into prior to
the formation of the Trust. This prior agreement is a "Permitted Encumbrance"
under the Conveyances and the Trust accepted its Net Profits Interest subject to
this prior agreement. Pursuant to this prior agreement the coal lessee is
required to pay for the wells it causes to be plugged and abandoned. Eastern
American received $104,064 for the plugging and abandonment of the Berwind #5
well. Ninety percent (90%) of this amount or $93,658 is included on the June 30,
1999 Statement of Distributable Income under Cash Proceeds on Sale of Net
Profits Interests.
Since March 31, 1999, four (4) additional wells in which the Trust owns a Net
Profits interest have also been plugged and abandoned by the coal lessee of the
property upon which the wells were drilled because of interference with proposed
mining operations. These wells, Berwind #14, Berwind #15, Berwind #36, and
Berwind #37 were plugged June 25, June 21, June 29 and July 1, 1999,
respectively. Under the terms of the Agreement, consideration due Eastern with
respect to each well is to be paid ten days after the completion of the plugging
of the well. Consideration of $244,989 for the plugging of these wells was not
received by Eastern until after June 30, 1999. Since consideration for the
plugging of these wells was not received until after June 30, 1999, ninety
percent (90%) of this amount or $220,490 will be included on the September 30,
1999 Statement of Distributable Income under Cash Proceeds on the Sale of Net
Profit Interest.
9
<PAGE>
COMPARISON OF RESULTS OF OPERATIONS FOR THREE MONTHS ENDED JUNE 30, 1999 AND
THREE MONTHS ENDED JUNE 30, 1998
The Trust's distributable income was $1,931,405 for the three months ended
June 30, 1999 as compared to $2,462,867 for the three months ended June 30,
1998. This decrease was due in part, to a decrease in production of gas
attributable to the Net Profits Interests for the three months ended June 30,
1999 (687 Mmcf) as compared to the three months ended June 30, 1998 (765 Mmcf).
This decline is partially attributable to the natural declines in production and
the required plugging and abandonment of certain wells in previous and current
periods. This decrease was partially offset by an increase in the price payable
to the Trust under the Gas Purchase Contract as discussed below ($3.243 per Mcf
for the three months ended June 30, 1999; $3.221 per Mcf for the three months
ended June 30, 1998). The distributable income includes Cash Proceeds on Sale of
Net Profits Interest of $93,658 for the quarter ended June 30, 1999, as compared
to $396,310 of Cash Proceeds on Sale of Net Profits Interest included in the
quarter ended June 30, 1998.
The price payable to the Trust for gas production attributable to the Net
Profits Interests was $3.243 per Mcf for the three months ended June 30, 1999
and $3.221 per Mcf for the three months ended June 30, 1998. The price per Mcf
was higher for the three months ended June 30, 1999 than for the corresponding
three month period ending June 30, 1998 due to a higher Fixed Price component
($3.56 per Mcf for the three months ended June 30, 1999; $3.39 per Mcf for the
three months ended June 30, 1998). This increase in price was partially offset
by a decrease in the Variable Price component established by the average futures
spot market price for gas delivered at the Henry Hub near Henry, Louisiana
($2.075 per Dth for the three months ended June 30, 1999; $2.320 per Dth for the
three months ended June 30, 1998).
COMPARISON OF RESULTS OF OPERATIONS FOR SIX MONTHS ENDED JUNE 30, 1999 AND SIX
MONTHS ENDED JUNE 30, 1998
The Trust's distributable income was $4,040,073 for the six months ended
June 30, 1999 as compared to $5,207,331 for the six months ended June 30, 1998.
This decrease was due to a decrease in production of gas attributable to the Net
Profits Interests for the six months ended June 30, 1999 (1,432 Mmcf) as
compared to the six months ended June 30, 1998 (1,608 Mmcf). The production
decreases were attributable to the natural production declines associated with
the Underlying Properties and the required plugging and abandonment of certain
wells in previous and current periods. This decrease was also due to a decrease
in the average price payable to the Trust under the Gas Purchase Contract
($3.206 per Mcf for the six months ended June 30, 1999; $3.244 per Mcf for the
six months ended June 30, 1998). The distributable income includes Cash Proceeds
on Sale of Net Profits Interest of $282,944 for the six months ended June 30,
1999, as compared to $838,474 of Cash Proceeds on Sale of Net Profits Interest
included in the six months ended June 30, 1998.
The average price payable to the Trust for gas production attributable to
the Net Profits Interests was $3.206 per Mcf for the six months ended June 30,
1999 and $3.244 per Mcf for the six months ended June 30, 1998. The price per
Mcf was lower for the six months ended June 30, 1999 than for the corresponding
six month period ending June 30, 1998 due to a lower Variable Price component of
the Index Price under the Gas Purchase Contract ($2.500 per Mcf for the six
months ended June 30, 1999; $2.952 per Mcf for the six months ended June 30,
1998) which was partially offset by a higher Fixed Price component of the Index
Price under the Gas Purchase Contract ($3.56 per Mcf for the six months ended
June 30, 1999; $3.39 per Mcf for the three months ended June 30, 1998). Such
lower Variable Price is directly attributable to a decrease in the average
futures spot market prices for gas delivered at the Henry Hub near Henry,
Louisiana for the six months ended June 30, 1999 ($1.9725 per Dth) as compared
to the six months ended June 30, 1998 ($2.3830 per Dth).
10
<PAGE>
PART II - OTHER INFORMATION
ITEM 1. Legal Proceedings.
None.
ITEM 2. Changes in Securities.
None.
ITEM 3. Defaults Upon Senior Securities.
None.
ITEM 4. Submission of Matters to a Vote of Security Holders.
None.
ITEM 5. Other Information.
For the calendar quarter ended June 30, 1999, 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 $448.70 and $407.50 respectively. On June 30, 1999 the closing price of the
Treasury Obligations, as quoted on such market, was $422.20.
ITEM 6. Exhibits and Reports on Form 8-K.
(a) Exhibits
None
(b) Reports on Form 8-K
No reports on Form 8-K were filed during the fiscal quarter
ended June 30, 1999.
11
<PAGE>
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.
EASTERN AMERICAN NATURAL GAS TRUST
By: Bank of Montreal Trust Company, Trustee
/s/ ROBERT D. FOLTZ
Robert D. Foltz
Vice President
Date: August 13, 1999
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.
12
<TABLE> <S> <C>
<ARTICLE> 5
<LEGEND>
THIS FINANCIAL DATA SCHEDULE CONTAINS INFORMATION EXTRACTED FROM EASTERN
AMERICAN NATURAL GAS TRUST'S FINANCIAL STATEMENTS FOR THE QUARTER ENDED JUNE 30,
1999 CONTAINED IN THE TRUST'S QUARTERLY REPORT ON FORM 10-Q FOR THE QUARTER
ENDED JUNE 30, 1999 AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH
FINANCIALS.
</LEGEND>
<S> <C>
<PERIOD-TYPE> 6-MOS
<FISCAL-YEAR-END> DEC-31-1999
<PERIOD-END> JUN-30-1999
<CASH> 1,491
<SECURITIES> 0
<RECEIVABLES> 2,048,968
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 2,050,459
<PP&E> 93,162,180
<DEPRECIATION> 37,151,971
<TOTAL-ASSETS> 58,060,668
<CURRENT-LIABILITIES> 119,054
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 56,010,209
<TOTAL-LIABILITY-AND-EQUITY> 58,060,668
<SALES> 2,229,264
<TOTAL-REVENUES> 2,229,264
<CGS> 0
<TOTAL-COSTS> 237,769
<OTHER-EXPENSES> 119,054
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 0
<INCOME-PRETAX> 1,931,405
<INCOME-TAX> 0
<INCOME-CONTINUING> 1,931,405
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 1,931,405
<EPS-BASIC> 0.327
<EPS-DILUTED> 0.327
</TABLE>
