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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, 1997
OR
[_] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d) OF THE
SECURITION EXCHANGE ACT OF 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 of (I.R.S. Employer
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 [_]
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<PAGE>
PART 1 - 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
1997 1996 1997 1996
------------ ------------ ------------ ------------
<S> <C> <C> <C> <C>
Royalty Income ............................ $ 6,056,161 $ 5,859,654 $ 3,122,434 $ 3,129,174
Operating Expenses:
Taxes on production and property ....... 414,149 402,011 215,519 213,467
Operating cost charges ................. 228,820 225,563 114,410 112,167
------------ ------------ ------------ ------------
Total Operating Expenses ........ 642,969 627,574 329,929 325,634
------------ ------------ ------------ ------------
Net Proceeds to the Trust ................. 5,413,192 5,232,080 2,792,505 2,803,540
General and Administrative Expenses ....... (272,177) (249,646) (98,779) (93,229)
Interest Income ........................... 4,382 3,318 1,835 2,246
Cash Proceeds on Sale of Net
Profit Interests .................... 0 0 0 0
------------ ------------ ------------ ------------
Distributable Income ............ $ 5,145,397 $ 4,985,752 $ 2,695,561 $ 2,712,557
============ ============ ============ ============
Distributable Income Per Unit (5,900,000
units authorized and outstanding):
Distributable Income Per Unit ............. $ 0.8721 $ 0.8450 $ 0.4569 $ 0.4598
============ ============ ============ ============
</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
JUNE 30, 1997 DECEMBER 31, 1996
------------ ------------
(Unaudited)
Assets:
Cash ..................................... $ 1,835 $ 1,511
Net Proceeds Receivable .................. 2,792,505 2,795,254
Net Profits Interests in Gas Properties .. 93,162,180 93,162,180
Accumulated Amortization ................. (26,199,762) (23,145,237)
------------ ------------
Total Assets .......................... $ 69,756,758 $ 72,813,708
============ ============
Liabilities and Trust Corpus:
Trust General and Administrative
Expenses Payable ...................... $ 98,779 $ 74,427
Distributions Payable .................... 2,695,561 2,722,338
Trust Corpus (5,900,000 Trust Units
authorized and outstanding) ........... 66,962,418 70,016,943
------------ ------------
Total Liabilities and Trust Corpus .... $ 69,756,758 $ 72,813,708
============ ============
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, 1997 JUNE 30, 1996
------------ ------------
Trust Corpus, Beginning of Period .......... $ 70,016,943 $ 75,854,100
Distributable Income ....................... 5,145,397 4,985,753
Distributions Declared to Unitholders ...... (5,145,397) (4,985,753)
Amortization of Net Profits Interests
in Gas Properties ....................... (3,054,525) (2,855,560)
------------
Trust Corpus, End of Period ............... $ 66,962,418 $ 72,998,540
============ ============
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 consist 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, 1996.
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 shows
Distributable Income, defined as Trust income available for distribution to
Unitholders before application of those Unitholders' additional expenses, if
any, for depletion, interest income and 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 and expenses 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 has been impaired. The Trust will
provide a write-down 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. Any such write-down would not reduce
Distributable Income, but 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
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 1996 was based on an annual rate of $456,391,
and for 1997 this annual rate is $465,519. 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 will not be increased as Development Wells
are 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.
Pursuant to the Gas Purchase Contract, Eastern Marketing Corporation will be
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 and 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 $2.36 per Mcf for 1996 and shall
be $2.57 per Mcf for 1997, $2.84 per Mcf for 1998 and $3.09 per Mcf for 1999, in
each case subject to
7
<PAGE>
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 $3.08 per Mcf for
the 1996 calendar year, and escalates at 5% for each year thereafter. The fixed
price for the 1997 calendar year is $3.23 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).
Pursuant to the Conveyances Eastern American is obligated to drill the 65
Development Wells and bear the costs of drilling and completing the same. As of
December 31, 1996, Eastern American had drilled 56 Development Wells. Eastern
American was obliged to drill three additional Development Wells by March 31,
1997 and six more during the remainder of 1997. As disclosed previously certain
third parties have drilled wells in close proximity to the drill sites for four
of the Development Wells that have not been drilled. Since the wells drilled by
the third parties were within 1,000 feet of these Development Wells Eastern
American had a disagreement with the Trust over Eastern American's obligation to
drill these closely offset wells. The Trust has agreed that in lieu of drilling
these closely offset wells that Eastern American 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 and
based on those estimates, an additional 10,565 Mcf's for the quarter ending June
30, 1997 has been delivered to the Trust, representing the production on these
four wells. In addition, Eastern American has drilled one additional Development
Well during the period.
COMPARISON OF RESULTS OF OPERATIONS FOR THREE MONTHS ENDED JUNE 30, 1997 AND
THREE MONTHS ENDED JUNE 30, 1996
Trust's distributable income was $2,695,561 for the three months ended
June 30, 1997 as compared to $2,712,557 for the three months ended June 30,
1996. This increase was due to an increase in the price payable to the Trust
under the Gas Purchase Contract ($3.155 per Mcf for the three months ended June
30, 1997; $3.052 per Mcf for the three months ended June 30, 1996) and was
partially offset by a decrease in production of gas attributable to the Net
Profits Interests for the three months ended June 30, 1997 (989 MMcf) as
compared to the three months ended June 30, 1996 (1,026 MMcf).
The price payable to the Trust for gas production attributable to the Net
Profits Interests was $3.155 per Mcf for the three months ended June 30, 1997
and $3.052 per Mcf for the three months ended June 30, 1996. The price per Mcf
was higher for the three months ended June 30, 1997 than for the corresponding
three month period ending June 30, 1996 due to a higher Fixed Price component
($3.23 per MCF for the three months ended June 30, 1997; $3.08 per MCF for the
three months ended
8
<PAGE>
June 30, 1996) and was partially offset by a lower Variable Price component of
the Index Price under the Gas Purchase Contract ($3.000 per Mcf for the three
months ended June 30, 1997; $3.006 per Mcf for the three months ended June 30,
1996). Such lower Variable Price is directly attributable to an decrease in the
average futures spot market prices for gas delivered at the Henry Hub near
Henry, Louisiana for the three months ended June 30, 1997 ($2.427 per Dth) as
compared to the prior period ($2.433 per Dth).
COMPARISON OF RESULTS OF OPERATIONS FOR SIX MONTHS ENDED JUNE 30, 1997 AND SIX
MONTHS ENDED JUNE 30, 1996.
The Trust's distributable income was $5,145,397 for the six months ended
June 30, 1997 as compared to $4,985,752 for the six months ended June 30, 1996.
This increase was due to an increase in the price payable to the Trust under the
Gas Purchase Contract ($3.181 per Mcf for the six months ended June 30, 1997;
$2.987 per Mcf for the six months ended June 30, 1996) and was partially offset
by a decrease in production of gas attributable to the Net Profits Interests for
the six months ended June 30, 1997 (1,903 MMcf) as compared to the six months
ended June 30, 1996 (1,959 MMcf). The production decreases were attributable to
normal production declines associated with the Underlying Properties.
The price payable to the Trust for gas production attributable to the Net
Profits Interests was $3.181 per Mcf for the six months ended June 30, 1997 and
$2.987 per Mcf for the six months ended June 30, 1996. The price per Mcf was
higher for the six months ended June 30, 1997 than for the corresponding six
month period ending June 30, 1996 due to a higher Fixed Price component ($3.23
per Mcf for the six months ended June 30, 1997; $3.08 per Mcf for the six months
ended June 30, 1996) and was partially offset by a lower Variable Price
component of the Index Price under the Gas Purchase Contract ($2.797 per Mcf for
the six months ended June 30, 1997; $2.810 per Mcf for the six months ended June
30, 1996). 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, 1997 ($2.497 per Mcf) as
compared to the prior period ($2.255 per Mcf).
9
<PAGE>
PART II - OTHER INFORMATION
ITEM 1. Legal Proceedings.
Eastern American has previously advised that it had been served with a
Complaint from Columbia Gas Transmission Corporation that alleges that
some of Eastern American's wells are producing storage gas from a
Columbia storage field in West Virginia. A portion of the wells are
ones in which the Trust owns a Net Profit Interest. The Trust was not
named as a party to this action. Eastern American and Columbia have
entered into a Settlement Agreement and Mutual Release of All Claims
dated as of July 16, 1997. This Agreement settles all matters in
controversy between the parties and requires the suit to be dismissed
with prejudice. Eastern American and the Trust are evaluating how, if
in any way, the settlement may affect the Trust.
As disclosed in the Prospectus, Eastern American and Eastern Marketing
are parties to a long-term gas sales contract pursuant to which Eastern
American is entitled to sell gas at prices which are expected to
approximate the Fixed Price Component of the Index Price under the Gas
Purchase Contract. Eastern has received notice from Seneca Power
Partners, L.P., the gas purchaser, that it has reached an agreement in
principle regarding the consensual restructuring of Seneca Power
Partners, L.P. power purchase agreement with Niagara Mohawk Power
Corporation. This restructuring is to be accomplished through the
termination or restructuring of the existing power purchase agreement
in exchange for cash, common stock and price hedging agreements.
Representatives of Seneca Power Partners, L.P. have contacted Eastern
American and advised that they desire to terminate or restructure the
existing gas sales contract with Seneca Power Partners, L.P. No further
discussions have been had regarding this issue other than the initial
discussions. In any case, any such termination or restructuring of the
gas sales contract will not affect the obligations of Eastern Marketing
and Eastern American under the Gas Purchase Contract, and thus are not
expected to have any affect on the Trust.
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 1997, 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 $365.00 AND $311.02 RESPECTIVELY. ON JUNE 30, 1997 THE CLOSING PRICE OF THE
TREASURY OBLIGATIONS, AS QUOTED ON SUCH MARKET, WAS $337.62.
ITEM 6. Exhibits and Reports on Form 8-K.
(a) Exhibits
NONE
(b) Reports on Form 8-K
NONE
10
<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/ E. KAY LIEDERMAN
Name: E. Kay Liederman
Title: Vice President
Date: August 13, 1997
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.
11
<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,
1997 CONTAINED IN THE TRUST'S QUARTERLY REPORT ON FORM 10-Q FOR THE QUARTER
ENDED JUNE 30, 1997 AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH
FINANCIAL STATEMENTS.
</LEGEND>
<S> <C>
<PERIOD-TYPE> 6-MOS
<FISCAL-YEAR-END> DEC-31-1997
<PERIOD-END> JUN-30-1997
<CASH> 1,835
<SECURITIES> 0
<RECEIVABLES> 2,792,505
<ALLOWANCES> 0
<INVENTORY> 0
<CURRENT-ASSETS> 2,792,505
<PP&E> 93,162,180
<DEPRECIATION> 26,199,762
<TOTAL-ASSETS> 69,756,758
<CURRENT-LIABILITIES> 2,794,340
<BONDS> 0
0
0
<COMMON> 0
<OTHER-SE> 66,962,418
<TOTAL-LIABILITY-AND-EQUITY> 69,756,758
<SALES> 6,056,161
<TOTAL-REVENUES> 6,056,161
<CGS> 0
<TOTAL-COSTS> 642,969
<OTHER-EXPENSES> 272,177
<LOSS-PROVISION> 0
<INTEREST-EXPENSE> 0
<INCOME-PRETAX> 5,145,397
<INCOME-TAX> 0
<INCOME-CONTINUING> 5,145,397
<DISCONTINUED> 0
<EXTRAORDINARY> 0
<CHANGES> 0
<NET-INCOME> 5,145,397
<EPS-PRIMARY> 0.872
<EPS-DILUTED> 0.872
</TABLE>
