<PAGE> 1
PROSPECTUS
575,000 DEPOSITARY UNITS
EVIDENCED BY
SECURE PRINCIPAL ENERGY RECEIPTS (SPERS(TM))
CONSISTING OF INTERESTS IN
SANTA FE ENERGY TRUST
AND A
UNITED STATES TREASURY OBLIGATION
---------------------------
The Depositary Units are offered by Santa Fe Energy Resources, Inc. ("Santa
Fe"). The Depositary Units offered hereby were issued to Santa Fe in connection
with the formation of Santa Fe Energy Trust (the "Trust"). Each Depositary Unit
consists of beneficial ownership of one unit of undivided 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 February 15, 2008. The Depositary Units are evidenced
by Secure Principal Energy Receipts (SPERs(TM)), which are transferable only in
denominations of 50 Depositary Units or integral multiples thereof. Holders may
present Depositary Units in multiples of 50 for withdrawal and receive an equal
number of Trust Units and a discrete Treasury Obligation in a face amount equal
to $1,000 per 50 Depositary Units ($20 per Depositary Unit) presented for
withdrawal. The Trust will not receive any proceeds from the Depositary Units
offered hereby.
The Trust is a grantor trust formed to hold certain term and net profits
royalty interests in domestic producing oil and gas properties owned by Santa
Fe. The net proceeds from the royalty payments made to the Trust in respect of
the royalty interests (net of Trust expenses) are distributed to holders of
Depositary Units for each calendar quarter ending on or prior to December 31,
2007. Subject to certain limitations, the Trust is entitled to receive, during
the period ending on December 31, 2002, certain additional royalty payments
described herein from one of the term royalty interests to support quarterly
cash distributions on Depositary Units at levels specified herein.
Prior to February 15, 2008 (the "Liquidation Date"), certain of the royalty
interests will terminate and the remaining net profits royalties,which are not
limited in term, will be sold by the Trust. A liquidating distribution,
consisting of the pro rata proceeds from the matured Treasury Obligations and
the net proceeds from the sale of the net profits royalties (to the extent not
previously distributed), will be made to the holders of record of Depositary
Units as of approximately the Liquidation Date. Accordingly, each holder of
Depositary Units will receive a liquidating distribution of not less than $20
per Depositary Unit. There are certain limitations inherent in viewing an
investment in Depositary Units as providing "secure principal." No additional
property or interest has been pledged to secure any portion of a Depositary Unit
investment. The term, "secure principal," refers only to the return of a
substantial portion of the initial Depositary Unit investment ($20 per
Depositary Unit) through maturity of the Treasury Obligations, assuming that
Depositary Units are held until the Liquidation Date. The withdrawal and sale of
Treasury Obligations prior to maturity will result in a holder receiving less
than face value for the Treasury Obligations and will subject the holder to
certain market risks. While the accretion in value of the Treasury Obligations
is intended to offset to some extent the inherent decline in value of the Trust
Units, such accretion will also result in taxable income to the holders even
though no cash distributions will be made with respect to the Treasury
Obligations prior to the Liquidation Date.
The Depositary Units are listed for trading on the New York Stock Exchange
under the symbol "SFF". On February 9, 1994, the last reported sale price of the
Depositary Units on the New York Stock Exchange was $20 5/8 per Depositary Unit.
SEE "RISK FACTORS" FOR CERTAIN CONSIDERATIONS RELEVANT TO AN INVESTMENT IN
THE DEPOSITARY UNITS.
---------------------------
THESE SECURITIES HAVE NOT BEEN APPROVED OR DISAPPROVED BY THE SECURITIES
AND EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION
NOR HAS THE SECURITIES AND EXCHANGE COMMISSION OR ANY STATE
SECURITIES COMMISSION PASSED UPON THE ACCURACY OR
ADEQUACY OF THIS PROSPECTUS. ANY REPRESENTATION
TO THE CONTRARY IS A CRIMINAL OFFENSE.
================================================================================
<TABLE>
<CAPTION>
- ------------------------------------------------------------------------------------------
UNDERWRITING
PRICE TO DISCOUNTS AND PROCEEDS TO
PUBLIC COMMISSIONS(1) SANTA FE(2)
- ------------------------------------------------------------------------------------------
<S> <C> <C> <C>
Per Depositary Unit.......... $20.625 $1.03 $19.595
- ------------------------------------------------------------------------------------------
Total........................ $11,859,375 $592,250 $11,267,125
==========================================================================================
</TABLE>
(1) Santa Fe has agreed to indemnify the Underwriter against certain
liabilities, including liabilities under the Securities Act of 1933. See
"Underwriting."
(2) Before deducting expenses payable by Santa Fe estimated to be $325,000.
---------------------------
The Depositary Units offered by this Prospectus are offered by the
Underwriter subject to prior sale, to withdrawal, cancellation or modification
of the offer without notice, to delivery to and acceptance by the Underwriter
and certain further conditions. It is expected that delivery of certificates
representing the Depositary Units will be made at the offices of Lehman Brothers
Inc., New York, New York, on or about February 17, 1994.
---------------------------
LEHMAN BROTHERS
February 10, 1994
<PAGE> 2
AVAILABLE INFORMATION
Santa Fe and the Trust are subject to the informational requirements of the
Securities Exchange Act of 1934 (the "Exchange Act"), and in accordance
therewith file reports, proxy statements and other information with the
Securities and Exchange Commission (the "Commission"). Such reports, proxy
statements and other information can be inspected and copied at the public
reference facilities maintained by the Commission at 450 Fifth Street, N.W.,
Room 1024, Washington, D.C. 20549 and at its regional offices located at
Northwestern Atrium Center, 500 West Madison Street, Suite 1400, Chicago,
Illinois 60621-2511 and at 7 World Trade Center, New York, New York 10048.
Copies of such materials can be obtained from the Public Reference Section of
the Commission, 450 Fifth Street, N.W., Judiciary Plaza, Washington, D.C. 20549,
on payment of prescribed rates. Such reports, proxy statements and other
information concerning Santa Fe and the Trust can also be inspected at the
offices of the New York Stock Exchange, 20 Broad Street, New York, New York
10005, on which the Common Stock and the Convertible Preferred Stock of Santa Fe
and the Depositary Units are listed.
This Prospectus does not contain all of the information set forth in the
Registration Statement (the "Registration Statement") of which this Prospectus
is a part, and exhibits relating thereto, which have been filed with the
Commission. Statements contained herein concerning the provisions of documents
are necessarily summaries of such documents, and each statement is qualified in
its entirety by reference to the copy of the applicable document filed with the
Commission. Copies of the Registration Statement and the exhibits thereto are on
file at the offices of the Commission and may be obtained upon payment of the
fees prescribed by the Commission, or may be examined without charge at the
public reference facilities of the Commission described above.
The Trustee of the Trust furnishes the Depositary for mailing to holders of
Depositary Units ("Holders") annual reports containing audited financial
statements of the Trust and certain additional information, and with quarterly
reports showing the assets, liabilities and Trust corpus, income and expenses of
the Trust and changes in Trust corpus for the corresponding quarter. Santa Fe
also provides the Depositary certain information regarding the Treasury
Obligations to be distributed to Holders on a quarterly basis. See "Description
of the Trust and the Trust Agreement -- Periodic Reports" and "Description of
the Depositary Units -- Duties and Status of Depositary." Annual financial
statements of the Trust are audited and reported on with an opinion expressed by
a firm of independent public accountants.
INCORPORATION OF CERTAIN DOCUMENTS BY REFERENCE
The following documents have been filed by Santa Fe and the Trust with the
Commission pursuant to the Exchange Act and are incorporated herein by
reference:
(1) Santa Fe's Annual Report on Form 10-K for the year ended December
31, 1992 (as amended by Amendment No. 1 on Form 8 dated April 21, 1993);
(2) Santa Fe's Quarterly Reports on Form 10-Q for the quarters ended
March 31, June 30, and September 30, 1993;
(3) Santa Fe's Current Reports on Form 8-K dated June 28, 1993 (as
amended by Amendment No. 1 on Form 8-K/A dated November 10, 1993), October
27, 1993 and December 14, 1993;
(4) the Trust's Annual Report on Form 10-K for the year ended December
31, 1992; and
(5) the Trust's Quarterly Reports on Form 10-Q for the quarters ended
March 31, June 30, and September 30, 1993.
All documents filed by Santa Fe and the Trust pursuant to Section 13(a),
13(c), 14 or 15(d) of the Exchange Act subsequent to the date of this Prospectus
and prior to the termination of the offering made by this Prospectus shall be
deemed to be incorporated by reference herein and to be a part hereof from the
date of filing thereof. Any statement contained in a document incorporated or
deemed to be incorporated by reference herein shall be deemed to be modified or
superseded for purposes of this Prospectus to the extent that a statement
contained herein, or in any other subsequently filed document that also is or is
deemed to be incorporated by reference herein, modifies or supersedes such
statement. Any such statement so modified or superseded shall not be deemed,
except as so modified or superseded, to constitute a part of this Prospectus.
Santa Fe hereby undertakes to provide without charge to each person to whom
a copy of this Prospectus has been delivered, including any beneficial owner of
Depositary Units, upon the written or oral request of any such person, a copy of
any and all information filed by Santa Fe or the Trust that has been
incorporated by reference in this Prospectus (not including exhibits to the
information that is incorporated by reference herein unless such exhibits are
specifically incorporated by reference in such information). Requests for such
copies should be directed to Santa Fe at 1616 South Voss Road, Suite 1000,
Houston, Texas 77057, Attention: Ed Hall (phone: (713) 783-2401).
IN CONNECTION WITH THIS OFFERING, THE UNDERWRITER MAY OVER-ALLOT OR EFFECT
TRANSACTIONS WHICH STABILIZE OR MAINTAIN THE MARKET PRICE OF THE DEPOSITARY
UNITS OFFERED HEREBY AT LEVELS ABOVE THOSE WHICH MIGHT OTHERWISE PREVAIL IN THE
OPEN MARKET. SUCH TRANSACTIONS MAY BE EFFECTED ON THE NEW YORK STOCK EXCHANGE,
IN THE OVER-THE-COUNTER MARKET, OR OTHERWISE. SUCH STABILIZING, IF COMMENCED,
MAY BE DISCONTINUED AT ANY TIME.
2
<PAGE> 3
PROSPECTUS SUMMARY
The following summary is qualified in its entirety by the more detailed
information and financial statements appearing elsewhere in this Prospectus and
should be read only in conjunction with the entire Prospectus.
THE DEPOSITARY UNITS
Each of the Depositary Units offered hereby consists of beneficial
ownership of one unit of undivided beneficial interest ("Trust Unit") in the
Santa Fe Energy Trust (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 February 15, 2008 (the "Liquidation Date").
The Depositary Units are evidenced by Secure Principal Energy Receipts
(SPERs(TM)), which have been issued and are transferable only in denominations
of 50 Depositary Units or integral multiples thereof. Holders of Depositary
Units ("Holders") may present Depositary Units in multiples of 50 to the
depositary of the Depositary Units for withdrawal and receive an equal number of
Trust Units and a discrete Treasury Obligation in a face amount equal to $1,000
per 50 Depositary Units ($20 per Depositary Unit) presented for withdrawal.
Withdrawn Trust Units will not be certificated and generally will not be
transferable. See "Description of the Trust and the Trust
Agreement -- Withdrawal of Trust Units and Restrictions on Transfer" and
"Description of the Depositary Units."
The Trust Units and Treasury Obligations are held by Texas Commerce Bank
National Association ("TCB"), as depositary (the "Depositary") for the Holders
of Depositary Units. TCB also serves as Trustee. The Trust is a grantor trust
formed by Santa Fe Energy Resources, Inc. ("Santa Fe") to hold royalty interests
(the "Royalty Interests") in certain oil and gas properties owned by Santa Fe
(the "Royalty Properties"). Neither the Depositary Units nor the Trust Units are
obligations of Santa Fe or the Depositary.
Holders of the Depositary Units receive quarterly cash distributions based
upon their proportionate interest in the Royalty Interests represented by Trust
Units. Minimum annual distributions of $1.60 per Depositary Unit will be
supported through December 31, 2002 from additional royalty payments ("Support
Payments") from the Wasson ODC Royalty (described below), subject to certain
limitations. See "The Royalty Interests -- Support Payments." No assurances can
be given that Support Payments will be available in sufficient amounts to
provide such minimum distribution. From the inception of the Trust through the
third quarter of 1993, net cash proceeds from the Royalty Interests were
sufficient to make quarterly distributions of at least $0.40 per Depositary Unit
and Support Payments were not, therefore, required. The distribution declared
with respect to the fourth quarter of 1993, however, includes a Support Payment
of approximately $362,000 (approximately $0.06 per Depositary Unit). This
Support Payment was required primarily due to lower realized oil prices and
unanticipated capital expenditures incurred with respect to certain Royalty
Properties, a substantial portion of which is related to the drilling of new
wells. See "Risk Factors -- Recent Significant Declines in Oil Prices" and
" -- Uncertainties Involved in Reserve Estimates and Possible Production Risks."
The following table shows cash distributions paid or payable in respect of the
periods indicated since the inception of the Trust:
<TABLE>
<CAPTION>
CASH
DISTRIBUTION
PER
TRUST
UNIT
--------
<S> <C>
1992:
Fourth Quarter(1)............................................... $0.30753
1993:
First Quarter................................................... 0.46660
Second Quarter.................................................. 0.49485
Third Quarter................................................... 0.44218
Fourth Quarter(2)............................................... 0.40000
</TABLE>
- ---------------
(1) Distributed in respect of the two-month period ended December 31, 1992.
(2) Includes a Support Payment of approximately $0.06 per Depositary Unit.
Declared payable on February 28, 1994 to Holders of Depositary Units of
record on February 14, 1994.
3
<PAGE> 4
The Depositary Units are designed so that the accreting value of the
Treasury Obligations will in general offset the depleting nature of the Royalty
Interests. As the Liquidation Date approaches, it is expected that the
Depositary Units will assume more of the investment characteristics of the
Treasury Obligations, including the tax characteristics thereof.
The Royalty Interests consist of three significant conveyances of oil and
gas interests to the Trust, each with different attributes. The Wasson
Royalties, consisting of the Wasson ODC Royalty and the Wasson Willard Royalty
described herein, were conveyed to the Trust out of Santa Fe's royalty interests
in the Wasson oil field ("Wasson Field") located in the Permian Basin of West
Texas, the sixth largest oil field in the United States. The Wasson Royalties
are fixed percentage royalty interests in specified levels of quarterly maximum
production from the underlying properties in each year during the term of the
respective royalty. The Wasson ODC Royalty and the Wasson Willard Royalty
terminate on December 31, 2007 and December 31, 2003, respectively. See "The
Royalty Interests -- The Wasson Royalties." The Net Profits Royalties consist of
a net profits interest in a diversified portfolio of oil and gas properties
located predominantly in Texas, Louisiana and Oklahoma. The Net Profits
Royalties are life-of-property interests which will be sold by the Trust prior
to the Liquidation Date. Based on oil and gas prices as of December 31, 1993 and
production estimates contained in the reserve report dated January 1, 1994 of
Ryder Scott Company, independent petroleum engineers (the "Reserve Report"), the
Wasson ODC Royalty, the Wasson Willard Royalty and the Net Profits Royalties
comprised approximately 51%, 11% and 38% of the discounted estimated future net
revenues attributable to the Royalty Interests, respectively. A summary of the
Reserve Report is included in this Prospectus as Appendix A.
The Net Profits Royalties generally were conveyed from mature producing oil
and gas properties that are not expected to undergo substantial additional
development during the remainder of their producing lives. Accordingly, the
proved reserves attributable to the Net Profits Royalties are expected to
decline substantially over the remaining life of the Trust and to have a
relatively small liquidation value at the Liquidation Date. In order to enhance
the stability and longer-term production characteristics of the royalties
conveyed to the Trust, the Wasson Royalties were conveyed from relatively longer
lived properties. Due to royalty production limitations, any future increases in
proved reserves attributable to the properties underlying the Wasson Royalties
will not result in the Trust or Holders receiving royalty payments from
production in excess of such royalty production limitations.
The "secure principal" return of a substantial portion of the initial
investment of a holder of Depositary Units through the maturity of the Treasury
Obligations assumes that the Holder will hold the Depositary Units and
underlying Treasury Obligation until its maturity and does not take into account
the accretion of value of the Treasury Obligations over time. See "Risk
Factors -- Certain Investment Limitations Inherent in Viewing Depositary Units
as 'Secure Principal'."
THE OFFERING
Depositary Units Offered... A total of 575,000 Depositary Units are being
offered hereby.
Depositary Units
Outstanding................ 6,300,000 Depositary Units (and an equal number of
Trust Units) are issued and outstanding.
New York Stock Exchange
Trading Symbol........... "SFF"
Quarterly Cash
Distributions.............. Holders of Depositary Units receive cash
distributions based on the production of oil and gas
from the Royalty Properties for each calendar
quarter ending on or prior to December 31, 2007. The
Trust distributed $0.30753 per Trust Unit for the
period from November 1, 1992 through December 31,
1992, and $0.46660, $0.49485 and $0.44218 per Trust
Unit for the calendar quarters ended March 31, June
30 and September 30, 1993, respectively, and has
declared a distribution of $0.40 per Trust Unit for
the quarter ended December 31, 1993. The amount of
future cash
4
<PAGE> 5
distributions to Holders will depend upon the
quantity of oil and gas produced from the Royalty
Properties, the prices received therefor and other
factors. Oil and gas production from proved reserves
attributable to the Royalty Interests is expected to
decline over the term of the Trust. See "Risk
Factors." Quarterly cash distributions during the
term of the Trust are made by the Trustee on the
last day of the second month after the close of each
calendar quarter to Holders of record on the 45th
day following each calendar quarter.
Distribution Support....... For any calendar quarter ending on or prior to
December 31, 2002, to the extent that net cash
proceeds from the Royalty Interests would be
insufficient to distribute at least $0.40 per
Depositary Unit per quarter, the Trust will receive
the Support Payments, subject to certain
limitations. The Support Payments will be made from
an additional royalty granted to the Trust from the
retained royalty interest of Santa Fe in the oil
producing Wasson ODC Unit (as described below).
There is no assurance that the Support Payments will
be sufficient to enable the Trust to distribute the
supported distribution amount in any quarter during
the support period. If Support Payments are made for
any quarter, the royalties payable with respect to
the Wasson Royalties (as described below) in
subsequent quarters will be reduced to the extent
necessary to permit Santa Fe to recoup such Support
Payments, provided that such reductions do not
reduce Trust distributions below $0.45 per
Depositary Unit for any such quarter. The aggregate
amount of Support Payments (net of any amounts
recouped by Santa Fe) is limited to $20 million on a
revolving basis. The distribution declared with
respect to the fourth quarter of 1993 includes a
Support Payment of approximately $362,000
(approximately $0.06 per Depositary Unit). This
Support Payment was required primarily due to lower
realized oil prices and unanticipated capital
expenditures incurred with respect to the Royalty
Properties burdened by the Net Profits Royalties (as
described below), a substantial portion of which is
related to the drilling of new wells. See "The
Royalty Interests -- Support Payments."
Liquidating
Distributions.............. The assets of the Trust will be liquidated on or
prior to the Liquidation Date and a liquidating
distribution will be made to Holders of record on or
about the Liquidation Date. The liquidating
distribution with respect to each Depositary Unit
will include proceeds from the matured Treasury
Obligations in an amount equal to $20 per Depositary
Unit and a pro rata portion of the net proceeds from
the sale of the Net Profits Royalties to the extent
not previously distributed. Because of the depleting
nature of the properties underlying the Net Profits
Royalties, however, the net proceeds from the sale
of the Net Profits Royalties are not expected to be
significant. The Wasson Royalties (as described
below), which terminate prior to the Liquidation
Date, will have no liquidation value to Holders.
Royalty Interests.......... The Royalty Interests consist of (i) two term
royalty interests (the "Wasson Royalties") conveyed
to the Trust out of Santa Fe's royalty interests in
two production units in the Wasson Field, and (ii) a
net profits royalty interest (the "Net Profits
Royalties") conveyed to the Trust out of Santa Fe's
royalty interests and working interests in a
diversified portfolio of oil and gas properties
located in 12 states. According to the Reserve
Report, as of December 31, 1993, total proved
reserves
5
<PAGE> 6
attributable to the Royalty Interests consisted of
7,769 MBbls of oil and 11,121 MMcf of gas,
substantially all of which are proved developed.
Wasson ODC Royalty...... The Wasson ODC Royalty entitles the Trust to receive
quarterly royalty payments from the Wasson ODC
production unit (the "Wasson ODC Unit") based upon
the average price per barrel received by Santa Fe
for Wasson ODC Unit oil production during each
calendar quarter through December 31, 2007 (net of
post-production costs and production taxes)
multiplied by an annually varying number of barrels
first produced from Santa Fe's royalty interest in
the Wasson ODC Unit. See "The Royalty
Interests -- The Wasson Royalties -- The Wasson ODC
Royalty" for a schedule of the applicable maximum
quarterly royalty production limitations. Based upon
the Reserve Report, estimated oil production from
the Wasson ODC Unit for each calendar quarter during
the term of the Wasson ODC Royalty will exceed the
quarterly production limitations over the term of
the Trust, although such excess will narrow in the
latter years of the term. Any Support Payments will
be made by payment of an additional royalty out of
Santa Fe's remaining royalty interest in the Wasson
ODC Unit.
Wasson Willard Royalty.. The Wasson Willard Royalty entitles the Trust to
receive quarterly royalty payments from the Wasson
Willard production unit (the "Wasson Willard Unit")
based upon the average price per barrel received by
Santa Fe for Wasson Willard Unit oil production
during each calendar quarter through December 31,
2003 (net of post-production costs and production
taxes) multiplied by an annually varying number of
barrels first produced from Santa Fe's royalty
interest in the Wasson Willard Unit. The number of
barrels applicable to the Wasson Willard Royalty
represents 100% of current estimated production of
proved reserves attributable to Santa Fe's royalty
interest in the Wasson Willard Unit. See "The
Royalty Interests -- The Wasson Royalties -- The
Wasson Willard Royalty" for a schedule of the
applicable maximum quarterly barrel limitations.
Net Profits Royalties... The Net Profits Royalties entitle the Trust to
receive 90% of the Net Proceeds (as defined herein)
from the sale of oil and gas production from the
Royalty Properties burdened by the Net Profits
Royalties. "Net Proceeds" consists generally of the
aggregate proceeds from the sale of production
attributable to the Royalty Properties subject to
the Net Profits Royalties less the costs
attributable to such Royalty Properties. Such costs
include post-production costs, production and ad
valorem taxes and, with respect to Royalty
Properties consisting of working interests,
production and development costs.
Distributions from Sale of
Net Profits Royalties... Santa Fe may cause the Trust, without the consent of
the Holders, to sell up to $5 million of the Net
Profits Royalties at the then prevailing fair market
value in any 12-month period in connection with a
sale by Santa Fe of the Royalty Properties to which
such Net Profits Royalties relate, provided that not
more than $15 million in the aggregate may be sold
prior to January 1, 2003. Any net proceeds paid to
the Trust from such a sale will be distributed to
the Holders with respect to the calendar quarter in
which the proceeds are received. Since the effect of
such a sale is to reduce the asset base of the Trust
through a distribution to Holders, such a sale of
any Net Profits Royalties will reduce below $20
million the maximum amount of Support Payments which
may be made to the Trust
6
<PAGE> 7
in future periods by an amount in proportion to the
reduction in reserve value resulting from such a
sale. Santa Fe may cause all of the Net Profits
Royalties to be sold, without regard to dollar
limitations, on and after December 31, 2005.
Treasury Obligations....... The Treasury Obligations consist of a portfolio of
United States Treasury stripped interest coupons
that mature on the Liquidation Date in the aggregate
face amount of $126,000,000, which amount equals $20
(the price at which Depositary Units were initially
offered to the public in November 1992) multiplied
by the aggregate number of outstanding Depositary
Units. The Treasury Obligations are deposited with
the Depositary for the benefit of the Holders. Since
Depositary Units are only traded in denominations of
50 or integral multiples thereof, each holder of 50
Depositary Units will own the entire beneficial
ownership of a discrete Treasury Obligation, in a
face amount of $1,000, the minimum denomination of
such Treasury Obligation. The Treasury Obligations
pay no current interest. See "Federal Income Tax
Consequences."
SUMMARY OF DISTRIBUTABLE CASH
(UNAUDITED)
The following table sets forth a summary of the components of distributable
cash for the Trust in respect of the period from inception of the Trust (October
22, 1992) through December 31, 1992 and the year ended December 31, 1993. The
amounts presented below are included in the period in which they accrue to the
Trust. The financial statements of the Trust included herein are presented on a
cash basis.
<TABLE>
<CAPTION>
INCEPTION YEAR
THROUGH ENDED
DECEMBER 31, DECEMBER 31,
1992(1) 1993(2)
------- -------
<S> <C> <C>
(IN THOUSANDS, EXCEPT
PER UNIT DATA)
Total Distributable Cash:
Wasson ODC Royalty............................................. $ 144 $ 2,563
Wasson Willard Royalty......................................... 399 2,194
Net Profits Royalties.......................................... 1,559 7,933
Support Payment................................................ -- 362
Less: Trust expenses and property taxes........................ (165) (1,689)
------- -------
Total.................................................. $ 1,937 $11,363
======= =======
Distributable Cash Per Trust Unit (6,300,000 Trust Units
Outstanding):
Wasson ODC Royalty............................................. $0.0229 $0.4067
Wasson Willard Royalty......................................... 0.0633 0.3483
Net Profits Royalties.......................................... 0.2475 1.2592
Support Payment................................................ -- 0.0575
Less: Trust expenses and property taxes........................ (0.0262) (0.2680)
------- -------
Total.................................................. $0.3075 $1.8037
======= =======
</TABLE>
- ---------------
(1) Distributed to Holders of record on February 16, 1993.
(2) Distributed or distributable to Holders of record on May 17, August 16, and
November 15, 1993 and February 14, 1994.
7
<PAGE> 8
THE ROYALTY PROPERTIES
The Wasson Properties. The Wasson Royalties were conveyed out of Santa Fe's
12.3934% royalty interest in the Wasson ODC Unit and its 6.83548% royalty
interest in the Wasson Willard Unit, located in the Wasson Field. The Wasson
Field is the sixth largest oil field in the United States covering over 70,000
surface acres with over 2,000 producing wells. Since its discovery in 1936, the
Wasson Field has produced over 1.7 billion barrels of oil. Santa Fe's production
from the Wasson Field commenced in 1939. The Wasson Field has been significantly
redeveloped for tertiary recovery operations utilizing CO2 flooding, which
commenced in 1984. Gross capital expenditures in excess of $600 million have
been made by all working interest owners in respect of these operations in the
Wasson ODC Unit and Wasson Willard Unit. Most of the capital expenditures for
plant, facilities, wells and equipment necessary for such tertiary recovery
operations have been made, although significant ongoing capital expenditures for
CO2 acquisition will be required to complete the flood of the Wasson Field,
particularly the Wasson Willard Unit. See "Risk Factors." The Wasson Royalties
are not subject to development costs or operating costs (including CO2
acquisition costs).
The Wasson ODC Unit and the Wasson Willard Unit are production units formed
by the various interest owners in the Wasson Field to facilitate development and
production of certain geographically concentrated leases. The Wasson ODC Unit
covers approximately 7,840 acres with approximately 322 producing wells and is
operated by Amoco Production Company. The Wasson Willard Unit covers
approximately 13,520 acres with approximately 343 producing wells and is
operated by a subsidiary of Atlantic Richfield Company. During the year ended
December 31, 1993, production from the Wasson ODC Unit (net to Santa Fe's
12.3934% royalty interest) averaged approximately 163.0 MBbls of oil quarterly,
and production from the Wasson Willard Unit (net to Santa Fe's 6.83548% royalty
interest) averaged approximately 37.3 MBbls of oil quarterly. Santa Fe may sell
its royalty interests in the Wasson Field subject to and burdened by the Wasson
Royalties, without the consent of the Trustee of the Trust or the Holders. The
Wasson Royalties may not be sold by the Trust without the consent of Santa Fe.
The Net Profits Properties. The Royalty Properties burdened by the Net
Profits Royalties (the "Net Profits Properties") consist of royalty and working
interests in a diversified portfolio of producing properties located in
established oil and gas producing areas in 12 states. Over 90% of the discounted
present value of estimated future net revenues attributable to the Net Profits
Royalties are generated from Net Profits Properties located in Texas, Oklahoma
and Louisiana. The Net Profits Properties generally consist of mature producing
properties and Santa Fe does not anticipate substantial additional development
during the producing lives of these properties. Production attributable to the
Net Profits Properties is principally sold at the wellhead at market responsive
prices.
Santa Fe owns the Net Profits Properties subject to and burdened by the Net
Profits Royalties, and is entitled to proceeds attributable to its ownership
interest in excess of 90% of the Net Proceeds paid to the Trust. Santa Fe is
required to receive payments representing the sale of production from the Net
Profits Properties, deduct the costs described above and pay 90% of the net
amount to the Trust. Santa Fe may sell the Net Profits Properties subject to and
burdened by the Net Profits Royalties. In addition, Santa Fe may, subject to
certain limitations, cause the Trust to release portions of the Net Profits
Royalties in connection with the sale of the underlying Net Profits Properties.
See "Description of the Trust and the Trust Agreement -- Transfer of Royalty
Properties and Royalty Interests."
SUMMARY RESERVE INFORMATION
Proved Reserves of the Trust. The following table sets forth, as of
December 31, 1993, certain estimated proved reserves, estimated future net
revenues and the discounted present value thereof attributable to the Wasson ODC
Royalty, the Wasson Willard Royalty and the Net Profits Royalties. This
information is derived from the Reserve Report. Proved reserve quantities for
each of the Wasson Royalties are calculated by multiplying the net revenue
interest attributable to each of the Wasson Royalties in effect for a given year
by the total amount of oil estimated to be economically recoverable from the
respective production units (subject to limitation by applicable maximum
quarterly production amounts). Reserve quantities are calculated differently for
the Net Profits Royalties because such interests do not entitle the Trust to a
specific quantity of
8
<PAGE> 9
oil or gas but to the Net Proceeds derived therefrom. Proved reserves
attributable to the Net Profits Royalties are calculated by deducting an amount
of oil or gas sufficient, if sold at the prices used in preparing the reserve
estimates for the Net Profits Royalties, to pay the future estimated costs and
expenses deducted in the calculation of Net Proceeds with respect to the Net
Profits Royalties. Accordingly, the reserves presented for the Net Profits
Royalties reflect quantities of oil and gas that are free of future costs or
expenses if the price and cost assumptions set forth in the Reserve Report
occur. The Reserve Report was prepared in accordance with criteria established
by the Commission and, accordingly, assumes constant prices and costs in effect
as of the date of the Reserve Report throughout the life of the reserves. A
summary of the Reserve Report is included as Appendix A to this Prospectus.
Estimated future net revenues and the discounted present value thereof were
determined using oil prices of $11.50, $11.50 and $11.97 per barrel with respect
to production from the Wasson ODC Unit, the Wasson Willard Unit and the Net
Profits Properties, respectively, a weighted average gas price of $2.12 per Mcf
and a discount rate of 10%. As of January 31, 1994, the Trust was realizing a
price of approximately $12.98 per barrel on all Wasson production.
<TABLE>
<CAPTION>
DISCOUNTED
PROVED RESERVES(1) ESTIMATED ESTIMATED
-------------------- FUTURE FUTURE
OIL GAS NET NET
ROYALTY INTERESTS OF THE TRUST (MBBLS) (MMCF) REVENUES REVENUES
------------------------------ ------- ------- -------- --------
<S> <C> <C> <C> <C>
(DOLLARS IN THOUSANDS)
Wasson ODC Royalty(2).................... 5,535 -- $ 58,681 $33,198
Wasson Willard Royalty................... 1,026 -- 10,715 7,314
Net Profits Royalties(3)................. 1,208(4) 11,121 38,148 24,804
------- ------- -------- -------
Total(2)....................... 7,769 11,121 $107,544 $65,316
======= ======= ======== =======
</TABLE>
- ---------------
(1) Substantially all of the proved reserves are developed. See "The Royalty
Properties -- Reserves."
(2) The information presented includes 1,891 MBbls of oil, $20,000,000 of
estimated future net revenues and $12,663,000 of discounted estimated future
net revenues attributable to an additional royalty in respect of Support
Payments which would be paid, in the years 1994 through 2001, under the
constant pricing assumptions and production estimates specified in the
Reserve Report. Under these assumptions and estimates no Support Payments
would be paid in 2002, the last year of the support period, because total
Support Payments are limited to $20 million.
(3) Approximately 41% of the discounted present value of estimated future net
revenues attributable to the Net Profits Royalties relates to Net Profits
Properties that are royalty and overriding royalty interests and 59% of such
discounted present value relates to Net Profits Properties that are working
interests. See "The Royalty Properties."
(4) Includes 57 MBbls of natural gas liquids attributable to the Net Profits
Royalties.
Proved Reserves Available for Support Payments. Support Payments payable in
the support period will be made from Santa Fe's remaining royalty interest in
the Wasson ODC Unit pursuant to an additional royalty paid in order to provide
Support Payments to the Trust. Support Payments, if made, will be made from
royalties on actual quarterly production. From the inception of the Trust
through the third quarter of 1993, net cash proceeds from the Royalty Interests
were sufficient to make quarterly distributions of at least $0.40 per Depositary
Unit and Support Payments were not, therefore, required. The distribution
declared with respect to the fourth quarter of 1993, however, includes a Support
Payment of approximately $362,000 (approximately $0.06 per Depositary Unit).
This Support Payment was required primarily due to lower realized oil prices and
unanticipated capital expenditures incurred with respect to the Net Profits
Properties, a substantial portion of which is related to the drilling of new
wells.
The Support Payments are limited by the amount of production attributable
to Santa Fe's remaining royalty interest in the Wasson ODC Unit and are further
limited to an aggregate of $20 million on a revolving basis. Under the constant
pricing assumptions (including an $11.50 per barrel price for all Wasson
production) and production estimates specified in the Reserve Report, the Trust
is projected to pay the $0.40 minimum quarterly royalty for each quarter through
1998. Thereafter, Support Payments would not be sufficient or available in the
last four years of the support period to pay a full $0.40 minimum quarterly
royalty
9
<PAGE> 10
distribution. The estimated quarterly distribution shortfalls range from $0.01
per Depositary Unit in 1999 to $0.22 per Depositary Unit in 2002.
The following are estimates of proved production and related future net
revenues during each of the calendar years in the support period attributable to
Santa Fe's remaining royalty interest in the Wasson ODC Unit from which Support
Payments could be made, subject to the $20 million limitation on aggregate
unrecouped Support Payments. The amounts include annual estimates of proved
reserves and future net revenues attributable to the additional royalty paid to
the Trust in respect of Support Payments as described in note (2) above. Such
information is based upon the constant pricing assumptions and production
estimates made in the Reserve Report. The aggregate amount of Support Payments
(net of any amount recouped by Santa Fe) is limited to $20 million on a
revolving basis. See "The Royalty Interests -- Support Payments."
<TABLE>
<CAPTION>
ESTIMATED ESTIMATED
ANNUAL ANNUAL
PRODUCTION FUTURE
OF NET
PROVED REVENUES
RESERVES (IN
YEAR (MBBLS)(1) THOUSANDS)(2)
---- ---------- -------------
<S> <C> <C>
1994................................................. 462.0 $ 4,841
1995................................................. 413.9 4,345
1996................................................. 411.0 4,324
1997................................................. 402.0 4,243
1998................................................. 385.2 4,074
1999................................................. 347.4 3,681
2000................................................. 339.1 3,600
2001................................................. 290.4 3,090
2002................................................. 221.6 2,360
------ -------
Total...................................... 3,272.6 $34,558(3)
======= =======
</TABLE>
- ---------------
(1) Includes reserves and future net revenues attributable to additional
royalties paid in respect of Support Payments that are included in the
Royalty Interests of the Trust, as described in Note (2) to the previous
table.
(2) Based upon an assumed oil price of $11.50 per barrel received for production
from the Wasson ODC Unit.
(3) The discounted value of the aggregate estimated future net revenues is
$23,815,000.
SANTA FE
Santa Fe is engaged in the exploration, development and production of oil
and gas in most of the major producing basins in the Continental United States.
Santa Fe's oil production is principally located in California and Texas, while
its gas production comes primarily from the Gulf of Mexico, Oklahoma, New
Mexico, Wyoming and Texas. A substantial portion of Santa Fe's oil production is
in long-lived fields with well established production histories and where
enhanced oil recovery methods are employed. Substantially all of Santa Fe's
reserves are located in the United States, with the balance located in Argentina
and Indonesia. The principal executive offices of Santa Fe are located at 1616
South Voss Road, Suite 1000, Houston, Texas 77057 and its telephone number is
(713) 783-2401. For additional information concerning Santa Fe, including a
discussion of certain recent events, see "Santa Fe."
SUMMARY FEDERAL INCOME TAX CONSEQUENCES
THE TAX CONSEQUENCES OF AN INVESTMENT IN DEPOSITARY UNITS TO A PARTICULAR
INVESTOR WILL DEPEND IN PART ON THE INVESTOR'S OWN TAX CIRCUMSTANCES. EACH
PROSPECTIVE INVESTOR SHOULD THEREFORE CONSULT HIS OWN TAX ADVISOR ABOUT THE
FEDERAL, STATE AND LOCAL TAX CONSEQUENCES TO SUCH INVESTOR IN DEPOSITARY UNITS.
The following is a summary of certain Federal income tax consequences of
acquiring, owning and disposing of Depositary Units and is based on the opinions
of Andrews & Kurth L.L.P., counsel to Santa Fe
10
<PAGE> 11
("Counsel"). For a more detailed discussion of these consequences and the
qualifications to and limitations of the opinions of Counsel, see "Federal
Income Tax Consequences" and "Risk Factors -- Tax Considerations."
Allocation of Purchase
Price...................... Each purchaser of a Depositary Unit will be required
to allocate his purchase price between the interest
in the Treasury Obligations and the Trust Unit
underlying such Depositary Unit on a relative fair
market value basis. In addition, because the Trust
will be treated as a grantor trust for Federal
income tax purposes, a purchaser will be required to
further allocate the amount allocated to Trust Units
among the Royalty Interests on a relative fair
market value basis. Information regarding purchase
price allocations will be furnished to Holders by
the Trustee.
Classification and Taxation
of the Trust............. The Trust will be treated as a grantor trust and not
as an association taxable as a corporation. As a
grantor trust, the Trust will not be subject to tax.
If the Trust were treated as an association taxable
as a corporation, it would be treated as a separate
entity subject to corporate tax on its taxable
income.
Taxation of Holders........ Because the Trust will be treated as a grantor trust
for Federal income tax purposes, and because a
Holder will be treated, for Federal income tax
purposes, as directly owning an interest in the
assets of the Trust and the Treasury Obligations,
each Holder will be taxed directly on his pro rata
share of income attributable to the assets of the
Trust and the Treasury Obligations consistent with
the Holder's method of accounting and without regard
to the taxable year or accounting method employed by
the Trust.
Interest Income............ For Federal income tax purposes, the Wasson
Royalties will be treated as debt obligations. As a
result, each purchaser of a Depositary Unit will be
required to treat a portion of each payment received
by the Trust as interest income in accordance with
the original issue discount rules of Sections 1272
through 1275 of the Internal Revenue Code of 1986,
as amended. In addition, each purchaser of a
Depositary Unit will be required to recognize
original issue discount income with respect to the
Treasury Obligations even though no cash
distributions will be made with regard thereto prior
to the Liquidation Date.
Royalty Income and
Depletion.................. The income from the Net Profits Royalties will be
royalty income subject to an allowance for the
higher of cost depletion or, if allowable,
percentage depletion.
Taxable Income Estimate.... Santa Fe estimates that, under certain assumptions,
a purchaser of a Depositary Unit in this offering
who continues to hold that unit through the record
date for the distribution with respect to the final
quarter of 1994 will recognize taxable income of
approximately 73% of cash received for 1994. This
estimate is based upon numerous assumptions more
particularly described under "Federal Income Tax
Consequences -- Estimate of Taxable Income,"
including (i) a purchase price per Depositary Unit
based upon an approximation of recent trading prices
of the Depositary Units, (ii) cash distributed by
the Trust in 1994 based upon assumed production and
future net revenues as estimated for 1994 in the
Reserve Report, (iii) estimated Trust expenses are
deductible by the Holder and (iv) various other
assumptions regarding allocation of purchase price
among the Royalty Interests and Treasury
Obligations.
Holder Reporting
Information................ Year-end tax information will be furnished to
Holders no later than March 31 of the following
year.
11
<PAGE> 12
RISK FACTORS
VOLATILITY OF OIL AND GAS PRICES AND PRODUCTION
The Trust's revenues and distributions to Holders are dependent on the
sales prices and quantities of oil and gas production from the Royalty
Properties. Oil and gas prices have historically been volatile and are likely to
continue to be volatile. Such volatility makes it difficult to estimate the
future levels of cash distributions to Holders or the value of the Depositary
Units. The Trust, however, is entitled under certain circumstances to receive
Support Payments which should minimize, to the extent Support Payments are
available, the effects of low oil and gas prices or lower than expected
production levels during periods prior to December 31, 2002. Although the
Support Payments will enhance the likelihood that such minimum distributions
will be made to Holders, the production from which the Support Payments will be
made is subject to the same pricing and production risks and uncertainties as is
the production attributable to the Royalty Interests. Thus, no assurances can be
given that Support Payments will be available to provide for the minimum
quarterly cash distributions to Holders specified herein. See "-- Limitations on
Support Payments" and "The Royalty Interests -- Support Payments."
Prices for oil and gas are subject to wide fluctuations in response to
relatively minor changes in supply, market uncertainty and a variety of
additional factors that are beyond the control of the Trust and Santa Fe. These
factors include political conditions in the Middle East, the foreign supply of
oil and gas, the price of foreign imports, the level of consumer product demand,
the severity of weather conditions, governmental regulations, the price and
availability of alternative fuels and overall economic conditions. Additionally,
lower oil and gas prices may reduce the amount of oil and gas that is economic
to produce from the Royalty Properties. As a result, operators of the Royalty
Properties may elect to reduce or completely suspend production.
INCREASING DEPENDENCE ON OIL REVENUES AND PRICES
At December 31, 1993, approximately three-fourths of the future net
revenues of the Royalty Interests was attributable to oil reserves. Cash
distributions from the Trust are therefore more dependent upon oil revenues and
prices than gas revenues and prices. Dependence upon oil revenues and prices
will also increase over the term of the Trust due to the relatively shorter life
of gas reserves attributable to the Net Profits Royalties and the corresponding
increased relative significance of the oil producing Wasson ODC Royalty.
RECENT SIGNIFICANT DECLINES IN OIL PRICES
Oil prices have declined significantly since the inception of the Trust.
The Reserve Report is prepared using prices in effect at December 31, 1993,
which prices were $11.50, $11.50 and $11.97 per barrel with respect to
production from the Wasson ODC Unit, the Wasson Willard Unit and the Net Profits
Properties, respectively. The average actual price realized by the Trust in
respect of the Wasson Royalties for December 1993 was approximately $12.18 per
barrel. As of January 31, 1994, the Trust was receiving approximately $12.98 per
barrel for production in respect of the Wasson Royalties. If prices for oil and
gas used in the Reserve Report were to be sustained over the life of the Trust
and Trust reserves are produced as estimated in the Reserve Report, (i) Support
Payments would be required and no more than the $0.40 per Depositary Unit
minumum quarterly royalty would be paid throughout the support period, (ii)
Support Payments would be insufficient during 1999 through 2001 to assure a full
$0.40 per Depositary Unit quarterly cash distribution during such years and
(iii) the $20 million limitation on unrecouped Support Payments would result in
no Support Payments being paid during 2002, the last year in which Support
Payments are available. Assuming Trust reserves are produced at levels estimated
in the Reserve Report, lower oil and gas prices will increase the Support
Payments that may be required to be made to the Trust to support a quarterly
cash distribution of $0.40 per Depositary Unit. Such increased Support Payment
would accelerate the time at which the $20 million limitation on Support
Payments would be reached. As a result of lower realized oil prices and
unanticipated capital expenditures incurred with respect to the Net Profits
Properties, the distribution declared with respect to the fourth quarter of 1993
includes a Support Payment of approximately $362,000 (approximately $0.06 per
Depositary Unit). Actual Trust production will also effect the amount and timing
of Support Payments. See "-- Limitations on Support Payments" below.
12
<PAGE> 13
OIL AND GAS RESERVES CONSTITUTE DEPLETING ASSETS
Payments to the Trust are attributable to the sale of depleting assets.
Thus, the reserves attributable to the Royalty Properties are expected to
decline over time. Based on the estimated production volumes in the Reserve
Report, the oil and gas production from proved reserves attributable to the
Royalty Interests is expected to decline at an annually compounded rate of
approximately 9% over the life of the Trust. Based on this decline rate, the
production rate during the year preceding the Liquidation Date is estimated to
be reduced to approximately one-fourth of the initial production rate
attributable to the Royalty Properties.
The Net Profits Properties generally consist of mature producing properties
and Santa Fe does not anticipate substantial additional development during the
productive lives of the properties.
Reservoir engineering studies prepared by or on behalf of Santa Fe indicate
that significant additions to Santa Fe's proved reserves attributable to its
royalty interests in the Wasson Field may continue to be made through additional
enhanced recovery operations. Due to the production limitations applicable to
the Wasson Royalties, however, the Trust and Holders would not benefit directly
from increased reserves attributable to properties underlying the Wasson
Royalties except that such increases will provide additional assurance that the
maximum barrels applicable to the Wasson Royalties will be produced. Increases
in reserves produced from the Wasson ODC Unit through 2002 will also provide
additional reserves available for Support Payments. Such increased reserves are,
of course, subject to the same uncertainties and risks described elsewhere under
this "Risk Factors" caption in respect of the reserves attributable to the
Royalty Properties.
LIMITATIONS ON SUPPORT PAYMENTS
The Support Payments are intended to provide distribution support to
Holders through 2002 in the event of declines in oil and gas prices or
production from the Royalty Properties or increases in costs deducted in
determining Net Proceeds from the Net Profits Properties. Subject to certain
limitations, the Trust is entitled to receive Support Payments only to the
extent the amount available for distribution by the Trust for any calendar
quarter through 2002 does not otherwise equal or exceed $0.40 per Depositary
Unit. Based upon the production estimates set forth in the Reserve Report, as
production from the Wasson ODC Unit declines, the production from Santa Fe's
royalty interest in the Wasson ODC Unit in excess of the maximum quarterly
barrel limitations (which excess is available for Support Payments) is
significantly reduced in the later years of the Trust term. See "The Royalty
Properties -- The Wasson Properties." Additionally, the Support Payments are
limited by the amount of production attributable to Santa Fe's remaining royalty
interest in the Wasson ODC Unit and are further limited to an aggregate of $20
million on a revolving basis. Under the constant pricing assumptions (including
an $11.50 per barrel price for all Wasson production) and production estimates
specified in the Reserve Report, Support Payments would not be sufficient or
available in the last four years of the support period to pay a full $0.40
minimum quarterly royalty distribution. The estimated quarterly distribution
shortfalls range from $0.01 per Depositary Unit in 1999 to $0.22 per Depositary
Unit in 2002.
There is no assurance that Support Payments will be available from Santa
Fe's remaining interest in the Wasson ODC Unit in an amount sufficient to enable
the Trust to distribute the full supported distribution amount ($0.40 per
Depositary Unit) in any quarter. Additionally, the aggregate Support Payments,
net of any amounts recouped by Santa Fe pursuant to reductions in the royalties
payable with respect to the Royalty Interests as described below, are limited to
$20 million ($3.175 per Depositary Unit) on a revolving basis (i.e., subject to
replenishment upon recoupment of certain amounts to Santa Fe through reductions
in payments from the Wasson Royalties). See "The Royalty Interests -- Support
Payments." In the event any Support Payments are made to the Trust, the
royalties payable with respect to the Royalty Interests will be reduced in
future distribution quarters to the extent necessary to recoup the amount of
proceeds paid to the Trust as a result of the Support Payments, provided that
such reductions would not reduce distributions to Holders for any quarter below
$0.45 per Depositary Unit.
13
<PAGE> 14
UNCERTAINTIES INVOLVED IN RESERVE ESTIMATES AND POSSIBLE PRODUCTION RISKS
The value of the Depositary Units and the Trust Units evidenced thereby are
substantially dependent upon the proved reserves and production levels
attributable to the Royalty Interests. There are many uncertainties inherent in
estimating quantities and values of proved reserves and in projecting future
rates of production and the timing of development expenditures. The reserve data
set forth herein, although prepared by independent reservoir engineers in a
manner customary in the industry, are estimates only, and actual quantities and
values of oil and gas are likely to differ from the estimated amounts set forth
herein. In addition, the discounted present values of estimated proved reserves
shown herein were prepared using guidelines established by the Commission for
disclosure of reserves and should not be considered representative of the market
value of such reserves or the Depositary Units or the Trust Units evidenced
thereby. A market value determination would include many additional factors.
Distributions to Holders could be adversely affected if any of the hazards
typically associated with the development, production and transportation of oil
and gas were to occur, including personal injuries, property damage, damage to
productive formations or equipment and environmental damages. Uninsured costs
for damages from any of the foregoing will directly reduce payments to the Trust
from those Royalty Properties that are working interests, and will reduce
payments to the Trust from those Royalty Properties that are royalties and
overriding royalties to the extent such damages reduce the volumes of oil and
gas produced.
QUARTERLY PRODUCTION LIMITATIONS AFFECTING WASSON ROYALTIES
In contrast to the Net Profits Royalties, which have no production
limitations, the Wasson Royalties are structured with quarterly production
limitations. Thus, the Trust and Holders do not receive cash distributions from
oil production from the two Wasson production units burdened by the Wasson
Royalties in excess of such amounts. While the Wasson ODC Unit is expected to
produce at levels substantially in excess of the applicable production
limitations, failure of actual production from either of the two Wasson
production units to meet or exceed the applicable quarterly production
limitations will reduce amounts payable in respect of the Wasson Royalties. See
"The Royalty Properties -- The Wasson Properties" for information regarding
estimated production from the Wasson ODC Unit and the Wasson Willard Unit. Since
the inception of the Trust on October 22, 1992, production from the two Wasson
production units has exceeded the applicable quarterly production limitations,
although no assurance can be given that future production will continue to
exceed applicable limitation amounts.
LACK OF CONTROL OF OPERATIONS AND DEVELOPMENT OF THE ROYALTY PROPERTIES
Under the terms of the conveyances creating the Royalty Interests, neither
the Trustee or the Trust nor the Holders are able to influence or control the
operation or future development of the Royalty Properties. Santa Fe operates
only a small number of the Royalty Properties. Santa Fe is not expected to be
able to significantly influence the operations or future development of the
Royalty Properties that are royalty interests or that consist of relatively
small working interests. Such operations will generally be controlled by persons
unaffiliated with the Trustee and Santa Fe. Santa Fe, however, owns working
interests in the Wasson ODC Unit and the Wasson Willard Unit and may be able to
exercise some influence, though not control, over unit operations.
The tertiary recovery operations in the Wasson Field have required
substantial capital expenditures and will involve significant future capital
expenditures for CO(') acquisition, particularly in the Wasson Willard Unit. A
prolonged oil price downturn could cause the operators in the Wasson Field to
reassess the economic viability of capital intensive production operations
notwithstanding their substantial unrecovered investment. Such decisions will
not be in the control of either Santa Fe or the Trustee and could have the
effect of substantially reducing expected production from the Wasson Field.
The current operators of the Royalty Properties are under no obligation to
continue operating such properties, and neither the Trustee, the Holders nor
Santa Fe will be able to appoint or control the appointment of replacement
operators. The operators of the Royalty Properties and any transferee will have
the right to abandon any well or property on a Royalty Property that is a
working interest if, in its opinion, such
14
<PAGE> 15
well or property ceases to produce or is not capable of producing in
commercially paying quantities, and upon termination of any such lease, that
portion of the Royalty Interests relating thereto will be extinguished.
CHANGES IN PRODUCTION AND DEVELOPMENT COSTS COULD AFFECT TRUST REVENUES
In general, the owner of a royalty interest receives a specified portion of
the gross sales proceeds of oil and gas production (net of post-production costs
and certain taxes) regardless of the production expenses necessary to produce
such oil and gas. A working interest owner, however, is obligated for its
proportionate share of production expenses. Production expenses typically
include labor, fuel, repairs, hauling, pumping, insurance, storage, and
supervision and administration. Accordingly, higher or lower production expenses
on those portions of the Net Profits Royalties that are working interests will
directly decrease or increase the amount received by the Trust. The amount
received by the Trust from the Net Profits Royalties which burden royalty
interests or the Wasson Royalties, however, will not be directly affected by
changes in production costs. According to the Reserve Report, at December 31,
1993, working interests and royalty interests comprised approximately 59% and
41% of the discounted estimated future net revenues attributable to the Net
Profits Royalties, respectively. Including the Wasson Royalties, working
interests and royalty interests comprised approximately 22% and 78% of the
discounted estimated future net revenues attributable to the Royalty Interests,
respectively.
Development costs consist principally of drilling and completion of wells.
Payments to the Trust with respect to Net Profits Properties that are working
interests are reduced by development costs. Amounts payable to the Trust with
respect to production from Net Profits Properties that are royalties are not
reduced by development costs, although such costs may affect the working
interest owner's decision to develop a property. The Royalty Properties
generally consist of mature producing properties and Santa Fe does not
anticipate substantial additional development costs during the producing lives
of these properties. If the requisite percentage of working interest holders in
a production unit approves a development project, all such holders are required
to pay their proportionate share of development costs. If additional development
costs are incurred with respect to working interests in properties burdened by
the Net Profits Royalties, the Trust will not be liable for any development
costs, but the amount of such development costs will be deducted when computing
Net Proceeds.
POSSIBLE CURTAILMENT OF GAS PRODUCTION; RISKS OF THE MARKET FOR GAS
At December 31, 1993, approximately one-fourth of the estimated future net
revenues from proved reserves of the Royalty Interests was attributable to gas.
Thus, the revenues of the Trust and the amount of cash distributions to Holders
are dependent upon, among other things, the volume of gas produced and the price
at which such gas is sold. Since the early 1980s, the available gas production
capacity nationwide has exceeded the demand by users of such gas, resulting in
demand-related production curtailments. No assurances can be made that
curtailments will not continue to exist. In addition, excess gas production
capacity in the United States has generally resulted in downward pressure on gas
prices. The effect of any excess production capacity which exists in the future
cannot be predicted with certainty; however, any such excess capacity may have a
material adverse effect on Trust distributions through its impact on prices and
production volumes.
Due to the seasonal nature of demand for gas and its effect on sales prices
and production volumes, the amount of cash distributions by the Trust that are
attributable to gas production may vary substantially on a seasonal basis.
Generally, gas production volumes and prices tend to be higher during the first
and fourth quarters of the calendar year. Because of the lag between Santa Fe's
receipt of revenues related to the Net Profits Properties and the dates on which
distributions are made to Holders, however, any seasonality that affects
production and prices generally should be reflected in distributions to Holders
in later periods.
TITLE TO PROPERTIES
See "The Royalty Properties -- Title to Properties" for a discussion of
title risks and issues concerning the effect of the conveyance of the Royalty
Interests under state law and Federal bankruptcy laws.
15
<PAGE> 16
CERTAIN INVESTMENT LIMITATIONS INHERENT IN VIEWING DEPOSITARY UNITS AS "SECURE
PRINCIPAL"
The Depositary Units are designed so that the accreting value of the
Treasury Obligations will in general offset the depleting nature of the gas
reserves attributable to the Royalty Interests. A Holder who holds 50 Depositary
Units as of the record date for the final quarter of the Trust's existence will
receive $1,000 upon the maturity of the Treasury Obligations (or $20 per
Depositary Unit). The trading price of the Depositary Units will fluctuate prior
to the Liquidation Date, which fluctuations may be significant. Such
fluctuations may be caused by fluctuations in cash distributions to Holders or
other factors relating to the economic performance of the Royalty Properties.
A Depositary Unit represents a direct beneficial ownership interest in the
Trust and a Treasury Obligation. No additional property or interest has been
pledged to secure any portion of a Depositary Unit investment. The term "secure
principal," when applied to an investment in Depositary Units, is intended to
refer only to the zero coupon nature of the Treasury Obligations, which if held
to maturity, will return to a Holder its face value (in the amount of $20 per
Depositary Unit) at its approximate 14-year maturity. The return of a
substantial portion of the initial investment of a Holder of Depositary Units
through the maturity of the Treasury Obligations assumes that the Holder will
hold the Depositary Units and underlying Treasury Obligations until maturity.
Due to the accreting nature of the value of the zero coupon Treasury
Obligations, the withdrawal and sale of a Treasury Obligation underlying
Depositary Units prior to its maturity will result in the Holder receiving less
than the face value for its Treasury Obligation investment. The amount a
withdrawing Holder may receive from the sale of a Treasury Obligation prior to
its maturity will be affected by such factors as then current interest rates and
the small size of the Treasury Obligation relative to typical trades in the
secondary market for United States Treasury obligations (which may result in a
discount to quoted market values). Over time, the accretion in value of the
Treasury Obligations is intended to offset to some extent the inherent decline
in value of the Trust Units as production from the Royalty Interests declines.
An early withdrawal and sale of the underlying Treasury Obligations will
eliminate this offset and leave the holder with an investment in withdrawn,
non-transferable Trust Units which are expected to decrease in value over time.
The accretion in value of the Treasury Obligations will also generate taxable
income to Holders of Depositary Units without corresponding distributable cash.
See "Federal Income Tax Consequences."
An investment in Depositary Units should not, therefore, be viewed as a
"secured" investment to the extent that the market price of the Depositary Units
may fluctuate prior to the Liquidation Date and to the extent of the effects of
withdrawal and sale of a Treasury Obligation prior to its maturity.
LIMITED VOTING RIGHTS OF HOLDERS
While Holders have certain voting rights pursuant to the terms of the Trust
Agreement, these rights are more limited than those of stockholders of most
public corporations. For example, there is no requirement for annual meetings of
Holders or for an annual or other periodic re-election of the Trustee.
Amendments to the Trust Agreement require the affirmative vote of the holders of
a majority of the outstanding Trust Units. Any such amendment is binding on all
Holders, regardless of whether they vote for or against such amendment. See
"Description of the Trust and the Trust Agreement -- Voting Rights of Holders of
Trust Units."
POSSIBLE ADVERSE TREATMENT OF ROYALTY INTERESTS IN BANKRUPTCY OF SANTA FE
It is not entirely clear that all of the Royalty Interests would be treated
as fully conveyed real or personal property interests under the laws of each of
the states in which the Royalty Properties are located. If during the term of
the Trust, Santa Fe were to become the subject of a Federal bankruptcy
proceeding and a determination were made in such proceeding that the Royalty
Interests do not constitute fully conveyed property interests, the Conveyances
conveying the Royalty Interests (including the additional Wasson ODC Royalty
conveyed in respect of Support Payments) could be subject to possible rejection
as an executory contract. In such event, the Trust would be treated as an
unsecured creditor of Santa Fe. Although no assurance can be given and no formal
legal opinions have been obtained, based upon discussions with legal counsel
Santa Fe does not believe that the Conveyances (other than conveyances of
Royalty Interests in Louisiana properties) should be subject to rejection in a
bankruptcy proceeding as executory contracts. A
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mortgage on the Louisiana Royalty Properties burdened by the Conveyance has been
granted in favor of the Trust to secure the Trust's interests in such Royalty
Properties, which should enhance the Trust's position in the event of such a
proceeding. See "The Royalty Properties -- Title to Properties."
POSSIBLE LACK OF LIMITED LIABILITY OF HOLDERS
The Trust is intended to be classified as an "express trust" under Texas
law and thus subject to the Texas Trust Code. Under the Texas Trust Code, a
trust beneficiary will not be held personally liable for obligations incurred by
the Trust except in limited circumstances principally related to wrongful
conduct by the trust beneficiary. It is unclear whether the Trust constitutes an
"express trust" under the Texas Trust Code. If the Trust were held not to be an
express trust a Holder could be held jointly and severally liable in the event
that the satisfaction of such liability was not by contract limited to the
assets of the Trust and insurance proceeds and the assets of the Trust were
insufficient to discharge such liability. Examples of such liability would
include liabilities arising under environmental laws and damages arising from
product liability and personal injury in connection with the Trust's business.
Santa Fe has neither sought nor received an opinion of counsel on the matter due
to the lack of conclusive precedent. However, after discussions with legal
counsel, Santa Fe believes that, because of the value of the Trust assets which
could first be reached by any Trust creditor or claimant, the passive nature of
the Royalty Interests constituting the Trust assets and restrictions on the
ability of the Trustee to engage in active business operations, the imposition
of any liability on a Holder is unlikely.
TAX CONSIDERATIONS
Classification and Taxation of the Trust May be Successfully
Challenged. The Trust has received an opinion of Counsel that the Trust is a
"grantor trust" for Federal income tax purposes, and that each Holder will be
taxed directly on his pro rata share of the income attributable to assets of the
Trust, and will be entitled to claim depletion deductions equal to the greater
of percentage depletion or cost depletion on a portion of such income (computed
on a portion of the basis of his Depositary Units) and his pro rata share of
other deductions of the Trust. Counsel believes that its opinion is in
accordance with the present position of the Internal Revenue Service (the "IRS")
regarding such trusts. Neither Santa Fe nor the Trustee has requested a ruling
from the IRS regarding any tax matters, however. There can be no assurance that
Santa Fe or the Trust would be granted such a ruling if requested or that the
IRS will not change its position in the future. The tax treatment of the Trust
and Holders could be materially different from that described above if the IRS
were to successfully challenge that treatment. See "Federal Income Tax
Consequences."
Allocation of Purchase Price and Original Issue Discount. The purchaser of
a Depositary Unit will be required to allocate his purchase price between the
underlying Treasury Obligations and Trust Units on a relative fair market value
basis. Because the Trust is a grantor trust, the Holder will be required to
further allocate that portion of his purchase price allocated to the Trust Units
among the assets of the Trust on a relative fair market value basis. Because the
Treasury Obligations and the assets of the Trust will produce original issue
discount income to a Holder as well as royalty income subject to depletion, the
manner in which a Holder allocates his purchase price (which allocation may be
challenged by the IRS) may materially affect the amount or timing of the
Holder's recognition of taxable income. Each purchaser of a Depositary Unit will
be required to recognize original issue discount income for Federal tax purposes
with respect to the Treasury Obligations even though no cash distributions will
be made with regard thereto prior to the Liquidation Date, and such original
issue discount income and the taxes imposed thereon may exceed the amount of
Trust distributions. In general, each payment (at the time the amount of such
payment becomes fixed) made to the Trust with respect to the Wasson Royalties
will be treated first as consisting of a payment of interest to the extent of
interest deemed accrued under the original issue discount rules of Sections 1272
through 1275 of the Internal Revenue Code of 1986, as amended, and the excess
(if any) will be treated as a payment of principal. See "Federal Income Tax
Consequences -- Interest Income."
POTENTIAL CONFLICTS OF INTEREST AMONG SANTA FE, THE TRUST AND THE HOLDERS
The interests of Santa Fe and the Trust with respect to the Royalty
Properties could at times be different. To the extent Santa Fe is a working
interest owner in Royalty Properties, Santa Fe could have interests that
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<PAGE> 18
conflict with the interests of the Trust and Holders. For example, due to a
number of factors including, but not limited to, future budgetary
considerations, Santa Fe could substantially curtail production or curtail or
delay the timing of future capital expenditures relating to the Royalty
Properties. Santa Fe may also approve the incurrence of development costs on Net
Profits Properties that are working interests, thus reducing net proceeds from
such properties in the near term. Such decisions may have the effect of changing
the amount or timing of future distributions to the Trust and the Holders. In
addition, Santa Fe's interests may conflict with that of the Trust and Holders
in situations involving the sale of the Royalty Properties. In certain
circumstances, Santa Fe has the right to compel the Trust to sell its Net
Profits Royalties in properties to be sold by Santa Fe. While the Trust will
receive distributions of proceeds from these sales, such sales could have the
effect of reducing aggregate distributions ultimately paid to the Trust and the
Holders. Santa Fe also has the right to sell any of the Royalty Properties,
subject to the Royalty Interests, to third parties who will then have
responsibility for accounting for the Royalty Interests with respect to the sold
property. Sales to such third parties may not be in the best interests of the
Trust and the Holders. See "The Royalty Interests -- Sale and Abandonment of
Royalty Properties."
The Support Payment provisions could also result in situations in which the
interests of Santa Fe and the Trust were different. Such differences could
relate to, among other things, the timing and control of expenditures, contract
negotiations, production volumes and other matters that could affect
distributions to Holders.
POSSIBLE EFFECTS OF GOVERNMENTAL REGULATIONS
The operation of the Royalty Properties and the sale of oil and gas
produced from such properties are subject to various Federal, state and local
laws and regulations relating to, among other things, the transportation of gas,
allowable production and environmental matters. In 1989, the Natural Gas
Wellhead Decontrol Act of 1989 (the "Decontrol Act") was enacted which removed
all remaining Federal price controls on gas. Under current market conditions,
deregulated gas prices under new contracts tend to be substantially lower than
most regulated price ceilings previously in effect. See "The Royalty
Properties -- Marketing of Production" and "-- Regulation of Oil and Gas."
THE ROYALTY INTERESTS
The Royalty Interests held by the Trust, which were conveyed to the Trust
at the closing of the initial public offering of Depositary Units in November
1992, consist of the Wasson Royalties and the Net Profits Royalties. The Wasson
Royalties were conveyed out of royalty interests owned by Santa Fe (the "Wasson
Royalty Properties") in the Wasson Willard Unit and the Wasson ODC Unit located
in the Wasson Field. The Net Profits Royalties were conveyed out of the Net
Profits Properties owned by Santa Fe, which Net Profits Properties consist of
Santa Fe's royalty interests and working interests in producing oil and gas
properties located in 12 states and related state waters.
The Wasson Royalties were conveyed from Santa Fe to the Trust pursuant to a
single instrument of conveyance (the "Wasson Conveyance"). The Net Profits
Royalties were conveyed from Santa Fe to the Trust pursuant to separate,
substantially similar conveyances (the "Net Profits Conveyances") except with
respect to the Net Profits Royalties in properties located within the State of
Louisiana and its related state waters. Due to the effect of certain Louisiana
laws governing the transfer of properties to trusts, the Louisiana Net Profits
Royalties were conveyed from Santa Fe to the Trust pursuant to a separate
conveyance in the form of a secured interest in proceeds of production from such
properties (the "Louisiana Conveyance"). The Louisiana Conveyance provides the
Trust with the economic equivalent of the Net Profits Royalties determined with
respect to the Net Profits Properties located in Louisiana. The Net Profits
Conveyances, Wasson Conveyance and Louisiana Conveyance are referred to
collectively as the "Conveyances."
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The Conveyances (other than the Louisiana Conveyance) are recorded in the
appropriate real property records in each county or parish where the respective
Royalty Properties are located so as to give notice of the Royalty Interests to
Santa Fe's creditors and transferees, who would take the Royalty Properties
subject to the Royalty Interests. The Conveyances (other than the Louisiana
Conveyance) are intended to convey the Royalty Interests as real property
interests under applicable state law. The Louisiana Conveyance constitutes a
conveyance of personal property under Louisiana law, but it is registered under
the Louisiana registry records and secured by a mortgage on the underlying
leaseholds or royalty interests of Santa Fe.
Santa Fe owns the Royalty Properties subject to and burdened by the Royalty
Interests. Santa Fe receives all payments relating to the sale of production
from the Royalty Properties and is required, pursuant to the Conveyances, to pay
to the Trust the portion thereof attributable to the Royalty Interests. Under
the Conveyances, the amounts payable with respect to the Royalty Interests are
computed with respect to each calendar quarter, and such amounts are paid by
Santa Fe to the Trust not later than 60 days after the end of each calendar
quarter. The amounts paid to the Trust do not include interest on any amounts
payable with respect to the Royalty Interests which are held by Santa Fe prior
to payment to the Trust. Santa Fe is entitled to retain any amounts attributable
to the Royalty Properties which are not required to be paid to the Trust with
respect to the Royalty Interests.
The following descriptions of the Wasson Royalties and the Net Profits
Royalties, and the calculation of amounts payable to the Trust in respect
thereof, are subject to and qualified by the more detailed provisions of the
Conveyances included as exhibits to the Registration Statement of which this
Prospectus constitutes a part.
THE WASSON ROYALTIES
The Wasson ODC Royalty. The Wasson ODC Royalty was conveyed out of Santa
Fe's 12.3934% royalty interest in the Wasson ODC Unit and entitles the Trust to
receive quarterly royalty payments with respect to oil production from the
Wasson ODC Unit for each calendar quarter during the period ending on December
31, 2007. The royalties payable with respect to the Wasson ODC Royalty for any
calendar quarter are determined by multiplying (a) the Average Per Barrel Price
(as defined below) received for such quarter with respect to oil production from
the Wasson ODC Unit by (b) the Royalty Production (as defined below) for such
quarter related to the Wasson ODC Royalty.
"Royalty Production" for the Wasson ODC Royalty is defined as 12.3934% of
the lesser of (i) the actual number of gross barrels of oil produced for such
quarter from the Wasson ODC Unit and (ii) the applicable maximum quarterly gross
production limitation set forth in the table below. The table also shows the
maximum number of barrels of Royalty Production that may be produced per quarter
in respect of the Wasson ODC Royalty (12.3934% of the quarterly gross production
limitation).
<TABLE>
<CAPTION>
WASSON ODC WASSON ODC
CALENDAR QUARTERS ROYALTY QUARTERLY ROYALTY MAXIMUM
IN THE YEAR ENDING GROSS PRODUCTION NET QUARTERLY
DECEMBER 31, LIMITATION (MBBLS) PRODUCTION (MBBLS)
------------------ ------------------ ------------------
<S> <C> <C>
1994........................... 418 51.8
1995........................... 515 63.8
1996........................... 521 64.6
1997........................... 539 66.8
1998........................... 532 65.9
1999........................... 561 69.5
2000........................... 522 64.7
2001........................... 504 62.5
2002........................... 530 65.7
2003........................... 582 72.1
2004........................... 604 74.9
2005........................... 536 66.4
2006........................... 502 62.2
2007........................... 486 60.2
</TABLE>
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Based upon the Reserve Report, estimated production of oil from proved
reserves attributable to the Wasson ODC Unit for each calendar quarter during
the remaining approximately 14-year term of the Wasson ODC Royalty will exceed
the quarterly gross production limitations over the term of the Trust, although
such excess will narrow in the latter years of the term of the Trust. Net
production to Santa Fe from the Wasson ODC Unit during the year ended December
31, 1993 averaged 163.0 MBbls per quarter, which amount exceeded the Wasson ODC
Royalty maximum net quarterly production limitation applicable to such period by
an average of 121.4 MBbls. See "The Royalty Properties -- The Wasson Properties"
for a further discussion of historical and estimated future production from the
Wasson ODC Unit.
The Wasson ODC Royalty will terminate on December 31, 2007. Thus, the Trust
will receive a final quarterly distribution from the Wasson ODC Royalty in
respect of the fourth quarter of 2007 on or about the Liquidation Date.
The Wasson Willard Royalty. The Wasson Willard Royalty was conveyed out of
Santa Fe's 6.83548% royalty interest in the Wasson Willard Unit and entitles the
Trust to receive quarterly royalty payments with respect to oil production from
the Wasson Willard Unit for each calendar quarter terminating on December 31,
2003. The royalty payable for any calendar quarter is determined by multiplying
(a) the Average Per Barrel Price (as defined below) received for such quarter
with respect to oil production from the Wasson Willard Unit by (b) the Royalty
Production (as defined below) for such quarter related to the Wasson Willard
Royalty.
"Royalty Production" for the Wasson Willard Royalty is defined as 6.83548%
of the lesser of (i) the actual number of gross barrels of oil produced for such
quarter from the Wasson Willard Unit and (ii) the applicable maximum quarterly
gross production limitation set forth in the table below. The table also shows
the maximum number of barrels of Royalty Production that may be produced per
quarter in respect of the Wasson Willard Royalty (6.83548% of the quarterly
gross production limitation).
<TABLE>
<CAPTION>
WASSON WILLARD WASSON WILLARD
CALENDAR QUARTERS ROYALTY QUARTERLY ROYALTY MAXIMUM
IN THE YEAR ENDING GROSS PRODUCTION NET QUARTERLY
DECEMBER 31, LIMITATION (MBBLS) PRODUCTION (MBBLS)
------------------ ------------------ ------------------
<S> <C> <C>
1994........................... 514 35.1
1995........................... 494 33.8
1996........................... 474 32.4
1997........................... 455 31.1
1998........................... 437 29.9
1999........................... 390 26.7
2000........................... 323 22.1
2001........................... 268 18.3
2002........................... 222 15.2
2003........................... 175 12.0
</TABLE>
The quarterly gross production limitation applicable to the Wasson Willard
Royalty is approximately equal to the proved reserve production projected in the
Reserve Report. Thus, neither the Trust nor the Holders will benefit from
production from the Wasson Willard Unit in excess of the production estimates in
the Reserve Report. The Reserve Report reflects no production from the Wasson
Willard Royalty after the year 2003 because the Wasson Willard Royalty
terminates on December 31 of such year. Net production to Santa Fe from the
Wasson Willard Unit during the year ended December 31, 1993 averaged 37.3 MBbls
per quarter, which amount exceeded the Wasson Willard Royalty maximum net
quarterly production limitation attributable to such period by an average of 1.8
MBbls. See "The Royalty Properties -- The Wasson Properties" for additional
information concerning historical and estimated future production from the
Wasson Willard Unit.
Average Per Barrel Price. The "Average Per Barrel Price" with respect to
the Wasson Royalties for any calendar quarter generally means (a) the aggregate
revenues received by Santa Fe for such quarter from the sale of oil production
from its royalty interest in the Wasson Field production unit to which the
particular
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Wasson Royalty relates less certain actual costs for such quarter which consist
of post-production costs (including gathering, transporting, separating,
processing, treatment, storing and marketing charges), costs of litigation
concerning title to or operations of the Wasson Royalties, severance taxes, ad
valorem taxes, excise taxes (including windfall profits taxes, if any), sales
taxes and other similar taxes imposed upon the reserves or upon production,
delivery or sale of such production, costs of audits, insurance premiums and
amounts reserved for the foregoing, divided by (b) the aggregate number of
barrels produced for such quarter from its royalty interest in the Wasson Field
production unit to which the particular Wasson Royalty relates.
THE NET PROFITS ROYALTIES
The Net Profits Royalties entitle the Trust to receive, on a quarterly
basis, 90% of the Net Proceeds (as defined in the Net Profits Conveyances) from
the sale of production from the Net Profits Properties. The Net Profits
Royalties are not limited in term, although under the Trust Agreement the
Trustee is directed to sell the Net Profits Royalties prior to February 15,
2008. The definitions, formulas, accounting procedures and other terms governing
the computation of Net Proceeds are detailed and extensive, and reference is
made to the Net Profits Conveyances and the Louisiana Conveyance for a more
detailed discussion of the computation thereof.
Calculation of Net Proceeds. "Net Proceeds" generally means, for any
calendar quarter, (a) with respect to Net Profits Properties that are conveyed
from working interests, the excess of Gross Proceeds (as defined below) over all
costs, expenses and liabilities incurred in connection with exploring,
prospecting and drilling for, operating, producing, selling and marketing oil
and gas, including, without limitation, all amounts paid as royalties,
overriding royalties, production payments or other burdens against production
pursuant to permitted encumbrances, delay rentals, payments in connection with
the drilling or deferring of drilling any well in the vicinity, adjustment
payments to others in connection with contributions upon pooling, unitization or
communitization, rent for use of or damage to the surface, costs under any joint
operating unit or similar agreement, costs incurred with respect to reworking,
drilling, equipping, plugging back, completing and recompleting wells, making
production ready or available for market, constructing production and delivery
facilities, producing, transporting, compressing, dehydrating, separating,
treating, storing and marketing production, secondary or tertiary recovery or
other operations conducted for the purpose of enhancing production, litigation
concerning title to or operation of the working interests, renewals and
extensions of leases, and taxes, and (b) with respect to Net Profits Properties
that are conveyed from royalty interests, the excess of Gross Proceeds over all
costs, expenses and liabilities incurred in making production available or ready
for market, including, without limitation, costs paid for gathering,
transporting, compressing, dehydrating, separating, treating, storing and
marketing oil and gas, litigation concerning title to or operation of royalty
interests, taxes, costs of audits and insurance premiums.
"Gross Proceeds" generally means, for any calendar quarter, the amount of
cash received by Santa Fe during such quarter from the sales of oil and gas
produced from the Net Profits Properties excluding (a) all amounts attributable
to nonconsent operations conducted with respect to any working interest in which
Santa Fe or its assignee is a nonconsenting party and which is dedicated to the
recoupment or reimbursement of penalties, costs and expenses of the consenting
parties, (b) damages arising from any cause other than drainage or reservoir
injury, (c) rental for reservoir use, (d) payments in connection with the
drilling of any well on or in the vicinity of the Net Profits Properties and (e)
all amounts set aside as reserved amounts. Gross Proceeds do not include (x)
consideration for the transfer or sale of the Net Profits Properties (except as
provided below under "Sale and Abandonment of Royalty Properties") or (y) any
amount not received for oil and gas lost in the production or marketing thereof
or used by the owner of the Net Profits Properties in drilling, production and
plant operations. Gross Proceeds include payments for future production to the
extent they are not subject to repayment in the event of insufficient subsequent
production.
If a dispute arises as to the correct or lawful sales prices of any oil or
gas produced from any of the Net Profits Properties, then for purposes of
determining whether the amounts have been received by the owner of the Net
Profits Properties and therefore constitute Gross Proceeds (a) the amounts
withheld by a purchaser and deposited with an escrow agent shall not be
considered to be received by the owner of the Net Profits Properties until
actually collected, (b) amounts received by the owner of the Net Profits
Properties and
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promptly deposited with a non-affiliated escrow agent will not be considered to
have been received until disbursed to it by such escrow agent and (c) amounts
received by the owner of the Net Profits Properties and not deposited with an
escrow agent will be considered to have been received.
The Trust is not liable to the owners or operators of the Net Profits
Properties for any operating, capital or other costs or liabilities attributable
to the Net Profits Properties or oil and gas produced therefrom, and the Trustee
is not obligated to return any income received from the Net Profits Royalties.
Overpayments to the Trust will reduce future amounts payable.
Santa Fe is required to and will maintain books and records sufficient to
determine the amounts payable with respect to the Net Profits Royalties. Santa
Fe is also required to deliver to the Trust a statement of the computation of
the Net Proceeds attributable to each calendar quarter. Santa Fe causes an
annual computation of Net Proceeds to be audited and the cost of such audit is
borne by the Trust. See "Description of the Trust and the Trust
Agreement -- Fees and Expenses."
The Net Profits Properties generally consist of mature producing properties
and Santa Fe does not anticipate substantial additional development costs during
the producing lives of these properties.
SUPPORT PAYMENTS
The Wasson Conveyance provides that the Trust is entitled to additional
quarterly royalty payments, subject to certain limitations, from an additional
royalty burdening Santa Fe's interests in the Wasson ODC Unit during the period
ending on December 31, 2002 (the "Support Period") in the event that the net
cash available for distribution to Holders from the Royalty Interests for any
calendar quarter during the Support Period is less than an amount sufficient to
distribute to Holders a minimum supported quarterly royalty per Depositary Unit
equal to $0.40 (the "Minimum Quarterly Royalty"). The distribution declared with
respect to the fourth quarter of 1993 includes a Support Payment of
approximately $362,000 (approximately $0.06 per Depositary Unit). This Support
Payment was required primarily due to lower realized oil prices and
unanticipated capital expenditures incurred with respect to the Net Profits
Properties, a substantial portion of which is related to the drilling of new
wells.
Calculation of Amount of Support Payment. Support Payments payable to the
Trust for any calendar quarter during the Support Period shall be equal to the
additional amount necessary to cause the Minimum Quarterly Royalty for such
quarter to be paid by the Trust in respect of all outstanding Trust Units;
provided that the aggregate amount of Support Payments, net of any amounts
recouped by Santa Fe pursuant to reductions in the royalties payable with
respect to the Royalty Interests as described below, is limited to $20 million
(the "Aggregate Support Payment Limitation Amount"), as such amount may be
replenished upon recoupment of any prior Support Payments as described in the
following paragraph.
Reduction of Royalty Interests. In the event Support Payments are paid to
the Trust for any quarter, the royalties payable with respect to the Royalty
Interests will be reduced in future quarters (including quarters after the
Support Period but prior to the Liquidation Date) after the Trust has received
(or amounts are set aside for payment of) proceeds from the Royalty Interests in
amounts sufficient to pay 112.5% of the Minimum Quarterly Royalty ($0.45 per
Depositary Unit) on all Trust Units outstanding at the end of such quarter, in
order to permit Santa Fe to recoup the aggregate amount of any prior unrecouped
Support Payments. Any such reduction in royalties payable with respect to the
Royalty Interests would be made first to the Wasson ODC Royalty and then, if
additional reductions are necessary, from the Wasson Willard Royalty. The effect
of such reductions in the royalties payable with respect to the Wasson Royalties
would be to eliminate distributions in excess of $0.45 per Depositary Unit until
the Support Payments, if any, received by the Trust have been recouped by Santa
Fe through such reductions in the Wasson Royalties.
Proportionate Reduction of Minimum Quarterly Royalty and Aggregate Support
Payment Limitation Amount Upon Certain Sales. In the event that Santa Fe causes
the Trust to sell or release a portion of the Net Profits Royalties in
connection with the sale by Santa Fe of underlying Net Profits Properties as
described below under "-- Sale and Abandonment of Royalty Properties," the
Minimum Quarterly Royalty and the Aggregate Support Payment Limitation Amount
will be adjusted proportionately downward to equal the
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<PAGE> 23
product resulting from multiplying each of the Minimum Quarterly Royalty and the
Aggregate Support Payment Limitation Amount by a fraction, the numerator of
which will be the Remaining Royalty Interests Amount (defined below) and the
denominator of which will be the Existing Royalty Interests Amount (defined
below). For such purposes, the "Remaining Royalty Interests Amount" means, at
any time, the Existing Royalty Interests Amount (defined below) less the present
value of the future net revenues attributable to the portion of the Net Profits
Royalties sold by the Trust, determined by reference to the reserve report for
the Royalty Properties prepared in accordance with Commission guidelines, as of
the December 31 immediately preceding the date of the sale. The "Existing
Royalty Interests Amount" means, at any time, the then present value of the
future net revenues attributable to the Royalty Interests (including the portion
sold or released by the Trust), determined by reference to the reserve report
for the Royalty Properties prepared in accordance with Commission guidelines as
of the December 31 immediately preceding the date of the sale. Following any
such sale of Net Profits Royalties, the Trustee will notify the Holders of the
adjusted Minimum Quarterly Royalty and the adjusted Aggregate Support Payment
Limitation Amount.
SALE AND ABANDONMENT OF ROYALTY PROPERTIES
Santa Fe and any transferees of the Net Profits Properties have the right
to abandon any well or property on a Net Profits Property that is a working
interest if, in its opinion, such well or property ceases to produce or is not
capable of producing in commercially paying quantities, and upon termination of
any such lease that portion of the Net Profits Royalties relating thereto will
be extinguished. The Net Profits Conveyance provides that Santa Fe may establish
reasonable cash reserves from the net proceeds from sales of production
attributable to the working interests from which the Net Profits Royalties will
be conveyed to pay the costs of plugging and abandoning uneconomic wells.
The trust agreement establishing the Trust provides that Santa Fe may sell
the Royalty Properties, subject to and burdened by the Royalty Interests,
without the consent of the Holders. In addition, Santa Fe may, without the
consent of the Holders, require the Trust to release up to $5 million of the Net
Profits Royalties in any 12-month period (limited to $15 million in the
aggregate for all sales prior to January 1, 2002) in connection with a sale of
the Net Profits Properties provided that the Trust receives an amount equal to
90% of the net proceeds received by Santa Fe with respect to the Net Profits
Properties so sold and such cash price represents the fair market value of such
properties (which fair market value for sales in excess of $500,000 will be
determined by independent appraisal). Such sales can be required of the Trust
without regard to any dollar limitation on and after December 31, 2005. Any net
sales proceeds paid to the Trust are distributable to Holders for the quarter in
which they are received. Santa Fe has not identified for sale any of the Royalty
Properties. Under the trust agreement establishing the Trust, the Trustee is
required to sell all of the Net Profits Royalties prior to the Liquidation Date.
The proceeds of such sale, together with the matured face amount of the Treasury
Obligations, will be distributed to Holders on or prior to the Liquidation Date.
Under the Trust Agreement, Santa Fe has the right of first refusal to purchase
any of the Royalty Interests at the fair market value, or if applicable at the
offered third-party price, on or prior to the Liquidation Date.
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THE ROYALTY PROPERTIES
The Royalty Interests were conveyed by Santa Fe to the Trust from its
interests in two groups of domestic oil and gas properties. The Wasson Royalties
were conveyed out of Santa Fe's royalty interests in two oil production units,
the Wasson Willard Unit and the Wasson ODC Unit located in the Wasson Field in
the Permian Basin of West Texas. The Wasson Field is the sixth largest oil field
in the United States covering over 70,000 surface acres with over 2,000
producing wells. Since its discovery in 1936, the Wasson Field has produced over
1.7 billion barrels of oil. The Net Profits Royalties burden royalty and working
interests of Santa Fe in a diversified portfolio of producing oil and gas
properties located in established oil and gas producing areas in 12 states and
related state waters.
RESERVES
Royalty Interests. The following table summarizes proved reserves estimated
as of December 31, 1993 and certain related information for each of the Wasson
Royalties and the Net Profits Royalties. This information is derived from the
Reserve Report. The reserves and related information concerning the Net Profits
Royalties have been segregated between those properties that are working
interests and those that are royalty interests. Proved reserve quantities for
the Wasson Royalties are calculated by multiplying the net revenue interest
attributable to the Wasson Royalties in effect for a given year by the total
amount of oil and gas estimated to be economically recoverable from the
respective production units (subject to limitation by applicable maximum
quarterly production amounts). Reserve quantities are calculated differently for
the Net Profits Royalties because such interests do not entitle the Trust to a
specific quantity of oil or gas but to the Net Proceeds derived therefrom.
Proved reserves attributable to the Net Profits Royalties are calculated by
deducting an amount of oil or gas sufficient, if sold at the prices used in
preparing the reserve estimates for the Net Profits Royalties contained in the
Reserve Report, to pay the future estimated costs and expenses deducted in the
calculation of Net Proceeds with respect to the Net Profits Royalties.
Accordingly, the reserves presented for the Net Profits Royalties reflect
quantities of oil and gas that are free of future costs or expenses if the price
and cost assumptions set forth in the Reserve Report occur. The Reserve Report
was prepared in accordance with criteria established by the Commission and,
accordingly, assumes constant prices and costs in effect as of the date of the
Reserve Report throughout the life of the reserves. Estimated future net
revenues and the discounted present value thereof were determined using oil
prices of $11.50, $11.50 and $11.97 per barrel with respect to production from
the Wasson ODC Unit, the Wasson Willard Unit and the Net Profits Royalties,
respectively, a weighted average gas price of $2.12 per Mcf and a discount rate
of 10%.
<TABLE>
<CAPTION>
WASSON ROYALTIES NET PROFITS ROYALTIES
------------------------------- -------------------------------
WASSON WASSON
ODC WILLARD ROYALTY WORKING
ROYALTY(1) ROYALTY TOTAL(1) INTERESTS INTERESTS TOTAL TOTAL(1)
---------- ------- ------- ------- ------- ------- --------
<S> <C> <C> <C> <C> <C> <C> <C>
Proved developed:
Oil (MBbls)............ 5,535 1,026 6,561 649 555 1,204 7,765
Gas (MMcf)............. -- -- -- 3,711 7,189 10,900 10,900
Proved undeveloped:
Oil (MBbls)............ -- -- -- -- 4 4 4
Gas (MMcf)............. -- -- -- -- 221 221 221
Total proved:
Oil (MBbls)............ 5,535 1,026 6,561 649 559 1,208(2) 7,769(2)
Gas (MMcf)............. -- -- -- 3,711 7,410 11,121 11,121
Future Net Revenues (in
thousands)............. $58,681 $10,715 $69,396 $15,718 $22,430 $38,148 $107,544
Future Net Revenues
discounted at 10% (in
thousands)............. $33,198 $ 7,314 $40,512 $10,221 $14,583 $24,804 $ 65,316
</TABLE>
(See footnotes on following page)
24
<PAGE> 25
- ---------------
(1) The information presented includes 1,891 MBbls of oil, $20,000,000 of
estimated future net revenues and $12,663,000 of discounted estimated future
net revenues attributable to the additional royalty in respect of Support
Payments which would be paid under the pricing assumptions and production
estimates specified in the Reserve Report. Any Support Payments would be
made from funds which would otherwise be paid to Santa Fe in respect of
Santa Fe's retained royalty interest in the Wasson ODC Unit. The amount of
actual Support Payments paid to the Trust, if any, will be dependent upon
(i) the actual oil and gas prices received by the Trust and (ii) the actual
production from the Royalty Properties.
(2) Includes 57 MBbls of natural gas liquids with a weighted average price at
December 31, 1993 of $12.58 per barrel.
Information concerning historical revisions, extensions, discoveries,
additions and production from proved reserves attributable to the Royalty
Properties, and the calculation of the standardized measure of discounted future
net revenues related thereto, is contained in the unaudited financial
information of the Trust contained herein. The Trust has not filed reserve
estimates covering the Royalty Properties with any other Federal authority or
agency.
Santa Fe believes that significant quantities of probable and possible
reserves exist in the Wasson ODC and Wasson Willard production units. The Trust
will benefit from future increases in proved reserves or production attributable
to any probable or possible reserves only to the extent that such reserves serve
to provide additional assurance that the maximum barrels will be produced from
each of the Wasson Royalties and, in the case of the Wasson ODC Royalty, to
provide additional reserves available for Support Payments. Due to the
production limitations, however, these future increases will not otherwise
directly benefit the Trust or Holders and Santa Fe is retaining the excess
production potential of these properties.
25
<PAGE> 26
Proved Reserves Available for Support Payments. The following estimates of
proved reserve production and related future net revenues during each of the
calendar years in the Support Period are attributable to Santa Fe's remaining
royalty interest in the Wasson ODC Unit from which an additional royalty would
be paid in order to provide Support Payments to the Trust. The amounts shown are
annual estimates. Support Payments will be made from royalties on actual
quarterly production. The amounts include proved reserves and future net
revenues attributable to the additional royalty paid to the Trust in respect of
Support Payments. Such information is based upon the constant pricing
assumptions and production estimates made in the Reserve Report. The aggregate
amount of Support Payments (net of any amount recouped by Santa Fe) are limited
by the amount of production attributable to Santa Fe's remaining royalty
interest in the Wasson ODC Unit and are further limited to an aggregate of $20
million on a revolving basis. Under the constant pricing assumptions (including
an $11.50 per barrel price for all Wasson production) and production estimates
specified in the Reserve Report, the Trust is projected to pay the $0.40 minimum
quarterly royalty for each quarter through 1998. Thereafter, Support Payments
would not be sufficient or available in the last four years of the Support
Period to pay a full $0.40 minimum quarterly royalty distribution. The estimated
quarterly distribution shortfalls range from $0.01 per Depositary Unit in 1999
to $0.22 per Depositary Unit in 2002. Actual amounts of Support Payments, if any
are so required, will be dependent upon oil and gas prices and production levels
realized by the Trust in each quarter. See "The Royalty Interests -- Support
Payments."
<TABLE>
<CAPTION>
ESTIMATED ESTIMATED
ANNUAL ANNUAL
PRODUCTION FUTURE
OF NET
PROVED REVENUES
RESERVES (IN
YEAR (MBBLS)(1) THOUSANDS)
---- ---------- ----------
<S> <C> <C>
1994................................................. 462.0 4,841
1995................................................. 413.9 4,345
1996................................................. 411.0 4,324
1997................................................. 402.0 4,243
1998................................................. 385.2 4,074
1999................................................. 347.4 3,681
2000................................................. 339.1 3,600
2001................................................. 290.4 3,090
2002................................................. 221.6 2,360
------- -------
Total...................................... 3,272.6 $34,558(2)
------- -------
------- -------
</TABLE>
- ---------------
(1) Includes reserves and future net revenues attributable to additional
royalties paid in respect of Support Payments that are included in the
Royalty Interests of the Trust.
(2) The discounted value of the aggregate estimated future net revenues is
$23,815,000.
THE WASSON PROPERTIES
The Wasson Royalties were conveyed out of Santa Fe's 12.3934% royalty
interest in the Wasson ODC Unit and its 6.83548% royalty interest in the Wasson
Willard Unit, located in the Wasson Field. Santa Fe also owns significant
working interests in each of these units. Santa Fe's production from the Wasson
Field commenced in 1939. A secondary waterflooding phase in the Wasson Field
began in the early 1960s. The Wasson Field has been significantly redeveloped
for tertiary recovery operations utilizing CO2 flooding, which commenced in
1984. Gross capital expenditures in excess of $600 million have been made by all
working interest owners in respect of these operations in the Wasson ODC Unit
and Wasson Willard Unit. Most of the capital expenditures for plant, facilities,
wells and equipment necessary for such tertiary recovery operations in the
Wasson Field have been made, although significant further capital expenditures
for CO2 acquisition will be required, particularly in the Wasson Willard Unit.
The Wasson Royalties do not bear development costs or operating costs (including
CO2 acquisition costs).
The Wasson ODC Unit covers approximately 7,840 gross acres with
approximately 315 producing oil wells and is operated by Amoco Production
Company. The Wasson Willard Unit covers approximately 13,520 gross acres with
approximately 338 producing oil wells and is operated by a subsidiary of
Atlantic Richfield
26
<PAGE> 27
Company. Production attributable to Santa Fe's royalty interest in the Wasson
ODC and Wasson Willard Units is marketed by Santa Fe and in some cases is sold
at the wellhead at market responsive prices that approximate spot oil prices for
West Texas Sour crude, and in other cases such production is sold at points
within common carrier pipeline systems on terms whereby Santa Fe pays the cost
of transporting same to such points.
The following bar graph depicts estimated production of proved reserves
attributable to Santa Fe's 12.3934% royalty interest in the Wasson ODC Unit and
the portion of such estimated production attributable to the Wasson ODC Royalty,
based upon estimates contained in the Reserve Report. The Wasson ODC Royalty
terminates on December 31, 2007. Production attributable to Santa Fe's royalty
interest in excess of the Wasson ODC Royalty production is available for Support
Payments during the remaining approximately nine-year period ending on December
31, 2002 up to a maximum of $20 million on a revolving basis. Actual production
from the Wasson ODC Unit may vary significantly from the following estimates.
Neither the Trust nor the Holders will directly benefit from any future
increases in proved reserves or production, but any such increases will improve
the likelihood that the maximum royalty production levels will be produced from
the Wasson ODC Unit.
ESTIMATED NET PROVED RESERVE PRODUCTION FROM WASSON ODC UNIT
ATTRIBUTABLE TO SANTA FE'S ROYALTY INTEREST AND WASSON ODC ROYALTY
(BASED ON RESERVE REPORT)
{GRAPH}
27
<PAGE> 28
The following bar graph depicts estimated production of proved reserves
attributable to the Wasson Willard Royalty based upon estimates contained in the
Reserve Report. The Wasson Willard Royalty terminates on December 31, 2003.
Actual production from the Wasson Willard Unit may vary significantly from the
following estimates. Neither the Trust nor the Holders will directly benefit
from any future increases in proved reserves or production, but any such
increases will provide additional assurance that the maximum production levels
of the Wasson Willard Royalty will be produced from the Wasson Willard Unit.
{GRAPH}
ESTIMATED NET PROVED RESERVE PRODUCTION FROM WASSON WILLARD UNIT
ATTRIBUTABLE TO WASSON WILLARD ROYALTY
(BASED ON RESERVE REPORT)
The following table shows, for the periods indicated, the average quarterly
net oil production attributable to Santa Fe's 12.3934% royalty interest in the
Wasson ODC Unit and its 6.83548% royalty interest in the Wasson Willard Unit.
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
---------------------------------------
1989 1990 1991 1992 1993
--- --- --- --- ---
<S> <C> <C> <C> <C> <C>
Wasson ODC Unit (MBbls)................................ 183 174 164 166 163
Wasson Willard Unit (MBbls)............................ 29 30 31 35 37
--- --- --- --- ---
Total........................................ 212 204 195 201 200
--- --- --- --- ---
--- --- --- --- ---
</TABLE>
For additional information derived from the Reserve Report concerning
proved reserves with respect to the Wasson Properties, see "Reserves" above.
28
<PAGE> 29
THE NET PROFITS PROPERTIES
The Net Profits Properties consist of working interests and royalty
interests in over 1,000 oil and gas producing properties located in 12 states
and related state waters generally with established production histories. Over
90% of the estimated future net revenues attributable to the Net Profits
Properties are from properties located in Texas, Louisiana and Oklahoma and
related state waters. No single property or field accounts for more than 7% of
the estimated future net revenues attributable to the Net Profits Royalties.
The Net Profits Properties generally consist of mature producing properties
and Santa Fe does not anticipate substantial additional development costs during
the producing lives of these properties.
Santa Fe estimates that as of December 31, 1993 the gross and net
productive wells within the Net Profits Properties covered approximately 246,000
gross acres (approximately 36,000 net to Santa Fe). Productive well information
generally is not made available by operators to owners of royalties and
overriding royalties. Accordingly, such information is unavailable to Santa Fe
for the Net Profits Properties.
For additional information derived from the Reserve Report concerning
proved reserves with respect to the Net Profits Properties, see "Reserves"
above.
OIL AND GAS SALES PRICES AND PRODUCTION COSTS
The following table sets forth for each of the Wasson ODC Unit, the Wasson
Willard Unit and the Net Profits Properties the average sales price per barrel
of oil and natural gas liquids and per Mcf of gas produced and the production
costs (including taxes on production and property) per NEB produced for each of
the years ended December 31, 1991, 1992 and 1993:
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
------------------------------
1991 1992 1993
------ ------ ------
<S> <C> <C> <C>
Weighted average sales price per Bbl of oil produced(1)
Wasson ODC Unit...................................... $17.71 $17.12 $14.64
Wasson Willard Unit.................................. $17.64 $17.10 $14.57
Net Profits Properties............................... $17.06 $16.04 $16.08
Weighted average sales price per Mcf of gas produced(1)
Net Profits Properties............................... $ 1.54 $ 1.52 $ 2.00
Weighted average production cost per NEB(2)
Wasson ODC Unit...................................... $ 2.12 $ 1.90 $ 2.06
Wasson Willard Unit.................................. $ 2.74 $ 2.75 $ 2.77
Net Profits Properties............................... $ 2.64 $ 2.98 $ 3.65
</TABLE>
- ---------------
(1) Average sales price generally represents the wellhead price of oil and gas
which is net of transportation and marketing charges. Such wellhead prices
do not include any marketing premium realized by the Trust for Santa Fe's
marketing of production from the Wasson Willard and Wasson ODC Units, as
discussed below.
(2) Production costs include, for all properties, severance and ad valorem taxes
and include lease operating and lifting costs for Net Profits Properties
that are working interests.
While oil and gas prices realized by the Trust generally follow oil and gas
price trends evidenced by benchmark prices, Trust production has historically
been sold at prices below benchmark spot market prices. Production from the
Wasson Field generally is classified as West Texas Sour crude. Posted prices for
Santa Fe's production from the Wasson Willard and Wasson ODC Units have averaged
approximately $2.20 per barrel below West Texas Intermediate crude oil posted
prices during the past twelve months. Santa Fe, through its marketing efforts,
has historically achieved a premium over West Texas Sour crude posted prices
(ranging from $1.22 to $1.60 per barrel during the past twelve months), although
below West Texas Intermediate crude oil prices. Under the terms of the Wasson
Conveyance, the Trust is entitled to
29
<PAGE> 30
receive this marketing premium. There is no assurance, however, that such a
marketing premium will be achieved in the future.
Oil production attributable to the Net Profits Royalties has historically
been sold at a discount to West Texas Intermediate spot prices. Gas production
attributable to the Net Profits Royalties has historically sold for a discount
to Gulf Coast (Henry Hub) spot gas prices after taking into account deductions
for quality, marketing and transportation costs.
TITLE TO PROPERTIES
Santa Fe believes that its title to the Royalty Properties is, and title of
the Trust to the Royalty Interests is, good and defensible in accordance with
standards generally accepted in the oil and gas industry, subject to such
exceptions which, in the opinion of Santa Fe, do not detract materially from the
use or value of such Royalty Properties or Royalty Interests. The Wasson
Properties have been owned by Santa Fe for over 40 years. The Conveyances
contain a warranty of title, limited to claims by, through or under Santa Fe,
and covering the Wasson Properties and certain of the Net Profits Properties
aggregating approximately 82% of the discounted present value of the proved
reserves attributable to the Royalty Interests according to the Reserve Report.
The Conveyances contain no title warranty with respect to the remaining Net
Profits Properties. As is customary in the oil and gas industry, Santa Fe or the
operator of its properties performs only a perfunctory title examination when it
acquires leases, except leases covering proved reserves. Generally, prior to
drilling a well, a more thorough title examination of the drill site tract is
conducted and curative work is performed with respect to significant title
defects, if any, before proceeding with operations. The Royalty Properties are
typically subject, to one degree or another, to one or more of the following:
(i) royalties and other burdens and obligations, expressed and implied, under
oil and gas leases; (ii) overriding royalties (such as the Royalty Interests)
and other burdens created by Santa Fe or its predecessors in title; (iii) a
variety of contractual obligations (including, in some cases, development
obligations) arising under operating agreements, farmout agreements, production
sales contracts and other agreements that may affect the properties or their
titles; (iv) liens that arise in the normal course of operations, such as those
for unpaid taxes, statutory liens securing unpaid suppliers and contractors and
contractual liens under operating agreements; (v) pooling, unitization and
communitization agreements, declarations and orders; and (vi) easements,
restrictions, rights-of-way and other matters that commonly affect property. To
the extent that such burdens and obligations affect Santa Fe's rights to
production and production revenues from the Royalty Properties, they have been
taken into account in calculating the Royalty Interests and in estimating the
size and value of the Trust's reserves attributable to the Royalty Interests.
Santa Fe believes that the burdens and obligations affecting the Royalty
Properties and Royalty Interests are conventional in the industry for similar
properties, do not, in the aggregate, materially interfere with the use of the
Royalty Properties and will not materially and adversely affect the value of the
Royalty Interests.
It is not entirely clear that all of the Royalty Interests would be treated
as fully conveyed real or personal property interests under the laws of each of
the states in which the Royalty Properties are located. Based upon discussions
with legal counsel, which discussions included a review of applicable legal
precedent but did not include the issuance of formal opinions, Santa Fe believes
that the Royalty Interests (other than those conveyed pursuant to the Louisiana
Conveyance) constitute real property interests under applicable state law of
most states in which the Royalty Properties are located. Consistent therewith,
the Conveyances (other than the Louisiana Conveyance) state that the Royalty
Interests constitute real property interests and Santa Fe has recorded the
Conveyances (other than the Louisiana Conveyance) in the appropriate real
property records of the states in which the Royalty Properties are located in
accordance with local recordation provisions. If during the term of the Trust,
Santa Fe becomes involved as a debtor in bankruptcy proceedings, it is not
entirely clear that all of the Royalty Interests would be treated as fully
conveyed property interests under the laws of each of the states in which the
Royalty Properties are located. If in such a proceeding a determination were
made that a Royalty Interest (or a portion thereof) did not constitute fully
conveyed property interests under applicable state law, the Conveyance related
to such Royalty Interest (or a portion thereof) could be subject to rejection as
an executory contract (a term used in the Federal Bankruptcy Code to refer to a
contract under which the obligations of both the debtor and the other party to
the contract are so unsatisfied
30
<PAGE> 31
that the failure of either to complete performance would constitute a material
breach excusing performance of the other) in a bankruptcy proceeding involving
Santa Fe. In such event, the Trust would be treated as an unsecured creditor of
Santa Fe with respect to such Royalty Interest in the pending bankruptcy. Under
Louisiana law, the Louisiana Conveyance constitutes personal property that could
be rejected as an executory contract in a bankruptcy proceeding involving Santa
Fe, although the mortgage on the Royalty Properties that is burdened by the
Louisiana Conveyance and which secures the Trust's interests in such Royalty
Properties should enhance the Trust's position in the event of such a
proceeding. Although no assurance can be given and no formal opinions have been
obtained, based upon discussions with legal counsel, Santa Fe does not believe
that the Royalty Interests (other than those in Louisiana) should be subject to
rejection in a bankruptcy proceeding as executory contracts.
COMPETITION
The oil and gas industry is highly competitive in all of its phases. Santa
Fe and the other operators of the Royalty Properties encounter competition from
major oil and gas companies, international energy organizations, independent oil
and gas concerns, and individual producers and operators. Many of these
competitors have greater financial and other resources than Santa Fe.
Competition may also be presented by alternative fuel sources, including heating
oil and other fossil fuels.
MARKETING OF PRODUCTION
Production attributable to Santa Fe's royalty interests in the Wasson ODC
Unit and Wasson Willard Unit is marketed by Santa Fe and is principally sold at
the wellhead at market responsive prices that approximate spot oil prices for
West Texas sour crude, and in other cases is sold at points within common
carrier pipeline systems on terms whereby Santa Fe pays the cost of transporting
same to such points.
With respect to the Net Profits Properties, where such properties consist
of royalty interests, the operators of the properties will make all decisions
regarding the marketing and sales of oil and gas production. Although Santa Fe
generally has the right to market oil and gas produced from the Royalty
Properties that are working interests, Santa Fe has historically relied on the
operators of the properties to market the production. The ability of the
operators to market the oil and gas produced from the Royalty Properties depends
upon numerous factors beyond their control, including the extent of domestic
production and imports of oil and gas, the proximity of the gas production to
gas pipelines, the availability of capacity in such pipelines, the demand for
oil and gas by utilities and other end-users, the effects of inclement weather,
state and Federal regulation of oil and gas production and Federal regulation of
gas sold or transported in interstate commerce. There is no assurance that such
operators will be able to market all of the oil or gas produced from the Royalty
Properties or that favorable prices can be obtained for the oil and gas
produced.
In connection with the recent sale of gas gathering and processing assets,
Santa Fe entered into a seven year gas sales contract with a subsidiary of
Hadson Corporation ("Hadson"). Under the contract, Hadson has the right (but not
the obligation) to purchase certain domestic gas production from Santa Fe
including gas produced from the Net Profits Properties that is marketable by
Santa Fe. In the event Hadson exercises its right to purchase gas from the Net
Profits Properties, Santa Fe will receive a price based upon recently published
monthly index prices, which price will be used to calculate net profits
attributable to the Net Profits Royalties. The price paid by Hadson may be
higher or lower than the price otherwise obtained by Santa Fe for gas production
attributable to the Net Profits Properties.
The supply of gas capable of being produced in the United States has
exceeded demand in recent years as a result of decreased demand for gas in
response to economic factors, conservation, lower prices for alternative energy
sources and other factors. As a result of this excess supply of gas, gas
producers have experienced increased competitive pressure and significantly
lower prices. Many gas pipelines have reduced their takes from producers below
the amounts they were contractually obligated to take or pay at fixed prices in
excess of spot prices or have renegotiated their obligations to reflect more
market responsive terms. The decline in demand for gas has resulted in many
pipelines reducing or ceasing altogether their purchase of new gas.
Substantially all of the gas production from the Net Profits Properties is sold
at market responsive prices.
31
<PAGE> 32
Demand for gas production has historically been seasonal in nature. Due to
unseasonably warm weather over the last several years the demand for gas has
decreased, resulting in lower prices received by producers during the winter
months than in prior years. Consequently, on an energy equivalent basis, gas has
sold at a discount to oil for the past several years. Such price fluctuations
will directly impact Trust distributions, estimates of Trust reserves and
estimated future net revenue from Trust reserves.
In view of the many uncertainties affecting the supply and demand for crude
oil, gas and refined petroleum products, Santa Fe is unable to make reliable
predictions of future oil and gas prices and demand or the overall effect they
will have on the Trust. Santa Fe does not believe that the loss of any of its
purchasers would have a material adverse effect on the Trust, since
substantially all of the oil and gas sales from the Royalty Properties are made
on the spot market at market responsive prices.
REGULATION OF OIL AND GAS
The production, transportation and sale of oil and gas from the Royalty
Properties are subject to Federal and state governmental regulation, including
regulations concerning the ceiling prices at which certain categories of gas may
be sold, regulation of tariffs charged by pipelines, taxes, the prevention of
waste, the conservation of oil and gas, pollution controls and various other
matters. The United States has government power to permit increases in the
amount of oil imported from other countries and to impose pollution control
measures.
Federal Regulation of Gas. The Net Profits Properties are subject to the
jurisdiction of the Federal Energy Regulatory Commission ("FERC") and the
Department of Energy with respect to various aspects of oil and gas operations
including marketing and production of oil and gas. The Natural Gas Act and the
Natural Gas Policy Act of 1978 ("Policy Act") mandate Federal regulation of
interstate transportation of gas and of wellhead pricing of certain domestic
gas, depending on the category of the gas and the nature of the sale. In July
1989, however, Congress enacted the Natural Gas Wellhead Decontrol Act of 1989
that eliminated wellhead price controls on all domestic gas effective January 1,
1993.
In 1992, FERC issued Orders Nos. 636 and 636-A which generally opened
access to interstate pipelines by requiring the operators of such pipelines to
unbundle their transportation services which historically were combined with
their sales services and allow customers to choose and pay for only the services
they require, regardless of whether the customer purchases gas from such
pipelines or from other suppliers. The orders also require upstream pipelines to
permit downstream pipelines to assign upstream capacity to their shippers, and
place analogous, unbundled access requirements on the downstream pipelines.
Although these regulations should generally facilitate the transportation of gas
produced from the Net Profits Properties and the direct access to end user
markets, the impact of FERC Order Nos. 636 and 636A on marketing production from
the Net Profits Properties cannot be predicted at this time. A number of parties
which are aggrieved by the FERC's Order No. 636 program have filed petitions for
review of these orders which are now pending in various U.S. Courts of Appeal.
Numerous questions have been raised concerning the interpretation and
implementation of several significant provisions of the Natural Gas Act and the
Policy Act (collectively, "Acts"), and of the regulations and policies
promulgated by FERC thereunder. A number of lawsuits and administrative
proceedings have been instituted which challenge the validity of regulations
implementing the Acts. In addition, FERC currently has under consideration
various policies and proposals in addition to those discussed above that may
affect the marketing of gas under new and existing contracts. Accordingly, Santa
Fe is unable to estimate the full impact that the Acts and the regulations
issued thereunder by FERC may have on the Net Profits Properties.
Legislative Proposals. In the past, Congress has been very active in the
area of gas regulation. Recently enacted legislation repeals incremental pricing
requirements and gas use restraints previously applicable. There are other
legislative proposals pending in the Federal and state legislatures which, if
enacted, would significantly affect the petroleum industry. At the present time,
it is impossible to predict what proposals, if any, might actually be enacted by
Congress or the various state legislatures and what effect, if any, such
proposals might have on the Royalty Properties and the Trust.
32
<PAGE> 33
State Regulation. Many state jurisdictions have at times imposed
limitations on the production of gas by restricting the rate of flow for gas
wells below their actual capacity to produce and by imposing acreage limitations
for the drilling of a well. States may also impose additional regulation of
these matters. Most states regulate the production and sale of oil and gas,
including requirements for obtaining drilling permits, the method of developing
new fields, provisions for the unitization or pooling of oil and gas properties,
the spacing, operation, plugging and abandonment of wells and the prevention of
waste of oil and gas resources. The rate of production may be regulated and the
maximum daily production allowable from oil and gas wells may be established on
a market demand or conservation basis or both.
ENVIRONMENTAL REGULATION
General. Activities on the Royalty Properties are subject to existing
Federal, state and local laws and regulations governing environmental quality
and pollution control. It is anticipated that, absent the occurrence of an
extraordinary event, compliance with existing Federal, state and local laws,
rules and regulations regulating the discharge of materials into the environment
or otherwise relating to the protection of the environment will not have a
material effect upon the Trust. Santa Fe cannot predict what effect additional
regulation or legislation, enforcement policies thereunder, and claims for
damages to property, employees, other persons and the environment resulting from
operations on the Royalty Properties could have on the Trust.
Solid and Hazardous Waste. The Royalty Properties include numerous
properties that have produced oil and gas for many years and that have been
owned by Santa Fe for only a relatively short time. Although, to Santa Fe's
knowledge, the operators have utilized operating and disposal practices that
were standard in the industry at the time, hydrocarbons or other solid wastes
may have been disposed or released on or under the Royalty Properties by the
current or previous operator. State and Federal laws applicable to oil and gas
wastes and properties have become increasingly more stringent. Under these new
laws, Santa Fe or an operator of the Royalty Properties could be required to
remove or remediate previously disposed wastes or property contamination
(including groundwater contamination) or to perform remedial plugging operations
to prevent future contamination.
The operators of the Royalty Properties may generate wastes that are
subject to the Federal Resource Conservation and Recovery Act and comparable
state statutes. The Environmental Protection Agency ("EPA") has limited the
disposal options for certain hazardous wastes and is considering the adoption of
more stringent disposal standards for nonhazardous wastes. Furthermore, it is
anticipated that additional wastes (which could include certain wastes generated
by oil and gas operations) will be designated as "hazardous wastes," which are
subject to more rigorous and costly disposal requirements.
Superfund. The Comprehensive Environmental Response, Compensation and
Liability Act
("CERCLA"), also known as the "superfund" law, imposes liability, without regard
to fault or the legality of the original conduct, on certain classes of persons
that contributed to the release of a "hazardous substance" into the environment.
These persons include the owner and operator of a site and companies that
disposed or arranged for the disposal of the hazardous substance found at a
site. CERCLA also authorizes the EPA and, in some cases, third parties to take
actions in response to threats to the public health or the environment and to
seek to recover from the responsible classes of persons the costs of such
action. In the course of their operations, the operators of the Royalty
Properties have generated and will generate wastes that may fall within CERCLA's
definition of "hazardous substances." Santa Fe or the operators of the Royalty
Properties may be responsible under CERCLA for all or part of the costs to clean
up sites at which such wastes have been disposed.
Air Emissions. The operators of the Royalty Properties are subject to
Federal, state and local regulations concerning the control of emissions from
sources of air pollution. Administrative enforcement actions for failure to
comply strictly with air regulations or permits are generally resolved by
payment of a monetary penalty and correction of any identified deficiencies.
Alternatively, regulatory agencies could require the operators to forego
construction or operation of certain air emission sources.
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<PAGE> 34
OSHA. The operators of the Royalty Properties are subject to the
requirements of the Federal Occupational Safety and Health Act ("OSHA") and
comparable state statutes. The OSHA hazard communication standard, the EPA
community right-to-know regulations under Title III of the Federal Superfund
Amendment and Reauthorization Act and similar state statutes require an operator
to organize information about hazardous materials used or produced in its
operations. Certain of this information must be provided to employees, state and
local government authorities and local citizens.
PRICE RANGE OF DEPOSITARY UNITS AND DISTRIBUTION POLICY
The Depositary Units have been listed for trading on the New York Stock
Exchange under the symbol "SFF" since November 13, 1992. The following table
sets forth, for the periods indicated, the high and low closing prices of the
Depositary Units and cash distributions paid or payable in respect of Trust
Units.
<TABLE>
<CAPTION>
CLOSING CASH
SALES PRICE DISTRIBUTION
------------- PER TRUST
LOW HIGH UNIT
--- ---- ------------
<S> <C> <C> <C>
1992:
Fourth Quarter (beginning November 13)....................... $17 7/8 $19 7/8 $ 0.30753(a)
1993:
First Quarter................................................ $18 $19 3/4 $ 0.46660
Second Quarter............................................... $19 3/8 $20 7/8 $ 0.49485
Third Quarter................................................ $19 5/8 $22 $ 0.44218
Fourth Quarter............................................... $19 5/8 $23 5/8 $ 0.40000(b)
1994:
First Quarter (through February 9)........................... $20 1/2 $21 3/4 (c)
</TABLE>
- ---------------
(a) Distributed in respect of the two-month period ended December 31, 1992.
(b) Includes a Support Payment of approximately $0.06 per Depositary Unit.
Declared payable on February 28, 1994 to Holders of Depositary Units of
record on February 14, 1994.
(c) The distribution for the first quarter of 1994 has not been declared as of
the date hereof.
The closing price of the Depositary Units on the New York Stock Exchange on
February 9, 1994 was $20 5/8. As of December 28, 1993, there were approximately
435 holders of record of Depositary Units.
Holders of Depositary Units receive cash distributions based on the
production of oil and gas from the Royalty Properties for each calendar quarter
ending on or prior to December 31, 2007. The amount of cash distributions to
Holders with respect to the Depositary Units is directly dependent on the sales
prices for the Trust's oil and gas, the volume of oil and gas sold, the costs of
marketing such oil and gas and, for the Net Profits Properties that are working
interests, the costs of producing and developing such oil and gas. Oil and gas
production from proved reserves attributable to the Royalty Interests is
expected to decline over the term of the Trust. In addition, the Reserve Report
indicates that over the term of the Trust gas revenues will constitute a
diminishing percentage of total net revenues in comparison to the percentage of
estimated proved gas reserves currently attributable to the Royalty Properties.
This is because of the relatively shorter life of the proved gas reserves
produced from the Net Profits Properties and the fact that in the later years of
the Trust quarterly distributions will be comprised of a larger proportion of
proceeds from the Wasson Royalties, which consist solely of oil production.
Thus, over time the cash distributions to Holders will become increasingly
dependent upon oil revenues and prices and such distributions will be less
sensitive to gas price changes. Due to the seasonal demand for gas and the
customary changes in gas prices in response to such changes in demand, the
amount of quarterly cash distributions from the Trust may vary on a seasonal
basis. Additionally, quarter-to-quarter distributions may vary based on the
timing of development expenditures on the Net Profits Properties that are
working interests and the net revenues, if any, generated by development
projects. Quarterly cash distributions during the term of the Trust are made by
the Trustee on the last day of the second
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<PAGE> 35
month after the close of each calendar quarter to Holders of record on the 45th
day following each calendar quarter.
As is typical in the oil industry, actual receipt of revenue and payment of
expenses and costs may lag behind the period of production by as much as several
months. Since payments for Wasson Royalties production is made generally within
30 days of the month of production, this delay will not be significant to
Holders. Payments for production burdened by the Net Profits Royalty may be
delayed by as much as three months for gas and two months for oil. Since the Net
Profits Interest is calculated on a cash basis, the payment delay may affect the
timing of the receipt of distributions.
For any calendar quarter ending on or prior to December 31, 2002, to the
extent that net cash proceeds from the Royalty Interests would be insufficient
to distribute at least $0.40 per Depositary Unit per quarter, the Trust will
receive the Support Payments, subject to certain limitations. There is no
assurance that the Support Payments will be sufficient to enable the Trust to
distribute the supported distribution amount ($0.40 per Depositary Unit) in any
quarter during the Support Period. If Support Payments are made for any quarter,
the royalties payable with respect to the Wasson Royalties in subsequent
quarters will be reduced to the extent necessary to permit Santa Fe to recoup
such Support Payments, provided that such reductions do not reduce Trust
distributions below $0.45 per Depositary Unit for any such quarter. The
aggregate amount of Support Payments (net of any amount recouped by Santa Fe)
are limited by the amount of production attributable to Santa Fe's remaining
royalty interest in the Wasson ODC Unit and are further limited to an aggregate
of $20 million on a revolving basis. Under the constant pricing assumptions
(including an $11.50 per barrel price for all Wasson production) and production
estimates specified in the Reserve Report, Support Payments would not be
sufficient or available in the last four years of the Support Period to pay a
full $0.40 minimum quarterly royalty distribution. The estimated quarterly
distribution shortfalls range from $0.01 per Depositary Unit in 1999 to $0.22
per Depositary Unit in 2002. Actual amounts of Support Payments, if any are so
required, will be dependent upon oil and gas prices and production levels
realized by the Trust in each quarter. See "The Royalty Interests -- Support
Payments."
The assets of the Trust will be liquidated on or prior to the Liquidation
Date and a liquidating distribution will be made to Holders of record on or
about the Liquidation Date. The liquidating distribution with respect to each
Depositary Unit will include proceeds from the matured Treasury Obligations in
an amount equal to $20 per Depositary Unit and a pro rata portion of the net
proceeds from the sale of the Net Profits Royalties (to the extent not
previously distributed).
SANTA FE
Santa Fe is engaged in the exploration, development and production of oil
and gas in most of the major producing basins in the continental United States.
Santa Fe's crude oil production is principally located in California and Texas,
while its gas production comes primarily from the Gulf of Mexico, Oklahoma, New
Mexico, Wyoming and Texas. A substantial portion of Santa Fe's oil production is
in long-lived fields with well established production histories and where
enhanced oil recovery methods are employed. Substantially all of Santa Fe's
reserves are located in the United States, with the balance located in Argentina
and Indonesia. After the closing of this offering, Santa Fe will not own any
Depositary Units. The principal executive offices of Santa Fe are located at
1616 South Voss Road, Suite 1000, Houston, Texas 77057 and its telephone number
is (713) 783-2401.
RECENT DEVELOPMENTS
In October 1993, Santa Fe announced a broad corporate restructuring program
that will include disposing of certain non-core oil and gas properties (other
than the Royalty Properties); increasing development spending during 1994 and
1995 in certain productive areas that generally do not include the Royalty
Properties; and evaluating Santa Fe's capital and cost structures aimed at
increasing flexibility and strengthening Santa Fe's financial condition and
results of operations. The proposed dispositions will be in addition to the sale
of gas gathering and processing assets to Hadson.
In December 1993, Santa Fe completed the sale of all of the common stock of
its wholly owned subsidiary, Adobe Gas Pipeline Company ("AGPC"), to Hadson
Corporation ("Hadson") in exchange for
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<PAGE> 36
new Hadson 11.25% preferred stock with a face value of $52 million plus 40% of
Hadson's outstanding common stock on a fully-diluted basis. AGPC owned all of
Santa Fe's gas gathering and processing assets. In addition, Santa Fe agreed to
a seven-year gas sales contract pursuant to which Hadson will market a
substantial portion of Santa Fe's natural gas production.
THE TREASURY OBLIGATIONS
The Treasury Obligations consist of a portfolio of interest coupons
stripped from United States Treasury Bonds. All of the Treasury Obligations
become due on the Liquidation Date in the aggregate face amount of $126,000,000,
which amount equals $20 per outstanding Depositary Unit. The Treasury
Obligations were purchased on behalf of the Depositary at a deep discount from
face value at a price of $30.733 per hundred dollars, which was approximately
the asked price on the over-the-counter U.S. Treasury market for such
obligations on November 12, 1992 (after adjustment for five-day settlement). The
Treasury Obligations were deposited with the Depositary on November 19, 1992 in
connection with the initial public offering of Depositary Units. On February 9,
1994, the last bid and asked prices for the Treasury Obligations on the over-
the-counter U.S. Treasury market were approximately $39.982 per hundred dollars
and $40.418 per hundred dollars, respectively.
The Treasury Obligations were issued under the Separate Trading of
Registered Interest and Principal of Securities ("STRIPS") program of the U.S.
Treasury, which permits the trading of the Treasury Obligations in book-entry
form. The Treasury Obligations are held for the benefit of Holders in the name
of the Depositary in book-entry form with a Federal Reserve Bank, subject to
withdrawal by a Holder. The deposited Treasury Obligations are not considered
assets of the Depositary or the Trust. In the unlikely event of default by the
U.S. Treasury in the payment of the Treasury Obligations when due, each Holder
would have the right to withdraw a deposited Treasury Obligation in a face
amount of $1,000 for each 50 Depositary Units and, as a real party in interest
and as the owner of the entire beneficial interest in discrete Treasury
Obligations, proceed directly and individually against the United States of
America in whatever manner he deems appropriate without any requirement to act
in concert with the Depositary, other Holders or any other person. See
"Description of the Depositary Units -- Withdrawal of Trust Units and Treasury
Obligations."
Santa Fe makes available quarterly to the Depositary for distribution to
Holders certain information regarding the Treasury Obligations including high,
low and recent asked prices quoted during each calendar quarter on the
over-the-counter United States Treasury market. The Treasury Obligations pay no
current interest. See "Federal Income Tax Consequences."
PRINCIPAL AND SELLING SECURITY HOLDERS
The following table sets forth as of December 29, 1993 the beneficial
ownership by Santa Fe, the only person who was known to the Trustee to be the
beneficial owner of more than five percent of the outstanding Depositary Units.
<TABLE>
<CAPTION>
DEPOSITARY UNITS BENEFICIALLY OWNED
----------------------------------------------
BEFORE OFFERING AFTER OFFERING
--------------------- ---------------------
NAME NUMBER PERCENT NUMBER PERCENT
---- ------ ------- ------ -------
<S> <C> <C> <C> <C>
Santa Fe Energy Resources, Inc...................... 575,000 9.1% 0 0%
1616 South Voss Road
Suite 1000
Houston, Texas 77057
</TABLE>
FEDERAL INCOME TAX CONSEQUENCES
This section is a summary of Federal income tax matters of general
application which addresses all material tax consequences of the ownership and
sale of Depositary Units. Unless noted otherwise, statements of legal
conclusions set forth in this section constitute the opinion of Counsel. Except
where indicated, the
36
<PAGE> 37
discussion below describes general Federal income tax considerations applicable
to individuals who are citizens or residents of the United States. Accordingly,
the following discussion has limited application to domestic corporations and
persons subject to specialized Federal income tax treatment, such as tax-exempt
entities, regulated investment companies and insurance companies. The following
discussion does not address tax consequences to foreign persons. It is
impractical to comment on all aspects of Federal, state, local and foreign laws
that may affect the tax consequences of the transactions contemplated hereby and
of an investment in Depositary Units as they relate to the particular
circumstances of every prospective Holder. EACH PROSPECTIVE HOLDER SHOULD
CONSULT HIS OWN TAX ADVISOR WITH RESPECT TO HIS PARTICULAR CIRCUMSTANCES.
This summary was prepared by Counsel and is based on current provisions of
the Internal Revenue Code of 1986, as amended (the "Code"), existing and
proposed regulations thereunder and current administrative rulings and court
decisions, all of which are subject to changes that may or may not be
retroactively applied. Some of the applicable provisions of the Code have not
been interpreted by the courts or the IRS.
No ruling has been or will be requested from the IRS with respect to any
matter affecting the Trust or Holders, and thus no assurance can be provided
that the opinions and statements set forth herein (which do not bind the IRS or
the courts) will not be challenged by the IRS or will be sustained by a court if
so challenged.
TREATMENT OF DEPOSITARY UNITS
A purchaser of a Depositary Unit will be treated, for Federal income tax
purposes, as purchasing directly an interest in the Treasury Obligations and a
Trust Unit. A purchaser will therefore be required to allocate the purchase
price of his Depositary Unit between the interest in the Treasury Obligations
and the Trust Unit in the proportion that the fair market value of each bears to
the fair market value of the Depositary Unit. Information regarding purchase
price allocations will be furnished to Holders by the Trustee.
CLASSIFICATION AND TAXATION OF THE TRUST
The Trust will be treated as a grantor trust and not as an association
taxable as a corporation. As a grantor trust, the Trust will not be subject to
tax. For tax purposes, Holders will be considered to own and receive the Trust's
income and principal as though no trust were in existence. The Trust will file
an information return, reporting all items of income, credit or deduction which
must be included in the tax returns of Holders. If, contrary to the opinion of
Counsel, the Trust were determined to be an association taxable as a
corporation, it would be treated as a separate entity subject to corporate tax
on its taxable income, Holders would be treated as shareholders, and
distributions to Holders from the Trust would be treated as nondeductible
corporate distributions. Those distributions would generally be taxable to a
Holder, first, as dividends to the extent of the Holder's pro rata share of the
Trust's earnings and profits, then as a tax-free return of capital to the extent
of his basis in his Trust Units, and finally as capital gain to the extent of
any excess.
DIRECT TAXATION OF HOLDERS
Because the Trust will be treated as a grantor trust for Federal income tax
purposes, and a Holder will be treated, for Federal income tax purposes, as
owning a direct interest in the Treasury Obligations and the assets of the
Trust, each Holder will be taxed directly on his pro rata share of the income
attributable to the Treasury Obligations and the assets of the Trust and will be
entitled to claim his pro rata share of the deductions attributable to the Trust
(subject to certain limitations discussed below). Income and expenses
attributable to the assets of the Trust and the Treasury Obligations will be
taken into account by Holders consistent with their method of accounting and
without regard to the taxable year or accounting method employed by the Trust.
The Trust will make quarterly distributions to Holders of record on each
quarterly record date. The terms of the Trust Agreement, as described below,
seek to assure to the extent practicable that taxable income attributable to
such distributions will be reported by the Holder who receives such
distributions, assuming that he is the owner of record on the quarterly record
date. In certain circumstances, however, a Holder will not receive the
distribution attributable to such income. For example, if the Trustee
establishes a reserve or borrows money to satisfy debts and liabilities of the
Trust, income associated with the cash used to establish
37
<PAGE> 38
that reserve or to repay that loan must be reported by the Holder, even though
that cash is not distributed to him. In addition, Holders will be required to
recognize certain interest income attributable to the Treasury Obligations with
respect to which no current cash distributions will be made.
The Trust intends to allocate income and deductions to Holders based on
record ownership at quarterly record dates. It is unknown whether the IRS will
accept that allocation or will require income and deductions of the Trust to be
determined and allocated daily or require some method of daily proration, even
retroactively to the date of this offering, which could result in an increase in
the administrative expenses of the Trust.
TREATMENT OF TRUST UNITS
Because the Trust will be treated as a grantor trust for tax purposes, each
Holder will be treated as purchasing directly an interest in the Royalty
Interests. The purchaser of a Depositary Unit will be required to allocate the
portion of his total purchase price allocated to the Trust Unit among the
Royalty Interests in the proportion that the fair market value of each of the
Royalty Interests bears to the total fair market value of all of the Royalty
Interests. For purposes of making this allocation, the Royalty Interests will
include the Wasson ODC Royalty, the Wasson Willard Royalty and the Net Profits
Royalties. Information regarding purchase price allocations will be furnished to
Holders by the Trustee.
INTEREST INCOME
Based on representations made by Santa Fe regarding the reserves burdened
by the Wasson Royalties and the expected life of the Wasson Royalties, the
Wasson Royalties will be treated as "production payments" under Section 636(a)
of the Code. Thus, each Holder will be treated as making a mortgage loan on the
Royalty Properties to Santa Fe in an amount equal to the amount of the purchase
price of each Depositary Unit allocated to the Wasson Royalties. Because they
are treated as debt instruments for tax purposes, the Wasson Royalties will be
subject to the Original Issue Discount ("OID") rules of Sections 1272 through
1275 of the Code. Section 1272 generally requires the periodic inclusion of
original issue discount in income of the purchaser of a debt instrument. Section
1275 provides special rules and authorizes the IRS to prescribe regulations
modifying the statutory provisions where, by reason of contingent payments, the
tax treatment provided under the statutory provisions does not carry out the
purposes of such provisions. The IRS has not yet issued either temporary or
final regulations dealing with contingent payments. Proposed regulations dealing
with contingent payments were issued in 1986 and modified in 1991 (the "Proposed
Regulations").
Under the Proposed Regulations, each payment (at the time the amount of
such payment becomes fixed) made to the Trust with respect to the Wasson
Royalties will be treated first as consisting of a payment of interest to the
extent of interest deemed accrued under the OID rules and the excess (if any)
will be treated as a payment of principal. The total amount treated as principal
will be limited to the amount of the purchase price of each Depositary Unit
allocated to the Wasson Royalties. For purposes of determining the amount of
accrued interest, the Proposed Regulations require the use of the Applicable
Federal Rate based on the due date of the final payment due under the terms of
each of the production payments, which for the Wasson Willard Royalty and the
Wasson ODC Royalty is December 31, 2003 and December 31, 2007, respectively.
Recently, new proposed regulations were issued which, if applicable, could
accelerate the recognition of income attributable to the Wasson Royalties. Those
proposed regulations have been withdrawn by the Clinton Administration and it is
not possible to predict whether they will become effective.
The amount of interest income will be reported periodically to Holders.
Because of uncertainties related to the computation of that amount, that amount
may be based upon an assumption that each Holder purchased his Depositary Units
in the initial public offering of Depositary Units on November 19, 1992, which
may result in greater interest income being reported to all Holders who
purchased after the initial offering, including those who purchase in this
offering.
Holders will also be required to recognize and report OID interest income
attributable to the Treasury Obligations. In general, the total amount of OID a
Holder will be required to recognize will be calculated as the difference
between the amount of the purchase price of a Depositary Unit allocated to the
Treasury Obligations and the pro rata portion of the face amount of such
Treasury Obligations attributable to the
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<PAGE> 39
Depositary Unit. The amount of OID so calculated will be included in income by a
Holder on the basis of a constant interest rate computation.
ROYALTY INCOME AND DEPLETION
The income from the Net Profits Royalties will be royalty income subject to
an allowance for depletion. The depletion allowance must be computed separately
by each Holder for each oil or gas property (within the meaning of Code Section
614). The IRS presently takes the position that a net profits interest carved
out of multiple properties is a single property for depletion purposes.
Accordingly, the Trust intends to take the position that the Net Profits
Royalties are a single property for depletion purposes until such time as the
issue is resolved in some other manner.
The allowance for depletion with respect to a property is determined
annually and is the greater of cost depletion or, if allowable, percentage
depletion. Percentage depletion is generally available to "independent
producers" (generally persons who are not substantial refiners or retailers of
oil or gas or their primary products) on the equivalent of 1,000 barrels of
production per day. Percentage depletion is a statutory allowance equal to 15%
of the gross income from production from a property subject to a net income
limitation which is 100% of the taxable income from the property, computed
without regard to depletion deductions and certain loss carrybacks. The
depletion deduction attributable to percentage depletion for a taxable year is
limited to 65% of the taxpayer's taxable income for the year before allowance of
"independent producers" percentage depletion. Unlike cost depletion, percentage
depletion is not limited to the adjusted tax basis of the property, although it
reduces such adjusted tax basis (but not below zero).
In computing cost depletion for each property for any year, the adjusted
tax basis of that property at the beginning of that year is divided by the
estimated total units (Bbls of oil or Mcf of gas) recoverable from that property
to determine the per-unit allowance for such property. The per-unit allowance is
then multiplied by the number of units produced and sold from that property
during the year. Cost depletion for a property cannot exceed the adjusted tax
basis of such property. Since the Trust will be taxed as a grantor trust, each
Holder will compute cost depletion using his basis in his Trust Units allocated
to the Net Profits Royalties. Information will be provided to each Holder
reflecting how that basis should be allocated among each property represented by
his Trust Units.
OTHER INCOME AND EXPENSES
It is anticipated that the Trust may generate some interest income on funds
held as a reserve or held until the next distribution date. Expenses of the
Trust will include administrative expenses of the Trustee. Under the Code,
certain miscellaneous itemized deductions of an individual taxpayer are
deductible only to the extent that in the aggregate they exceed 2% of the
taxpayer's adjusted gross income. Certain administrative expenses attributable
to the Trust Units may have to be aggregated with an individual Holder's other
miscellaneous itemized deductions to determine the excess over 2% of adjusted
gross income. It is anticipated that the amount of such expenses will not be
significant in relation to the Trust's income.
NON-PASSIVE ACTIVITY INCOME AND LOSS
The income and expenses of the Trust will not be taken into account in
computing the passive activity losses and income under Code Section 469 for a
Holder who acquires and holds Depositary Units as an investment.
UNRELATED BUSINESS TAXABLE INCOME
Certain organizations that are generally exempt from tax under Code Section
501 are subject to tax on certain types of business income defined in Code
Section 512 as unrelated business income. The income of the Trust will not be
unrelated business taxable income within the meaning of Code Section 512 so long
as the Trust Units are not "debt-financed property" within the meaning of Code
Section 524(b). In general, a Trust Unit would be debt-financed if the Holder
incurs debt to acquire a Trust Unit or otherwise incurs or maintains a debt that
would not have been incurred or maintained if such Trust Unit had not been
acquired. Legislative
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<PAGE> 40
proposals have been made from time to time which, if adopted, would result in
the treatment of income attributable to the Net Profits Royalties as unrelated
business income.
ESTIMATE OF TAXABLE INCOME
Santa Fe estimates that a purchaser of a Depositary Unit in this offering
who continues to own that Depositary Unit through the record date for the
distribution with respect to the fourth quarter of 1994 will recognize taxable
income of approximately 73% of cash received for 1994, assuming that cash
distributions are made in respect of 1994 based upon the future net revenues
estimated in the Reserve Report. The Reserve Report assumes certain levels of
production and constant pricing in effect as of December 31, 1992. The estimate
of taxable income is based upon numerous other assumptions including (i) a
hypothetical purchase price of $20.75 per Depositary Unit, which is an
approximation of recent trading prices of the Depositary Units, (ii) production
of quantities of oil and gas in 1994, as estimated in the Reserve Report, (iii)
assumptions as to tax treatment of operating costs, development costs, depletion
and deductions related to trust administrative expenses and (iv) assumptions
regarding allocation of purchase price among the various Royalty Interests and
the Treasury Obligations. No assurance can be given that the foregoing estimate
will prove to be correct. Actual distributions and the 1994 taxable percentage
may be materially higher or lower. Over the life of the Trust, taxable income is
expected to increase as a percentage of distributable cash and at some point
should exceed such cash, as the Depositary Units assume more of the
characteristics of the Treasury Obligations due to declines in production from
the Royalty Interests. Fluctuations in oil and gas prices may also affect the
ratio of taxable income to distributable cash. See "-- Interest Income" above.
SALE OF DEPOSITARY UNITS; DEPLETABLE BASIS
Generally, a Holder will realize gain or loss on the sale or exchange of
his Depositary Units measured by the difference between the amount realized on
the sale or exchange and his adjusted basis for such Depositary Units. Gain or
loss on the sale of Depositary Units by a Holder who is not a dealer with
respect to such Depositary Units and who has a holding period for the Depositary
Units of more than one year will be treated as long-term capital gain or loss
except to the extent of the depletion recapture amount and any accrued market
discount as explained below. A Holder's basis in his Depositary Units will be
equal to the amount paid for those Depositary Units. That basis will be
increased by the amount of any OID income recognized by him attributable to the
Treasury Obligations and reduced by deductions for depletion claimed by him (but
not below zero). In addition, that basis will be reduced by the amount of any
payments attributable to the Wasson Royalties which are treated as payments of
principal under the OID rules. For Federal income tax purposes, the sale of a
Depositary Unit will be treated as a sale by the Holder of his interest in the
Treasury Obligations and the assets of the Trust. Thus, upon the sale of
Depositary Units, a Holder must treat as ordinary income his depletion recapture
amount, which is an amount equal to the lesser of (i) the gain on that sale
attributable to disposition of the Net Profits Royalties or (ii) the sum of the
prior depletion deductions taken with respect to the Net Profits Royalties (but
not in excess of the initial basis of such Depositary Units allocated to the Net
Profits Royalties). It is possible that the IRS would take the position that a
portion of the sales proceeds is ordinary income to the extent of any accrued
income at the time of sale allocable to the Depositary Units sold, but which is
not distributed to the selling Holder.
A purchaser of a Depositary Unit in the offering made hereby who allocates
his purchase price (or is required to allocate his purchase price) to the
Treasury Obligations in an amount less than the Holder's pro rata share of the
initial issue price of the Treasury Obligations, plus his pro rata share of OID
income recognized by prior holders of the Treasury Obligations (any such
difference represents "market discount"), will generally be required to
recognize ordinary income to the extent of any accrued market discount upon sale
of the Depositary Unit. In general, accrued market discount is an amount which
bears the same ratio to total market discount as the number of days which a
Holder holds a Depositary Unit bears to the number of days after the date the
Holder acquired the Depositary Unit and up to and including the Liquidation
Date.
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<PAGE> 41
SALE OF NET PROFITS ROYALTIES
In certain circumstances, Santa Fe may cause the Trustee, without the
consent of the Holders, to release a portion of the Net Profits Royalties in
connection with a sale by Santa Fe of the underlying Net Profits Properties.
Additionally, the assets of the Trust, including the Net Profits Royalties, will
be sold by the Trustee prior to the Liquidation Date in anticipation of the
termination of the Trust. A sale by the Trust of Net Profits Royalties will be
treated for Federal income tax purposes as a sale of Net Profits Royalties by a
Holder. Thus, a Holder will recognize gain or loss on a sale of Net Profits
Royalties by the Trust. A portion of that income may be treated as ordinary
income to the extent of depletion recapture. See "Sale of Depositary Units;
Depletable Basis," above.
BACKUP WITHHOLDING
In general, distributions of Trust income will not be subject to "backup
withholding" unless: (i) the Holder is an individual or other noncorporate
taxpayer and (ii) he fails to comply with certain reporting procedures.
TAX SHELTER REGISTRATION
Code Section 6111 requires a tax shelter organizer to register a "tax
shelter" with the IRS by the first day on which interests in the tax shelter are
offered for sale. The Trust is registered as a tax shelter with the IRS. The
Trust's tax shelter registration number is 92322000636.
A Holder who sells or otherwise transfers a Trust Unit in a subsequent
transaction must furnish the tax shelter registration number to the transferee.
The penalty for failure of the transferor of a Trust Unit to furnish such tax
shelter registration number to a transferee is $100 for each such failure.
Holders must disclose the tax shelter registration number of the Trust on Form
8271 to be attached to the tax return on which any deduction, loss, credit or
other benefit generated by the Trust is claimed or income of the Trust is
included. A Holder who fails to disclose the tax shelter registration number on
his return, without reasonable cause for such failure, will be subject to a $50
penalty for each such failure. (Any penalties discussed herein are not
deductible for income tax purposes.)
ISSUANCE OF A TAX SHELTER REGISTRATION NUMBER DOES NOT INDICATE THIS
INVESTMENT OR THE CLAIMED TAX BENEFITS HAVE BEEN REVIEWED, EXAMINED OR APPROVED
BY THE IRS.
REPORTS
The Trustee will furnish to the Depositary for mailing to Holders of record
annual reports in order to permit computation of their taxable income from
ownership of Trust Units. See "Description of the Trust and the Trust
Agreement -- Periodic Reports."
ERISA CONSIDERATIONS
The Employee Retirement Income Security Act of 1974, as amended ("ERISA"),
imposes certain requirements on pension, profit-sharing and other employee
benefit plans to which it applies ("Plans"), and contains standards on those
persons who are fiduciaries with respect to such Plans. In addition, under the
Code, there are similar requirements and standards which are applicable to
certain Plans and individual retirement accounts (whether or not subject to
ERISA) (collectively, together with Plans subject to ERISA, referred to herein
as "Qualified Plans").
A fiduciary of a Qualified Plan should carefully consider fiduciary
standards under ERISA regarding the Plan's particular circumstances before
authorizing an investment in Trust Units. A fiduciary should first consider (i)
whether the investment satisfies the prudence requirements of Section
404(a)(1)(B) of ERISA, (ii) whether the investment satisfies the diversification
requirements of Section 404(a)(1)(C) of ERISA and
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(iii) whether the investment is in accordance with the documents and instruments
governing the Plan as required by Section 404(a)(1)(D) of ERISA.
In order to avoid the application of certain penalties, a fiduciary must
also consider whether the acquisition of Trust Units and/or operation of the
Trust might result in direct or indirect nonexempt prohibited transactions under
Section 406 of ERISA and Code Section 4975. In determining whether there are
such prohibited transactions, a fiduciary must determine whether these are "plan
assets" involved in the transaction. On November 13, 1986, the Department of
Labor published final regulations (the "DOL Regulations") concerning whether or
not a Qualified Plan's assets (such as a Trust Unit) would be deemed to include
an interest in the underlying assets of an entity (such as the Trust) for
purposes of the reporting, disclosure and fiduciary responsibility provisions of
ERISA and analogous provisions of the Code, if the Plan acquires an "equity
interest" in such entity. The DOL Regulations provide that the underlying assets
of an entity will not be considered "plan assets" if the interests in the entity
are a publicly offered security. Trust Units are considered to be "publicly
offered" for this purpose if they are part of a class of securities that is (i)
widely held (i.e., owned by more than 100 investors independent of the issuer
and each other), (ii) freely transferable, and (iii) registered under Section
12(b) or 12(g) of the Exchange Act. Although no assurances can be given, it is
expected that these requirements will be satisfied with respect to Trust Units
offered hereunder. Fiduciaries, however, will need to determine whether the
acquisition of Trust Units is a nonexempt prohibited transaction under the
general requirements of ERISA Section 406 and Code Section 4975.
Due to the complexity of the prohibited transaction rules and the penalties
imposed upon persons involved in prohibited transactions, it is important that
potential Qualified Plan investors consult with their counsel regarding the
consequences under ERISA and the Code of their acquisition and ownership of
Trust Units.
STATE TAX CONSIDERATIONS
The following is intended as a brief summary of certain information
regarding state income taxes and other state tax matters affecting individuals
who are Holders. Holders are urged to consult their own legal and tax advisors
with respect to these matters.
Prospective investors should consider state and local tax consequences of
an investment in Depositary Units. The Trust owns Royalty Interests burdening
oil and gas properties located in Alabama, Arkansas, California, Colorado,
Kansas, Louisiana, Mississippi, New Mexico, North Dakota, Oklahoma, Texas and
Wyoming. Of these, all but Texas and Wyoming have income taxes applicable to
individuals. As stated, Texas currently has no income tax and Santa Fe
anticipates that more than 50% of the income generated by the Trust will be
attributable to properties located in Texas. A Holder may be required to file
state income tax returns and/or to pay taxes in those states imposing income
taxes and may be subject to penalties for failure to comply with such
requirements. Further, in some states, the Trust may be taxed as a separate
entity.
The Depositary will provide information prepared by the Trustee concerning
the Depositary Units sufficient to identify the income from Depositary Units
that is allocable to each state. Holders of Depositary Units should consult
their own tax advisors to determine their income tax filing requirements with
respect to their share of income of the Trust allocable to states imposing an
income tax on such income.
The Trust Units represented by Depositary Units may constitute real
property or an interest in real property under the inheritance, estate and
probate laws of some or all of the states listed above. If the Depositary Units
are held to be real property or an interest in real property under the laws of a
state in which the Royalty Properties are located, the Holders of Depositary
Units may be subject to devolution, probate and administration laws, and
inheritance or estate and similar taxes, under the laws of such state.
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DESCRIPTION OF THE TRUST AND THE TRUST AGREEMENT
The following information is subject to the detailed provisions of the
Trust Agreement of Santa Fe Energy Trust, dated November 19, 1992, between Santa
Fe and Texas Commerce Bank National Association, as Trustee (the "Trust
Agreement"). The principal executive offices of the Trustee are located at
Corporate Trust Division, 600 Travis, Suite 1150, Houston, Texas 77002 and its
telephone number is (713) 216-5100. A copy of the Trust Agreement has been filed
as an exhibit to the Registration Statement of which this Prospectus is a part.
The provisions governing the Trust are complex and extensive and no attempt has
been made below to describe all of such provisions. The following is a general
description of the basic framework of the Trust, and detailed provisions
concerning the Trust may be found in the Trust Agreement.
CREATION AND ORGANIZATION OF THE TRUST
Santa Fe owns, and after this offering will continue to own, the Royalty
Properties subject to and burdened by the Royalty Interests. Accordingly, Santa
Fe, as owner of the Royalty Properties receives payments from purchasers of
production or the operators of such properties. Santa Fe aggregates these
payments, deducts costs and expenses where applicable, and makes quarterly
payments to the Trustee of the amounts due to the Trust.
Pursuant to the Conveyances, Santa Fe conveyed the Royalty Interests to the
Trust in conjunction with the November 1992 initial public offering of Trust
Units. The Depositary Units offered hereby were issued to Santa Fe as partial
consideration for such conveyances.
The beneficial interest in the Trust created by the Trust Agreement is
divided into 6,300,000 Trust Units, each representing equal undivided interests
in the assets of the Trust. Pursuant to the Trust Agreement, the Holder of each
Depositary Unit is treated as the holder of a Trust Unit. All of the Trust Units
were placed on deposit with the Depositary (defined below) although Holders have
the right to hold Trust Units directly under certain circumstances. See
"Description of the Depositary Units -- Withdrawal of Trust Units and Treasury
Obligations."
The Trust was formed under Texas law to acquire and hold the Royalty
Interests for the benefit of the holders of Trust Units. The Royalty Interests
are passive in nature and the Trustee has no control over and no responsibility
relating to the operation of the Royalty Properties. Neither Santa Fe nor the
operators of the Royalty Properties have any contractual commitments to the
Trust to conduct further development drilling on the Royalty Properties, to
remain as operator with respect to any of the leases on the Royalty Properties
or to maintain their ownership interest in any of the properties. However, Santa
Fe retains a substantial revenue interest in each of the Royalty Properties. For
a description of the Royalty Properties and other information relating to such
properties, see "The Royalty Properties."
The Trustee may resign with or without cause at any time or be removed with
or without cause by a vote of holders of a majority of the Trust Units. Any
resignation shall be effective upon the appointment by Santa Fe of and
acceptance of the appointment by a successor Trustee. Any successor must be a
bank or trust company meeting certain requirements including having capital,
surplus and undivided profits of at least $100,000,000.
ASSETS OF THE TRUST
The only assets of the Trust, other than cash and temporary investments
being held for the payment of expenses and liabilities and for distribution to
the Holders, are the Royalty Interests. See "The Royalty Properties" and "The
Royalty Interests."
DUTIES AND LIMITED POWERS OF THE TRUSTEE
Under the Trust Agreement, the Trustee receives the payments attributable
to the Royalty Interests and pays all expenses, liabilities and obligations of
the Trust. With respect to any liability that is contingent or uncertain in
amount or that otherwise is not currently due and payable, the Trustee has the
discretion to establish a cash reserve for the payment of such liability. If at
any time the cash on hand and to be received by
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the Trustee is not, in its judgment, sufficient to pay liabilities of the Trust
as they become due, the Trustee is authorized to borrow the funds required to
pay such liabilities, in which event no further distributions will be made to
Holders until such borrowing has been repaid. The Trustee is permitted to borrow
such funds from any bank, including itself. To secure payment of any such
indebtedness, the Trustee is authorized to mortgage, pledge, grant security
interests in or otherwise encumber assets of the Trust, or any portion thereof,
including the Royalty Interests, and to carve out and convey production
payments. After payment of or provision for Trust expenses and obligations, the
Trustee makes quarterly distributions to Holders of all the proceeds received
from the Royalty Interests and not theretofore distributed.
The Trust Agreement authorizes the Trustee to take such action as in its
judgment is necessary or advisable to achieve the purposes of the Trust. The
Trust Agreement provides that cash being held by the Trustee as a reserve for
liabilities or for distribution at the next distribution date be placed in
interest-bearing accounts or certificates, but the Trustee is otherwise
prohibited from acquiring any asset other than the Royalty Interests or engaging
in any business or investment activity of any kind whatsoever.
The Trustee is responsible as a fiduciary to the Holders, as beneficial
owners of Trust Units. However, the Trust Agreement provides that the Trustee is
not personally liable to the Holders except for fraud or acts or omissions in
bad faith or which constitute gross negligence.
Due to the passive nature of the Trust Units and the Trust, the Trustee is
not required to make business decisions affecting the Trust Units or the Trust
assets. Therefore, the primary functions of the Trustee are ministerial. Under
certain circumstances, however, the Trustee may be required to approve or
disapprove an extraordinary transaction affecting the Trust and the Holders.
These transactions include a sale of the Royalty Interests (in addition to
certain sales of Net Profits Royalties within limitations described herein) and
amendment of the Trust Agreement. The Trustee has a fiduciary duty to represent
the interests of the Holders in connection with any future extraordinary
transactions, but is not required to retain an unaffiliated person as counsel to
represent the Holders.
Under Texas law and the terms of the Trust Agreement, if the Trustee were
to commit fraud or engage in any act or omissions in bad faith or which
constitutes gross negligence that would harm Holders, the Trustee would be
liable to the Holders for damages caused by any such act or omission. Texas law
permits the Holders to file an action seeking other remedies for such acts or
omissions in addition to damages, including removal of the Trustee, specific
performance, appointment of a receiver, an accounting by the Trustee to the
Holders, exemplary damages and other remedies.
DISTRIBUTIONS AND INCOME COMPUTATIONS
The Trustee determines for each calendar quarter during the term of the
Trust the amount of cash available for distribution to holders of Depositary
Units and the Trust Units evidenced thereby. Such amount (the "Quarterly
Distribution Amount") is equal to the excess, if any, of the cash received by
the Trust from the Royalty Interests then held by the Trust during such quarter,
plus any other cash receipts of the Trust during such quarter, over the
liabilities of the Trust paid during such quarter, subject to adjustments for
changes made by the Trustee during such quarter in any cash reserves established
for the payments of contingent or future obligations of the Trust. Based on
industry practice and the payment procedures relating to the Net Profits
Properties, cash received by the Trustee in a particular quarter from the Net
Profits Properties generally represents proceeds from sales of production for
the three months ending two months prior to the end of such quarter with respect
to gas, and one month prior to the end of such quarter with respect to oil. For
example, the royalty income received by the Trust for the third calendar quarter
with respect to gas is attributable to production in the months of May, June and
July (for which Santa Fe would have received payment from the purchasers in
July, August and September, respectively). Since proceeds from the sale of
production from the Wasson Properties are received within one month of
production, payments in respect of the Wasson Royalties are made for production
from the calendar quarter to which the Quarterly Distribution Amount relates.
The Quarterly Distribution Amount for each quarter is payable to Holders of
Depositary Units of record on the 45th day following each calendar quarter (or
the next succeeding business day following such day if such day is not a
business day) or such later date as the Trustee determines
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is required to comply with legal or stock exchange requirements ("Quarterly
Record Date"). The Trustee distributes cash to the Holders within two months
after the end of each calendar quarter to each person who was a Holder of
Depositary Units of record on a Quarterly Record Date.
The net taxable income of the Trust for each calendar quarter will be
reported by the Trustee for tax purposes as belonging to the Holders of record
to whom the Quarterly Distribution Amount was or will be distributed. Because
the Trust will be classified for tax purposes as a "grantor trust" (see "Federal
Income Tax Consequences"), the net taxable income will be realized by the
Holders for tax purposes in the calendar quarter received by the Trustee, rather
than in the quarter distributed by the Trustee. Taxable income of a Holder may
differ from the Quarterly Distribution Amount because the Wasson Royalties and
Treasury Obligations are treated as generating interest income for tax purposes.
There may also be minor variances because of the possibility that, for example,
a reserve will be established in one quarter that will not give rise to a tax
deduction until a subsequent quarter, an expenditure paid for in one quarter
will have to be amortized for tax purposes over several quarters, etc. See
"Federal Income Tax Consequences."
Each Holder of Depositary Units (including the underlying Trust Units) of
record as of the business day next preceding the Liquidation Date will be
entitled to receive a liquidating distribution equal to a pro rata portion of
the net proceeds from the sale of the Net Profits Royalties (to the extent not
previously distributed) and a pro rata portion of the proceeds from the matured
Treasury Obligations.
VOTING RIGHTS OF HOLDERS OF TRUST UNITS
While the holders of Trust Units have certain voting rights, such rights
differ from those of stockholders of a corporation. For example, there is no
requirement for annual meetings of holders of Trust Units or for annual or other
periodic reelection of the Trustee. Meetings may be called to consider
amendments to the Trust Agreement and removal of the Trustee and appointment of
a successor.
Meetings of holders of Trust Units may be called by the Trustee or by
holders of Trust Units owning not less than 10% in number of the Trust Units.
All such meetings shall be held in Houston, Texas and written notice of every
such meeting setting forth a time and place of the meeting and the matters
proposed to be acted upon shall be given to holders of Trust Units not more than
60 nor less than 20 days before such meeting. The presence in person or by proxy
of holders of Trust Units representing a majority of the Trust Units outstanding
is necessary to constitute a quorum. Each holder of a Trust Unit is entitled to
one vote for each Trust Unit owned by such holder. No matter other than that
stated in the notice shall be acted upon at any meeting. Any matter shall be
deemed to have been approved by the holders of Trust Units if it is approved by
the vote of such holders holding a majority of the then outstanding Trust Units.
Notwithstanding the foregoing, amendments to the provisions of the Trust
Agreement concerning the disposition of Royalty Interests require the prior
consent of Santa Fe. In addition, no amendment may be made to the Trust
Agreement that would increase the power of the Trustee to engage in any business
or investment activities or alter the rights of holders of Trust Units vis-a-vis
each other.
Under the Trust Agreement, Holders of Depositary Units are treated as
direct holders of the underlying Trust Units for the purposes of voting and
notices of meetings. The Depositary forwards voting and meeting information to
Holders upon receipt by the Trustee.
WITHDRAWAL OF TRUST UNITS AND RESTRICTIONS ON TRANSFER
Upon presentation of Depositary Units in denominations of 50 or integral
multiples thereof for withdrawal of the Trust Units and discrete Treasury
Obligations evidenced thereby in accordance with the Deposit Agreement, the
Holder will receive an uncertificated direct interest in Trust Units. These
withdrawn Trust Units will be evidenced on the books of the Trustee by a
transfer of such Trust Units from the name of the Depositary to the name of the
withdrawing Holder. Holders of withdrawn Trust Units are entitled to receive
Trust distributions and periodic Trust information (including tax information)
directly from the Trustee. Moreover, holders of Trust Units are entitled to each
of the rights accorded holders of Trust Units under the Trust Agreement,
including voting rights, as elsewhere described in this Prospectus, except that
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withdrawn Trust Units are not freely transferable as described below under
"Description of the Depositary Units -- Withdrawal of Trust Units and Treasury
Obligations."
Pursuant to the Trust Agreement and the transfer application, the form of
which is included as Appendix B hereto (the "Transfer Application"), withdrawn
Trust Units are not transferable except by operation of law. A holder of
withdrawn Trust Units may, however, transfer such Trust Units in denominations
of 50 (or integral multiples thereof) to the Depositary for redeposit, together
with Treasury Obligations in the face amount equal to $1,000 for each 50 Trust
Units redeposited, in exchange for Depositary Units. Such redeposit can be
effected by delivering written notice of such transfer jointly to the Depositary
and the Trustee together with proper documentation necessary to transfer the
requisite Treasury Obligations into the name of the Depositary.
TRANSFER OF ROYALTY PROPERTIES AND ROYALTY INTERESTS
The Trust Agreement provides that Santa Fe may sell the Royalty Properties,
subject to and burdened by the Royalty Interests, without the consent of the
Holders. Following any such transfer, the Royalty Properties will continue to be
burdened by the Royalty Interests, and after any such transfer the Conveyances
require that the royalty payment attributable to the transferred property be
calculated separately and paid by the transferee. In addition, Santa Fe may,
without the consent of the Holders, require the Trust to release up to $5
million of the Net Profit Royalties at the then prevailing fair market value in
any 12-month period in connection with a sale of the underlying Net Profits
Properties by Santa Fe; provided that not more than $15 million in the aggregate
may be released prior to January 1, 2003. Santa Fe may cause all of the Net
Profits Royalties to be sold, without regard to dollar limitations, on and after
December 31, 2005. Any net sales proceeds paid to the Trust are distributable to
Holders for the quarter in which such proceeds are received. The Trustee is
directed under the Trust Agreement to sell the remaining Net Profits Royalties
on or prior to the first business day of December 2007. The proceeds of such
sale (to the extent not previously distributed), together with the matured face
amount of the Treasury Obligations, will be distributed to Holders on or prior
to the Liquidation Date. Pursuant to the Trust Agreement, the Trust may not sell
the Wasson ODC Royalty or the Wasson Willard Royalty without the consent of
Santa Fe. Under the Trust Agreement, Santa Fe has a right of first refusal to
purchase any of the Royalty Interests at fair market value, or if applicable the
offered third-party price, prior to the Liquidation Date.
The Trustee is also authorized to agree to modifications of the terms of
the Conveyances and to settle disputes with respect thereto, so long as such
modifications or settlements will not adversely affect the classification of the
Trust as a "grantor trust" for Federal income tax purposes, and such
modifications or settlements do not alter the nature of the Royalty Interests as
a right to receive a share of the proceeds of oil and gas produced from the
Royalty Properties, free of any operating rights, expenses or obligations.
PERIODIC REPORTS
Within 60 days following the end of each calendar quarter during the term
of the Trust, the Trustee will furnish the Depositary for mailing to each party
who was a Holder of record as of a date selected by the Trustee a report which
shows in reasonable detail the assets and liabilities and receipts and
disbursements of the Trust for such quarter. Within 120 days following the end
of each fiscal year, the Trustee will cause the Depositary to mail to Holders of
record as of a date to be selected by the Trustee an annual report containing
audited financial statements relating to the Trust.
The Trustee files such returns for Federal income tax purposes as it is
advised are required to comply with applicable law and to permit each beneficial
owner of Trust Units to make all calculations reasonably necessary for tax
purposes. The Trustee treats all income, credits and deductions recognized
during each calendar quarter during the term of the Trust as having been
recognized by holders of record on the quarterly record date of such quarter
unless otherwise advised by counsel.
Each beneficial owner of Trust Units and his duly authorized agents and
attorneys have the right during reasonable business hours to examine and inspect
records of the Trust.
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POSSIBLE DIVESTITURE OF TRUST UNITS
The Trust Agreement imposes no restrictions based on nationality or other
status of holders of Trust Units. However, the Trust Agreement and the Deposit
Agreement provide that in the event of certain judicial or administrative
proceedings seeking the cancellation or forfeiture of any property in which the
Trust has an interest because of the nationality, citizenship or any other
status, of any one or more holders of Trust Units, including Holders of
Depositary Units, the Trustee will give written notice thereof to each holder
whose nationality or other status is an issue in the proceeding, which notice
will constitute a demand that such holder dispose of his Depositary Units or
withdrawn Trust Units within 30 days. If any holder fails to dispose of his
Depositary Units or withdrawn Trust Units in accordance with such notice, cash
distributions on such units are subject to suspension. In the event a holder
fails to dispose of Depositary Units in accordance with such notice, the
Depositary may cancel such holders' Depositary Units and reissue them in the
name of the Trustee, whereupon the Trustee will use its reasonable efforts to
sell the Depositary Units and remit the net sale proceeds to such holder. In the
case of Trust Units withdrawn from deposit with the Depositary, the Trustee
shall redeem such Trust Units not divested in accordance with such notice, for a
cash price equal to the then-current market price of the Depositary Units less
the then-current, over-the-counter bid price of the related, withdrawn Treasury
Obligations. The redemption price will be paid out in quarterly installments
limited to the amount that otherwise would have been distributed in respect of
such redeemed Trust Units.
LIABILITIES OF THE TRUST
Because of the passive nature of the Trust assets and the restrictions on
the activities of the Trustee, it is anticipated that the only liabilities the
Trust will incur will be those for routine administrative expenses, such as the
Trustee's fees and accounting, engineering, legal and other professional fees.
However, as discussed under "Federal Income Tax Consequences," if a court were
to hold that the Trust is taxable as a corporation, then the Trust would incur
substantial Federal income tax liabilities.
LIABILITIES OF THE TRUSTEE
The Trustee may act in its discretion and shall be personally or
individually liable only for fraud or acts or omissions in bad faith or which
constitute gross negligence, and will not otherwise be liable for any act or
omission of any agent or employee of the Trustee unless it has acted in bad
faith in the selection and retention of such agent or employee. The Trustee is
indemnified from the Trust assets for any liability, expense, claim, damage or
other loss incurred in performing its duties, unless resulting from gross
negligence, fraud or bad faith, and has a claim against the assets of the Trust
as security for such indemnification and for reimbursements and compensation to
which it is entitled. The Trustee is not entitled to indemnification from
Holders, except as described under "Description of the Depositary
Units -- Transfers of Depositary Units." Santa Fe has agreed to indemnify the
Trustee with respect to certain matters to the extent Trust assets are not
available for such indemnity.
LIABILITY OF HOLDERS
The Trust is intended to be classified as an "express trust" under Texas
law and thus subject to the Texas Trust Code. Under the Texas Trust Code, a
trust beneficiary will not be held personally liable for obligations incurred by
the Trust except in limited circumstances principally related to wrongful
conduct by the trust beneficiary. It is unclear whether the Trust constitutes an
"express trust" under the Texas Trust Code. If the Trust were held not to be an
express trust, a Holder could be jointly and severally liable for any liability
of the Trust in the event that (i) the satisfaction of such liability was not by
contract limited to the assets of the Trust and (ii) the assets of the Trust
were insufficient to discharge such liability. Examples of such liability would
include liabilities arising under environmental laws and damages arising from
product liability and personal injury in connection with the Trust's business.
Although each Holder should weigh this potential exposure in deciding whether to
retain or transfer his Trust Units, after discussions with legal counsel, Santa
Fe believes that because of the value and passive nature of the Trust assets and
the restrictions on the activities of the Trustee, the imposition of any
liability on a Holder is unlikely.
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LIQUIDATION OF THE TRUST
The Trust will be liquidated and the Net Profits Royalties will be sold on
or prior to the Liquidation Date. Holders of record as of the business day next
preceding the Liquidation Date will be entitled to receive a terminating
distribution with respect to each Depositary Unit equal to a pro rata portion of
the net proceeds from the sale of the Net Profits Royalties (to the extent not
previously distributed) and a pro rata portion of the proceeds from the matured
Treasury Obligations. Under the Trust Agreement, Santa Fe has a right of first
refusal to purchase any of the Royalty Interests at fair market value, or if
applicable the offered third-party price, prior to the Liquidation Date.
FEES AND EXPENSES
Trustee Fees and Trust Administrative Expenses. The Trustee is paid an
annual fee of approximately $12,500. The Trust is responsible for paying all
legal, accounting, engineering and stock exchange fees, printing costs and other
administrative expenses incurred by or at the direction of the Trustee. The
total of all Trustee fees and Trust administrative expenses aggregates
approximately $250,000 per year, although such costs could be greater or less
depending on future events that cannot be predicted.
Fees to Santa Fe. The Trust pays Santa Fe an annual fee of $200,000 to
reimburse Santa Fe for overhead expenses which increases by 3.5% per year,
payable quarterly.
Loans, Fees and Deposits. The Trustee is entitled to cause the Trust to
borrow money to pay expenses that cannot be paid out of cash held by the Trust.
Under certain circumstances, the Trustee is authorized to borrow funds on behalf
of the Trust and grant security interests in Trust assets. See "Duties and
Limited Powers of the Trustee," above. The terms of such indebtedness and
security interest, if funds were loaned by the entity serving as Trustee, would
be similar to the terms which such entity would grant to a similarly situated
commercial customer with whom it did not have a fiduciary relationship, and such
entity shall be entitled to enforce its rights with respect to any such
indebtedness and security interest as if it were not then serving as Trustee.
The Trustee may also deposit funds awaiting distribution in an account with the
Trustee, provided the interest paid thereon equals the amount paid by the
Trustee on similar deposits.
RELATIONSHIP WITH TRUSTEE
Marc J. Shapiro, a director of Santa Fe, is Chairman and Chief Executive
Officer of the Trustee. The Trustee is Agent and a principal lender to Santa Fe
under a $195 million Revolving Credit/Term Loan Facility (the "TCB Credit
Facility"). As of January 31, 1994, approximately $58.7 million was outstanding
under the TCB Credit Facility. In the opinion of Santa Fe, the terms of the TCB
Credit Facility and the fees and interest rates thereunder are within the range
of normal and customary bank credit transactions involving energy borrowers of
similar size and credit.
DESCRIPTION OF THE DEPOSITARY UNITS
The following information is subject to the detailed provisions of the
Deposit Agreement, dated November 19, 1992, by and between Santa Fe, the
Trustee, Texas Commerce Bank National Association, as Depositary, and all
holders from time to time of SPERs (the "Deposit Agreement"). A copy of the
Deposit Agreement has been filed as an exhibit to the Registration Statement of
which this Prospectus is a part. The provisions governing the Depositary Units
and the Depositary are complex and extensive and no attempt has been made below
to describe all of such provisions. The following is a general description of
the basic framework of the Deposit Agreement, the Depositary Units and the
Depositary, and detailed provisions concerning such matters may be found in the
Deposit Agreement.
GENERAL
The functions of the Depositary and the Deposit Agreement are custodial and
ministerial in nature and for the benefit of Holders. The Deposit Agreement and
the issuance of SPERs thereunder provide Holders an administratively convenient
form of holding an investment in the Trust and a Treasury Obligation.
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A total of 6,300,000 Depositary Units are outstanding. Each Depositary Unit
is evidenced by a transferable SPER, which have been issued by the Depositary
only in denominations of 50 Depositary Units or integral multiples thereof.
Accordingly, each Holder of 50 Depositary Units will own a beneficial interest
in 50 Trust Units and the entire beneficial interest in a discrete Treasury
Obligation in a face amount of $1,000, or $20 per Depositary Unit. Upon receipt
of a properly executed Transfer Application, the Depositary will issue SPERs to
each purchaser of Depositary Units in the offering made hereby.
Purchasers may hold Depositary Units in nominee accounts, provided that the
broker (or other nominee) executes and delivers a Transfer Application. The
Depositary is entitled to treat the nominee holder of a Depositary Unit as the
absolute owner thereof and the beneficial owner's rights are limited solely to
those that it has against the nominee holder as a result of or by reason of any
understanding or agreement between such beneficial owner and nominee holder.
The deposited Trust Units and Treasury Obligations are held solely for the
benefit of the Holders and do not constitute assets of the Depositary or the
Trust. The Deposit Agreement provides that the Holders, as the beneficial owners
of direct interests in the underlying Trust Units and Treasury Obligations, have
substantially all rights and privileges of the Depositary as the registered
owner thereof and that the deposited Trust Units and Treasury Obligations are
not subject to any lien, claim, charge or security interest in favor of the
Depositary. The Depositary has no power to assign, transfer, pledge or otherwise
dispose of any of the Trust Units or Treasury Obligations, except as described
under "Description of the Trust and the Trust Agreement -- Possible Divestiture
of Depositary Units and Trust Units."
In the case of a default with respect to the obligations owed under a Trust
Unit or Treasury Obligation, the Holder beneficially owning such Trust Unit or
Treasury Obligation, as the real party in interest and as the owner of the
entire beneficial interest in one or more Trust Units or discrete Treasury
Obligations, has the right to proceed directly and individually against the
Trustee (in the case of a Trust Unit) or the United States of America (in the
case of a Treasury Obligation) to enforce the Holder's rights with respect to
such Trust Unit or Treasury Obligation, respectively, in any manner that such
Holder deems appropriate. In enforcing its rights, a Holder is not required to
act in concert with any other Holder, the Depositary or any other person.
Generally, the Depositary Units are entitled to participate in
distributions with respect to the Trust Units and such distributions with
respect to the Treasury Obligations and the liquidation of the remaining assets
of the Trust. The Depositary Units are listed for trading on the New York Stock
Exchange under the symbol "SFF."
TRANSFERS OF DEPOSITARY UNITS
Depositary Units are transferable in denominations of 50 (or integral
multiples thereof) on the records of the Depositary upon the surrender of any
SPER in proper form for transfer as required by the Depositary. The transfer of
Depositary Units to persons that purchase directly from the Underwriter will be
accomplished through the completion, execution and delivery of Transfer
Applications by such purchasers in connection with such purchases. Any
subsequent transfers of a Depositary Unit will not be recorded by the Depositary
unless the transferee executes and delivers a Transfer Application. By executing
and delivering a Transfer Application, the transferee of Depositary Units
becomes the record holder of such Depositary Units, becomes a party to the
Deposit Agreement, thereby assenting to all of its provisions, agrees to be
bound by the terms and conditions of the Trust Agreement and the SPER, agrees
that his transferor's duty to provide such transferee with any requisite
information necessary to obtain registration of the transfer of the Depositary
Units shall exclude any duty by the transferor to deliver an executed Transfer
Application, makes the consents and approvals and gives the waivers contained in
the Deposit Agreement and the Trust Agreement, and irrevocably appoints the
Depositary as such transferee's attorney-in-fact to take all actions on his
behalf in connection with the Deposit Agreement. Pursuant to the Transfer
Application, each Holder agrees to indemnify and hold the Depositary, the
Trustee and Santa Fe harmless from certain losses in connection with claims
related to transfer, inheritance or gift taxes as provided in the Deposit
Agreement. By executing the Transfer Application, each Holder also agrees not to
transfer the Depositary Units other than in denominations of 50 and integral
multiples thereof.
49
<PAGE> 50
A purchaser or transferee of Depositary Units who does not execute and
deliver a Transfer Application obtains only the right to assign the Depositary
Units to a purchaser or other transferee and will not receive Trust
distributions unless the Depositary Units are held in a nominee or street name
account and the nominee or broker has executed and delivered a Transfer
Application with respect to such Depositary Units, and may not receive certain
Federal income tax information or reports furnished to Holders of record.
Whether or not a transferee executes the Transfer Application, a transferee, by
acceptance of a SPER, is deemed to become a party to the Deposit Agreement and
to be bound by the terms and conditions of the Deposit Agreement, the Trust
Agreement and the SPER. The transferor of Depositary Units will have a duty to
provide such transferee with all information that may be necessary to obtain
registration of the transfer of the Depositary Units, but a transferee agrees,
by acceptance of the SPER, that the transferor will not have a duty to cause the
execution of the Transfer Application by the transferee.
No service charge will be made to the transferor or transferee for any
transfer of a Depositary Unit, but the Depositary may require payment of a sum
sufficient to cover any tax or other governmental charge that may be imposed in
connection with such transfer. Until any such transfer, the Depositary may treat
the owner of any SPER as shown by its records as the owner of the Depositary
Units evidenced thereby and shall not be charged with notice of any claim or
demand respecting such SPER or the interest represented thereby by any other
party. Any such transfer of a Depositary Unit shall, as to the Depositary,
transfer to the transferee as of the close of business on the date of transfer,
all right, title and interest of the transferor in and to the Trust Unit
relating to such Depositary Unit and the interest in the Treasury Obligation
evidenced by such Depositary Unit, provided that a transfer of a Depositary Unit
after any Quarterly Record Date shall not transfer to the transferee the right
of the transferor to the Quarterly Distribution Amount payable to holders of
record on such date. As to matters affecting the title, ownership, warranty or
transfer of the SPERs and the Depositary Units represented thereby, the laws
from time to time in force in the State of Texas with respect to the transfer of
securities shall govern.
Under the Deposit Agreement, in the event that Santa Fe causes to be
delivered to the Depositary (i) a letter from the staff of the Securities and
Exchange Commission to the effect that the staff will raise no objection under
the Investment Company Act of 1940 if the Depositary Units are transferred in
denominations other than 50 and integral multiples thereof, and (ii) a written
opinion of counsel to Santa Fe to the effect that the Depositary Units may be
transferred in denominations other than 50 and integral multiples thereof
without registration of the depositary arrangements relating to the deposited
Trust Units and Treasury Obligations as an investment company under the
Investment Company Act of 1940, then the Depositary may permit the transfer of
Depositary Units without regard to the current limitation on transfers to 50
Depositary Units (or integral multiples thereof). Santa Fe is not obligated to
request such a letter and opinion and no assurance can be given that such a
letter and opinion could be obtained if requested.
WITHDRAWAL OF TRUST UNITS AND TREASURY OBLIGATIONS
Upon the written request of a Holder for withdrawal of Trust Units and
Treasury Obligations evidenced by SPERs in denominations of 50 Depositary Units
or an integral multiple thereof from deposit and the surrender of such Holder's
SPER in compliance with the terms of the Deposit Agreement, the Holder
surrendering such Depositary Units will be entitled to receive the underlying
Trust Units and whole Treasury Obligations as described herein. Upon such notice
of withdrawal and surrender of the SPERs, the Depositary will give notice
thereof to the Trustee, who will provide written confirmation of the appropriate
entry made in the ownership ledger maintained for such purpose by the Trustee,
and will make appropriate notation of such Holder's direct ownership of the
discrete Treasury Obligation previously represented by the surrendered
Depositary Units. Trust Units are uncertificated securities and if withdrawn
from the Depositary are not transferable, except by operation of law; provided,
however, that any holder may transfer Trust Units (in denominations of 50 or
integral multiples thereof) to the Depositary for redeposit to the extent that
they are accompanied by evidence of the assignment of the Treasury Obligation in
a face amount of $20 per Trust Unit in the name of the Depositary. See
"Description of the Trust and the Trust Agreement -- Withdrawal of Trust Units
and Restrictions on Transfer." Upon such notice and withdrawal and written
transfer instructions, a Treasury Obligation in a face amount equal to $1,000
for every 50 Depositary Units presented for withdrawal
50
<PAGE> 51
will be delivered by wire transfer through the Treasury book-entry system to a
clearing agent, securities firm or other eligible nominee depository institution
designated by the withdrawing Holder. The withdrawing Holder would then be free
to sell or hold the Treasury Obligation in the same manner as other holders of
book-entry U. S. Treasury securities traded in the STRIPS program. Redeposit of
Trust Units and Treasury Obligations with the Depositary will require 60 days'
advance written notice (except for redeposits by Santa Fe, the Trust or their
affiliates, which will not require any prior notice) and may be subject to
certain other restrictions.
AMENDMENT AND TERMINATION OF THE DEPOSIT AGREEMENT
Amendment. Any provision of the Deposit Agreement, including the form of
SPER and Transfer Application, may at any time and from time to time be amended
by the Depositary and Santa Fe in any respect deemed necessary or desirable by
them, without approval by the Holders, if such amendment would not have a
material adverse affect on Holders or is required to comply with applicable law.
No amendment to the Deposit Agreement, however, may impair the right of a Holder
to surrender SPERs in denominations of 50 Depositary Units or integral multiples
thereof and withdraw the underlying Trust Units and Treasury Obligations, and no
amendment to the Deposit Agreement may override, conflict with or supersede the
provisions of the Trust Agreement. The Depositary will furnish notice to each
record holder of a SPER and any securities exchange on which the Depositary
Units are listed for trading at the time any material amendment of the Deposit
Agreement becomes effective. Each record holder will be deemed, by continuing to
hold such SPER after effectiveness of any amendment to the Deposit Agreement, to
consent and agree to such amendment and to be bound by the Deposit Agreement as
so amended.
The Depositary must give notice of the imposition of any fee or charge
(other than fees and charges provided for in the Deposit Agreement), or change
with respect thereto, upon Holders or transferees of Depositary Units to any
securities exchange on which Depositary Units are listed for trading and to all
record holders of Depositary Units. The imposition of such fee or charge, or
change with respect thereto, shall not be effective until the expiration of 90
days after the date of such notice, unless it earlier becomes effective in the
form of any amendment to the Deposit Agreement effected by the Depositary.
Termination. The Depositary shall terminate the Deposit Agreement upon the
later to occur of the termination and liquidation of the Trust and the
distribution of the proceeds from the matured, deposited Treasury Obligations.
DUTIES AND STATUS OF DEPOSITARY
Duties. The Depositary's only duties as Depositary are the essentially
ministerial ones set forth in the Deposit Agreement. The Depositary has no
discretionary functions and serves merely as a conduit for distributions and
communications to Holders. In addition to acting as a depositary for the Trust
Units and the Treasury Obligations, the Depositary acts as a registrar and
transfer agent for the Depositary Units. All fees charged by the Depositary for
transfers and withdrawals of Depositary Units or the Trust Units or Treasury
Obligations evidenced thereby will be borne by Santa Fe, except that fees
similar to those customarily paid by stockholders for surety bond premiums to
replace lost or stolen certificates, taxes or other governmental charges,
special charges for services requested by a Holder and other similar fees or
charges will be borne by the affected Holder. There is no charge to Holders for
disbursements of the Trust's cash distributions. The Trust Estate has agreed to
indemnify the Trustee with respect to certain matters to the extent Trust assets
are not available for such indemnity.
Resignation and Removal. The Depositary may at any time resign, by notice
to Santa Fe and the Holders, or be removed by Santa Fe or by a vote of holders
of a majority of the Depositary Units, such resignation or removal to become
effective upon the appointment by Santa Fe of a successor depositary and its
acceptance of such appointment. Any successor must be a bank or trust company
meeting certain requirements including having capital surplus and undivided
profits of at least $100,000,000.
Periodic Reports. The Depositary forwards to Holders tax information
prepared by Santa Fe concerning interest income, royalty income and depletion
and the Treasury Obligations on a periodic basis. Year-end tax
51
<PAGE> 52
information prepared by Santa Fe is furnished to Holders on a cash and accrual
basis not later than March 31 of the following year.
The Depositary is obligated, pursuant to the Deposit Agreement, to forward
to each Holder all communications received by the Depositary as the registered
owner of the Trust Units and Treasury Obligations deposited with it and to
notify Holders if it becomes aware of a default on the Trust Units or Treasury
Obligations. The Depositary is authorized to take action with respect to the
Trust Units and Treasury Obligations only upon instructions from Holders.
Inspection. Each Holder and his duly authorized agents and attorneys have
the right during reasonable business hours to examine and inspect records of the
Depositary.
UNDERWRITING
Lehman Brothers Inc. (the "Underwriter") has agreed, subject to the terms
and conditions set forth in an Underwriting Agreement, dated February 10, 1994
(the "Underwriting Agreement"), to purchase from Santa Fe all of the Depositary
Units offered hereby.
The Underwriting Agreement provides that the obligations of the Underwriter
to purchase the Depositary Units are subject to certain conditions and that, if
any of the Depositary Units are purchased by the Underwriter pursuant to the
Underwriting Agreement, all the Depositary Units agreed to be purchased by the
Underwriter pursuant to the Underwriting Agreement must be so purchased.
Santa Fe has been advised by the Underwriter that the Underwriter proposes
to offer the Depositary Units offered hereby initially at the public offering
price set forth on the cover page of this Prospectus and to certain selected
dealers at such public offering price less a concession not to exceed $0.55 per
Depositary Unit. After the initial public offering, the public offering price
and the concession to selected dealers may be changed by the Underwriter.
The Depositary Units are listed for trading on the New York Stock Exchange
under the symbol "SFF."
Santa Fe has agreed in the Underwriting Agreement to indemnify the
Underwriter against certain liabilities, including liabilities under the
Securities Act.
In May 1992, Lehman Brothers Inc. acted as financial advisor to Santa Fe in
connection with Santa Fe's merger with Adobe Resources Corporation, for which it
received customary fees.
In November 1992, Lehman Brothers Inc. acted as managing underwriter of the
initial public offering of Depositary Units for which it received customary
underwriting discounts. In connection with such offering, Santa Fe engaged an
affiliate of Lehman Brothers Inc. to purchase the Treasury Obligations on the
Depositary's behalf, for which it received customary brokerage fees and
commissions.
Lehman Brothers Inc. is acting as financial adviser to Santa Fe in
connection with various transactions for which it is entitled to receive
customary fees.
Lehman Brothers Inc. has from time to time acted as broker-dealer for Santa
Fe in commodities hedging transactions for which it received customary fees.
LEGAL MATTERS
The validity of the Depositary Units is being passed upon by Andrews &
Kurth L.L.P., 4200 Texas Commerce Tower, Houston, Texas 77002, as counsel for
Santa Fe. Certain legal matters will be passed upon for the Underwriter by
Simpson Thacher & Bartlett (a partnership which includes professional
corporations), 425 Lexington Avenue, New York, New York 10017.
52
<PAGE> 53
EXPERTS
Certain information appearing in this Prospectus regarding the estimated
quantities of reserves of the oil and gas properties owned by the Trust, the
future net revenues from such reserves and the present value thereof is based on
estimates of such reserves and present values prepared by Ryder Scott Company,
independent petroleum engineers.
The statements of revenues and direct operating expenses of the Royalty
Properties for each of the two years in the period ended December 31, 1991 and
for the period January 1, 1992 through October 22, 1992, and the statement of
assets and trust corpus as of December 31, 1992 and the related statement of
changes in trust corpus of the Santa Fe Energy Trust for the period from
Inception (October 22, 1992) to December 31, 1992 included in this Prospectus
have been so included in reliance on the reports of Price Waterhouse,
independent accountants, given on the authority of said firm as experts in
auditing and accounting. The financial statements incorporated in this
Prospectus by reference to the Annual Report on Form 10-K of Santa Fe Energy
Resources, Inc. for the year ended December 31, 1992, have been so incorporated
in reliance on the report of Price Waterhouse, independent accountants, given on
the authority of said firm as experts in auditing and accounting.
DEFINITIONS AND OTHER MATTERS
Gas volumes are stated herein at the legal pressure base of the state or
area in which the reserves are located at 60 degrees Fahrenheit. In addition, as
used herein, the following terms have the meanings indicated: "Mcf" means
thousand cubic feet, "MMcf" means million cubic feet, "Bcf" means billion cubic
feet, "Bbl" means barrel (approximately 42 U.S. gallons), "MBbl" means thousand
barrels, "Btu" means a British Thermal Unit, a common unit of energy
measurement, and "NEB" means net equivalent barrel of oil. For purposes of
calculating an NEB, gas equivalents are determined by using a ratio of six Mcf
of gas to one Bbl of oil. With respect to information regarding interests in
wells and acreage, "net" oil and gas wells or acres are determined by
multiplying "gross" oil and gas wells or acres by the interest in such wells or
acres represented by the Royalty Interests or owned by Santa Fe, as the case may
be. Unless otherwise indicated, information regarding proved reserves, related
estimated future net revenues and the discounted present value thereof is
derived from the Reserve Report.
53
<PAGE> 54
INDEX TO FINANCIAL STATEMENTS
<TABLE>
<S> <C>
ROYALTY PROPERTIES
Report of Independent Accountants.................................................. F-2
Statements of Revenues and Direct Operating Expenses for the Years Ended December
31, 1990 and 1991 and for the Period January 1, 1992 through October 22, 1992... F-3
Notes to Financial Statements...................................................... F-4
Supplemental Information to Financial Statements (Unaudited)....................... F-5
SANTA FE ENERGY TRUST
Report of Independent Accountants.................................................. F-7
Statement of Assets and Trust Corpus as of December 31, 1992....................... F-8
Statement of Changes in Trust Corpus for the Period from Inception (October 22,
1992) to December 31, 1992...................................................... F-9
Notes to Financial Statements...................................................... F-10
Supplemental Information to Financial Statements (Unaudited)....................... F-13
Statement of Cash Proceeds and Distributable Cash for the Three Months and Nine
Months ended September 30, 1993 (Unaudited)..................................... F-14
Statement of Assets, Liabilities and Trust Corpus at September 30, 1993 (Unaudited)
and December 31, 1992........................................................... F-14
Statement of Changes in Trust Corpus for the Nine Months Ended September 30, 1993
(Unaudited)..................................................................... F-15
Notes to Financial Statements (Unaudited).......................................... F-16
</TABLE>
F-1
<PAGE> 55
REPORT OF INDEPENDENT ACCOUNTANTS
To the Board of Directors and Shareholders of
Santa Fe Energy Resources, Inc.
We have audited the accompanying statements of revenues and direct
operating expenses of the Royalty Properties for each of the two years in the
period ended December 31, 1991 and for the period January 1, 1992 through
October 22, 1992. These financial statements are the responsibility of the
Company's management. Our responsibility is to express an opinion on these
financial statements based on our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by
management, as well as evaluating the overall presentation of the financial
statements. We believe that our audits provide a reasonable basis for our
opinion.
The accompanying statements of revenues and direct operating expenses
reflect the revenues and direct operating expenses attributable to the Royalty
Properties as described in Note 2 and are not intended to be a complete
presentation of the revenues and expenses of the Royalty Properties.
In our opinion, such statements present fairly, in all material respects,
the revenues and direct operating expenses described in Note 2 of the Royalty
Properties for each of the two years in the period ended December 31, 1991 and
for the period January 1, 1992 through October 22, 1992 in conformity with
generally accepted accounting principles.
PRICE WATERHOUSE
Houston, Texas
November 8, 1993
F-2
<PAGE> 56
ROYALTY PROPERTIES
STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
(DOLLARS IN THOUSANDS)
<TABLE>
<CAPTION>
JANUARY
1, 1992
YEAR ENDED DECEMBER 31, THROUGH
------------------------------------------------------------------------------------------- OCTOBER
22,
1990 1991 1992
------------------------------------------- ------------------------------------------- -------
NET NET
WASSON WASSON PROFITS WASSON WASSON PROFITS WASSON
ODC WILLARD PROPERTIES TOTAL ODC WILLARD PROPERTIES TOTAL ODC
------- ------- ------- ------- ------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C> <C> <C> <C> <C>
Revenues
Oil.............. $15,013 $ 2,545 $ 9,736 $27,294 $11,623 $ 2,196 $ 8,293 $22,112 $ 9,571
Gas.............. -- -- 8,329 8,329 -- -- 7,671 7,671 --
------- ------- ------- ------- ------- ------- ------- ------- -------
Total.......... 15,013 2,545 18,065 35,623 11,623 2,196 15,964 29,783 9,571
------- ------- ------- ------- ------- ------- ------- ------- -------
Direct Operating
Expenses
Taxes on
production
and property... 1,177 225 1,140 2,542 1,392 341 1,034 2,767 1,177
Production
and other
expenses....... -- -- 2,582 2,582 -- -- 2,398 2,398 --
------- ------- ------- ------- ------- ------- ------- ------- -------
Total.............. 1,177 225 3,722 5,124 1,392 341 3,432 5,165 1,177
------- ------- ------- ------- ------- ------- ------- ------- -------
Excess of Revenues
over Direct
Operating
Expenses......... $13,836 $ 2,320 $14,343 $30,499 $10,231 $ 1,855 $12,532 $24,618 $ 8,394
------- ------- ------- ------- ------- ------- ------- ------- -------
------- ------- ------- ------- ------- ------- ------- ------- -------
<CAPTION>
NET
WASSON PROFITS
WILLARD PROPERTIES TOTAL
------- ------- -------
<S> <C<C> <C> <C>
Revenues
Oil.............. $ 1,979 $ 6,306 $17,856
Gas.............. -- 5,157 5,157
------- ------- -------
Total.......... 1,979 11,463 23,013
------- ------- -------
Direct Operating
Expenses
Taxes on
production
and property... 339 858 2,374
Production
and other
expenses....... -- 2,056 2,056
------- ------- -------
Total.............. 339 2,914 4,430
------- ------- -------
Excess of Revenues
over Direct
Operating
Expenses......... $ 1,640 $ 8,549 $18,583
------- ------- -------
------- ------- -------
</TABLE>
The accompanying notes are an integral part of these financial statements.
F-3
<PAGE> 57
ROYALTY PROPERTIES
NOTES TO FINANCIAL STATEMENTS
NOTE 1. ROYALTY PROPERTIES
The Royalty Properties consist of royalty interests and working interests
in the following domestic oil and gas properties owned by Santa Fe Energy
Resources, Inc. ("Santa Fe"):
- Royalty interests in oil production of two units of the Wasson oil field,
Wasson ODC and Wasson Willard, located in the Permian Basin of West Texas
(collectively, the "Wasson Properties").
- Royalty interests and working interests in producing oil and gas
properties located in twelve states (collectively, the "Net Profits
Properties").
Santa Fe has produced from the Wasson field since 1939. The Wasson field
has been significantly redeveloped for tertiary recovery operations utilizing
CO2 flooding, which commenced in 1984. The Net Profits Properties consist
principally of properties acquired by Santa Fe in May 1992 as a result of its
merger with Adobe Resources Corporation. The accompanying statements include the
historical revenues and direct operating expenses from such acquired properties
for all periods presented. Revenues related to the acquired Adobe properties
approximate $15,000,000 for each of the two years in the period ended December
31, 1991 and approximately $10,000,000 for the period January 1, 1992 through
October 22, 1992.
Santa Fe Energy Products, a wholly owned subsidiary of Santa Fe, purchased
all of Santa Fe's share of Wasson ODC and Wasson Willard's oil production at the
average of prices posted by unaffiliated purchasers.
NOTE 2. BASIS OF PRESENTATION
The statements of revenues and direct operating expenses were derived from
the historical accounting records of Santa Fe (accrual basis, successful efforts
method of accounting for oil and gas activities, in accordance with generally
accepted accounting principles). The statements include the oil and gas revenues
and expenses directly attributable to the producing properties described above.
The statements do not include depreciation, depletion and amortization, general
and administrative or interest expenses.
Full financial statements, including historical balance sheets, have not
been prepared since many of the Royalty Properties were owned by others prior to
their acquisition by Santa Fe and, therefore, all of the historical information
necessary to prepare such financial statements is not available to Santa Fe.
Further, in management's opinion, the historical statements are not relevant
since the Royalty Interests will be valued by the Trust in accordance with
purchase accounting.
Royalty income of the Trust will be derived from the Wasson ODC Royalty,
Wasson Willard Royalty and the Net Profits Royalties, as defined. Royalty income
will be determined based on the defined royalties in the Wasson Properties and
the defined net profits interests in the Net Profits Properties. The computation
of the defined net profits will include deductions for capital development
expenditures on the working interests. Exploration and development expenditures
related to the Royalty Properties totaled approximately $2,335,000, $1,266,000
and $424,000 in 1990, 1991 and for the period January 1, 1992 through October
22, 1992, respectively. Accordingly, royalty income of the Trust will be
materially different than the excess of revenues over direct operating expenses
of the Royalty Properties.
F-4
<PAGE> 58
SUPPLEMENTAL INFORMATION TO FINANCIAL STATEMENTS
(UNAUDITED)
Information with respect to oil and gas producing activities of the Royalty
Properties is presented in the following tables. Reserve information for 1990
and 1991 with regard to the Wasson Royalties is based on reserve reports
prepared by Ryder Scott Company, independent petroleum consultants. For the Net
Profits Royalties, however, no separate engineering data exists prior to June
30, 1992. For these properties, Santa Fe computed year-end 1990 and 1991
information by adjusting Ryder Scott's June 30, 1992 reserve report for
production, prices and known additions. Reserve information for 1992 for the
Wasson Royalties and the Net Profits Royalties is based on reserve reports
prepared by Ryder Scott Company as of December 31, 1992. Santa Fe computed
October 22, 1992 information by adjusting Ryder Scott's December 31, 1992
reserve report for production, prices and other changes.
OIL AND GAS RESERVES
The following table sets forth the Royalty Properties' proved oil and gas
reserves (all located in the United States) at December 31, 1990 and 1991 and
October 22, 1992 and the related changes in such reserves for the years ended
December 31, 1990 and 1991 and for the period January 1, 1992 through October
22, 1992.
<TABLE>
<CAPTION>
CRUDE OIL (MBBLS) NATURAL GAS (MMCF)
-------------------------- --------------------------
1990 1991 1992 1990 1991 1992
------ ------ ------ ------ ------ ------
<S> <C> <C> <C> <C> <C> <C>
Proved reserves at beginning of period... 13,225 11,981 12,074 32,759 28,881 25,326
Increases (decreases) due to:
Revisions of previous estimates........ 9 680 1,115 -- -- (472)
Improved recovery techniques........... -- 562 -- -- -- --
Extensions, discoveries and other
additions........................... 69 118 -- 1,059 1,340 --
Production............................. (1,322) (1,267) (1,057) (4,937) (4,895) (3,441)
------ ------ ------ ------ ------ ------
Proved reserves at end of period......... 11,981 12,074 12,132 28,881 25,326 21,413
------ ------ ------ ------ ------ ------
------ ------ ------ ------ ------ ------
Proved developed reserves at end of
period................................. 11,058 11,165 11,221 28,560 25,044 21,158
------ ------ ------ ------ ------ ------
------ ------ ------ ------ ------ ------
</TABLE>
Proved developed reserves at December 31, 1989 were 12,302 MBbls of crude
oil and 32,396 MMcf of natural gas.
Proved reserves are estimated quantities of crude oil and natural gas which
geological and engineering data indicate with reasonable certainty to be
recoverable in future years from known reservoirs under existing economic and
operating conditions. Proved developed reserves are proved reserves which are
expected to be recovered through existing wells with existing equipment and
operating methods.
ESTIMATED PRESENT VALUE OF FUTURE NET CASH FLOWS
Estimated future net cash flows from the Royalty Properties proved oil and
gas reserves at December 31, 1990 and 1991 and October 22, 1992 are presented in
the following table (in thousands of dollars):
<TABLE>
<CAPTION>
1990 1991 1992
--------- -------- --------
<S> <C> <C> <C>
Future cash inflows................................. $ 365,647 $241,381 $261,974
Future costs and expenses........................... (44,381) (33,325) (37,972)
--------- -------- --------
Net future cash flows............................... 321,266 208,056 224,002
Discount at 10% for timing of cash flows............ (125,413) (85,794) (95,481)
--------- -------- --------
Present value of future net cash flows for proved
reserves.......................................... $ 195,853 $122,262 $128,521
--------- -------- --------
--------- -------- --------
</TABLE>
Estimated future cash flows represent an estimate of future net revenues
from the production of proved reserves using estimated sales prices and
estimates of the production costs, ad valorem and production taxes,
F-5
<PAGE> 59
SUPPLEMENTAL INFORMATION TO FINANCIAL STATEMENTS -- (CONTINUED)
(UNAUDITED)
and future development costs necessary to produce such reserves. No deduction
has been made for depletion, depreciation or any indirect costs such as general
corporate overhead or interest expense.
The sales prices used in the calculation of estimated future net cash flows
are based on the prices in effect at the end of the period. Such prices have
been held constant except for known and determinable escalations.
Operating costs and ad valorem and production taxes are estimated based on
current costs with respect to producing oil and gas properties. Future
development costs are based on the best estimate of such costs assuming current
economic and operating conditions.
The following table sets forth the changes in the present value of
estimated future net cash flows from proved reserves during the years ended
December 31, 1990 and 1991 and for the period January 1, 1992 through October
22, 1992 (in thousands of dollars):
<TABLE>
<CAPTION>
1990 1991 1992
-------- -------- --------
<S> <C> <C> <C>
Balance at beginning of period....................... $155,940 $195,853 $122,262
-------- -------- --------
Increase (decrease) due to:
Sales of oil and gas, net of production costs of
$5,124 in 1990, $5,165 in 1991 and $4,430 in
1992............................................ (30,499) (24,618) (18,583)
Net changes in prices and costs.................... 53,095 (93,912) 7,444
Extensions, discoveries and improved recovery...... 1,748 8,937 --
Changes in estimated volumes....................... 9 16,340 7,210
Interest factor -- accretion of discount........... 15,560 19,662 10,188
-------- -------- --------
39,913 (73,591) 6,259
-------- -------- --------
Balance at end of period............................. $195,853 $122,262 $128,521
-------- -------- --------
-------- -------- --------
</TABLE>
The information presented with respect to estimated future net revenues and
cash flows and the present value thereof is not intended to represent the fair
value of oil and gas reserves. Actual future sales prices and production and
development costs may vary significantly from those in effect at the end of the
period and actual future production may not occur in the periods or amounts
projected. This information is presented to allow a reasonable comparison of
reserve values prepared using standardized measurement criteria and should be
used only for that purpose.
F-6
<PAGE> 60
REPORT OF INDEPENDENT ACCOUNTANTS
To the Unitholders and Trustee
of the Santa Fe Energy Trust
We have audited the statement of assets and trust corpus as of December 31,
1992 and the related statement of changes in trust corpus for the period from
Inception (October 22, 1992) to December 31, 1992. These financial statements
are the responsibility of the Trustee. Our responsibility is to express an
opinion on these financial statements based on our audit.
We conducted our audit in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material
misstatement. An audit includes examining, on a test basis, evidence supporting
the amounts and disclosures in the financial statements. An audit also includes
assessing the accounting principles used and significant estimates made by the
Trustee, as well as evaluating the overall financial statement presentation. We
believe that our audit provides a reasonable basis for our opinion.
As described in Note 2, these financial statements have been prepared on
the basis of cash receipts and disbursements, which is a comprehensive basis of
accounting other than generally accepted accounting principles.
In our opinion such statements audited by us present fairly, in all
material respects, the financial position of the Santa Fe Energy Trust at
December 31, 1992 and the changes in trust corpus for the period from inception
(October 22, 1992) to December 31, 1992, on the basis of accounting described in
Note 2.
PRICE WATERHOUSE
Houston, Texas
March 26, 1993
F-7
<PAGE> 61
SANTA FE ENERGY TRUST
STATEMENT OF ASSETS AND TRUST CORPUS
DECEMBER 31, 1992
(IN THOUSANDS OF DOLLARS)
ASSETS
<TABLE>
<S> <C>
Current Assets..................................................................... $ 1
Cash............................................................................. 87,276
-------
Investment in Royalty Interests, at cost......................................... $87,277
-------
-------
TRUST CORPUS
Trust Corpus (6,300,000 Trust Units issued and outstanding)........................ $87,277
-------
-------
</TABLE>
The accompanying notes are an integral part of these financial statements.
F-8
<PAGE> 62
SANTA FE ENERGY TRUST
STATEMENT OF CHANGES IN TRUST CORPUS
FOR THE PERIOD FROM INCEPTION (OCTOBER 22, 1992) TO DECEMBER 31, 1992
(IN THOUSANDS OF DOLLARS)
<TABLE>
<S> <C>
Balance at Inception (October 22, 1992)............................................ $ 1
Issuance of Trust Units for Royalty Interests...................................... 87,276
-------
Balance at December 31, 1992....................................................... $87,277
-------
-------
</TABLE>
The accompanying notes are an integral part of these financial statements.
F-9
<PAGE> 63
SANTA FE ENERGY TRUST
NOTES TO FINANCIAL STATEMENTS
(1) THE TRUST
Santa Fe Energy Trust (the "Trust") was formed on October 22, 1992, with
Texas Commerce Bank National Association as trustee (the "Trustee"), to acquire
and hold certain royalty interests (the "Royalty Interests") in certain
properties (the "Royalty Properties") conveyed to the Trust by Santa Fe Energy
Resources, Inc. ("Santa Fe"). The Royalty Interests consist of two term royalty
interests in two production units in the Wasson field in west Texas (the "Wasson
Royalties") and a net profits royalty interest in certain royalty and working
interests in a diversified portfolio of properties located in twelve states (the
"Net Profits Royalties"). The Royalty Interests are passive in nature and the
Trustee has no control over or responsibility relating to the operation of the
Royalty Properties. The Trust will be liquidated on February 15, 2008 (the
"Liquidation Date").
In November 1992, 5,725,000 Depositary Units, each consisting of beneficial
ownership of one unit of undivided beneficial interest in the Trust ("Trust
Units") and a $20 face amount beneficial ownership interest in a $1,000 face
amount zero coupon United States Treasury obligation maturing on or about
February 15, 2008, were sold in a public offering for $20 per Depositary Unit. A
total of $114.5 million was received from public investors, of which $38.7
million was used to purchase the Treasury obligations and $5.7 million was used
to pay underwriting commissions and discounts. Santa Fe received the remaining
$70.1 million and 575,000 Depositary Units.
The trust agreement under which the Trust was formed (the "Trust
Agreement") provides, among other things, that:
- the Trustee shall not engage in any business or commercial activity or
acquire any asset other than the Royalty Interests initially conveyed to
the Trust;
- the Trustee may not sell all or any portion of the Wasson Royalties or
substantially all of the Net Profits Royalties without the prior consent
of Santa Fe;
- Santa Fe may sell the Royalty Properties, subject to and burdened by the
Royalty Interests, without consent of the holders of the Trust Units;
following any such transfer, the Royalty Properties will continue to be
burdened by the Royalty Interests and after any such transfer the royalty
payment attributable to the transferred property will be calculated
separately and paid by the transferee:
- the Trustee may establish a cash reserve for the 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 the holders of the Trust Units;
- the Trustee will make quarterly cash distributions to the holders of the
Trust Units.
(2) BASIS OF ACCOUNTING
The financial statements of the Trust are prepared on the cash basis of
accounting for revenues and expenses. Royalty income will be recorded when
received (generally during the quarter following the end of the quarter in which
the income from the Royalty Properties is received by Santa Fe) and will be net
of any cash basis exploration and development expenditures. Expenses of the
Trust, which will include accounting, engineering, legal, and other professional
fees, Trustee fees, an administrative fee paid to Santa Fe and out-of-pocket
expenses, will be recognized when paid. Under generally accepted accounting
principles, revenues and expenses would be recognized on an accrual basis.
Amortization of the Trust's investment in Royalty Interests will be recorded
using the unit-of-production method in the period in which the cash is received
with respect to such production. No royalty income was received and no Trust
expenses were paid during the period from inception (October 22, 1992) through
December 31, 1992 (see Note 4).
F-10
<PAGE> 64
SANTA FE ENERGY TRUST
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
The conveyance of the Royalty Interests to the Trust was accounted for as a
purchase transaction. The $87,276,000 reflected in the Statement of Assets and
Trust Corpus as Investment in Royalty Interests represents 6,300,000 Trust Units
valued at $20 per unit less the $38,724,000 paid for the Treasury obligations.
The carrying value of the Trust's investment in the Royalty Interests is not
necessarily indicative of the fair value of such Royalty Interests.
The Trust is a grantor trust and as such is not subject to income taxes and
accordingly no recognition has been given to income taxes in the Trust's
financial statements. The tax consequences of owning Trust Units are included in
the income tax returns of the individual Trust Unitholders.
(3) THE ROYALTY INTERESTS
The Wasson Royalties consist of interests conveyed out of Santa Fe's
royalty interest in the Wasson ODC Unit (the "ODC Royalty") and the Wasson
Willard Unit (the "Willard Royalty"). The ODC Royalty entitles the Trust to
receive quarterly royalty payments with respect to 12.3934% of the actual gross
oil production from the Wasson ODC Unit, subject to certain quarterly
limitations set forth in the conveyance agreement, for the period from November
1, 1992 to December 31, 2007. The Willard Royalty entitles the Trust to receive
quarterly royalty payments with respect to 6.83548% of the actual gross oil
production from the Wasson Willard Unit, subject to certain quarterly
limitations set forth in the conveyance agreement, for the period from November
1, 1992 to December 31, 2003.
The Net Profits Royalties entitle the Trust to receive, on a quarterly
basis, 90% of the net proceeds, as defined in the conveyance agreement, from the
sale of production from the properties subject to the conveyance agreement. The
Net Profits Royalties are not limited in term, although the Trustee is required
to sell such royalties prior to the Liquidation Date.
For any calendar quarter ending on or prior to December 31, 2002, the Trust
will receive additional royalty payments to the extent it needs such payments to
distribute $0.40 per Trust Unit per quarter (two-thirds of such amount for the
period ending December 31, 1992). Such additional royalty payments are limited
to Santa Fe's remaining royalty interest in the Wasson ODC Unit. If such
additional payments are received, certain proceeds otherwise payable to the
Trust in subsequent quarters may be reduced to recoup the amount of such
additional payments. The aggregate of the additional royalty payments, net of
any amounts recouped, will be limited to $20,000,000 on a revolving basis.
(4) DISTRIBUTIONS TO TRUST UNITHOLDERS
In February 1993 the Trust received royalty payments with respect to the
period ended December 31, 1992 totalling $1,937,000 and on February 26, 1992
made a distribution of $0.30753 per Trust Unit to holders of record on February
16, 1993.
(5) PRO FORMA FINANCIAL INFORMATION -- (UNAUDITED)
The following unaudited pro forma financial information has been prepared
assuming the Trust was formed and the Royalty Interests were conveyed on January
1, 1991. Royalty income with respect to the Wasson Royalties has been calculated
assuming the quarterly limitations with respect to such royalties commence with
the limits applicable to the period ended December 31, 1992. Trust
administrative expenses are estimated to be $450,000 annually, including legal,
accounting, engineering, trustee and other administra-
F-11
<PAGE> 65
SANTA FE ENERGY TRUST
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
tive fees of $250,000 and $200,000 to reimburse Santa Fe for overhead expenses.
The information presented herein is not necessarily indicative of the future
distributable income or financial condition of the Trust.
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER
31,
--------------------
1992 1991
------- -------
(AMOUNTS IN
THOUSANDS,
EXCEPT AS NOTED)
(UNAUDITED)
<S> <C> <C>
Distributable Income
Royalty Income
ODC Royalty........................................................ $ 3,202 $ 2,210
Willard Royalty.................................................... 1,930 1,827
Net Profits Royalties.............................................. 8,282 10,665
Trust Administrative Expenses......................................... (450) (450)
------- -------
Distributable Income.................................................. $12,964 $14,252
------- -------
------- -------
Distributable Income per Trust Unit (in dollars)...................... $ 2.06 $ 2.26
------- -------
------- -------
Trust Units Outstanding............................................... 6,300 6,300
------- -------
------- -------
Changes in Trust Corpus
Balance at Beginning of Year.......................................... $78,967 $87,277
Distributable Income.................................................. 12,964 14,252
Distributions to Trust Unitholders.................................... (12,964) (14,252)
Amortization of Royalty Interests..................................... (7,245) (8,310)
------- -------
Balance at End of Year................................................ $71,722 $78,967
------- -------
------- -------
</TABLE>
F-12
<PAGE> 66
SUPPLEMENTAL INFORMATION TO FINANCIAL STATEMENTS
(UNAUDITED)
OIL AND GAS RESERVES
The following table sets forth the Royalty Interests' proved oil and gas
reserves (all located in the United States) at December 31, 1992 prepared by
Ryder Scott Company, independent petroleum consultants. Proved reserve
quantities for each of the Wasson Royalties are calculated by multiplying the
net revenue interest attributable to each of the Wasson Royalties in effect for
a given year by the total amount of oil estimated to be economically recoverable
from the respective production units (subject to limitation by applicable
maximum quarterly production amounts). Reserve quantities are calculated
differently for the Net Profits Royalties because such interests do not entitle
the Trust to a specific quantity of oil or gas but to the Net Proceeds derived
therefrom. Proved reserves attributable to the Net Profits Royalties are
calculated by deducting from estimated quantities of oil and gas reserves an
amount of oil and gas sufficient, if sold at the prices used in preparing the
reserve estimates for the Net Profits Royalties, to pay the future estimated
costs and expenses deducted in the calculation of Net Proceeds with respect to
the Net Profits Royalties. Accordingly, the reserves presented for the Net
Profits Royalties reflect quantities of oil and gas that are free of future
costs or expenses if the price and cost assumptions set forth in the applicable
reserve report occur.
<TABLE>
<CAPTION>
CRUDE
OIL
AND NATURAL
LIQUIDS GAS
(MBBLS) (MMCF)
----- ------
<S> <C> <C>
Proved reserves................................................... 7,258 12,638
----- ------
----- ------
Proved developed reserves......................................... 7,169 12,500
----- ------
----- ------
</TABLE>
Proved reserves are estimated quantities of crude oil and natural gas which
geological and engineering data indicate with reasonable certainty to be
recoverable in future years from known reservoirs under existing economic and
operating conditions. Proved developed reserves are proved reserves which can be
expected to be recovered through existing wells with existing equipment and
operating methods.
ESTIMATED PRESENT VALUE OF FUTURE NET CASH FLOWS
Estimated future net cash flows from the Royalty Interests' proved oil and
gas reserves at December 31, 1992 are presented in the following table (in
thousands of dollars):
<TABLE>
<S> <C>
Net future cash flows...................................................... 138,005
Discount at 10% for timing of cash flows................................... (59,503)
-------
Present value of future net cash flows for proved reserves................. 78,502
-------
-------
</TABLE>
Estimated future cash flows represent an estimate of future net revenues
from the production of proved reserves using estimated sales prices and
estimates of the production costs, ad valorem and production taxes, and future
development costs necessary to produce such reserves. No deduction has been made
for depletion, depreciation or any indirect costs such as professional and
administrative fees.
The sales prices used in the calculation of estimated future net cash flows
are based on the prices in effect at year end. Such prices have been held
constant except for known and determinable escalations.
Operating costs and ad valorem and production taxes are estimated based on
current costs with respect to producing oil and gas properties. Future
development costs are based on the best estimate of such costs assuming current
economic and operating conditions.
The information presented with respect to estimated future net revenues and
cash flows and the present value thereof is not intended to represent the fair
value of oil and gas reserves. Actual future sales prices and production and
development costs may vary significantly from those in effect at December 31,
1992 and actual future production may not occur in the periods or amounts
projected. This information is presented to allow a reasonable comparison of
reserve values prepared using standardized measurement criteria and should be
used only for that purpose.
F-13
<PAGE> 67
SANTA FE ENERGY TRUST
STATEMENT OF CASH PROCEEDS AND DISTRIBUTABLE CASH
(UNAUDITED)
(DOLLARS IN THOUSANDS, EXCEPT AS NOTED)
<TABLE>
<CAPTION>
THREE NINE
MONTHS MONTHS
ENDED ENDED
SEPTEMBER 30, SEPTEMBER 30,
1993 1993
------------- -------------
<S> <C> <C>
Royalty Income
ODC Royalty................................................ $ 693 $ 1,539
Willard Royalty............................................ 590 1,588
Net Profits Royalty........................................ 2,290 5,895
Property Taxes............................................... (232) (596)
Administrative Fee to Santa Fe............................... (50) (133)
Trust Formation Costs........................................ (98) (173)
------------- -------------
Cash Proceeds................................................ 3,193 8,120
Advance from Santa Fe Energy Resources, Inc.................. 25 25
Cash Withheld for Trust Expenses............................. (100) (150)
------------- -------------
Distributable Cash........................................... $ 3,118 $ 7,995
------------- -------------
------------- -------------
Distributable Cash per Trust Unit (in dollars)............... $ 0.49485 $ 1.26904
------------- -------------
------------- -------------
Trust Units Outstanding (thousands).......................... 6,300 6,300
------------- -------------
------------- -------------
</TABLE>
STATEMENT OF ASSETS, LIABILITIES AND TRUST CORPUS
(DOLLARS IN THOUSANDS)
ASSETS
<TABLE>
<CAPTION>
SEPTEMBER 30, DECEMBER 31,
1993 1992
------------- ------------
(UNAUDITED)
<S> <C> <C>
Current Assets
Cash......................................................... $ 10 $ 1
------------- ------------
Investment in Royalty Interests, at cost....................... 87,276 87,276
Less: Accumulated Amortization................................. (7,127) --
------------- ------------
80,149 87,276
------------- ------------
$80,159 $ 87,277
------------- ------------
------------- ------------
LIABILITIES AND TRUST CORPUS
Advance from Santa Fe Energy Resources, Inc.................... $ 25 $ --
Trust Corpus (6,300,000 Trust Units issued and outstanding).... 80,134 87,277
------------- ------------
$80,159 $ 87,277
------------- ------------
------------- ------------
</TABLE>
The accompanying notes are an integral part of these financial statements.
F-14
<PAGE> 68
SANTA FE ENERGY TRUST
STATEMENT OF CHANGES IN TRUST CORPUS
(UNAUDITED)
(DOLLARS IN THOUSANDS)
<TABLE>
<S> <C>
Balance at December 31, 1992....................................................... $87,277
Cash Proceeds...................................................................... 1,937
Amortization of Royalty Interests.................................................. (1,702)
Cash Distributions................................................................. (1,937)
-------
Balance at March 31, 1993.......................................................... 85,575
Cash Proceeds...................................................................... 2,990
Amortization of Royalty Interests.................................................. (2,677)
Cash Distributions................................................................. (2,940)
Trust Expenses..................................................................... (39)
-------
Balance at June 30, 1993........................................................... 82,909
Cash Proceeds...................................................................... 3,193
Amortization of Royalty Interests.................................................. (2,748)
Cash Distributions................................................................. (3,118)
Trust Expenses..................................................................... (102)
-------
Balance at September 30, 1993...................................................... $80,134
-------
-------
</TABLE>
The accompanying notes are an integral part of these financial statements.
F-15
<PAGE> 69
SANTA FE ENERGY TRUST
NOTES TO FINANCIAL STATEMENTS
(1) THE TRUST
Santa Fe Energy Trust (the "Trust") was formed on October 22, 1992, with
Texas Commerce Bank National Association as trustee (the "Trustee"), to acquire
and hold certain royalty interests (the "Royalty Interests") in certain
properties (the "Royalty Properties") conveyed to the Trust by Santa Fe Energy
Resources, Inc. ("Santa Fe"). The Royalty Interests consist of two term royalty
interests in two production units in the Wasson field in West Texas (the "Wasson
Royalties") and a net profits royalty interest in certain royalty and working
interests in a diversified portfolio of properties located in twelve states (the
"Net Profits Royalties"). The Royalty Interests are passive in nature and the
Trustee has no control over or responsibility relating to the operation of the
Royalty Properties. The Trust will be liquidated on February 15, 2008 (the
"Liquidation Date").
In November 1992, 5,725,000 Depositary Units, each consisting of beneficial
ownership of one unit of undivided beneficial interest in the Trust ("Trust
Units") and a $20 face amount beneficial ownership interest in a $1,000 face
amount zero coupon United States Treasury obligation maturing on or about
February 15, 2008, were sold in a public offering for $20 per Depositary Unit. A
total of $114.5 million was received from public investors, of which $38.7
million was used to purchase the Treasury obligations and $5.7 million was used
to pay underwriting commissions and discounts. Santa Fe received the remaining
$70.1 million and 575,000 Depositary Units.
The trust agreement under which the Trust was formed (the "Trust
Agreement") provides, among other things, that:
- the Trustee shall not engage in any business or commercial activity or
acquire any asset other than the Royalty Interests initially conveyed to
the Trust;
- the Trustee may not sell all or any portion of the Wasson Royalties or
substantially all of the Net Profits Royalties without the prior consent
of Santa Fe;
- Santa Fe may sell the Royalty Properties, subject to and burdened by the
Royalty Interests, without consent of the holders of the Trust Units;
following any such transfer, the Royalty Properties will continue to be
burdened by the Royalty Interests and after any such transfer the royalty
payment attributable to the transferred property will be calculated
separately and paid by the transferee;
- the Trustee may establish a cash reserve for the 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 the holders of the Trust Units;
- the Trustee will make quarterly cash distributions to the holders of the
Trust Units.
(2) BASIS OF ACCOUNTING
The accompanying unaudited financial information has been prepared by the
Trustee in accordance with the instructions to Form 10-Q and does not include
all of the information required by generally accepted accounting principles for
complete financial statements, although the Trustee believes that the
disclosures are adequate to make the information presented not misleading. 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 financial information should be read in conjunction with
the financial statements and notes thereto included in the Trust's Annual Report
on Form 10-K for the year ended December 31, 1992.
The financial statements of the Trust are prepared on the cash basis of
accounting for revenues and expenses. Royalty income will be recorded when
received (generally during the quarter following the end of the quarter in which
the income from the Royalty Properties is received by Santa Fe) and will be net
of any cash basis exploration and development expenditures. Expenses of the
Trust, which will include accounting,
F-16
<PAGE> 70
SANTA FE ENERGY TRUST
NOTES TO FINANCIAL STATEMENTS -- (CONTINUED)
engineering, legal, and other professional fees, Trustee fees, an administrative
fee paid to Santa Fe and out-of-pocket expenses, will be recognized when paid.
Under generally accepted accounting principles, revenues and expenses would be
recognized on an accrual basis. Amortization of the Trust's investment in
Royalty Interests will be recorded using the unit-of-production method in the
period in which the cash is received with respect to such production.
The conveyance of the Royalty Interests to the Trust was accounted for as a
purchase transaction. The $87,276,000 reflected in the Statement of Assets and
Trust Corpus as Investment in Royalty Interests represents 6,300,000 Trust Units
valued at $20 per unit less the $38,724,000 paid for the Treasury obligations.
The carrying value of the Trust's investment in the Royalty Interests is not
necessarily indicative of the fair value of such Royalty Interests.
The Trust is a grantor trust and as such is not subject to income taxes and
accordingly no recognition has been given to income taxes in the Trust's
financial statements. The tax consequences of owning Trust Units are included in
the income tax returns of the individual Trust Unitholders.
(3) THE ROYALTY INTERESTS
The Wasson Royalties consist of interests conveyed out of Santa Fe's
royalty interest in the Wasson ODC Unit (the "ODC Royalty") and the Wasson
Willard Unit (the "Willard Royalty"). The ODC Royalty entitles the Trust to
receive quarterly royalty payments with respect to 12.3934% of the actual gross
oil production from the Wasson ODC Unit, subject to certain quarterly
limitations set forth in the conveyance agreement, for the period from November
1, 1992 to December 31, 2007. The Willard Royalty entitles the Trust to receive
quarterly royalty payments with respect to 6.83548% of the actual gross oil
production from the Wasson Willard Unit, subject to certain quarterly
limitations set forth in the conveyance agreement, for the period from November
1, 1992 to December 31, 2003.
The Net Profits Royalties entitle the Trust to receive, on a quarterly
basis, 90% of the net proceeds, as defined in the conveyance agreement, from the
sale of production from the properties subject to the conveyance agreement. The
Net Profits Royalties are not limited in term, although the Trustee is required
to sell such royalties prior to the Liquidation Date.
For any calendar quarter ending on or prior to December 31, 2002, the Trust
will receive additional royalty payments to the extent it needs such payments to
distribute $0.40 per Trust Unit per quarter (two-thirds of such amount for the
period ended December 31, 1992). Such additional royalty payments are limited to
Santa Fe's remaining royalty interest in the Wasson ODC Unit. If such additional
payments are received, certain proceeds otherwise payable to the Trust in
subsequent quarters may be reduced to recoup the amount of such additional
payments. The aggregate of the additional royalty payments, net of any amounts
recouped, will be limited to $20,000,000 on a revolving basis.
(4) DISTRIBUTIONS TO TRUST UNIT HOLDERS
In February 1993 the Trust received payments with respect to the two-month
period ended December 31, 1992 totalling $1,937,000 and on February 26, 1993
made a distribution of $0.30753 per Trust Unit to holders of record on February
16, 1993. In May 1993 the Trust received payments with respect to the
three-month period ended March 31, 1993 totalling $2,940,000 and on May 31, 1993
a distribution of $0.4666 per Trust Unit was made to holders of record on May
17, 1993. In August 1993 the Trust received payments with respect to the
three-month period ended June 30, 1993 totalling $3,193,000 and on August 31,
1993 a distribution of $0.49485 per Trust Unit was made to holders of record on
August 16, 1993. In November, 1993, the Trust received payments with respect to
the three-month period ended September 30, 1993 totalling $2,787,000 and on
November 30, 1993 a distribution of $0.44218 per Trust Unit was made to holders
of record on November 15, 1993. In February 1994, the Trust will receive
payments with respect to the three-month period ended December 31, 1993
totalling $2,520,000 (which payments include a Support Payment of $362,000) and
on February 28, 1994 a distribution of $0.40 per Trust Unit will be made to
holders of record on February 14, 1994.
F-17
<PAGE> 71
APPENDIX A
[LETTERHEAD]
February 1, 1994
Santa Fe Energy Resources, Inc.
1616 South Voss Road
Houston, Texas 77057-2696
Gentlemen:
Pursuant to your request, we present below our estimates of the net proved
reserves attributable to the interests of the Santa Fe Energy Trust (Trust) as
of December 31, 1993. The Trust is a grantor trust formed to hold interests in
certain domestic oil and gas properties owned by Santa Fe Energy Resources, Inc.
(Santa Fe). The interests conveyed to the Trust consist of royalty interests in
the Wasson Field, Texas (Wasson Royalties) and a net profits interest derived
from working and royalty interests in numerous other properties (Net Profits
Royalties). The properties included in the Trust are located in the states of
Alabama, Arkansas, California, Colorado, Kansas, Louisiana, Mississippi, New
Mexico, North Dakota, Oklahoma, Texas, Wyoming, and in state waters offshore
Louisiana and Texas.
The estimated reserve quantities and future income quantities presented in
this report are related to a large extent to hydrocarbon prices. Hydrocarbon
prices in effect at December 31, 1993 were used in the preparation of this
report as required by Securities and Exchange Commission (SEC) and Financial
Accounting Standards Bulletin No. 69 (FASB 69) guidelines; however, actual
future prices may vary significantly from December 31, 1993 prices for reasons
discussed in more detail in other sections of this report. Therefore, quantities
of reserves actually recovered and quantities of income actually received may
differ significantly from the estimated quantities presented in this report.
<TABLE>
<CAPTION>
AS OF DECEMBER 31, 1993
-----------------------------------------
ESTIMATED PRESENT
FUTURE NET VALUE
LIQUIDS GAS CASH INFLOWS AT 10%
(MBBLS) (MMCF) (M$) (M$)
------- ------ ------------ -------
<S> <C> <C> <C> <C>
Proved Net Developed and Undeveloped
Wasson ODC Royalty.................................... 5,535 0 58,681 33,198
Wasson Willard Royalty................................ 1,026 0 10,715 7,314
Net Profits Royalties................................. 1,208 11,121 38,148 24,804
------- ------ ------- ------
Totals........................................ 7,769 11,121 107,544 65,316
Proved Net Developed
Wasson ODC Royalty.................................... 5,535 0 58,681 33,198
Wasson Willard Royalty................................ 1,026 0 10,715 7,314
Net Profits Royalties................................. 1,204 10,900 37,618 24,438
------- ------ ------- ------
Totals........................................ 7,765 10,900 107,014 64,950
</TABLE>
The estimated proved reserves and income quantities for the Wasson
Royalties presented in this report are calculated by multiplying the net revenue
interest attributable to each of the Wasson Royalties by the total amount of oil
estimated to be economically recoverable from the respective productive units,
subject to
A-1
<PAGE> 72
production limitations applicable to the Wasson Royalties and an additional
royalty to provide Support Payments, which have been described to us by Santa
Fe.
Reserve quantities are calculated differently for the Net Profits Royalties
because such interests do not entitle the Trust to a specific quantity of oil or
gas but to 90 percent of the Net Proceeds derived therefrom. Accordingly, there
is no precise method of allocating estimates of the quantities of proved
reserves attributable to the Net Profits Royalties between the interest held by
the Trust and the interests to be retained by Santa Fe. For purposes of this
presentation, the proved reserves attributable to the Net Profits Royalties have
been proportionately reduced to reflect the future estimated costs and expenses
deducted in the calculation of Net Proceeds with respect to the Net Profits
Royalties. Accordingly, the reserves presented for the Net Profits Royalties
reflect quantities of oil and gas that are free of future costs or expenses
based on the price and cost assumptions utilized in this report. The allocation
of proved reserves of the Net Profits Properties between the Trust and Santa Fe
will vary in the future as relative estimates of future gross revenues and
future net incomes vary. Furthermore, Santa Fe requested that for purposes of
our report the Net Profits Royalties be calculated beyond the Liquidation Date
of December 31, 2007, even though by the terms of the Trust Agreement the Net
Profits Royalties will be sold by the Trustee on or about this date and a
liquidating distribution of the sales proceeds from such sale would be made to
holders of Trust Units.
The "Liquid" reserves shown above are comprised of crude oil, condensate
and natural gas liquids. Natural gas liquids comprise 0.7 percent of the Trust's
developed liquid reserves and 0.7 percent of the Trust's developed and
undeveloped liquid reserves. All hydrocarbon liquid reserves are expressed in
standard 42 gallon barrels. All gas volumes are sales gas expressed in MMCF at
the pressure and temperature bases of the area where the gas reserves are
located. The estimated future net cash inflows are described later in this
report.
Santa Fe has indicated that the conveyance of the Wasson Royalties to the
Trust provides that the Trust will receive an additional royalty interest in the
Wasson ODC Unit which could be available for Support Payments. Payment of this
additional royalty is subject to numerous limitations which are detailed in the
Conveyance. The tables shown on Pages A-1 and A-4 include 1,890,522 barrels of
oil, $20,000,000 of estimated future net revenue, and $12,662,967 of discounted
estimated future net revenue attributable to an additional royalty in respect of
Support Payments which have been described to us by Santa Fe.
In accordance with information provided by Santa Fe, proved reserves and
revenues attributable to Santa Fe's remaining royalty interest in the Wasson ODC
Unit available for Support Payments, which includes the above mentioned reserves
and revenues, are presented below.
<TABLE>
<CAPTION>
ESTIMATED
PROVED FUTURE NET
OIL ESTIMATED REVENUES
RESERVES FUTURE NET DISCOUNTED
(BBLS) REVENUES -- $ AT 10% -- $
- --------- ----------- -----------
<S> <C> <C>
3,272,552 $34,558,352 $23,815,495
</TABLE>
The Support Payments are limited to $20,000,000 in the aggregate. As a
result, even though we have calculated total estimated future net revenues of
$34,558,352 available for Support Payments and $20,000,000 of such amount has
been included in our estimate of the future net cash inflow for the Wasson ODC
Royalty attributable to the Trust, no additional Support Payment would be
allowed due to the $20,000,000 limitation.
The proved reserves presented in this report comply with the Securities and
Exchange Commission's Regulation S-X Part 210.4-10 Sec. (a) as clarified by
subsequent Commission Staff Accounting Bulletins, and are based on the following
definitions and criteria:
Proved reserves of crude oil, condensate, natural gas, and natural gas
liquids are estimated quantities that geological and engineering data
demonstrate with reasonable certainty to be recoverable in the future from
known reservoirs under existing conditions. Reservoirs are considered
proved if economic producibility is supported by actual production or
formation tests. In certain instances, proved reserves
A-2
<PAGE> 73
are assigned on the basis of a combination of core analysis and electrical
and other type logs which indicate the reservoirs are analogous to
reservoirs in the same field which are producing or have demonstrated the
ability to produce on a formation test. The area of a reservoir considered
proved includes (1) that portion delineated by drilling and defined by
fluid contacts, if any, and (2) the adjoining portions not yet drilled that
can be reasonably judged as economically productive on the basis of
available geological and engineering data. In the absence of data on fluid
contacts, the lowest known structural occurrence of hydrocarbons controls
the lower proved limit of the reservoir. Proved reserves are estimates of
hydrocarbons to be recovered from a given date forward. They may be revised
as hydrocarbons are produced and additional data become available. Proved
natural gas reserves are comprised of non-associated, associated, and
dissolved gas. An appropriate reduction in gas reserves has been made for
the expected removal of natural gas liquids, for lease and plant fuel and
the exclusion of non-hydrocarbon gases if they occur in significant
quantities and are removed prior to sale. Reserves that can be produced
economically through the application of improved recovery techniques are
included in the proved classification when these qualifications are met:
(1) successful testing by a pilot project or the operation of an installed
program in the reservoir provides support for the engineering analysis on
which the project or program was based, and (2) it is reasonably certain
the project will proceed. Improved recovery includes all methods for
supplementing natural reservoir forces and energy, or otherwise increasing
ultimate recovery from a reservoir, including (1) pressure maintenance, (2)
cycling, and (3) secondary recovery in its original sense. Improved
recovery also includes the enhanced recovery methods of thermal, chemical
flooding, and the use of miscible and immiscible displacement fluids.
Estimates of proved reserves do not include crude oil, natural gas, or
natural gas liquids being held in underground storage. Depending on the
status of development, these proved reserves are further subdivided into:
(i) "developed reserves" which are those proved reserves reasonably
expected to be recovered through existing wells with existing equipment
and operating methods, including (a) "developed producing reserves"
which are those proved developed reserves reasonably expected to be
produced from existing completion intervals now open for production in
existing wells, and (b) "developed non-producing reserves" which are
those proved developed reserves which exist behind the casing of
existing wells which are reasonably expected to be produced through
these wells in the predictable future where the cost of making such
hydrocarbons available for production should be relatively small
compared to the cost of a new well; and
(ii) "undeveloped reserves" which are those proved reserves
reasonably expected to be recovered from new wells on undrilled acreage,
from existing wells where a relatively large expenditure is required and
from acreage for which an application of fluid injection or other
improved recovery technique is contemplated where the technique has been
proved effective by actual tests in the area in the same reservoir.
Reserves from undrilled acreage are limited to those drilling units
offsetting productive units that are reasonably certain of production
when drilled. Proved reserves for other undrilled units are included
only where it can be demonstrated with reasonable certainty that there
is continuity of production from the existing productive formation.
Because of the direct relationship between quantities of proved undeveloped
reserves and development plans, we include in the proved undeveloped category
only reserves assigned to undeveloped locations that we have been assured will
definitely be drilled and reserves assigned to the undeveloped portions of
secondary or tertiary projects which we have been assured will definitely be
developed.
A-3
<PAGE> 74
In accordance with the requirements of FASB 69, our estimates of future
cash inflows, future costs and future net cash inflows before income tax, as
well as our estimated reserve quantities, as of December 31, 1993 from this
report are presented below.
<TABLE>
<CAPTION>
AS OF DECEMBER 31, 1993
------------------------------------------------------------
NET PROFITS ROYALTIES
----------------------------------
ROYALTY WORKING WASSON
INTERESTS INTERESTS TOTALS ROYALTIES TOTALS
--------- --------- ------ --------- -------
<S> <C> <C> <C> <C> <C>
Total Proved
Future Cash Inflows (M$).................. 15,718 22,430 38,148 75,455 113,603
Future Costs
Production (M$)........................ 0 0 0 6,059 6,059
Development (M$)....................... 0 0 0 0 0
--------- --------- ------ --------- -------
Total Costs (M$).................. 0 0 0 6,059 6,059
Future Net Cash Inflows Before Income
Tax (M$)............................... 15,718 22,430 38,148 69,396 107,544
Present Value at 10% Before Income
Tax (M$)............................... 10,221 14,583 24,804 40,512 65,316
Proved Net Developed Reserves
Liquids -- (MBbls)........................ 649 555 1,204 6,561 7,765
Gas (MMCF)................................ 3,711 7,189 10,900 0 10,900
Proved Net Undeveloped Reserves
Liquids (Mbbls)........................... 0 4 4 0 4
Gas (MMCF)................................ 0 221 221 0 221
Total Proved Net Reserves
Liquids (MBbls)........................... 649 559 1,208 6,561 7,769
Gas (MMCF)................................ 3,711 7,410 11,121 0 11,121
</TABLE>
In the case of the Wasson Royalties, the future cash inflows are gross
revenues after gathering and transportation costs where applicable, but before
any other deductions. The production costs are based on current data and include
production taxes and ad valorem taxes provided by Santa Fe.
In the case of the Net Profits Royalties, the future cash inflows are, as
described previously, after consideration of future costs or expenses based on
the price and cost assumptions utilized in this report. Therefore, the future
cash inflows are the same as the future net cash inflows. Included in these
future cash inflows is an estimated amount attributable to the sale of sulphur
in certain Gulf Coast properties.
Santa Fe furnished us gas prices in effect at December 31, 1993 and with
its forecasts of future gas prices which take into account Securities and
Exchange Commission guidelines, current market prices, regulations under the
Natural Gas Policy Act of 1978 and the Gas Decontrol Act of 1989, contract
prices and fixed and determinable price escalations where applicable. In
accordance with Securities and Exchange Commission guidelines, the future gas
prices used in this report make no allowances for future gas price increases
which may occur as a result of inflation nor do they account for seasonal
variations in gas prices which are likely to cause future yearly average gas
prices to be somewhat lower than December gas prices. In those cases where
contract market-out has occurred, the current market price was held constant to
depletion of the reserves. In those cases where market-out has not occurred,
contract gas prices including fixed and determinable escalations, exclusive of
inflation adjustments, were used until the contract expires and then reduced to
the current market price for similar gas in the area and held at this reduced
price to depletion of the reserves.
Santa Fe furnished us with liquid prices in effect at December 31, 1993 and
these prices were held constant to depletion of the properties. In accordance
with Securities and Exchange Commission guidelines, changes in liquid prices
subsequent to December 31, 1993 were not considered in this report.
A-4
<PAGE> 75
Operating costs for the leases and wells in this report were provided by
Santa Fe and include only those costs directly applicable to the leases or
wells. When applicable, the operating costs include a portion of general and
administrative costs allocated directly to the leases and wells under terms of
operating agreements. Development costs were furnished to us by Santa Fe and are
based on authorizations for expenditure for the proposed work or actual costs
for similar projects. The current operating and development costs were held
constant throughout the life of the properties. For properties located onshore,
this study does not consider the salvage value of the lease equipment or the
abandonment cost since both are relatively insignificant and tend to offset each
other. The estimated net cost of abandonment after salvage was considered for
offshore properties where abandonment costs net of salvage are significant. The
estimates of the offshore net abandonment costs furnished by Santa Fe were
accepted without independent verification.
No deduction was made for indirect costs such as general administration and
overhead expenses, loan repayments, interest expenses, and exploration and
development prepayments. No attempt has been made to quantify or otherwise
account for any accumulated gas production imbalances that may exist.
Our reserve estimates are based upon a study of the properties in which the
Trust has interests; however, we have not made any field examination of the
properties. No consideration was given in this report to potential environmental
liabilities which may exist nor were any costs included for potential liability
to restore and clean up damages, if any, caused by past operating practices.
Santa Fe informed us that it has furnished us all of the accounts, records,
geological and engineering data and reports and other data required for our
investigation. The ownership interests, terms of the Trust, prices, taxes, and
other factual data furnished to us in connection with our investigation were
accepted as represented. The estimates presented in this report are based on
data available through July, 1993.
The reserves included in this report are estimates only and should not be
construed as being exact quantities. They may or may not be actually recovered.
Estimates of proved reserves may increase or decrease as a result of future
operations of Santa Fe. Moreover, due to the nature of the Net Profits
Royalties, a change in the future costs, or prices, or capital expenditures
different from those projected herein may result in a change in the computed
reserves and the Net Proceeds to the Trust even if there are no revisions or
additions to the gross reserves attributed to the property.
The future production rates from properties now on production may be more
or less than estimated because of changes in market demand or allowables set by
regulatory bodies. In general, we estimate that gas production rates will
continue to be the same as the average rate for the latest available 12 months
of actual production until such time that the well or wells are incapable of
producing at this rate. The well or wells are then projected to decline at their
decreasing delivery capacity rate. Our general policy on estimates of future gas
production rates is adjusted when necessary to reflect actual gas market
conditions in specific cases. Properties which are not currently producing may
start producing earlier or later than anticipated in our estimates of their
future production rates.
The future prices received for the sale of the production may be higher or
lower than the prices used in this report as described above, and the operating
costs and other costs relating to such production may also increase or decrease
from existing levels; however, such possible changes in prices and costs were,
in accordance with rules adopted by the Securities and Exchange Commission,
omitted from consideration in preparing this report.
A-5
<PAGE> 76
Neither Ryder Scott Company nor any of its employees has any interest in
the subject properties and neither the employment to make this study nor the
compensation is contingent on our estimates of reserves and future cash inflows
for the subject properties.
Very truly yours,
RYDER SCOTT COMPANY
PETROLEUM ENGINEERS
Fred W. Ziehe, P.E.
Group Vice President
FWZ/db
A-6
<PAGE> 77
APPENDIX B
No transfer of the Depositary Units evidenced by this SPER(TM) will be
registered on the books of the Depositary unless the SPERs(TM) evidencing the
Depositary Units to be transferred are surrendered for registration of transfer
and an Application for Transfer of Depositary Units has been executed by a
transferee either (a) on the form set forth below of (b) on a separate
application that the Depositary will furnish on request without charge. A
transferor of the Depositary Units has no duty to the transferee to delivery an
executed transfer application in order for such transferee to obtain
registration of the transfers of such Depositary Units evidenced by this
SPER(TM).
APPLICATION FOR TRANSFER OF DEPOSITARY UNITS
The undersigned ("Assignee") hereby applies for transfer to the name of the
Assignee of the Depositary Units evidenced by this SPER(TM).
The Assignee (a) agrees to become a party to the Deposit Agreement thereby
assenting to all of its provisions, (b) agrees to comply with and be bound by
the terms and conditions of the Trust Agreement and this SPER(TM) and, in this
regard, Assignee acknowledges and agrees that (i) Depositary Units may not be
transferred or assigned except in denominations of 50 or an integral multiple
thereof unless otherwise permitted under the Deposit Agreement, (ii) under the
Trust Agreement, in the event Trust Units are withdrawn from deposit with the
Depositary, such withdrawn Trust Units may not be transferred or assigned except
by operation of law, (iii) under the Trust Agreement and the Deposit Agreement,
in the event a judicial or administrative proceeding is instituted seeking
cancellation or forfeiture of any property in which the Trust has an interest
because of the nationality, citizenship or any other status of Assignee, the
Trustee may request Assignee to dispose of his Depositary Units within 30 days,
and if Assignee fails to so dispose of such Depositary Units, the Trustee shall
have the right to cause the Depositary to cancel and sell such Depositary Units
in accordance with the Deposit Agreement, and (iv) under the Deposit Agreement,
Assignee indemnifies and holds the Depositary and the Trustee harmless from
certain losses in connection with claims related to transfer, inheritance or
gift taxes as provided in the Deposit Agreement, (c) agrees that his
transferor's duty to provide such transferee with any requisite information
necessary to obtain registration of the transfer of the Depositary Units shall
exclude any duty by the transferor to deliver an executed Transfer Application,
(d) makes the consents and waivers and gives the approvals contained in the
Trust Agreement and the Deposit Agreement, and (e) irrevocably appoints the
Depositary his attorney-in-fact to take all actions on his behalf in connection
with the Deposit Agreement. Capitalized terms not defined herein have the
meanings assigned to such terms in the Deposit Agreement.
The Assignee has acquired an interest in the Trust, whose taxpayer
identification number is 76-6081498. The Internal Revenue Service has issued the
Trust the following tax shelter registration number: 92322000636.
The Assignee must report this registration number to the Internal Revenue
Service if the Assignee claims any deduction, loss, credit or other tax benefit
or reports any income by reason of the Assignee's investment in the Trust.
The Assignee must report the registration number (as well as the name and
taxpayer identification number of the Trust) on Form 8271.
FORM 8271 MUST BE ATTACHED TO THE RETURN ON WHICH THE ASSIGNEE CLAIMS THE
DEDUCTION, LOSS, CREDIT OR OTHER TAX BENEFIT OR REPORTS ANY INCOME.
ISSUANCE OF A REGISTRATION NUMBER DOES NOT INDICATE THAT THIS INVESTMENT OR
THE CLAIMED TAX BENEFITS HAVE BEEN REVIEWED, EXAMINED OR APPROVED BY THE
INTERNAL REVENUE SERVICE.
B-1
<PAGE> 78
<TABLE>
<S> <C>
Dated: ____________________________________ __________________________________________
Signature of Assignee
___________________________________________ __________________________________________
Social Security or other identifying number Print or type name and address of Assignee
of Assignee
__________________________________________
Purchase Price (including commissions,
if any)
</TABLE>
<TABLE>
<S> <C> <C>
Type of Entity (Check One)
___________________ Individual _________________ Partnership ________________ Corporation
___________________ Trust _________________ Other (specify) ____________________________
</TABLE>
Nationality (Check One)
/ / U.S. Citizen, Resident or Domestic Entity
/ / Foreign Corporation, or / / Non-resident Alien
If the U.S. Citizen, Resident or Domestic Entity box is checked, the
following certification must be completed in order to avoid withholding of tax
under United States income tax laws:
Under Section 1445(e) of the Internal Revenue Code of 1986, as amended (the
"Code"), the Trustee must withhold tax with respect to certain transfers of
property if a holder of Depositary Units is a foreign person. To inform the
Trustee or the Depositary that no withholding is required with respect to the
undersigned interest-holder's interest in it, the undersigned hereby certifies
the following (or, if applicable, certifies the following on behalf of the
interest-holder).
Complete either A or B:
<TABLE>
<S> <C>
A. INDIVIDUAL INTEREST-HOLDER
1. I am not a non-resident alien for purposes of U.S. income taxation.
2. My U.S. taxpayer identification number (Social Security Number)
is _________________________________________________________________________
3. My home address is _________________________________________________________
B. PARTNERSHIP, CORPORATION OR OTHER INTEREST-HOLDER
1. __________________________________________ is not a foreign corporation, foreign
partnership, foreign trust or foreign estate (as those terms are defined in the Code
and Treasury Regulations).
2. The interest-holder's U.S. employer identification number is ______________________
3. The interest-holder's office address and place of incorporation (if applicable)
is ________________________________________________________________________________
</TABLE>
The interest-holder agrees to notify the Trustee within 60 days of the date
the interest-holder becomes a foreign person.
The interest-holder understands that this certification may be disclosed to
the Internal Revenue Service by the Trustee or the Depositary and that any false
statement contained herein could be punishable by fine, imprisonment or both.
B-2
<PAGE> 79
Under penalties of perjury, I declare that I have examined this
certification and to the best of my knowledge and belief it is true, correct and
complete and, if applicable, I further declare that I have authority to sign
this document on behalf of
__________________________________
Name of Interest-Holder
__________________________________
Signature and Date
__________________________________
Title (if applicable)
Note: If the Assignee is a broker, dealer, bank, trust company, clearing
corporation, other nominee holder or an agent of any of the foregoing, and is
holding for the account of any other person, this application should be
completed by an officer thereof or, in the case of a broker or dealer, by a
registered representative who is a member of a registered national securities
exchange or a member of the National Association of Securities Dealers, Inc.,
or, in the case of any other nominee holder, a person performing a similar
function. If the Assignee is a broker, dealer, bank, trust company, clearing
corporation, other nominee holder or an agent of any of the foregoing, the above
certification as to any Person for whom the Assignee will hold the Depositary
Units shall be made to the best of the Assignee's knowledge.
Note: This Transfer Application may be executed on behalf of a transferee by an
attorney, executor, administrator, personal representative, trustee,
attorney-in-fact or guardian, and, if so executed, the person executing this
Transfer Application must give his or her full title in such capacity, and
proper evidence of authority to act in such capacity, if not on file with the
Depositary, must be forwarded herewith.
B-3
<PAGE> 80
- -------------------------------------------------------------------------------
- -------------------------------------------------------------------------------
NO DEALER, SALESMAN OR ANY OTHER PERSON HAS BEEN AUTHORIZED TO GIVE ANY
INFORMATION OR TO MAKE ANY REPRESENTATIONS NOT CONTAINED IN OR INCORPORATED BY
REFERENCE IN THIS PROSPECTUS AND, IF GIVEN OR MADE, SUCH INFORMATION OR
REPRESENTATIONS MUST NOT BE RELIED UPON AS HAVING BEEN AUTHORIZED BY SANTA FE OR
THE UNDERWRITER. THIS PROSPECTUS DOES NOT CONSTITUTE AN OFFER OF ANY SECURITIES
OTHER THAN THOSE TO WHICH IT RELATES OR AN OFFER TO SELL, OR A SOLICITATION OF
AN OFFER TO BUY, TO ANY PERSON IN ANY JURISDICTION WHERE SUCH AN OFFER OR
SOLICITATION WOULD BE UNLAWFUL. NEITHER THE DELIVERY OF THIS PROSPECTUS NOR ANY
SALE MADE HEREUNDER SHALL, UNDER ANY CIRCUMSTANCES, CREATE ANY IMPLICATION THAT
THE INFORMATION CONTAINED HEREIN IS CORRECT AS OF ANY TIME SUBSEQUENT TO THE
DATE HEREOF.
---------------------------
TABLE OF CONTENTS
<TABLE>
<CAPTION>
PAGE
----
<S> <C>
Available Information.................. 2
Incorporation of Certain Documents by
Reference............................ 2
Prospectus Summary..................... 3
Risk Factors........................... 12
The Royalty Interests.................. 18
The Royalty Properties................. 24
Price Range of Depositary Units and
Distribution Policy.................. 34
Santa Fe............................... 35
The Treasury Obligations............... 36
Principal and Selling Security
Holders.............................. 36
Federal Income Tax Consequences........ 36
ERISA Considerations................... 41
State Tax Considerations............... 42
Description of the Trust and the Trust
Agreement............................ 43
Description of the Depositary Units.... 48
Underwriting........................... 52
Legal Matters.......................... 52
Experts................................ 53
Definitions and Other Matters.......... 53
Index to Financial Statements.......... F-1
Summary Report of Ryder Scott Company
Petroleum Engineers.................. A-1
Form of Transfer Application........... B-1
</TABLE>
575,000
DEPOSITARY UNITS
Evidenced by
Secure Principal
Energy Receipts
(SPERs(TM))
Consisting of Interests in
Santa Fe Energy Trust
and a
United States
Treasury Obligation
---------------------------
PROSPECTUS
February 10, 1994
---------------------------
LEHMAN BROTHERS
- -------------------------------------------------------------------------------
- -------------------------------------------------------------------------------
<PAGE> 81
APPENDIX A
Page 2 -- A map of the continental United States follows page 2 that
illustrates in shaded color the areas in which Santa Fe Energy Trust
Properties are located.
Page 27 -- A bar graph that depicts annual estimated production of proved
reserves attributable to the Wasson ODC Royalty during the term of
such royalty, including reserves available for Support Payments,
based upon estimates contained in the Reserve Report.
Page 28 -- A bar graph that depicts annual estimated production of proved
reserves attributable to the Wasson Willard Royalty during the term
of such royalty based upon estimates contained in the Reserve Report.
