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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
[X] ANNUAL REPORT PURSUANT TO SECTION 13
OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended September 30, 2000
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13
OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _________ to __________
Commission file number: 0-4408
RESOURCE AMERICA, INC.
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(Exact name of registrant as specified in its charter)
DELAWARE 72-0654145
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(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
1521 Locust Street
Suite 400
Philadelphia, PA 19102
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(Address of principal executive offices) (Zip code)
Registrant's telephone number, including area code: (215) 546-5005
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Securities registered pursuant to Section 12(b) of the Act: None
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Securities registered pursuant to Section 12(g) of the Act:
Common stock, par value $.01 per share
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(Title of class)
Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
the preceding 12 months (or for such shorter period that the registrant was
required to file such reports), and (2) has been subject to such filing
requirements for the past 90 days. Yes [X] No [ ]
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405
of Regulation S-K is not contained herein, and will not be contained, to the
best of registrant's knowledge, in definitive proxy or information statements
incorporated by reference in Part III of this Form 10-K or any amendment to this
Form 10-K. [X]
The aggregate market value of the voting stock held by nonaffiliates of the
registrant, based upon the closing price of such stock on December 15, 2000, was
approximately $155 million.
The number of outstanding shares of the registrant's common stock on December
15, 2000 was 17,448,125.
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Proxy Statement for registrant's 2001 Annual Meeting of
Stockholders are incorporated by reference in Part III of this Form 10-K.
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RESOURCE AMERICA, INC. AND SUBSIDIARIES
INDEX TO ANNUAL REPORT
ON FORM 10-K
<TABLE>
<CAPTION>
PART I Page
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<S> <C> <C>
Item 1: Business.................................................................................. 3
Item 2: Properties................................................................................ 26
Item 3: Legal Proceedings......................................................................... 26
Item 4: Submission of Matters to a Vote of Security Holders....................................... 26
PART II
Item 5: Market for Registrant's Common Equity and Related Stockholder Matters..................... 27
Item 6: Selected Financial Data................................................................... 28
Item 7: Management's Discussion and Analysis of Financial Condition
and Results of Operation.............................................................. 29
Item 7A: Quantitative and Qualitative Disclosures About Market Risk................................ 38
Item 8: Financial Statements and Supplementary Data............................................... 41
Item 9: Changes in and Disagreements with Accountants
on Accounting and Financial Disclosure................................................ 75
PART III
Item 10: Directors and Executive Officers of the Registrant........................................ 76
Item 11: Executive Compensation.................................................................... 76
Item 12: Security Ownership of Certain Beneficial Owners and Management............................ 76
Item 13: Certain Relationships and Related Transactions............................................ 76
PART IV
Item 14: Exhibits, Financial Statement Schedules and
Reports on Form 8-K................................................................... 77
SIGNATURES ...................................................................................... 83
</TABLE>
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PART I
ITEM 1. BUSINESS
General
We operate energy and real estate finance businesses through our
subsidiaries, Atlas America, Inc. and Resource Properties, Inc. In energy, we
drill for and produce natural gas in the Appalachian Basin and, as of September
30, 2000, owned interests, either directly or through partnerships managed by us
in 4,067 wells. In addition, we own 100% of the general partner and a majority
of the limited partner interest in Atlas Pipeline Partners, L.P., a publicly
traded (AMEX symbol "APL") master limited partnership that owns natural gas
pipeline systems in the Appalachian Basin. Our interest in Atlas Pipeline
includes the right to receive incentive distributions if the partnership meets
or exceeds its minimum quarterly distribution obligations. In real estate, we
own and manage a portfolio of commercial loans on office buildings, multifamily
housing, commercial and hotel properties located primarily in the Washington
D.C.-Baltimore, Philadelphia, and Chicago metropolitan areas. We also sponsored
and own approximately 14% of the common shares of RAIT Investment Trust (AMEX
symbol "RAS"), a real estate investment trust. For information regarding each of
our businesses, you should review Note 18 of the notes to consolidated financial
statements.
During the past two fiscal years, our energy business has undergone a
significant expansion through an increased commitment of corporate assets and
management resources and the acquisitions of The Atlas Group (now Atlas America,
Inc.) in September 1998 and Viking Resources Corporation in August 1999. Our
revenues from energy operations have risen substantially, from $6.7 million in
fiscal 1998 to $55.1 million in fiscal 1999 and $70.6 million in fiscal 2000.
Our energy business now accounts for 71% of our total revenues, as compared to
51% of total revenues in fiscal 1999 and 10% in fiscal 1998, and 30% of our
total assets and 39% of non-cash assets, as compared to 26% of total assets and
27% of non-cash assets in fiscal 1999 and 23% of total assets and 28% of
non-cash assets in fiscal 1998.
Concurrently we have been reducing our involvement in financial
activities. In August 2000, we sold our small ticket equipment leasing business
to subsidiaries of ABN AMRO Bank, N.V. for $583.0 million, including the
assumption of approximately $431.0 million in debt payable to third parties. In
November 2000, we disposed of Fidelity Mortgage Funding, Inc., our residential
mortgage lending business. In fiscal 2000 we did not acquire any new real estate
loans.
Energy Operations
General
Our energy operations are concentrated in the Western New York, Eastern
Ohio and Western Pennsylvania region of the Appalachian Basin. As of September
30, 2000:
o We had, either directly or through partnerships and joint ventures
managed by us, interests in 4,067 wells (including royalty or
overriding royalty interest in 540 wells), of which we operate
3,472 wells.
o Wells in which we have an interest produced, net to our interest,
approximately 17,600 thousand cubic feet ("mcf") of natural gas
per day.
o We owned proved reserves of approximately 124 billion cubic feet
equivalent ("bcfe") of natural gas and oil with a net present
value of $140.8 million. (Net present value is defined as the
pre-tax future net revenues from the reserves priced at
approximately $4.49 per mcf of natural gas and $26.84 per barrel
of oil, discounted at 10% over the productive life of the
reserves).
o We had an interest in 396,000 gross acres (325,000 net acres) of
undeveloped properties.
o We owned and operated, directly or through our Atlas Pipeline
subsidiary, over 900 miles of gas gathering systems and pipelines.
Since 1976, we or our predecessors have financed our development and
production operations through private and, since 1992, public drilling
partnerships sponsored by us. We act as the managing general partner of each of
these partnerships, contribute the leases on which the partnership drills, and
contribute a proportionate share of the partnership's cash capital. We retain a
percentage interest in the wells through our general partner's interest,
generally between 25% and 32% and receive a monthly administrative fee. In
3
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addition, we typically act as the drilling contractor and operator of the wells
drilled by the partnerships on a fee basis. In the fiscal year ended September
30, 2000, we obtained funding of $30.3 million through two private and one
public investment partnerships.
Natural gas produced from wells we operate is collected in gas
gathering pipeline systems owned and operated by Atlas Pipeline. We sell the
natural gas produced to customers such as gas brokers and local utilities under
a variety of contractual arrangements. We sell oil produced to regional oil
refining companies at the prevailing spot price for Appalachian crude oil.
Industry Overview
Natural gas is the second largest energy source in the United States,
after liquid petroleum. The 22 trillion cubic feet of natural gas consumed in
1999 represented approximately 23% of the total energy used in the United
States. The Appalachian Basin (in which substantially all of our wells are
located) accounted for 3.2% of total 1999 domestic natural gas production, or
627 billion cubic feet ("bcf"). Furthermore, according to the Energy Information
Administration of the U.S. Department of Energy, the Appalachian Basin holds
8,707 bcf of economically recoverable reserves representing approximately 6% of
total domestic reserves as of December 31, 1998. Although the potential to find
recoverable quantities of oil and gas exists at depths below 6,500 feet, the
vast majority of wells in Appalachia produce from depths between 1,000 and 6,500
feet. Companies drilling at these depths, including us, have historically
realized well completion rates of greater than 90% and well production periods
that last longer than 20 years. The Appalachian Basin is strategically located
near the energy consuming population centers in the Mid-Atlantic and
Northeastern United States, which generally allows Appalachian producers to sell
their natural gas at a premium to the benchmark price for natural gas on the New
York Mercantile Exchange.
Business Strategy
Our goal is to expand our natural gas reserves, production and
revenues. Our strategy to achieve these goals includes the following key
elements:
o Acquiring additional oil and gas leasehold acreage in the
Appalachian Basin.
o Developing leasehold acreage currently in our inventory.
o Acquiring other small capitalization energy companies through
merger, consolidation or purchase.
o Increasing the amount of development financing provided by our
drilling partnerships.
o Testing deeper formations on leasehold acreage on which we already
have drilled wells.
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Exploration, Development and Operation
The following table sets forth information as of September 30, 2000
regarding productive natural gas and oil wells in which we have a working
interest:
<TABLE>
<CAPTION>
Number of Productive Wells
-----------------------------------
Gross(1) Net(1)
------------ -------------
<S> <C> <C>
Oil wells......................................................... 313 178
Gas wells......................................................... 3,214 1,672
-------- ---------
Total ................................................... 3,527 1,850
======== =========
</TABLE>
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(1) Includes our equity interest in wells owned by 85 partnerships and various
joint ventures. Does not include our royalty or overriding interests in 540
other wells.
As of December 15, 2000, we were in the process of drilling 46 gross
(12 net) wells.
The following table sets forth the quantities of natural gas and oil
produced (net to our interest), average sales prices, and average production
(lifting) costs per equivalent unit of production, for the periods indicated:
<TABLE>
<CAPTION>
Production Average Sales Price Average Lifting
Fiscal ----------------------------- --------------------------- Cost per
Period Oil(bbls) Gas(mcf) per bbl per mcf mcfe(1)(2)
------ --------- -------- ------- ------- ------------
<S> <C> <C> <C> <C> <C>
2000 195,974 6,440,154 $24.50 $3.15 $0.95
1999(3) 85,045 4,342,430 $14.57 $2.37 $0.99
1998(4) 48,113 1,485,008 $14.38 $2.66 $1.13
</TABLE>
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(1) "mcfe" means a thousand cubic feet equivalent. Oil production is converted
to mcfe at the rate of six mcf per barrel ("bbl").
(2) Lifting costs include labor to operate the wells and related equipment,
repairs and maintenance, materials and supplies, property taxes, insurance
and gathering charges.
(3) Includes production relating to Viking Resources for only the one month
period from August 31, 1999, the date of its acquisition, to the end of the
fiscal year.
(4) Excludes production relating to Atlas America and Viking Resources, which
we did not acquire until the end of the 1998 and 1999 fiscal years,
respectively.
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We are not, nor are the partnerships and joint ventures we manage,
obligated to provide any fixed quantities of oil or gas in the future under
existing contracts.
The following table sets forth information with respect to the number
of wells for which drilling was completed at any time during fiscal 2000, 1999
and 1998, regardless of when drilling was initiated.
<TABLE>
<CAPTION>
Exploratory Wells Development Wells
----------------------------------------- ---------------------------------------
Productive Dry Productive Dry
--------------- --------------- --------------- --------------
Fiscal
Period Gross Net Gross Net Gross Net Gross Net
------ ----- --- ----- --- ----- --- ----- ---
<S> <C> <C> <C> <C> <C> <C> <C> <C>
2000 - - 1.0 .18 155.0 41.2 3 .80
1999(1) - - 1.0 .20 145.0 41.9 - -
1998(2) 1.0 .25 2.0 .75 3.0 3.0 - -
</TABLE>
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(1) Includes wells drilled by Viking Resources only since August 31, 1999, the
date of its acquisition.
(2) Excludes wells drilled by Atlas America, which was not acquired until the
end of the 1998 fiscal year.
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We provide, on a fee basis, a variety of well services to wells we
operate and to wells operated by independent third parties. These services
include well operations, petroleum engineering, well maintenance and well work
over and are provided at rates in conformity with general industry standards.
Oil and Gas Reserve Information
The following tables summarize information regarding our estimated
proved natural gas and oil reserves as of September 30, 2000, 1999 and 1998. All
of the reserves are located in the United States. The estimates relating to our
proved natural gas and oil reserves and future net revenues of natural gas and
oil reserves are based upon reports prepared by Wright & Company, Inc. In
accordance with SEC guidelines, the standardized and SEC PV-10 estimates of
future net cash flows from proved reserves are made using natural gas and oil
sales prices in effect as of the dates of the estimates and are held constant
throughout the life of the properties. Our estimates of proved reserves were
based upon the following weighted average prices:
<TABLE>
<CAPTION>
Years Ended September 30,
----------------------------------------
2000 1999 1998
--------- -------- ----------
<S> <C> <C> <C>
Natural gas (per mcf).................................................. $ 4.49 $ 2.91 $ 2.47
Oil (per bbl).......................................................... $ 26.84 $ 20.92 $ 13.40
</TABLE>
Reserve estimates are imprecise and may be expected to change as
additional information becomes available. Furthermore, estimates of oil and
natural gas reserves, of necessity, are projections based on engineering data,
and there are uncertainties inherent in the interpretation of this data as well
as the projection of future rates of production and the timing of development
expenditures. Reservoir engineering is a subjective process of estimating
underground accumulations of oil and natural gas that cannot be measured in an
exact way, and the accuracy of any reserve estimate is a function of the quality
of available data and of engineering and geological interpretation and judgment.
Reserve reports of other engineers might differ from the reports of Wright &
Company. Results of drilling, testing and production subsequent to the date of
the estimate may justify revision of this estimate. Future prices received from
the sale of natural gas and oil may be different from those used by Wright &
Company in preparing its reports. The amounts and timing of future operating and
development costs may also differ from those used. Accordingly, we cannot assure
you that the reserves set forth in the following tables will ultimately be
produced nor can we assure you that the proved undeveloped reserves will be
developed within the periods anticipated. You should not construe the discounted
future net cash inflows as representative of the fair market value of our proved
natural gas and oil properties. Discounted future net cash inflows are based
upon projected cash inflows which do not provide for changes in natural gas and
oil prices or for escalation of expenses and capital costs. The meaningfulness
of these estimates is highly dependent upon the accuracy of the assumptions upon
which they were based.
All natural gas reserves are evaluated at constant temperature and
pressure, which can affect the measurement of natural gas reserves. We deducted
operating costs, development costs and some production-related and ad valorem
taxes in arriving at the estimated future cash flows. We made no provision for
income taxes, and based the estimates on operating methods and existing
conditions prevailing at the dates indicated above. We cannot assure you that
these estimates are accurate predictions of future net cash flows from natural
gas and oil reserves or their present value.
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For additional information concerning our natural gas and oil reserves
and estimates of future net revenues, see Note 19 of the notes to consolidated
financial statements included in this report.
<TABLE>
<CAPTION>
Proved Natural Gas and Oil Reserves
Years Ended September 30,
------------------------------------------
2000 1999 1998
-------- -------- --------
<S> <C> <C> <C>
Natural gas reserves (mmcf) (1):
Proved developed reserves ........................................... 74,333 66,216 49,868
Proved undeveloped reserves ......................................... 38,810 41,956 40,016
-------- -------- --------
Total proved reserves of natural gas ................................ 113,143 108,172 89,884
-------- -------- --------
Oil reserves (mbbl) (2):
Proved developed reserves ........................................... 1,767 1,685 573
Proved undeveloped reserves ......................................... -- -- --
-------- -------- --------
Total proved reserves of oil ........................................ 1,767 1,685 573
-------- -------- --------
Total proved reserves (mmcfe) (3): ..................................... 123,745 118,282 93,322
======== ======== ========
PV-10 estimate of cash flows of proved reserves (in thousands)
Proved developed reserves ........................................... $122,852 $ 66,134 $ 43,581
Proved undeveloped reserves ......................................... 17,929 9,083 5,570
-------- -------- --------
Total PV-10 estimate ............................................ $140,781 $ 75,217 $ 49,151
======== ======== ========
</TABLE>
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(1) "mmcf" means a million cubic feet.
(2) "mbbl" means a thousand barrels.
(3) "mmcfe" means a million cubic feet equivalent. Oil production is converted
to mcfe at the rate of six mcf per barrel.
Developed and Undeveloped Acreage
The following table sets forth information about our developed and
undeveloped natural gas and oil acreage as of September 30, 2000. The
information in this table includes our equity interest in acreage owned by
partnerships sponsored by us.
<TABLE>
<CAPTION>
Developed Acreage Undeveloped Acreage
------------------- --------------------
Gross Net Gross Net
-------- --------- -------- --------
<S> <C> <C> <C> <C>
Arkansas............................................... 2,560 403 - -
Kansas................................................. 160 20 - -
Kentucky............................................... 9,676 4,838 4,712 2,356
Louisiana.............................................. 1,819 206 - -
Mississippi............................................ 40 3 2,410 241
New York............................................... 22,454 16,840 13,379 13,379
Ohio................................................... 106,893 82,575 49,862 46,973
Oklahoma............................................... 4,883 715 1,470 147
Pennsylvania........................................... 52,170 51,701 94,009 94,009
Texas.................................................. 5,160 369 603 151
Utah................................................... 160 37 4,954 1,151
West Virginia............................................ 1,348 674 17,304 8,652
-------- --------- -------- --------
207,323 158,381 188,703 167,059
======== ========= ======== ========
</TABLE>
The terms of our oil and gas leases on our developed acreage generally
extend for the life of wells on our developed acreage, while the terms of our
oil and gas leases vary from less than one year to five years. Rentals of
approximately $394,000 were paid in fiscal 2000 to maintain our leases.
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We believe that we hold good and indefeasible title to our properties,
in accordance with standards generally accepted in the natural gas industry,
subject to exceptions stated in the opinions of counsel employed by us in the
various areas in which we conduct our activities; we do not believe that these
exceptions detract substantially from our use of any property. As is customary
in the natural gas industry, only a perfunctory title examination is conducted
at the time we acquire a property. Before we commence drilling operations, we
conduct an extensive title examination; curative work is performed with respect
to defects which we deem significant. We have obtained title examinations for
substantially all of our managed producing properties. No single property
represents a material portion of our holdings.
Our properties are subject to royalty, overriding royalty and other
outstanding interests customary in the industry. Our properties are also subject
to burdens such as liens incident to operating agreements, current taxes,
development obligations under natural gas and oil leases, farm-out arrangements
and other encumbrances, easements and restrictions. We do not believe that any
of these burdens will materially interfere with our use of our properties.
Financing Our Drilling Activities
Since our acquisition of Atlas America and Viking Resources, a
substantial portion of our capital resources for drilling operations have been
derived from our sponsored drilling partnerships. Accordingly, the amount of
development activities we undertake depends upon our ability to obtain investor
subscriptions to the partnerships. During fiscal 2000, our drilling
partnerships invested $39.9 million in drilling and completing wells, of which
we contributed $9.6 million. In fiscal 1999, drilling partnerships invested
$38.8 million in drilling and completing wells, of which we contributed $9.4
million.
Our drilling partnerships are generally structured so that, upon
formation of the partnership, we contribute leaseholds to the partnership, enter
into a drilling and well operating agreement and become the general or managing
partner of the partnership.
As general partner, we typically receive an interest in partnership net
revenues in proportion to our contributed capital (including the costs of leases
contributed), which increases as specified target levels of distributions to
investors are met. Our interests in partnerships formed during the past three
fiscal years range from 25.0% to 31.7%. We also receive monthly operating fees
of approximately $275 per well and monthly administrative fees of $75 per well.
Pipeline Operations
In February 2000, we sold substantially all of our pipeline systems to
Atlas Pipeline for $16.6 million in cash and 1,641,026 subordinated units of
limited partnership interest. As of September 30, 2000, our subordinated units
constituted a 51% interest in Atlas Pipeline. Atlas Pipeline Partners GP, LLC,
an indirect wholly-owned subsidiary of ours, is the general partner of Atlas
Pipeline and, on a consolidated basis, has a 2% interest in Atlas Pipeline.
Atlas Pipeline Partners GP manages the activities of Atlas Pipeline using Atlas
America and Viking Resources personnel who act as its officers and employees. At
September 30, 2000, Atlas Pipeline owned approximately 900 miles of intrastate
gathering systems located in Eastern Ohio, Western New York and Western
Pennsylvania, to which 3,013 natural gas wells were connected.
Our limited partnership interests are a special class of interest in
Atlas Pipeline under which our rights to distributions are subordinated to those
of the publicly-held common units. The subordination period extends until
December 31, 2004 and will continue beyond that date if financial tests
specified in the partnership agreement are not met. Our interests also include a
right to receive incentive distributions if the partnership meets or exceeds its
minimum quarterly distribution obligations to the common and subordinated units
as follows:
o of the first $.10 per unit available for distribution in excess of
the minimum quarterly distribution of $.42, 85% goes to all
unitholders (including to us as subordinated unitholders) and 15%
goes to us as general partner;
o of the next $.08 per unit available for distribution, 75% goes to
all unitholders and 25% goes to us as general partner, and
o after that, 50% goes to all unitholders and 50% goes to us as
general partner.
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In connection with our sale of the gathering systems to Atlas Pipeline,
we entered into agreements that:
o Require us to connect wells owned or controlled by us that are
within specified distances of Atlas Pipeline's gathering systems
to those gathering systems and to drill and connect a minimum of
225 wells (including wells drilled from January 1, 1999).
o Require us to provide stand-by construction financing to Atlas
Pipeline for gathering system extensions and additions to a
maximum of $1.5 million per year for five years.
o Require us to pay gathering fees to Atlas Pipeline for natural gas
gathered by the gathering systems equal to the greater of $.35 per
mcf ($.40 per mcf in certain instances) or 16% of the gross sales
price of the natural gas transport. For the quarter ended
September 30, 2000, these gathering fees averaged $.71 per mcf.
o Require us to support a minimum quarterly distribution by Atlas
Pipeline to holders of non-subordinated units of $0.42 per unit
(an aggregate of $1.68 per fiscal year) until February 2003. We
have established a letter of credit administered by PNC Bank to
support our obligation. The face amount of the letter of credit as
of September 30, 2000 is $5.7 million. The required face amount of
the letter of credit reduces $630,000 per quarter.
At September 30, 2000, we had drilled all of the required 225 wells. We
have not been required to provide any construction financing or distribution
support.
Sources and Availability of Raw Materials
We contract for drilling rigs and purchase goods necessary for the
drilling and completion of wells from a substantial number of drillers and
suppliers, none of which supplies a significant portion of our annual needs.
During fiscal 2000, we faced no shortage of these goods and services. We
anticipate that natural gas price increases that have occurred after the end of
fiscal 2000 may increase the demand for drilling rigs and other goods. This may
result in an increase in our costs, decreased availability of rigs or goods, or
both which could adversely affect our energy operations.
Major Customers
During fiscal 2000, gas sales to three purchasers accounted for 37%,
11% and 11%, respectively, of our total production revenues. Also during fiscal
2000, oil sales to one purchaser accounted for 17% of such revenues. During
fiscal 1999, gas sales to two purchasers accounted for 26% and 14%,
respectively, and during fiscal 1998 such sales to two purchasers accounted for
35% and 15% respectively.
Competition
The oil and gas business is intensely competitive in all of its
aspects. Competition arises not only from numerous domestic and foreign sources
of natural gas and oil but also from other industries that supply alternative
sources of energy. Moreover, competition is intense for the acquisition of
leases considered favorable for the development of natural gas and oil in
commercial quantities. Product availability and price are the principal means of
competition in selling oil and natural gas. Many of our competitors possess
greater financial resources than ours. While it is impossible for us to
accurately determine our comparative industry position, we do not consider our
operations to be a significant factor in the industry.
Markets
The availability of a ready market for natural gas and oil produced by
us, and the price obtained, will depend upon numerous factors beyond our
control, including the extent of domestic production, import of foreign natural
gas and oil, political instability in oil and gas producing countries and
regions, market demand, the effect of federal regulation on the sale of natural
gas and oil in interstate commerce, other governmental regulation of the
production and transportation of natural gas and oil and the proximity,
availability and capacity of pipelines and other required facilities. Currently,
there appears to be at least a near-term imbalance between the supply of natural
gas and consumer demand. This imbalance has caused substantial increases in the
current price of natural gas through December 15, 2000. We cannot predict
whether or for how long these conditions will last, or their impact on our
business strategy of acquiring additional natural gas properties and energy
companies.
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Governmental Regulation
Our energy business and the energy industry in general are heavily
regulated, including regulation of production, environmental quality and
pollution control, and pipeline construction and operation. State and federal
regulations generally are intended to prevent waste, protect rights to produce
natural gas and oil between owners in a common reservoir and control
contamination of the environment. Failure to comply with regulatory requirements
can result in substantial fines and other penalties. We believe that we are in
substantial compliance with applicable regulatory requirements. The following
discussion of the regulation of the United States energy industry is not
intended to constitute a complete discussion of the various statutes, rules,
regulations and environmental orders to which our operations may be subject.
Regulation of Exploration and Production. Many states require permits
for drilling operations, drilling bonds and reports concerning operations, and
impose requirements concerning the location of wells, the method of drilling and
casing wells, the surface use and restoration of properties on which wells are
drilled, the plugging and abandoning of wells and the disposal of fluids used in
connection with operations. Many states also impose various conservation
requirements, including regulation of the size of drilling and spacing (or
proration) units, the density of wells which may be drilled and the unitization
or pooling of properties. In this regard, some states allow the forced pooling
or integration of tracts to facilitate exploration while other states rely
primarily or exclusively on voluntary pooling of lands and leases. In areas
where pooling is voluntary, it may be more difficult to form units and,
therefore, more difficult to develop a project if the operator owns less than
100% of the leasehold. In addition, some state conservation laws establish
requirements regarding production rates and generally prohibit the venting or
flaring of natural gas. The effect of these regulations may limit the amount we
can produce and may limit the number of wells or the locations at which we can
drill. The regulatory burden on the energy industry increases our costs of doing
business and, consequently, affects our profitability. Inasmuch as such laws and
regulations are frequently expanded, amended and reinterpreted, we are unable to
predict the future cost or impact of complying with such regulations.
Regulation of Pipelines. While natural gas pipelines generally are
subject to regulation by the Federal Energy Regulatory Commission under the
Natural Gas Act of 1938, because Atlas Pipeline's individual gathering systems
perform primarily a gathering function, as opposed to the transportation of
natural gas in interstate commerce, Atlas Pipeline believes that it is not
subject to regulation under the Natural Gas Act. However, Atlas Pipeline
delivers a significant portion of the natural gas it transports to interstate
pipelines subject to FERC regulation. The regulation principally involves
transportation rates and service conditions which affect revenues we receive for
our natural gas production. Through a series of initiatives by FERC, the
interstate natural gas transportation and marketing system has been
substantially restructured to increase competition. In particular, in Order No.
636, FERC required that interstate pipelines provide transportation separate, or
"unbundled," from their sales activities, and required that interstate pipelines
provide transportation on an open access basis that is equal for all natural gas
suppliers. Although Order No. 636 does not directly regulate our production and
marketing activities, it does affect how buyers and sellers gain access to the
necessary transportation facilities and how we and our competitors sell natural
gas in the marketplace. The courts have largely affirmed the significant
features of Order No. 636 and the numerous related orders pertaining to
individual pipelines, although some appeals remain pending and FERC continues to
review and modify its regulations regarding the transportation of natural gas.
For example, FERC has recently begun a broad review of its transportation
regulations, including how its regulations operate in conjunction with state
proposals for retail natural gas marketing restructuring, whether to eliminate
cost-of-service based rates for short-term transportation, whether to allocate
all short-term capacity on the basis of competitive auctions, and whether
changes to its long-term transportation service policies may be appropriate to
avoid a market bias toward short-term contracts. We cannot predict what action
FERC will take on these matters, nor can we accurately predict whether FERC's
actions will achieve the goal of increasing competition in markets in which our
natural gas is sold. However, we do not believe that any action taken will
affect us in a way that materially differs from the way it affects other natural
gas produces, gatherers and marketers.
State-level regulation for pipeline operations in Ohio, New York and
Pennsylvania is generally through the Public Utility Commission of Ohio, the New
York Public Service Commission and the Pennsylvania Public Utilities Commission,
respectively. Atlas Pipeline has been granted an exemption from regulation by
the Public Utility Commission of Ohio, and is not subject to New York or
Pennsylvania regulation since it does not provide service to the public
generally.
11
<PAGE>
Environmental and Safety Regulation. Under the Comprehensive
Environmental Response, Compensation and Liability Act, the Toxic Substances
Control Act, the Resource Conservation and Recovery Act, the Oil Pollution Act
of 1990, the Clean Air Act, and other federal and state laws relating to the
environment, owners and operators of wells producing natural gas or oil, and
pipelines, can be liable for fines, penalties and clean-up costs for pollution
caused by the wells or the pipelines. Moreover, the owners' or operators'
liability can extend to pollution costs from situations that occurred prior to
their acquisition of the assets. Natural gas pipelines are also subject to
safety regulation under the Natural Gas Pipeline Safety Act of 1968 and the
Pipeline Safety Act of 1992 which, among other things, dictate the type of
pipeline, quality of pipeline, depth, methods of welding and other
construction-related standards. The state public utility regulators referenced
above have either adopted federal standards or promulgated their own safety
requirements consistent with the federal regulations.
We do not anticipate that we will be required in the near future to
expend amounts that are material in relation to our revenues by reason of
environmental laws and regulations, but inasmuch as these laws and regulations
change frequently, we cannot predict the ultimate cost of compliance. We cannot
assure you that more stringent laws and regulations protecting the environment
will not be adopted or that we will not otherwise incur material expenses in
connection with environmental laws and regulations in the future.
Energy Technology
We own a 50% interest in Optiron Corporation, with a right, through
conversion of a note from Optiron, to increase that interest to 68.5%, in
Optiron Corporation. Optiron's business, which focuses on providing the energy
industry with information management software, currently offers one principal
product, the ReadiSystem(TM) (Retail Energy Automated Data Integration). The
ReadiSystem(TM) consolidates all billing and customer account information into a
single source and features online bill paying for customers, flexible invoice
generation, account and payment history tracking, management of payment
adjustments, delinquent customer tracking and production of collection notices
and service/work order dispatching and tracking. The technology also provides
accounting and management reporting functions. Although originally designed for
natural gas and electric utility companies, we believe that the ReadiSystem(TM)
can be used by other mass market distribution companies such as
telecommunications and water utility companies.
Real Estate Finance
General
From fiscal 1991 through fiscal 1999, we sought to purchase and resolve
troubled commercial real estate loans at discounts to their outstanding loan
balances and the appraised value of their underlying properties. During fiscal
2000, we determined to concentrate our real estate finance activities on
managing our existing loan portfolio and did not acquire any new loans. As part
of the management process, we anticipate that we may sell selected portfolio
loans in appropriate circumstances.
At September 30, 2000, our loan portfolio consisted of 38 loans with
aggregate outstanding loan balances of $691.4 million. These loans were acquired
at an investment cost of $447.3 million, including subsequent advances. During
the fiscal years ended September 30, 2000, 1999 and 1998, the yield on our net
investment in our portfolio loans equaled 9%, 22% and 40%, respectively,
including gains on sale of senior lien interests in, and gains, if any,
resulting from refinancing of, the loans. Gross profit from our real estate
finance activities for the same periods was $11.8 million, $35.3 million and
$43.7 million, respectively. For these purposes, we calculate gross profit as
revenues from loan activities minus costs, including interest, provision for
possible losses and less depreciation and amortization, without allocation of
corporate overhead.
We seek to reduce the amount of our capital invested in portfolio
loans, and to enhance our returns, through borrower refinancing of the
properties underlying our loans. Before January 1, 1999, we also sought to sell
senior lien interests; since that date, we have sought to structure our senior
lien transactions as financings rather than sales. See "Management's Discussion
and Analysis of Financial Condition and Results of Operations - Results of
12
<PAGE>
Operations: Real Estate Finance." During fiscal 2000, borrowers refinanced three
loans, incurring $129.5 million in new senior lien indebtedness. At September
30, 2000, senior lenders held outstanding obligations of $351.9 million.
Pursuant to agreements with most borrowers, we generally retain the excess of
operating cash flow over required debt service on senior lien obligations as
debt service on the outstanding balance of our loans.
As a result of the troubled nature of our portfolio loans at the time
of their acquisition, they are typically subject to forbearance agreements
pursuant to which we defer foreclosure or other action on a loan so long as the
terms of the agreement are met. Generally, our forbearance agreements require:
o payment of all revenues from the property into an operating
account controlled by us or our managing agent;
o payment of all property expenses (including debt service, taxes,
operational expenses and maintenance costs) from the operating
account, after our review and approval;
o receipt by us of specified minimum monthly payments;
o retention by us of all cash flow above the minimum monthly payment
and application to accrued but unpaid debt service;
o appointment of a property manager acceptable to us;
o receipt of our approval before concluding any material contract or
commercial lease; and
o submission of monthly cash flow statements and occupancy reports.
We may alter these arrangements in appropriate circumstances. Where a
borrower has refinanced a portfolio loan (or where we acquired a loan subject to
existing senior debt), we may agree that the revenues be paid to an account
controlled by the senior lienor, with the excess over amounts payable to the
senior lienor being paid directly to us. As of September 30, 2000, revenues are
being paid directly to senior lienholders with respect to one loan (loan 7 in
the table under "Loan Status,"). Where the property is being managed by
Brandywine Construction and Management, Inc., a property manager affiliated with
us, we may direct that property revenues be paid to Brandywine as our managing
agent. As of September 30, 2000, revenues are being paid to Brandywine with
respect to two loans (loans 25 and 30). Where we believe that operating problems
with respect to an underlying property have been substantially resolved, we may
permit the borrower to retain revenues and pay property expenses directly. As of
September 30, 2000, we permitted borrowers with respect to seven loans (loans
24, 31, 32, 41, 47, 50 and 51) to do so.
As a result of the requirement of retaining a property management firm
acceptable to us, Brandywine has assumed responsibility for supervisory and, in
many cases, day-to-day management of the underlying properties with respect to
substantially all of our portfolio loans as of September 30, 2000. In ten
instances, the president of Brandywine (or an entity affiliated with him) has
also acted as the general partner, president or trustee of the borrower.
The minimum payments required under a forbearance agreement are
normally materially less than the debt service payments called for by the
original terms of the loan. The difference between the minimum required payments
under the forbearance agreement and the payments called for by the original loan
terms continues to accrue but, except for amounts recognized as an accretion of
discount, are not recognized as revenue until actually paid. See "Business -
Real Estate Finance: Accounting for Discounted Loans".
When we refinance or sell a senior loan interest, the forbearance
agreement typically will remain in effect, subject to any modifications required
by the refinance lender or senior lien holder.
At the end of a forbearance agreement, the borrower must pay the loan
in full. The borrower's ability to do so, however, will depend upon a number of
factors, including prevailing conditions at the underlying property, the state
of real estate and financial markets (generally and as regards to the particular
property), and general economic conditions. If the borrower does not or cannot
repay the loan, we anticipate it will seek to sell the property underlying the
13
<PAGE>
loan or otherwise liquidate the loan. Alternatively, where we already control
all of the cash flow and other economic benefits from the property, or where we
believe that the cost of foreclosure is more than any benefit we could obtain
from foreclosure, we may continue our forbearance.
Business Strategy
We seek to increase the income and value of the properties underlying
our portfolio loans. To achieve our goal, we employ experienced property
managers either to manage the properties directly or to supervise local property
managers. We encourage our managers to take an active management role to
increase rents, improve property conditions and, where possible, achieve cost
efficiencies in property operations. We may sell portfolio loans as appropriate
opportunities arise.
Refinancings
In refinancings, we reduce the amount outstanding on our loan by the
amount of net refinancing proceeds and either convert the outstanding balance of
the original note into the stated principal amount of an amended note on the
same terms as the original note, or retain the original loan obligation as paid
down by the amount of refinance proceeds we receive. The interest rate on the
refinancing is typically less than the interest rate on our retained interest.
Before January 1, 1999, we sought to sell senior lien interests in our
loans. Although we made a strategic decision to structure our transactions after
that date as financings, we retain the right to sell a senior interest in a loan
where it is economically advantageous to do so. When we sell a senior lien
interest, the outstanding balance of our loan at the time of sale remains
outstanding, including as a part of that balance the amount of the senior lien
interest. Thus, our remaining interest effectively "wraps around" the senior
lien interest.
As of September 30, 2000, senior lien interests with an aggregate
balance of $12.0 million relating to seven portfolio loans obligate us, in the
event of a default on a loan, to replace the loan with a performing loan. One
other senior lien interest obligates us, upon its maturity in fiscal 2003, to
repurchase the senior lien interest (if not already paid off) at a price equal
to the outstanding balance of the senior lien interest plus accrued interest.
The aggregate outstanding balance will be $2.5 million at maturity, assuming all
debt service payments have been made. See "Business - Real Estate Finance: Loan
Status."
After a refinancing or sale of a senior lien interest, our retained
interest will usually be secured by a subordinate lien on the property. In some
situations, however, our retained interest may not be formally secured by a
mortgage because of conditions imposed by the senior lender. In these
situations, we may be protected by a judgment lien, an unrecorded deed-in-lieu
of foreclosure, the borrower's covenant not to further encumber the property
without our consent, a pledge of the borrower's equity or a similar device. Our
retained interests in seven loans aggregating $31.0 million and constituting
16.9%, by book value, of our loan portfolio as of September 30, 2000 are not
secured by a lien on the underlying property.
Loan Status
At September 30, 2000, our loan portfolio consisted of 38 loans. We
acquired 32 of these loans as first mortgage liens and six loans as junior lien
obligations. As of September 30, 2000:
o We had sold senior lien interests in 16 loans, including senior
interests in three loans initially acquired as junior lien loans.
o We had purchased senior lien interests in two loans initially
acquired as junior lien loans.
o Borrowers with respect to 17 loans had obtained refinancing.
After these sales, acquisitions and refinancings, we hold subordinated
interests in 32 loans.
The following table sets forth information about our portfolio loans,
grouped by the type of property underlying the loans, as of September 30, 2000.
14
<PAGE>
<TABLE>
<CAPTION>
Loan Type of
Number Property Location Seller/Originator
------ -------- -------- -----------------
<S> <C> <C> <C>
Office Properties
005 Office Pennsylvania Shawmut Bank(8)
011(10) Office Washington, D.C. First Union Bank(8)
014 Office Washington, D.C. Nomura/Cargill/Eastdil Realty(11)
020 Office New Jersey Cargill/Eastdil Realty(11)
026(10) Office Pennsylvania The Metropolitan Fund/First Trust Bank
029(10) Office Pennsylvania Castine Associates, L.P.(12)
035(14)(10) Office Pennsylvania Hudson United Bank (8)
036 Office North Carolina Union Labor Life Insurance Co.
044(16) Office Washington, D.C. Dai-Ichi Kangyo Bank
046 Office Pennsylvania Corestates Bank, N.A.
048(18) Office Pennsylvania Institutional Property Assets
049(19) Office Maryland Bre/Maryland
053(20)(32) Office Washington, D.C. Sumitomo Bank, Limited
Office Totals
Multifamily Properties
001(21) Multifamily Pennsylvania Alpha Petroleum Pension Fund
003 Multifamily New Jersey RAM Enterprises/Glenn Industries Pension Plan
015 Condo/Multifamily North Carolina First Bank/ SouthTrust Bank
021(10)(22) Multifamily Pennsylvania Bruin Holdings/Berkley Federal Savings Bank
022 Multifamily Pennsylvania FirsTrust FSB
024 Multifamily Pennsylvania U.S. Dept. of Housing and Urban Development
028 Condo/Multifamily North Carolina First Bank/South Trust Bank
031 Multifamily Connecticut John Hancock Mutual Life Ins. Co.
032(16) Multifamily New Jersey John Hancock Mutual Life Ins. Co.
034 Multifamily Pennsylvania Resource America, Inc.
037(31) Multifamily Florida Howe, Soloman & Hall Financial, Inc.
041 Multifamily Connecticut J.E. Robert Companies
042 Multifamily Pennsylvania Fannie Mae(23)
043(24) Multifamily Pennsylvania Downingtown National Bank
047(10) Multifamily New Jersey Credit Suisse First Boston Mortgage Capital, Inc.
050 Multifamily Illinois J.E. Roberts Companies
051 Multifamily Illinois J.E. Roberts Companies
054(26) Multifamily Connecticut Resource America, Inc.
Multifamily Totals
Commercial Properties
007 Single User/Retail Minnesota Prudential Insurance, Alpha Petroleum Pension Fund
013(10)(27) Single User/CommercialCalifornia California Federal Bank, FSB
017(10)(28) Single User/Retail West Virginia Triester Investments(8)
018 Single User/Retail California Emigrant Savings Bank/ Walter R. Samuels & Jay Furman(29)
033 Single User/Retail Virginia Brambilla, LTD
Commercial Totals
Hotel Properties
025 Hotel/Commercial Georgia Bankers Trust Co.
030 Hotel Nebraska CNA Insurance
Hotel Totals
</TABLE>
<PAGE>
<TABLE>
<CAPTION>
Fiscal Value
Year Outstanding of Property
Loan Loan Underlying
Acquired Receivable(1) Loan(2)
-------- ------------- -------
<S> <C> <C> <C>
Office Properties
1993 $ 8,425,072 $ 1,700,000
1995 1,691,890 1,500,000
1995 19,872,000 14,000,000
1996 8,082,379 4,600,000
1997 9,801,128 5,000,000
1997 8,767,634 4,025,000
1997 2,536,126 2,550,000
1997 4,978,742 4,150,000
1998 107,214,122 98,000,000
1998 6,061,494 5,300,000
1998 68,601,530 65,000,000
1998 103,038,924 99,000,000
1999 128,452,325 86,700,000
------------ ------------
Office Totals $477,523,366 $391,525,000
------------ ------------
Multifamily Properties
1991&99 9,564,294 5,350,000
1993 3,212,109 1,350,000
1995&97 5,302,906 5,019,500
1996&97 7,569,827 3,868,130
1996 6,080,003 4,300,000
1996 3,326,094 3,800,000
1997 505,795 455,500
1997 12,257,174 12,500,000
1997 12,854,851 13,278,000
1997 426,352 450,000
1997 8,628,535 3,500,000
1998 20,987,573 21,000,000
1998 6,336,986 5,740,000
1998 2,177,130 2,275,000
1998 2,629,051 3,375,000
1998 50,306,758 23,400,000
1998 24,612,352 24,000,000
1999 1,600,000 2,000,000
------------ ------------
Multifamily Totals $178,377,790 $135,661,130
------------ ------------
Commercial Properties
1993 5,049,726 2,545,000
1994 2,792,769 2,600,000
1996 1,627,864 1,900,000
1996 3,062,264 6,400,000
1997&99 4,657,837 2,650,000
------------ -----------
Commercial Totals $ 17,190,460 $ 16,095,000
------------ ------------
Hotel Properties
1997 7,512,818 8,000,000
1997 10,792,885 6,300,000
------------ -----------
Hotel Totals $ 18,305,703 $ 14,300,000
------------ ------------
Balance as of September 30, 2000 $691,397,319 $557,581,130
============ ============
</TABLE>
15
<PAGE>
<TABLE>
<CAPTION>
Maturity
Resource America's of Loan/
Ratio of Proceeds from Net Interest in Expiration
Cost of Refinancing or Outstanding of
Cost of Investment to Sale of Senior Net Book Value Loan Forbearance
Investment(3) Appraised Value Lien Interests Investment(4) of Investment(5) Receivables(6) Agreement(7)
------------- --------------- ---------------- ------------- ---------------- -------------- ------------
<S> <C> <C> <C> <C> <C> <C> <C>
$ 1,348,851 79% $ 940,000(9) $ 408,851 $ 952,562 $ 7,585,072 02/07/01
1,189,904 79% 660,000(9) 529,904 762,172 1,006,890 06/01/00(12a)
12,539,475 90% 6,487,000 6,052,475 7,546,955 13,231,989 11/30/98(12a)
3,317,878 72% 2,562,000 755,878 2,502,670 5,731,199 02/07/01
2,609,410 52% 2,231,693 377,717 1,824,851 7,674,329 09/30/03
3,088,476 77% 2,625,000(13) 463,476 1,385,290 6,219,579 07/01/02
1,841,889 72% 1,750,000(15) 91,889 789,907 810,107 09/25/02
3,094,950 75% 1,750,000(15) 1,344,950 2,008,853 3,254,241 12/31/11
79,990,948 82% 71,500,000(17) 8,490,948 20,692,832 27,349,128 08/01/08
3,995,859 75% 0 3,995,859 4,054,704 6,061,494 09/30/14
60,620,417 93% 44,000,000 16,620,417 19,612,890 25,639,531 08/01/08
90,190,604 91% 60,000,000 30,190,604 38,282,501 43,038,924 04/01/11
70,612,010 81% 65,000,000 5,612,010 11,769,066 55,167,726 01/15/06
------------- ------------ ------------- ------------ ------------
$ 334,440,671 $259,505,693 $ 74,934,978 $112,185,253 $202,770,209
------------- ------------ ------------- ------------ ------------
4,763,730 89% 0 4,763,730 5,253,412 9,564,294 08/01/21
1,122,353 83% 627,000 495,353 102,212 2,616,505 01/01/03
2,079,434 41% 3,000,000 (920,566) 2,355,734 2,362,602 03/23/09
2,531,574 65% 3,695,674(9) (15) (1,164,100) 757,219 4,719,242 07/01/16
2,471,782 57% 3,435,000 (963,218) 986,849 2,682,874 05/03/29
2,743,136 72% 2,318,750 424,386 795,627 896,073 11/01/22
451,510 99% 0 451,510 485,820 505,795 03/23/09
4,788,642 38% 9,375,000 (4,586,358) 1,628,209 3,007,271 10/14/14
7,404,156 56% 6,000,000(17) 1,404,156 5,410,620 7,410,085 09/01/05
401,500 89% 0 401,500 424,183 426,352 10/01/02
2,807,945 80% 2,096,000(9) 711,945 1,206,266 6,532,535 06/01/10
14,733,084 70% 14,100,000 633,084 7,176,034 7,130,129 01/01/09
4,287,056 75% 4,450,000 (162,944) 1,290,701 1,889,738 07/12/30
1,589,381 70% 1,000,000(25) 589,381 1,044,588 1,177,130 07/01/02
2,656,969 79% 1,800,000(15) 856,969 1,019,572 846,098 02/01/05
18,654,699 80% 15,350,000 3,304,699 7,921,612 35,097,805 09/30/09
17,375,252 72% 0 17,375,252 19,281,718 24,612,352 09/30/02
1,140,666 57% 0 1,140,666 1,600,000 1,600,000 04/01/11
------------- ------------ ------------- ------------ ------------
$ 92,002,869 $ 67,247,424 $ 24,755,445 $ 58,740,376 $113,076,880
------------- ------------ ------------- ------------ ------------
1,359,055 53% 2,099,000 (739,945) 719,958 3,095,160 12/31/14
1,701,049 65% 1,975,000(9) (273,951) 515,718 792,769 05/01/01
894,660 47% 1,000,000(15) (105,340) 567,741 652,753 12/31/16
2,427,268 38% 1,969,000(9) 458,268 975,739 1,093,264
12/01/00(12a)
2,425,090 92% 1,800,000(15) 625,090 951,239 2,957,034 02/01/21
------------- ------------ -------------- ------------ ------------
$ 8,807,122 $ 8,843,000 $ (35,878) $ 3,730,395 $ 8,590,980
------------- ------------ -------------- ------------ ------------
7,062,222 88% 875,000(30) 6,187,222 7,900,909 6,637,818 12/31/15
5,022,695 80% 2,400,000(9) 2,622,695 3,383,314 8,392,885 09/30/02
------------- ------------ -------------- ------------ ------------
$ 12,084,917 $ 3,275,000 $ 8,809,917 $ 11,284,223 $ 15,030,703
------------- ------------ ------------- ------------ ------------
$ 447,335,579 $338,871,117 $ 108,464,462 $185,940,247 $339,468,772
============= ============ ============= ============ ============
</TABLE>
16
<PAGE>
(1) Consists of the original stated or face value of the obligation plus
interest and the amount of the senior lien interest at September 30, 2000.
(2) We generally obtain appraisals on each of the properties underlying our
portfolio loans at least once every three years. Accordingly, appraisal
dates range from 1997 - 2000, except with respect to loan 3. However,
after the end of fiscal 2000, the property underlying loan 3 was sold and
our loan was repaid.
(3) Consists of the original cost of our investment, including the amount of
any senior lien obligation to which the property remains subject, plus
subsequent advances, but excludes the proceeds to us from the sale of
senior lien interests or borrower refinancings.
(4) Represents the unrecovered costs of our investment, calculated as the cash
investment made in acquiring the loan plus subsequent advances, less cash
received from the sale of a senior lien interest in or borrower
refinancing of the loan. Negative amounts represent our receipt of
proceeds from the sale of senior lien interests or borrower refinancings
in excess of our investment.
(5) Represents the book cost of our investment after accretion of discount and
allocation of gains from the sale of a senior lien interest in, or
borrower refinancing of the loan, but excludes an allowance for possible
losses of $2.0 million. For a discussion of accretion of discount and
allocation of gains, see "- Accounting for Discounted Loans."
(6) Consists of the amount set forth in the column "Outstanding Loan
Receivable" less senior lien interests at September 30, 2000.
(7) With respect to loans 7, 14, 17, 25, 27, 30, 31, 32, 34, 37, 42, 44, 46,
47, 48, 49, 53 and 54, the date given is for the maturity of our interest
in the loan. For loan 43, the date given is the expiration date of the
forbearance agreement with respect to the loan in the original principal
amount of $404,026 (see Note (24) below). For the remaining loans, the
date given is the expiration date of the related forbearance agreement.
(8) Successor by merger to the seller.
(9) Senior lien interest sold subject to the right of the holder, upon
default, to require us to substitute a performing loan.
(10) With respect to loans 13, 17 and 26, the president of Brandywine is the
general partner of the borrower; with respect to loan 29, he is the
general partner for the sole limited partner of the borrower; and with
respect to loan 11, he is the president of the borrower. With respect to
loan 35, he is the president of the general partner of the borrower. In
addition, with respect to loan 21, which consists of 22 separate mortgage
loans on 36 individual condominium units in a single building, the
president of Brandywine is the trustee of one borrower (for 11 mortgage
loans) and the president of the general partner of another borrower (for
four mortgage loans).
<PAGE>
(11) Seller was a partnership of these entities.
(12) From 1993 to October 1997, one of our executive officers served as the
general partner of the seller.
(12a) We are attempting to maximize our return by selling the properties
underlying these loans in cooperation with the borrowers. In the meantime,
we continue to forbear from exercising our remedies with respect to these
loans since we believe we receive all of the economic benefit from the
properties without having to incur the expense of foreclosure.
(13) Represents a senior lien interest sold to an institution. We have the
obligation to repurchase this interest on or after March 31, 2003.
(14) The borrower is a limited partnership formed in 1991. The general partner
of the partnership is owned by the president of Brandywine; our chairman
and his wife beneficially own a 49% limited partnership interest in the
partnership and our former executive vice president and vice chairman
beneficially owns a 1% limited partnership interest.
(15) Senior lien interest sold subject to the right of the holder, upon default
by borrower, to require us to substitute a performing loan.
(16) See note 3 to Consolidated Financial Statements, "- Relationships with
RAIT."
(17) A senior lien interest was sold to RAIT. See "Business - Real Estate
Finance: Sponsorship of Real Estate Investment Trust."
(18) The borrower is a partnership in which Brandywine owns an 11% interest and
RAIT owns an 89% interest.
(19) The borrower is a limited liability company whose manager is a corporation
of which our former vice chairman and current director of the Company is
the sole shareholder, officer and director. The chairman, two directors of
the Company and the president of Brandywine are equal limited partners
(25% each) of a partnership that is a 59% limited partner of the managing
partner which has a (99)% interest in the sole member of the borrower.
(20) We jointly purchased this loan with RAIT, which contributed $10.0 million
of the purchase price. RAIT's interest was subsequently paid down to $8.3
million.
17
<PAGE>
(21) We acquired a first mortgage loan at face value from RAIT. The loan is
secured by property in which we have held a subordinate interest since
1991.
(22) Consists of 22 separate mortgage loans on 36 individual condominium units
in a single building. Nine of such loans are due July 1, 2016, nine are
due January 1, 2015, one is due October 1, 2007, one is due July 7, 2003,
one is due May 5, 2001 and one due October 9, 2001. The president of
Brandywine and his wife own general and limited partnership interests in
the borrowers of some of these loans. The borrower with respect to other
loans is a trust, the trustee of which is the president of Brandywine and
the beneficiary of which is a limited partnership for which one of our
directors is general partner.
(23) Original lending institution.
(24) Consists of two related loans to one borrower secured by a single property
in the original principal amounts of $1.6 million and $404,026.
(25) Senior lien interest sold to a limited partnership in which our chairman
and our former executive vice president and vice chairman and current
director beneficially own a 14.4% limited partnership interest.
(26) Construction loan with a maximum borrowing of $1.6 million.
(27) Our chairman and his wife beneficially own a 40% limited partnership
interest in the borrower.
(28) Consists of a series of notes becoming due yearly through December 31,
2016.
(29) Amounts advanced by us were used in part to directly repay the loan of
Emigrant Savings Bank; the balance was applied to purchase a note held by
Messrs. Samuels and Furman.
(30) In May 1999, we borrowed $875,000 from a limited partnership in which our
chairman and our former executive vice president and vice chairman and
current director beneficially own a 22% limited partnership interest. The
loan is secured by a first priority lien on loan 25. Accordingly, the debt
is included in the cost of investment carried on our books.
(31) The borrower is a limited partnership of which our former executive vice
president and vice chairman and current director is the president of the
general partner and our chairman, two of our directors and the president
of Brandywine are equal limited partners of the borrower.
(32) One of our subsidiaries is the manager of the borrower.
18
<PAGE>
The following table sets forth average monthly cash flow from the
properties underlying our portfolio loans, average monthly debt service payable
to senior lienholders and refinance lenders, average monthly payments with
respect to our retained interest and cash flow coverage (the ratio of cash flow
from the properties to debt service payable on senior lien interests) for the
three months ended September 30, 2000. The loans are grouped by the type of
property underlying the loans.
<TABLE>
<CAPTION>
Average Monthly Average Monthly
Interest Principal
Payment on Debt Payment on Debt Average Monthly
Average Service on Service on Payment to
Loan Monthly Cash Flow Refinancing or Refinancing or Resource America's Cash Flow
Number from Property(1) Senior Lien Interests Senior Lien Interest Interest Coverage
------ ----------------- ---------------------- --------------------- ------------------ ---------
Office
------
<S> <C> <C> <C> <C> <C> <C>
005 $ 7,593 $ 6,825 $ 0 $ 768 1.11
011 9,572 5,566 0 4,006 1.72
014 76,098 44,510 18,223 13,365 1.21
020 41,560 17,903 1,624 22,033 2.13
026 31,885 17,694 3,906 10,285 1.48
029 31,695 19,419 2,835 9,441 1.42
035 24,914 14,408 1,494 9,012 1.57
036(5) 3,604 14,396 1,506 (12,298) N/A
044 716,096 489,013 67,088 159,995 1.29
046 31,900 0 0 31,900 N/A
048 393,288 245,728 42,586 104,974 1.36
049 744,170 378,000 72,000 294,170 1.65
053 712,961 554,717 37,923 120,321 1.20
----------- ----------- ----------- ----------
Office Totals $ 2,825,336 $ 1,808,180 $ 249,184 $ 767,973 1.37
=========== =========== =========== ==========
Multifamily
-----------
001 $ 26,473 $ 0 $ 0 $ 26,473 N/A
003 6,296 4,735 1,323 238 1.04
015&028(2)(6) 21,442 19,995 3,680 (2,233) N/A
021(4) 15,261 24,329 536 (9,604) N/A
022 27,744 22,045 2,623 3,076 1.12
024 25,926 15,804 2,158 7,964 1.44
031 85,355 60,034 10,901 14,420 1.20
032 105,407 54,927 23,878 26,602 1.34
034 3,422 0 0 3,422 N/A
037 25,630 17,030 0 8,600 1.50
041 132,500 86,115 13,490 32,895 1.33
042 55,267 22,424 2 752 30,091 2.20
043 12,096 8,343 0 3,753 1.45
047 17,876 14,883 1,474 1,519 1.09
050 147,916 100,854 11,137 35,925 1.32
051 77,292 0 0 77,292 N/A
054 18,085 0 0 18,085 N/A
----------- ----------- ----------- ----------
Multifamily Totals $ 803,988 $ 451,519 $ 73,951 $ 278,518 1.53
=========== =========== =========== ==========
Commercial
----------
007 $ 20,400 $ 14,423 $ 5,977 $ 0 1.00
013 25,023 15,833 0 9,190 1.58
017 10,690 8,142 945 1,603 1.18
018(3) 26,443 15,998 0 10,445 1.65
033 21,940 14,258 5,084 2,598 1.13
----------- ----------- ----------- ----------
Commercial Totals $ 104,496 $ 68,654 $ 12,006 $ 23,836 1.30
=========== =========== =========== ==========
Hotel
-----
025 $ 46,659 $ 7,292 $ 0 $ 39,367 6.40
030(7) 0 0 0 0 N/A
----------- ----------- ----------- ----------
Hotel Totals $ 46,659 $ 7,292 $ 0 $ 39,367 6.40
=========== =========== =========== ==========
Total Properties $ 3,780,479 $ 2,335,645 $ 335,141 $1,109,695 1.42
=========== =========== =========== ==========
</TABLE>
19
<PAGE>
(1) Cash flow consists of revenues from property operations less operating
expenses, including real estate and other taxes pertaining to the property
and its operations, and before depreciation, amortization and capital
expenditures.
(2) The properties underlying loans 15 and 28 are different condominium units
in the same building and, accordingly, are combined for cash flow purposes.
(3) Includes one-twelfth of an annual payment of $120,000 received in December
of each year.
(4) Loan 21 consists of 22 separate mortgage loans on 36 individual condominium
units. During fiscal 2000 we were repaid, and recorded gains on, four of
the units and held two units vacant in anticipation of future repayments.
Accordingly, cash flow from the property decreased while debt service on
refinancing or senior lien interests remained constant.
(5) In the quarter ending 12/30/99, the property underlying this loan lost its
biggest tenant, accounting for approximately 53% of the total square
footage. The space is marketed for lease and is currently unoccupied.
(6) The property underlying these loans is located in an area that has recently
seen an increase in construction of similar residential properties. Due to
the new construction in the area, the property's vacancy rate has
increased, consequently, cash flow has decreased.
(7) The property underlying the loan is a hotel property located in Omaha,
Nebraska. The forbearance agreement requires minimum monthly payments of
cash flows from the property based on net operating income. During fiscal
2000, there was a temporary economic decline in the Omaha market,
consequently, cash flows have been negatively impacted. We anticipate
resumption of cash flows within the next fiscal period.
Investments in Real Estate Ventures
In fiscal 1999, we became the owner of a hotel property in Savannah,
Georgia as a result of receiving a deed-in-lieu of foreclosure. Our carrying
cost in this property was $4.6 million at September 30, 2000. Also in fiscal
1999, the borrower with respect to an office property in Philadelphia,
Pennsylvania, exercised its right under the loan documents to satisfy its loan
by paying us $29.6 million in cash and giving us a 50% equity interest in the
property. Our carrying cost in this property is $11.4 million at September 30,
2000.
Accounting for Discounted Loans
We accrete the difference between our cost basis in a portfolio loan
and the sum of projected cash flows from the loan into interest income over the
estimated life of the loan using the interest method, which results in a level
rate of interest over the life of the loan. We review projected cash flow, which
include amounts realizable from the underlying property, on a quarterly basis.
Changes to projected cash flows reduce or increase the amounts accreted into
interest income over the remaining life of the loan.
We record our investments in portfolio loans at cost, which is
significantly discounted from the stated principal amount of, and accrued
interest and penalties (collectively, the face value) on the loans. This
discount from face value, as adjusted to give effect to refinancings and sales
of senior lien interests, totaled $156.5 million, $158.3 million and $139.7
million at September 30, 2000, 1999 and 1998, respectively. We review on a
quarterly basis the carrying value of our loans to determine whether it is
greater than the sum of the future projected cash flows. If we determine that
carrying value is greater, we provide an appropriate allowance through a charge
to operations. In establishing our allowance for possible losses, we also
consider the historic performance of our loan portfolio, characteristics of the
loans and their underlying properties, industry statistics and experience
regarding losses in similar loans, payment history on specific loans as well as
general economic conditions in the United States, in the borrower's geographic
area or in the borrower's (or its tenants') specific industries. For the year
ended September 30, 2000, we recorded a provision for possible losses of
$936,000, which increased our allowance for possible losses at September 30,
2000 to $2.0 million.
20
<PAGE>
Depending on the structure of the transaction, we can recognize gains
or losses on the sale of a senior lien interest in a loan. These gains and
losses are calculated by allocating our cost basis between the portion of the
loan sold and the portion retained based upon the fair value of those respective
portions on the date of sale. Gains resulting from the refinancing of a property
by its owners arise only when the financing proceeds exceed the carried cost of
our investment in the loan. Any gain recognized on a sale of a senior lien
interest or a refinancing is credited to income at the time of the sale or
refinancing.
Before January 1, 1999, most of our financing transactions involving
the sale of senior lien interests in our loans were structured to meet the
criteria for sale under generally accepted accounting principles. Thus, for
transactions that were completed before January 1, 1999, we recorded gains on
sale. Effective January 1, 1999, we made a strategic decision to structure
future transactions as financings. The cash flows available to us, which are
generally derived from the cash flows on the properties underlying our portfolio
loans were unaffected by the modification. The primary effect of the change is
that, instead of recognizing an immediate gain on the sale of a senior lien
interest, we retain our full investment in the loan on our books, recognize
interest income over the life of the loan, record as debt the proceeds from the
senior lien interest and recognize interest expense on that debt.
Sponsorship of Real Estate Investment Trust
We are the sponsor and a 14% shareholder of RAIT Investment Trust
("RAIT"), a real estate investment trust that began operations in January 1998.
RAIT acquires or originates commercial mortgage loans in situations that
generally do not conform to the underwriting standards of institutional lenders
or sources that provide financing through securitization. Betsy Z. Cohen, spouse
of our chairman, chief executive officer and president, Edward E. Cohen, and
mother of Daniel G. Cohen, one of our directors, is the chairman and chief
executive officer of RAIT. Jonathan Z. Cohen, another son of Mr. and Mrs. Cohen
and one of our senior vice presidents, is our nominee to RAIT's board of
trustees and is the secretary of RAIT. Scott F. Schaeffer, president of RAIT, is
one of our directors; Mr. Schaeffer was, until September 13, 2000, our executive
vice president and vice chairman of our Board of Directors.
Our relationship with RAIT is subject to the following:
o So long as we own 5% or more of RAIT's common shares, we will have
the right to nominate one person to RAIT's board of trustees.
o RAIT's declaration of trust permits it to acquire loans from us to
a maximum of 30% of RAIT's investments (on a cost basis),
excluding investments acquired from us at the time of RAIT's
initial public offering.
o If we sponsor a real estate investment trust with investment
objectives similar to those of RAIT, our representative on RAIT's
board of trustees must recuse himself or herself from considering
or voting upon matters relating to financings which may be deemed
to be within the lending guidelines of both RAIT and the real
estate investment trust we are then sponsoring.
For transactions between RAIT and us, see Part III, Item 13 of this
report, and Note 3, "Certain Relationships and Related Party
Transactions-Relationship with RAIT" in Notes to Consolidated Financial
Statements.
Partnership Management
Through our subsidiary, F.L. Partnership Management, Inc. we act as the
general partner and manager of five public limited partnerships formed between
1986 and 1990. These partnerships had total assets at September 30, 2000 of
$33.8 million, including $2.2 million (book value) of equipment with an original
cost of $13.4 million, and investments in direct financing leases of $18.1
million. The partnerships primarily lease computers and related peripheral
equipment to investment-grade, middle-market and capital-intensive companies.
The principal stated objective of each of the limited partnerships is to
generate leasing revenues for distribution to the investors in the partnerships.
The partnerships commenced their liquidation periods at various times between
December 1995 and December 1998.
21
<PAGE>
We receive management fees and an interest in partnership cash
distributions for our services as general partner. Management fees range from 4%
to 6% of gross rents except for full-payout leases where management fees range
from 2% to 3% of gross rents. In four of the partnerships, management fees are
subordinated to the receipt by limited partners of a cumulative annual cash
distribution of 11% (one partnership) or 12% (three partnerships) of the limited
partners' aggregate investment. Our general partner's interest in cash
distributions is 3.5% (one partnership) and 1% (four partnerships). The
partnerships reimburse us for specified expenses related to administration of
the partnerships, including costs of non-executive personnel, legal, accounting
and third-party contractor fees and costs and costs of equipment used in a
partnership's behalf.
Discontinued Operations
Residential Mortgage
On September 28, 1999, we adopted a plan to discontinue our residential
mortgage lending business. The business was disposed of in November 2000.
Accordingly, our financial statements report the business as a discontinued
operation for the years ended September 30, 2000, 1999 and 1998. Net assets of
the discontinued operation at September 30, 2000 consisted primarily of loan
receivables.
Equipment Leasing
On August 1, 2000, we sold our small ticket equipment leasing
subsidiary, Fidelity Leasing, to European American Bank and AEL Leasing Co.,
Inc., subsidiaries of ABN AMRO Bank, N.V. We received total consideration of
$152.2 million, including repayment of indebtedness of Fidelity Leasing to us;
the purchasers also assumed approximately $431.0 million in debt payable to
third parties and other liabilities. Of the $152.2 million consideration, $16.0
million was paid by a non-interest bearing promissory note. The promissory note
is payable to the extent that payments are made on a pool of Fidelity Leasing
lease receivables and refunds are received with respect to certain tax
receivables. The lease receivable pool consists of receivables that, as of June
30, 2000, were aged more than 90 days or on Fidelity Leasing's "watch list," or
had an outstanding balance of $200,000 or more that would have been rated "not
pass" under the purchasers' credit policies. In addition, $10.0 million was
placed in escrow until March 31, 2004 as security for our indemnification
obligations to the purchasers. In connection with the sale, we made $15.5
million of payments to Fidelity Leasing's management and incurred $3.4 million
in expenses.
Credit Facilities and Senior Notes
The following is a summary of the terms of our credit facilities
outstanding as of September 30, 2000 and of our senior notes:
Credit Facilities
We have an $18.0 million revolving credit facility with Hudson United
Bank, formerly Jefferson Bank, for our real estate finance operations. The
facility expires in February 2001. The facility bears interest at the prime rate
reported in The Wall Street Journal plus .75%, and is secured by our interest in
certain commercial loans. As amended in December 1999, credit availability is
based upon the amount of assets pledged as security for the facility and is
subject to the lender's approval of additional collateral. Credit availability
at September 30, 2000 was $7.0 million, all of which had been drawn at that
date.
22
<PAGE>
We also established an $18.0 million line of credit with Sovereign
Bank. The facility bears interest at the prime rate reported in The Wall Street
Journal and expires in July 2002. The facility is secured by our interest in
certain of our portfolio loans and real estate and by certain bonds held by us.
Credit availability is based on the value of the collateral pledged as security
and was $18.0 million as of September 30, 2000, all of which had been drawn at
that date. The facility imposes limitations on the incurrence of future
indebtedness by our subsidiaries whose properties were pledged, and on sales,
transfers or leases of their assets, and requires the subsidiaries to maintain
both a specified level of equity and a specified debt service coverage ratio.
At the same time, we established a similar $5.0 million line of credit
with Sovereign Bank. This facility bears interest at the same rate as the $18.0
million line of credit and also expires in July 2002. The facility is secured by
a pledge of our RAIT common shares and by a guaranty from the subsidiaries
involved in the $18.0 million line of credit. Credit availability is based on
the value of those shares and was $5.0 million as of September 30, 2000, all of
which had been drawn at that date. The facility restricts us from making loans
to our affiliates (except for subsidiaries) other than:
o existing loans,
o loans in connection with lease transactions in an aggregate not to
exceed $50,000 in any fiscal year, and
o loans to RAIT made in the ordinary course of business.
In September 1999, our energy subsidiaries, Atlas America, Resource
Energy and Viking Resources, entered into a $40.0 million revolving credit
facility administered by PNC Bank. Credit availability under the facility, as
amended in February 2000, is based on the proved developed producing, proved
developed non-producing and proved undeveloped natural gas and oil reserves
attributable to the borrowers' wells and the borrowers' projected fees and
revenues from the operation of wells and management of drilling partnerships,
and was $40.0 million at September 30, 2000. Up to $10.0 million of the
borrowings under the facility may be in the form of standby letters of credit. A
letter of credit in the original amount of $7.5 million was issued to Atlas
Pipeline under this facility to secure our obligation to support, through
February 2003, minimum quarterly distributions by Atlas Pipeline to holders of
its non-subordinated units. The letter of credit reduces each quarter as the
distribution support obligation reduces. Borrowings under the facility are
secured by the assets of the borrowers and their subsidiaries, including the
stock of subsidiaries and interests in Atlas Pipeline Partners GP and Atlas
Pipeline. Loans under the facility bear interest at one of the following two
rates, at the borrowers' election, which increase as the amount outstanding
under the facility increases:
o the PNC Bank prime rate plus 0 to 75 basis points, or
o the Eurodollar rate plus 150 and 225 basis points.
Draws under any letter of credit bear interest at the PNC Bank prime
rate plus 0 to 75 basis points.
The credit facility contains financial covenants, including
requirements that we maintain:
o a current ratio of .85 to 1.0,
o a ratio of earnings to fixed charges of 1.5 to 1.0, increasing to
2.0 to 1.0 in September 2000 and 2.5 to 1.0 in March 2002, and
o a leverage ratio of not less than 3.0 to 1.0.
In addition, the facility prohibits the borrowers' exploration expenses
from exceeding 20% of capital expenditures and limits sales, leases or transfers
of property by the borrowers and the incurrence of additional indebtedness. The
facility terminates in June 2003, when all outstanding borrowings must be
repaid.
At September 30, 2000, $29.5 million of the facility (including the
letter of credit, which had an outstanding balance of $5.7 million at such date)
had been drawn.
23
<PAGE>
Senior Notes
Our 12% senior notes are unsecured general obligations with interest
payable only until maturity on August 1, 2004. The senior notes are not subject
to mandatory redemption except upon a change in control, as defined in the
indenture governing the senior notes, when the noteholders have the right to
require us to redeem the senior notes at 101% of principal amount plus accrued
interest. There is no sinking fund for the senior notes. At our option, we may
redeem the senior notes in whole or in part on or after August 1, 2002 at a
price of 106% of principal amount (through July 31, 2003) and 103% of principal
amount (through July 31, 2004), plus accrued interest to the date of redemption.
At September 30, 2000, $80.4 million of these notes were outstanding.
The indenture contains covenants that, among other things, require us
to maintain certain levels of net worth (generally, an amount equal to $200.0
million plus a cumulative 25% of our consolidated net income less an adjustment
based upon the principal amount of senior notes we repurchase) and liquid assets
(generally, an amount equal to 100% of required interest payments for the next
succeeding interest payment date); and limit our ability to:
o incur indebtedness, but excluding secured indebtedness used to
acquire assets or refinance acquisitions;
o pay dividends or make other distributions in excess of 25% of
aggregate consolidated net income, offset by 100% of any deficit,
on a cumulative basis;
o engage in specified transactions with affiliates;
o dispose of subsidiaries;
o create liens and guarantees with respect to pari passu or junior
indebtedness;
o enter into any arrangement that would impose restrictions on the
ability of subsidiaries to make dividend and other payments to us
except in connection with specified indebtedness;
o merge, consolidate or sell all or substantially all of our assets;
o incur additional indebtedness if our "leverage ratio" exceeds 2.0
to 1.0; or
o incur pari passu or junior indebtedness with a maturity date prior
to that of the senior notes.
As defined by the indenture, the leverage ratio is the ratio of all
indebtedness (excluding debt used to acquire assets, obligations to repurchase
loans or other financial assets sold by us, guarantees of either of the
foregoing, non-recourse debt and certain securities issued by securitization
entities, as defined in the indenture) to our consolidated net worth.
Employees
As of September 30, 2000, we employed 199 persons, including 13 in
general corporate, 176 in energy, 8 in partnership management and 2 in real
estate finance.
Risk Factors
Statements made by us in written or oral form to various persons,
including statements made in filings with the SEC, that are not strictly
historical facts are "forward-looking" statements that are based on current
expectations about our business and assumptions made by management. These
statements are subject to risks and uncertainties that exist in our operations
and business environment that could result in actual outcomes and results that
are materially different than predicted. The following includes some, but not
all, of those factors or uncertainties:
24
<PAGE>
General
o Unforeseen interest rate increases will increase our interest
costs under our four credit facilities as well as interest costs
relating to some of the senior lien interests encumbering our
portfolio loans. This could have many material adverse effects,
including reduction of net revenues from both our energy and real
estate finance operations.
Energy
o Historically, the markets for natural gas and oil have been
volatile and are likely to continue to be volatile in the future.
Prices for natural gas and oil are subject to wide fluctuation in
response to relatively minor changes in the supply of and demand
for natural gas and oil, market uncertainty and other factors over
which we have no control. Depending on the purchasers' needs, the
price obtainable for our natural gas, or the amount of natural gas
which we are able to sell, our energy revenues and our ability to
obtain financing for our drilling and development operations
through sponsored drilling partnerships may be materially
adversely affected. While the effect of the current imbalance
between the supply of natural gas and consumer demand has
substantially increased prices for natural gas, we cannot predict
the duration of these conditions. Generally, however, while the
increased prices for natural gas increase our revenues, they may
make it more difficult, or more expensive, to drill and complete
wells due to potentially increased competition for drilling rigs
and related materials, whose services we obtain through
subcontracting, or to execute our business strategy of acquiring
additional natural gas properties and energy companies.
o The energy business involves operating hazards such as well
blowouts, cratering, explosions, uncontrollable flows of oil,
natural gas or well fluids, fires, formations with abnormal
pressures, pipeline ruptures or spills, pollution, releases of
toxic gas and other environmental hazards and risks, any of which
could result in substantial losses to us. In addition, we may be
liable for environmental damage caused by previous owners of
properties purchased or leased by us. As a result, we may incur
substantial liabilities to third parties or governmental entities
which could materially adversely affect our results of operations
or financial condition. In accordance with customary industry
practices, we maintain insurance against some, but not all, of
such risks and losses. We may elect to self-insure if we believe
that insurance, although available, is excessively costly relative
to the risks presented. The occurrence of an event that is not
covered, or not fully covered, by insurance could have a material
adverse effect on our business, financial condition and results of
operations. In addition, pollution and environmental risks
generally are not fully insurable.
o Although wells we drill are generally to formations that have a
high probability of resulting in commercially productive natural
gas reservoirs, the amount of recoverable reserves may vary
significantly from well to well. We may drill wells that, while
productive, do not produce sufficient net revenues to return a
profit after drilling, operating and other costs. If we do not
drill productive and profitable wells, our ability to finance our
drilling activities through drilling partnerships or otherwise
could be materially impaired, which would materially adversely
affect the financial condition and future revenues of our energy
business.
o We account for our energy properties under the successful efforts
method. The carrying value of our energy properties is reviewed
quarterly under standards outlined in FASB 121 "Accounting for the
Impairment of Long-Lived Assets and for Long-Lived Assets to Be
Disposed Of." Under these rules, the assets carrying value
(ignoring deferred income taxes) is compared with expected
undiscounted future pre-tax cash flows. The calculation of these
future cash flows may include adjustments for expected prices,
costs and production volumes. Impairment is limited to the assets
fair market value. Although "market conditions" ultimately
establish an assets fair value, the assets' future pre-tax cash
flows, using an appropriate discount rate is often used as a
standard. We may be required to write-down the carrying value of
our energy properties when natural gas and oil prices are
depressed or unusually volatile. If a write-down is required, it
could result in a material charge to earnings, but would not
impact cash flow from operating activities. Once incurred, a
write-down of natural gas and oil properties is not reversible at
a later date.
o The estimates of our proved natural gas and oil reserves and the
estimated future net revenues referred to immediately above are
based upon reserve reports that rely upon various assumptions,
including assumptions required by the SEC, as to natural gas and
oil prices, drilling and operating expenses, capital expenditures,
taxes and availability of funds. Such estimates are inherently
25
<PAGE>
imprecise. Actual future production, natural gas and oil prices,
revenues, taxes, development expenditures, operating expenses and
quantities of recoverable natural gas and oil reserves may vary
substantially from our estimates or estimates contained in the
reserve reports. Any significant variance in these assumptions
could materially affect the estimated quantity of our reserves.
Our properties also may be susceptible to hydrocarbon drainage
from production by other operators on adjacent properties. In
addition, our proved reserves may be subject to downward or upward
revision based upon production history, results of future
exploration and development, prevailing natural gas and oil
prices, mechanical difficulties, governmental regulation and other
factors, many of which are beyond our control.
o The rate of production from natural gas and oil properties
declines as reserves are depleted. Our proved reserves will
decline as reserves are produced unless we acquire additional
properties containing proved reserves, successfully develop new or
existing properties or identify additional formations with primary
or secondary reserve opportunities on our properties. If we are
not successful in expanding our reserve base, our future natural
gas and oil production, the primary source of our energy revenues,
will be adversely affected. Our ability to find and acquire
additional reserves depends on our generating sufficient cash flow
from operations and other sources of capital, principally our
sponsored drilling partnerships. We cannot assure you that we will
have sufficient cash flow or cash from other sources to expand our
reserve base.
o The growth of our energy operations has resulted from both our
acquisition of energy companies such as Atlas America and Viking
Resources and our ability to obtain capital funds through our
sponsored drilling partnerships. If we are unable to identify
acquisition candidates on acceptable terms, or if our ability to
obtain capital funds through our partnerships is impaired, we may
be unable to increase or maintain our inventory of properties and
reserve base, or be forced to curtail drilling, production or
other activities. This would materially adversely affect our
energy operations and their growth prospects.
Real Estate Finance
o Many of our portfolio loans are secured by properties that, while
income producing, are unable to generate sufficient revenues to
pay the full amount of debt service required under the original
loan terms or are subject to other problems. Although we generally
control cash flow from the properties underlying the loans and,
where appropriate, have made financial accommodations to take into
account the operating conditions of the underlying properties,
there may be a higher risk of default with these loans as compared
to conventional loans.
o Declines in real property values generally and/or in those
specific markets where the properties underlying our portfolio
loans are located due to changes in economic factors or otherwise
could affect the value of and default rates under those loans.
o Many of our portfolio loans were acquired as or became (as a
result of borrower refinancing) junior lien obligations.
Subordinate lien financing carries a greater credit risk,
including a substantially greater risk of non-payment of interest
or principal, than senior lien financing. In the event a loan is
foreclosed, we will be entitled to share only in the net
foreclosure proceeds after payment of all senior lienors. It is
therefore possible that we will not recover the full amount of a
foreclosed loan or of our unrecovered investment in the loan.
o At September 30, 2000, our allowance for possible losses was $2.0
million or (1%) of the book value of our loan portfolio. You
should not assume that this allowance will prove to be sufficient
or that future provisions for loan losses will not be materially
greater, either of which could materially reduce our earnings or
adversely affect our financial condition.
26
<PAGE>
ITEM 2. PROPERTIES
We maintain our executive office and our real estate finance operations
in Philadelphia, Pennsylvania under a month-to-month lease for 7,173 square feet
of office space. We also maintain a 2,100 square foot office in New York, New
York under a lease agreement which expires December 2001.
As a result of the Atlas America and Viking Resources acquisitions, we
own a 24,000 square foot office building in Pittsburgh, Pennsylvania, a 17,000
square foot field office and warehouse facility in Jackson Center, Pennsylvania
and a field office in Deerfield, Ohio. We also rent two field offices in Ohio
and New York on a month-to-month basis. We rent 7,585 square feet of office
space in Uniontown, Ohio under a lease expiring in March 2006. All of these
properties are used for our energy operations.
During fiscal 2000, we sold our Akron and Canton, Ohio offices.
ITEM 3. LEGAL PROCEEDINGS
We are a defendant, together with certain of our officers and directors
and our independent auditor, Grant Thornton LLP, in consolidated actions that
were instituted on October 14, 1998 in the U.S. District Court for the Eastern
District of Pennsylvania by stockholders, putatively on their own behalf and on
behalf of similarly situated stockholders, who purchased shares of our common
stock between December 17, 1997 and February 22, 1999. The complaint seeks
damages in an unspecified amount for losses allegedly incurred as the result of
misstatements and omissions allegedly contained in our periodic reports and a
registration statement filed with the SEC. The asserted misstatements and
omissions relate, among other matters, to (i) use of the accretion of discount
method of recognizing revenue on distressed loans we purchased at a discount and
(ii) accounting for the profit we realized on our sale of senior lien interests
in such loans. We believe that the complaint is without merit and are defending
ourselves vigorously.
We are also a defendant in a suit filed in February 2000 in the New
York Supreme Court, Chautauqua County, by individuals, putatively on their own
behalf and on behalf of similarly situated individuals, who leased acreage to
us. The complaint alleges that we are not paying landowners the proper amount of
royalty revenues derived from the natural gas produced from the wells on the
lease property. The complaint seeks damages in an unspecified amount for the
alleged difference between the amount of royalties actually paid and the amount
of royalties that allegedly should have been paid. We believe the complaint is
without merit and intend to defend ourselves vigorously.
We are also party to various routine legal proceedings arising out of
the ordinary course of our business. Management believes that none of these
actions, individually or in the aggregate, will have a material adverse effect
on our financial condition or operations.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
Not applicable.
27
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PART II
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
Our common stock is quoted on the Nasdaq Stock Market under the symbol
"REXI." The following table sets forth the high and low sale prices, as reported
by Nasdaq, on a quarterly basis for our last two fiscal years and fiscal 2001
through December 15, 2000.
<TABLE>
<CAPTION>
High Low
---- ---
<S> <C> <C>
Fiscal 2001
First Quarter (through December 15, 2000).......................... $10.25 $ 7.47
Fiscal 2000
Fourth Quarter..................................................... 9.22 6.50
Third Quarter...................................................... 8.75 6.38
Second Quarter .................................................... 8.25 6.25
First Quarter...................................................... 9.25 6.75
Fiscal 1999
Fourth Quarter..................................................... 15.88 6.50
Third Quarter...................................................... 18.50 8.50
Second Quarter .................................................... 12.31 8.56
First Quarter...................................................... 13.69 7.56
</TABLE>
As of December 15, 2000, there were 17,448,125 shares of common stock
outstanding held by 575 holders of record.
We have paid regular quarterly cash dividends on our common stock (as
adjusted for stock dividends) of $.03 per share commencing with the fourth
quarter of fiscal 1995. Under the terms of our senior notes, the payment of
dividends on our common stock is restricted unless certain financial tests are
met. See "Business - Credit Facilities: Senior Notes."
28
<PAGE>
ITEM 6. SELECTED FINANCIAL DATA
The following selected financial data should be read together with the
financial statements, the notes to the financial statements and "Management's
Discussion and Analysis of Financial Condition and Results of Operations" which
are included elsewhere in this report. The selected financial data set forth
below for each of the years ended September 30, 2000, 1999 and 1998, and at
September 30, 2000 and 1999 are derived from financial statements appearing
elsewhere in this report, audited by Grant Thornton LLP. The selected financial
data for the years ended September 30, 1997 and 1996 and at September 30, 1998,
1997 and 1996 are derived from financial statements audited by Grant Thornton
LLP not included in this report.
<TABLE>
<CAPTION>
For the Years Ended September 30,
----------------------------------------------------------------
2000 1999 1998 1997 1996
---- ---- ---- ---- ----
<S> <C> <C> <C> <C> <C>
(in thousands, except per share data)
Income statement data:
Revenues
Energy............................................ $ 70,552 $ 55,093 $ 6,734 $ 5,608 $ 5,157
Real estate finance............................... 18,649 45,907 55,834 19,144 7,171
Interest and other................................ 10,410 8,089 6,912 3,859 4,657
---------- ---------- --------- --------- ---------
Total revenues....................................... $ 99,611 $ 109,089 $ 69,480 $ 28,611 $ 16,985
========== ========== ========= ========= =========
Income from continuing operations
before income taxes, extraordinary
item and cumulative effect of a change
in accounting principle........................... $ 5,700 $ 35,291 $ 40,776 $ 13,758 $ 7,800
Provision for income taxes........................... 1,638 11,110 13,011 3,375 2,358
---------- ---------- --------- --------- ---------
Income from continuing operations
before extraordinary item and
cumulative effect of a change in
accounting principle.............................. $ 4,062 $ 24,181 $ 27,765 $ 10,383 $ 5,442
Discontinued operations:
Income (loss) from operations of subsidiary,
net of taxes.................................... 476 (5,686) (393) 568 (295)
Gain (loss) on disposal of subsidiary,
net of taxes.................................... 12,944 (275) - - -
Extraordinary item, net of taxes..................... 683 299 239 - -
Cumulative effect of change in accounting
principle, net of taxes........................... - (59) - - -
---------- ---------- --------- --------- ---------
Net income........................................... $ 18,165 $ 18,460 $ 27,611 $ 10,951 $ 5,147
========== ========== ========= ========= =========
Net income per common share-basic:
From continuing operations........................ $ .18 $ 1.09 $ 1.66 $ .79 $ .66
Discontinued operations........................... .57 (.26) (.02) .04 (.04)
Extraordinary item................................ .03 .01 .01 - -
Cumulative effect of change in accounting
principle....................................... - (.01) - - -
---------- ----------- --------- -------- ---------
Net income per common share-basic.................... $ .78 $ .83 $ 1.65 $ .83 $ .62
========== ========== ========= ======== =========
Net income per common share-diluted:
From continuing operations........................ $ .17 $ 1.06 $ 1.61 $ .79 $ .66
Discontinued operations........................... .56 (.25) (.02) .04 (.04)
Extraordinary item................................ .03 .01 .01 - -
Cumulative effect of change in accounting
principle....................................... - (.01) - - -
---------- ---------- --------- -------- ---------
Net income per common share-diluted.................. $ .76 $ .81 $ 1.60 $ .83 $ .62
========== ========== ========= ======== =========
Cash dividends per common share...................... $ .13 $ .13 $ .13 $ .13 $ .13
========== ========== ========= ======== =========
Balance sheet data:
Total assets......................................... $ 509,204 $ 540,132 $ 392,083 $ 193,340 $ 43,855
Long-term debt....................................... 127,682 220,695 140,280 118,786 8,966
Stockholders' equity................................. 281,215 263,789 236,478 64,829 31,123
</TABLE>
29
<PAGE>
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATION
Overview of Fiscal 2000
Our operating results and financial condition for fiscal 2000 reflect
the further expansion of our energy operations continuing a trend which began
with the acquisition of Atlas Group (now Atlas America) at the end of fiscal
1998 and continued with the acquisition of Viking Resources at the end of fiscal
1999. The importance of our energy operations was significantly increased in
fiscal 2000 as a result of the discontinuance and sale of our equipment leasing
business. The expansion of our energy operations over the past three years is
shown in the following tables, which have been restated to reflect the sale of
our equipment leasing business:
Revenues as a Percent of Total Revenues(1)
<TABLE>
<CAPTION>
Years Ended September 30,
-----------------------------------------
2000 1999 1998
---- ---- ----
<S> <C> <C> <C>
Energy ................................................................ 71% 51% 10%
Real estate finance.................................................... 19% 42% 80%
</TABLE>
Assets as a Percent of Total Assets(2)
<TABLE>
<CAPTION>
September 30,
-----------------------------------------
2000 1999 1998
---- ---- ----
<S> <C> <C> <C>
Energy(3) ............................................................. 30% 26% 23%
Real estate finance.................................................... 40% 51% 54%
</TABLE>
-------------
(1) The balance (10% in 2000, 7% in 1999 and 10% in 1998) is attributable to
revenues derived from corporate assets not allocated to a specific industry
segment, including cash and the common shares held in RAIT.
(2) The balance (30% in 2000, 23% in 1999 and 23% in 1998) is attributable to
corporate assets not attributable to a specific industry segment, as
referred to above.
(3) Energy assets expressed as a percent of total assets, excluding cash,
were 39%, 27% and 28% for the fiscal years ending September 2000,
1999 and 1998, respectively.
Before the sale of our equipment leasing business, for fiscal 1999
equipment leasing had accounted for 28% of our revenues and 48% of our assets,
while real estate finance had accounted for 32% of our revenues and 30% of our
assets and energy had accounted for 38% of our revenues and 15% of our assets.
The discontinuance and sale of our equipment leasing business also
significantly affected our liquidity and capital resources by increasing our
cash and cash equivalents to $117.1 million (23% of total assets) at September
30, 2000 as compared to $32.5 million (6% of total assets) at September 30,
1999. In October 2000, we used a portion ($49.7 million) of the September 30,
2000 cash balance to acquire approximately 5.5 million shares of our common
stock at $9.00 per share in a "dutch auction" tender offer. In addition, we used
$7.1 million to repurchase 793,000 shares in a private transaction.
30
<PAGE>
Results of Operations: Energy
In September 1998 and August 1999, we acquired Atlas Group and Viking
Resources, respectively. Results of operations for the respective years of
acquisition include the operations of these companies from their respective
dates of acquisition and, accordingly, are not comparable to the similar periods
of the prior years.
The following tables set forth information relating to revenues
recognized and costs and expenses incurred, daily production volumes, average
sales prices, production costs as a percentage of natural gas and oil sales, and
production cost per equivalent unit for our energy operations during fiscal
2000, 1999 and 1998:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Revenues:
Production.......................................................... $ 25,231 $ 12,233 $ 4,682
Well drilling....................................................... 31,869 32,421 -
Well services....................................................... 8,682 6,120 1,644
Transportation...................................................... 4,770 3,310 408
Gain on sales of assets............................................. - 1,009 -
----------- ----------- -----------
$ 70,552 $ 55,093 $ 6,734
=========== =========== ===========
Costs and expenses:
Exploration and production.......................................... $ 8,339 $ 5,366 $ 2,525
Well drilling....................................................... 25,806 26,312 -
Well services....................................................... 3,772 1,378 1,019
Transportation...................................................... 2,842 649 117
Non-direct.......................................................... 7,619 5,372 694
----------- ----------- -----------
$ 48,378 $ 39,077 $ 4,355
=========== =========== ===========
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
Revenues (in thousands):
<S> <C> <C> <C>
Gas (1)............................................................. $ 20,286 $ 10,994 $ 3,944
Oil................................................................. $ 4,802 $ 1,239 $ 692
Production volumes:
Gas (thousands of cubic feet (mcf)/day)(1).......................... 17,596 11,897 4,069
Oil (barrels (bbls)/day)............................................ 535 233 132
Average sales price:
Gas (per mcf)....................................................... $ 3.15 $ 2.37 $ 2.66
Oil (per bbl)....................................................... $ 24.50 $ 14.57 $ 14.38
Production costs:
As a percent of sales............................................... 29% 39% 43%
Gas (per mcf)....................................................... $ .95 $ .99 $ 1.13
Oil (per bbl)....................................................... $ 5.70 $ 5.94 $ 6.80
</TABLE>
(1) Excludes sales of residual gas and sales to landowners.
31
<PAGE>
Year Ended September 30, 2000 Compared to Year Ended September 30, 1999
Our natural gas revenues were $20.3 million in fiscal 2000, an increase
of $9.3 million (85%) from $11.0 million in fiscal 1999. The increase was due to
a 48% increase in production volumes, principally due to the completion of 24
wells and the additional Viking Resources production, and a 33% increase in the
average sales price of natural gas. Of the $9.3 million increase in gas
revenues, $6.6 million was attributable to volume increases while $2.7 million
was attributable to price increases.
Our oil revenues were $4.8 million in fiscal 2000, an increase of $3.6
million (288%) from $1.2 million in fiscal 1999. The increase was due to a 130%
increase in production volumes, principally due to the additional Viking
Resources production, and a 68% increase in the average sales price of oil. Of
the $3.6 million increase in oil revenues, $2.7 million was attributable to
volume increases while $900,000 was attributable to price increases.
Without the addition of Viking Resources, gas and oil revenues would
have been $13.4 million and $1.3 million, respectively, resulting in an overall
increase of $3.9 million (28%) compared to fiscal 1999. Average daily gas
production volumes would have been 11,911 mcf, a 4% increase compared to 1999.
The average sales price per mcf would have been $3.08 per mcf as compared to
$2.34 per mcf. Average daily oil production volumes would have decreased 56
barrels per day (28%) from 1999, offset by a 79% increase in the average sales
price per barrel of oil to $24.01.
Our well drilling revenues and expenses in fiscal 2000 represent the
billing and costs associated with the completion of 168 wells for partnerships
sponsored by Atlas America and Viking Resources as compared to 145 wells
completed in fiscal 1999, an increase of 23 wells.
Well services revenues and related costs increased significantly as a
result of an increase in the number of wells operated due to the acquisition of
Viking Resources and the operations associated with new partnership wells
drilled during the year.
Transportation revenues increased $1.5 million (44%) to $4.8 million in
the year ended September 30, 2000, as compared to the same period of the prior
year. This increase principally resulted from the additional revenue associated
with the Viking pipeline systems.
Our production costs, excluding exploration costs of $1.1 million,
increased $2.4 million (50%) to $7.2 million in fiscal 2000, as compared to $4.8
million in fiscal 1999 as a result of the acquisition of Viking Resources'
interests in producing properties and the drilling activities referred to above.
Our non-direct expenses were $7.6 million in fiscal 2000, an increase
of $2.2 million (42%) from $5.4 million in fiscal 1999. Fiscal 2000 non-direct
expenses increased due to the growth in our Energy Division. Atlas Pipeline
Partners, a public entity, was formed in February 2000 and incurs those normal
costs associated wiith public entities. Fiscal 2000 also includes a full twelve
months of costs associated with Viking. Finally, certain allocations changed
such that more costs remain in non-direct expense, rather than being allocated
to another energy function (Production, Drilling, Well Services, Well
Operations).
Amortization of oil and gas property costs as a percentage of oil and
gas revenues was 9% in fiscal 2000 compared to 25% in fiscal 1999. The variance
from period to period is directly attributable to changes in our oil and gas
reserve quantities, product prices and fluctuations in the depletable cost basis
of our gas and oil properties.
Year Ended September 30, 1999 Compared to Year Ended September 30, 1998
Our natural gas revenues increased to $11.0 million in fiscal 1999, an
increase of $7.1 million (179%) from $3.9 million in fiscal 1998. The increase
was due to a 192% increase in production volumes, principally due to the added
Atlas America production, partially offset by an 11% decrease in the average
sales price of natural gas. Of the $7.1 million increase in gas revenues, $6.7
million was attributable to volume increases which was partially offset by
$400,000 in price decreases.
32
<PAGE>
Our oil revenues were $1.2 million in fiscal 1999, an increase of
$547,000 (79%) from $692,000 in fiscal 1998. The increase was due to a 77%
increase in production volumes, principally due to the added Atlas America
production and a 1% increase in the average sales price of oil. Of the $547,000
increase in oil revenues, $538,000 was attributable to volume increases while
$9,000 was attributable to price increases.
Without the additions of Atlas America and Viking Resources, gas and
oil revenues would have been $3.6 million and $853,000 respectively, resulting
in an overall decrease of $182,000 (4%) compared to 1998. Average daily gas
production volumes would have been 3,498 mcf, a 3% decrease compared to 1998.
The average sales price per mcf would have been $2.50 per mcf as compared to
$2.37. Average daily oil production would have increased 39 barrels (29%) over
1998, offset by a 5% decrease in the average sales price per barrel to $13.67.
Our well drilling revenues and expenses in fiscal 1999 represent the
billing and costs associated with the completion of 145 wells for partnerships
sponsored by Atlas America. Well services revenues and related costs increased
significantly as a result of an increase in the number of wells operated due to
the acquisition of the Atlas Group and Viking Resources.
Our transportation revenues increased $2.9 million (711%) to $3.3
million in the year ended September 30, 1999 as compared to the same period of
the prior year. Of this increase, $2.8 million was associated with the Atlas
pipeline operations acquired in September 1998.
Our production costs, excluding exploration costs of $560,000,
increased $3.0 million (149%) to $5.0 million in the year ended September 30,
1999, as compared to the same period in the prior year as a result of the Atlas
Group and Viking Resources acquisitions.
Our transportation expenses increased $532,000 (455%) to $649,000 as
compared the same period of the prior year, of the increase, $528,000 was
related to the Atlas pipeline operations acquired in September 1998.
Our non-direct expenses were $5.4 million in fiscal 1999, an increase
of $4.7 million (674%) from $694,000 in fiscal 1998. This increase was due to
the additional ongoing expenses associated with Atlas America.
Amortization of oil and gas property costs as a percentage of oil and
gas revenues was 25% in the year ended September 30, 1999 compared to 17% in the
year ended September 30, 1998. The variance from period to period was directly
attributable to changes in our natural gas and oil reserve quantities, product
prices and fluctuations in the depletable cost basis of natural gas and oil
properties.
Results of Operations: Real Estate Finance
During fiscal 2000, we focused on managing our existing portfolio of
real estate loans rather than on acquiring further real estate loans. As a
result of this shift in focus, as well as the sale of three portfolio loans and
the partial repayment of two additional loans with a book value of $72.9
million, our portfolio decreased from 41 loans with a book value of $250.2
million in fiscal 1999 to 38 loans with a book value of $183.9 million in fiscal
2000.
The following table sets forth certain information relating to the
revenue recognized and cost and expenses incurred in our commercial real estate
finance operations during the periods indicated:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Revenue:
Interest.......................................................... $ 11,229 $ 17,280 $ 13,179
Accreted discount (net of collection of interest)................. 5,802 18,965 6,520
Gains on sales of senior lien interests and loans................. 1,443 3,784 30,196
Net rental and fee income......................................... 175 5,878 5,939
----------- ----------- -----------
$ 18,649 $ 45,907 $ 55,834
=========== =========== ===========
Cost and expenses...................................................... $ 3,256 $ 3,102 $ 1,801
=========== =========== ===========
</TABLE>
33
<PAGE>
Year Ended September 30, 2000 Compared to Year Ended September 30, 1999
Revenues from our real estate finance operations decreased $27.2
million (59%), from $45.9 million in fiscal 1999 to $18.6 million in fiscal
2000. We attribute the decrease primarily to the following:
o A decrease of $19.2 million (53%) in interest income, including a
decrease of $13.2 (69%) million of accretion of discount,
attributable to the following:
- The repayment in June 1999 of a loan which decreased interest
income by $9.7 million during fiscal 2000 compared to fiscal
1999.
- The repayment by a borrower in October 1999 of approximately
$58.8 million of another loan, which decreased interest
income by $1.4 million during fiscal 2000 compared to fiscal
1999.
- Three additional loans were repaid during fiscal 2000
resulting in a decrease in interest income of $1.9 million in
fiscal 2000 as compared to fiscal 1999.
- The completion of accretion of discount in fiscal 2000 on
five loans as to which $6.2 million accretion had been taken
in fiscal 1999.
o A decrease of $5.7 million (97%) in net rental and fee income
during fiscal 2000, to $175,000 in fiscal 2000 from $5.9 million
in fiscal 1999. The decrease primarily resulted from one-time fees
of $3.4 million and $1.2 million earned in fiscal 1999 for
services rendered to property owners in connection with the
operation, leasing and supervision of the collateral securing two
of our portfolio loans. We earned no comparable fees during fiscal
2000. In addition, we experienced a non-cash loss on one rental
real estate venture of approximately $219,000 in fiscal 2000,
attributable to accounting for the investment on the equity
method.
o A decrease of $2.3 million (62%) in gains on sales of senior lien
interests and loans due to a decrease in the number of loans sold.
Prior to January 1, 1999, we structured most of our transactions
in which senior lien interests were created to meet the criteria
under generally accepted accounting principles for sales of those
interests to the senior lienors. Effective January 1, 1999, we
made a strategic decision to structure future transactions as
financings rather than as sales. Thus, for most transactions that
were completed prior to January 1, 1999, we recorded a gain on
sale which we included in our revenues; refinancing proceeds
received subsequent to that date, although included in our cash
flow, are not recordable as revenues under generally accepted
accounting principles. This policy change resulted in a shift from
the recognition of an immediate gain upon the sale of a senior
lien interest in a loan receivable to the recognition of interest
income over the life of the loan receivable. However, during
fiscal 2000, we sold three loans and were partially repaid on a
fourth loan, resulting in gains of $1.4 million.
Costs and expenses of our real estate finance operations increased
$154,000 (5%) to $3.3 million in the year ended September 30, 2000. We attribute
the increase primarily to the increase in professional fees.
Year Ended September 30, 1999 Compared to Year Ended September 30, 1998
Revenues from our real estate finance operations decreased $9.9
million (18%) from $55.8 million in fiscal 1998 to $45.9 million in fiscal 1999.
We attribute the decrease primarily to a decrease of $26.4 million (87%) in
gains from sales of senior lien interests and loans. The decrease resulted
primarily from a decrease in the number of loans sold or loans in which senior
lien interests were sold from 39 loans in fiscal 1998 to two loans in fiscal
1999 due to the change in structure of our financing transactions as referred to
in our discussion of fiscal 2000 above. The change in structure did not,
however, affect our cash flow from financing transactions.
34
<PAGE>
The decrease in gain on sale revenues was partially offset by an
increase of $16.5 million (84%) in our interest income, including an increase of
$12.4 million of accretion of discount, of which $6.6 million resulted from
accretion of discount adjustments we made in connection with the June 1999 loan
repayment referred to in our discussion of fiscal 2000, above. In addition, two
loans acquired at the end of fiscal 1998 contributed $3.8 million of interest
income in fiscal 1999 as compared to $35,000 in fiscal 1998.
As a consequence of these factors, our yield decreased to 22% in fiscal
1999 as compared to 40% in fiscal 1998.
Costs and expenses of our real estate finance operations increased $1.3
million (72%) to $3.1 million in the year ended September 30, 1999. The increase
primarily resulted from hiring additional personnel, increased compensation to
existing employees and legal costs relating to management of our portfolio.
Results of Operations: Other Revenues, Costs and Expenses
Year Ended September 30, 2000 Compared to Year Ended September 30, 1999
Our interest and other income was $10.4 million in fiscal 2000, an
increase of $2.3 million (29%) from $8.1 million in fiscal 1999. The increase in
fiscal 2000 primarily resulted from intercompany interest on increased lending
to our discontinued small-ticket equipment leasing subsidiary ($1.8 million).
Also, as a result ofa substantial increase in our uncommitted cash balances from
the sale of our equipment leasing operations, and the temporary investment of
such balances interest income increased by $419,000.
Our general and administrative expenses were $7.9 million in fiscal
2000, an increase of $3.0 million (62%) from $4.9 million in fiscal 1999. The
increase primarily resulted from increases in pension costs ($2.0 million),
occupancy costs ($200,000), insurance and taxes ($271,000)
Our depreciation, depletion and amortization expense was $9.9 million
in fiscal 2000, an increase of $3.9 million (65%) from $6.0 million in fiscal
1999. This increase primarily resulted from depletion ($2.6 million) and
amortization and depreciation ($1.2 million) associated with the acquisition of
Viking Resources.
Our interest expense was $18.6 million in fiscal 2000, a decrease of
$1.6 million (8%) from $20.2 million in fiscal 1999. This decrease primarily
resulted from the repayment of one loan in October 1999 and lower average
borrowings on our credit facilities partially offset by higher interest rates as
compared to fiscal 1999.
In the fourth quarter of fiscal 2000, because of the sale of our
leasing operation and the re-emphasis on our energy operations, both our
president and vice chairman of the board, who was also president of the
commercial real estate finance business, were separated from the Company. Both
officers were parties to employment agreements and were terminated in accordance
with the terms of those agreements. Accordingly, continuing results of
operations were charged $1.8 million and discontinued operations were charged
$2.3 million.
The minority interest in Atlas Pipeline Partners, L.P. represents 47%
of the net earnings of Atlas Pipeline as a result of the sale in February 2000
of our natural gas gathering operations to Atlas Pipeline. Because we own more
than 50% of Atlas Pipeline it is included in our consolidated financial
statements and the ownership by the public is shown as a minority interest.
Our equity in the loss of an unconsolidated affiliate represents 50% of
the net loss of Optiron and its predecessor, and a provision for possible losses
of $500,000 against advances made.
Our provision for possible losses increased to $936,000 in fiscal 2000,
an increase of $436,000 (87%) from $500,000 in fiscal 1999. This increase
resulted from an increase to the provision in the fourth quarter of fiscal 2000
caused by the partial write-down of one loan in the amount of $328,000 during
the fourth quarter of 2000.
35
<PAGE>
Our effective tax rate decreased to 29% in fiscal 2000 compared to 31%
in fiscal 1999, as a result of a reduction in pre-tax earnings, coupled with a
consistent level of permanent differences between book and taxable income.
Year Ended September 30, 1999 Compared to Year Ended September 30, 1998
Our interest and other income was $8.1 million in fiscal 1999, an
increase of $1.2 million (17%) from $6.9 million in fiscal 1998, as a result of
the following:
o A substantial decrease in our uncommitted cash balances decreased
interest income by $1.9 million as compared to fiscal 1998.
o Reimbursement, in the third quarter of fiscal 1998, of payroll and
administrative costs in the amount of $513,000 for services we
provided to a partnership in connection with the partnership's
investment in an unrelated business (in which our former president
is the president of the general partner). There were no similar
reimbursements in fiscal 1999.
o The above increases were partially offset by of $1.7 million of
dividend income from RAIT in fiscal 1999, as compared to $801,300
in fiscal 1998.
Our general and administrative expenses were $4.9 million in fiscal
1999, an increase of $1.2 million (32%) from $3.7 million in fiscal 1998,
primarily as a result of hiring additional corporate staff and increases in the
compensation of senior officers, together with an increase in occupancy costs as
we leased additional office space to accommodate our increased staff.
Interest expense was $20.2 million in fiscal 1999, an increase of $3.3
million (20%) as from $16.9 million in fiscal 1998, primarily reflecting
increased borrowings in our real estate and energy divisions.
Our effective tax rate decreased to 31% in the year ended September 30,
1999 from 32% in the year ended September 30, 1998. The fiscal 1999 decrease
resulted from an increase in the generation of depletion for tax purposes due to
the Atlas Group acquisition and an increase in tax credits. These increases in
tax benefits were partially offset by an increase in state income taxes.
Liquidity and Capital Resources
Following the sale of our equipment leasing operations, our major
sources of liquidity have been the proceeds of that sale, funds generated by
operations, and borrowings under our existing energy and real estate finance
credit facilities. We have employed these funds principally in the expansion of
our energy operations and repurchase of senior notes. The following table sets
forth our sources and (uses) of cash for the years ended September 30, 2000,
1999, and 1998:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Provided by operations................................................. $ 8,547 $ 7,778 $ 127
Provided by (used in) investing activities............................. 177,818 (89,858) (71,860)
(Used in) provided by financing activities............................. (75,437) 89,556 96,247
Used in discontinued operations........................................ (26,325) (48,317) (18,478)
----------- ----------- -----------
Increase (decrease) in cash and cash equivalents....................... $ 84,603 $ (40,841) $ 6,036
=========== ============ ===========
</TABLE>
After the end of fiscal 2000, we employed $49.7 million of our funds to
repurchase 5,472,021 shares of our common stock in a "dutch auction" tender
offer and $7.1 million to repurchase 793,000 shares of our common stock in a
private transaction.
36
<PAGE>
Year Ended September 30, 2000 Compared to Year Ended September 30, 1999
We had $117.1 million in cash and cash equivalents on hand at September
30, 2000 as compared to $32.5 million at September 30, 1999. Our ratio of
earnings to fixed charges was 1.42 to 1.0 in the fiscal year ended September 30,
2000 as compared to 2.74 to 1.0 in the fiscal year ended September 30, 1999.
Cash provided by operating activities in fiscal 2000 increased $769,000
as compared to fiscal 1999. The increase is mostly due to an additional $8.2
million in non-cash charges offset by a $5.5 million decrease in accretion (net
of interest) and a $12.9 million gain on disposal from our two discontinued
subsidiaries.
Our cash provided by investing activities increased $267.7 million in
the fiscal year ended September 30, 2000 as compared to the fiscal year ended
September 30, 1999 primarily as a result of the following:
o Proceeds from sale of our equipment leasing operations increased
cash provided by investing activities $122.3 million during fiscal
2000.
o Principal payments on notes receivable increased $44.7 million
mostly due to the sale or refinancing of four real estate loans
during fiscal year 2000.
o Lower investments in real estate loans and ventures increased
investing cash flows in fiscal year 2000 by $92.4 million as
compared to fiscal year 1999.
Our cash flows used in financing activities increased $165.0 million in
fiscal 2000 as compared to the fiscal year ended September 30, 1999. This
increase resulted from a $179.5 million change in net borrowings in fiscal year
2000 as compared to fiscal year 1999. This change is offset by the net proceeds
of $15.3 million from the sale of our gathering systems to Atlas Pipeline. There
was no comparable sale in fiscal 1999.
Year Ended September 30, 1999 Compared to Year Ended September 30, 1998
We had $32.5 million in cash and cash equivalents on hand at September
30, 1999, as compared to $73.3 million at September 30, 1998. Our ratio of
earnings to fixed charges was 2.74 to 1.0 in the year ended September 30, 1999
as compared to 3.42 to 1.0 in the year ended September 30, 1998.
Cash provided by operating activities in fiscal 1999 increased $7.7
million as compared to fiscal 1998. Primarily the increase is due to an increase
of $4.5 million in non-cash changes offset by increased losses from our
discontinued subsidiaries of $5.6 million coupled with a decrease of $4.3
million in accretion of discount (net of interest).
Our cash used in investing activities increased $18.0 million in the
year ended September 30, 1999 as compared to the year ended September 30, 1998
as a result of the following:
o In energy, cash used increased $30.5 million principally as a
result of our participation in the drilling of 145 wells through
Atlas America ($11.6 million) and cash used to acquire Viking
Resources ($15.9 million).
o In real estate finance, cash used increased $1.0 million as a
result of a decrease of $247.4 million in principal payments and
proceeds from the sale of loans, offset by a $245.7 decrease in
investments in real estate loans and ventures.
o Cash used also decreased as a result of a $12.0 million investment
in RAIT in fiscal 1998 which was not repeated in fiscal 1999.
Our cash flow provided by financing activities decreased $6.7 million
during the year ended September 30, 1999 as compared to the year ended September
30, 1998. This increase resulted from a $106.7 million increase in our net
borrowings, and a decrease of $4.3 million in purchases of treasury stock,
partially offset by a decrease of $118.5 million in proceeds from the issuance
of common stock in fiscal 1999 resulting from an offering of common stock in
fiscal 1998. There was no comparable offering in fiscal 1999.
37
<PAGE>
Dividends
In the years ended September 30, 2000, 1999 and 1998, $3.1 million,
$2.9 million and $2.3 million were paid in dividends, respectively. We have paid
regular quarterly dividends since August 1995.
The determination of the amount of future cash dividends, if any, to be
declared and paid is in the sole discretion of our Board of Directors and will
depend on the various factors affecting our financial condition and other
matters the Board of Directors deems relevant, including restrictions which may
be imposed pursuant to the Indenture under which the senior notes were issued.
Environmental Regulation
A continuing trend to greater environmental and safety awareness and
increasing environmental regulation has generally resulted in higher operating
costs for the oil and gas industry. We monitor environmental and safety laws and
believe we are in compliance with applicable environmental laws and regulations.
To date, however, compliance with environmental laws and regulations has not had
a material impact on our capital expenditures, earnings or competitive position.
We believe, however, that environmental and safety costs will increase in the
future. We cannot offer you any assurance that compliance with environmental
laws and regulations will not, in the future, materially adversely affect our
operations through increased costs of doing business or restrictions on the
manner in which we conduct our operations.
38
<PAGE>
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Real Estate Finance Assets
The following table sets forth information regarding 37 of the 38 loans
held in our portfolio as of September 30, 2000. The presentation, for each
category of information, aggregates the loans by their maturity dates for
maturities occurring in each of the fiscal years 2001 through 2005 and
separately aggregates the information for all maturities arising after the 2005
fiscal year. We do not believe that these loans are sensitive to changes in
interest rates since:
o the loans are subject to forbearance or other agreements that
require all of the operating cash flow from the properties
underlying the loans, after debt service on senior lien interests,
to be paid to us and thus are not currently being paid based on
the stated interest rates of the loans;
o all senior lien interests are at fixed rates and are thus not
subject to interest rate fluctuation that would affect payments to
us; and
o each loan has significant accrued and unpaid interest and other
charges outstanding to which cash flow from the underlying
property would be applied even if cash flow were to exceed the
interest rate, as originally underwritten. For information
regarding specific loans, you should review Item 1 of this report,
"Business - Real Estate Finance: Loan Status," and the tables
included in that section.
<TABLE>
<CAPTION>
Portfolio Loans, Aggregated by Maturity Dates,(1) For the Years Ended September 30,
----------------------------------------------------------------------------------------------------
2001(2) 2002 2003 2004 2005 Thereafter Totals
------------ ----------- ----------- ---- ---------- ------------ ------------
<S> <C> <C> <C> <C> <C> <C>
Outstanding loan
receivable balances (to
Resource America's
interest) $29,441,183 $41,212,053 $45,814,991 N/A $8,256,183 $171,705,438 $296,429,848
Book value of investment
(fixed rate) $11,977,926 $24,499,527 $10,170,646 N/A $6,430,192 $86,772,510 $139,850,801
Average stated interest
rate (fixed rate) 11.00% 9.67% 8.13% N/A 9.13% 18.18%
Book value of investment
(variable rate) $1,277,890 $1,385,290 $102,212 N/A N/A $5,041,553 $7,806,945
Average stated interest
rate (variable rate) 7.61% 13.60% 9.00% N/A N/A 9.29%
Average interest payment
rate (3) (3) (3) N/A (3) (3)
Principal balance of
related senior lien
interests (4) $14,485,191 $7,674,074 $17,931,356 N/A $7,227,719 $244,610,207 $291,928,547
Average interest rate of
senior lien interests
(fixed rate) 8.75% 9.40% 9.98% N/A 11.51% 12.32%
</TABLE>
1) Maturity dates of related forbearance agreement or our interest in the
loan.
2) Includes two loans whose forbearance agreements expired during the fiscal
year ended September 30, 2000. These loans aggregated $14.2 million of
outstanding loan receivables (to our interest). The carried costs (fixed
rate and variable rate) of the loans were $7.5 million and $762,000,
respectively, and the principal balance of the related senior lien
interests was $7.3 million.
3) Pay rates are equal to the net cash flow from the underlying properties
after payments on senior lien interests and, accordingly, depend upon
future events not determinable as of the date hereof.
39
<PAGE>
4) Maturity dates for senior lien interests according to the maturity of the
underlying Resource loans are as follows:
<TABLE>
<CAPTION>
Maturity Date of Maturity Dates of
Company's Loans Senior Lien Interests Outstanding Balance
(Fiscal Year Ended (Fiscal Year Ended of Senior Lien Interests
September 30) September 30) at September 30, 2000
------------- ------------- ---------------------
<S> <C> <C> <C>
2000(a) 2000(b) $ 685,000
2010 6,640,011
2001 2000(b) 2,000,000
2001 2,809,000
2007 2,351,180
2002 2003 5,274,074
2004 2,400,000
2003 2003 15,804,557
2006 2,126,799
2004 2004 None
2005 2004 1,782,953
2010 5,444,766
Thereafter 2001 2,010,000
2004 2,096,000
2003 3,540,197
2004 2,575,803
2006 73,284,599
2008 125,257,014
2009 29,444,780
2010 4,447,248
2014 1,954,566
--------------
Total $ 291,928,547
==============
</TABLE>
-------------
(a) The forbearance agreements of the Company's underlying loans came due
during the fiscal year ended September 30, 2000. We continue to forbear
from exercising our remedies with respect to these loans since we believe
we receive all of the economic benefit from the properties without having
to incur the expense of foreclosure.
(b) The senior lien interests with respect to two loans came due during the
fiscal year ending September 30, 2000. Currently we are negotiating with
the senior lien holder to either extend the maturity of these loans or
repurchase the senior lien interest.
40
<PAGE>
The following table sets forth information concerning one of the 38
loans held in our portfolio at September 30, 2000 that we believe may be deemed
to be interest rate sensitive.
Outstanding receivable balance (to Resource
America's interest)........................ $ 43,038,924
Book value of investment.................... $ 38,282,501
Stated interest rate........................ 10.0%
Interest payment rate....................... Net cash flow from property
underlying loan
Principal balance of related senior lien
interest.................................... $ 60,000,000
Stated interest rate (senior lien interest). LIBOR plus 200 basis points
Current interest payment rate (senior lien
interest)................................... 8.8%(1)
Maturity date (senior lien interest)........ 10/01/05
-------------
(1) The loan was refinanced in September 2000. In conjunction with this
refinancing, the Company purchased an interest rate swap. As a result of
this swap, the interest pay rate was locked at 8.8%. Although the stated
interest rate on the loan continues to fluctuate over LIBOR, the Company
will never pay more than the 8.8% locked-in rate. If the effective rate for
a particular pay period is greater than the lock-in rate, then the Company
receives the benefit of this difference.
For a discussion of the changes in our loan portfolio, you should
review Item 7, "Management's Discussion and Analysis of Financial Condition and
Results of Operation: Real Estate Finance."
Corporate Liabilities
The following table sets forth certain information regarding our debt
obligations as of September 30, 2000. For further information regarding our
senior notes and credit facilities, you should review Item 1, "Business - Credit
Facilities and Senior Notes," and Note 5 to the consolidated financial
statements.
<TABLE>
<CAPTION>
2001 2002 2003 2004 2005 Thereafter Total
---- ---- ---- ---- ---- ---------- -----
<S> <C> <C> <C> <C> <C> <C> <C>
Fixed rate.............. - - - $81,266,000 - - $ 81,266,000
Average interest rate... - - - 11.98% - -
Variable rate........... $7,250,006 $23,219,054 $23,197,086 - - - $ 53,666,146
Average interest rate... 10.19% 9.49% 8.54% - - -
Totals $7,250,006 $23,219,054 $23,197,086 $81,266,000 - - $134,932,146
</TABLE>
Futures Contracts
For information regarding open natural gas futures contracts relating
to natural gas sales for fiscal 2000 and the results of natural gas hedging
during fiscal 2000, 1999 and 1998, you should review Note 10 of the notes to
consolidated financial statements.
41
<PAGE>
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Report of Independent Certified Public Accountants
Stockholders and Board of Directors RESOURCE AMERICA, INC.
We have audited the accompanying consolidated balance sheets of
Resource America, Inc. and subsidiaries as of September 30, 2000 and 1999, and
the related consolidated statements of income, comprehensive income, changes in
stockholders' equity, and cash flows for each of the three years in the period
ended September 30, 2000. 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 auditing standards generally
accepted in the United States. 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 financial
statement presentation. We believe that our audits provide a reasonable basis
for our opinion.
In our opinion, the financial statements referred to above present
fairly, in all material respects, the consolidated financial position of
Resource America, Inc. and subsidiaries as of September 30, 2000 and 1999, and
the consolidated results of their operations and cash flows for each of the
three years in the period ended September 30, 2000, in conformity with
accounting principles generally accepted in the United States.
We have also audited Schedule IV as of September 30, 2000. In our
opinion, this schedule presents fairly, in all material respects, the
information required to be set forth therein.
Grant Thornton LLP
Cleveland, Ohio
November 29, 2000
42
<PAGE>
RESOURCE AMERICA, INC.
CONSOLIDATED BALANCE SHEETS
SEPTEMBER 30, 2000 AND 1999
<TABLE>
<CAPTION>
2000 1999
---------- -----------
(in thousands, except share data)
<S> <C> <C>
ASSETS
Current assets:
Cash and cash equivalents................................................. $ 117,107 $ 32,504
Accounts and notes receivable............................................. 15,546 11,563
Prepaid expenses.......................................................... 2,531 971
---------- -----------
Total current assets.................................................... 135,184 45,038
Investments in real estate loans (less allowance for
possible losses of $2,013 and $1,405)..................................... 183,927 250,231
Investments in real estate ventures.......................................... 17,723 18,159
Investment in RAIT Investment Trust.......................................... 10,533 9,300
Property and equipment:
Oil and gas properties and equipment (successful efforts)................. 86,028 78,923
Gas gathering and transmission facilities................................. 18,775 18,061
Other..................................................................... 7,037 6,949
---------- -----------
111,840 103,933
Less - accumulated depreciation, depletion and amortization (26,977) (20,004)
---------- -----------
Net property and equipment................................................ 84,863 83,929
Net assets of discontinued operations........................................ 779 82,306
Other assets (less accumulated amortization of $8,641 and $5,064)............ 76,195 51,169
---------- -----------
Total assets.......................................................... $ 509,204 $ 540,132
========== ===========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Current portion of long-term debt......................................... $ 7,250 $ 13,333
Accounts payable.......................................................... 11,690 9,461
Accrued interest.......................................................... 1,966 3,243
Accrued liabilities....................................................... 26,768 11,359
Estimated income taxes.................................................... 7,470 2,563
---------- -----------
Total current liabilities............................................. 55,144 39,959
Long-term debt:
Senior.................................................................... 80,391 101,400
Non-recourse.............................................................. 42,040 113,718
Other..................................................................... 5,251 5,577
---------- -----------
127,682 220,695
Deferred revenue and other liabilities....................................... 7,676 2,620
Deferred income taxes........................................................ 19,567 13,069
Minority interest............................................................ 17,920 -
Commitments and contingencies................................................ - -
Stockholders' equity:
Preferred stock, $1.00 par value: 1,000,000 authorized shares ........... - -
Common stock, $.01 par value: 49,000,000 authorized shares................ 246 244
Additional paid-in capital................................................ 221,361 221,084
Less treasury stock, at cost.............................................. (15,778) (17,002)
Less loan receivable from Employee Stock Ownership Plan (ESOP)............ (1,393) (1,488)
Accumulated other comprehensive loss...................................... (974) (1,762)
Retained earnings......................................................... 77,753 62,713
---------- -----------
Total stockholders' equity.......................................... 281,215 263,789
---------- -----------
$ 509,204 $ 540,132
========== ===========
</TABLE>
See accompanying notes to consolidated financial statements
43
<PAGE>
RESOURCE AMERICA, INC.
CONSOLIDATED STATEMENTS OF INCOME
YEARS ENDED SEPTEMBER 30, 2000, 1999 AND 1998
<TABLE>
<CAPTION>
2000 1999 1998
---------- ----------- -----------
(in thousands, except per share data)
<S> <C> <C> <C>
REVENUES
Energy..................................................................... $ 70,552 $ 55,093 $ 6,734
Real estate finance........................................................ 18,649 45,907 55,834
Interest and other......................................................... 10,410 8,089 6,912
---------- ----------- -----------
99,611 109,089 69,480
COSTS AND EXPENSES
Energy..................................................................... 48,378 39,077 4,355
Real estate finance........................................................ 3,256 3,102 1,801
General and administrative................................................. 7,894 4,859 3,679
Depreciation, depletion and amortization................................... 9,872 5,985 1,493
Interest................................................................... 18,632 20,226 16,871
Provision for possible losses.............................................. 936 500 505
Termination charge......................................................... 1,753 - -
Minority interest in Atlas Pipeline Partners, L.P.......................... 2,058 - -
Equity in loss of unconsolidated affiliate................................. 1,132 49 -
---------- ----------- -----------
93,911 73,798 28,704
---------- ----------- -----------
Income from continuing operations before income taxes, extraordinary item and
cumulative effect of a change
in accounting principle................................................. 5,700 35,291 40,776
Provision for income taxes................................................. 1,638 11,110 13,011
---------- ----------- -----------
Income from continuing operations before extraordinary item
and cumulative effect of a change in accounting principle............... 4,062 24,181 27,765
---------- ----------- -----------
Discontinued operations:
Income (loss) from operations of subsidiary............................. 476 (5,686) (393)
Gain (loss) on disposal of subsidiary................................... 12,944 (275) -
---------- ------------ -----------
13,420 (5,961) (393)
Extraordinary item, net of taxes of $367, $142 and $112.................... 683 299 239
Cumulative effect of a change in accounting principle, net of taxes of $28. - (59) -
---------- ------------ -----------
Net income................................................................. $ 18,165 $ 18,460 $ 27,611
========== =========== ===========
Net income per common share - basic:
From continuing operations.............................................. $ .18 $ 1.09 $ 1.66
Discontinued operations................................................. .57 (.27) (.02)
Extraordinary item...................................................... .03 .01 .01
Cumulative effect of a change in accounting principle................... - - -
---------- ----------- -----------
Net income per common share - basic..................................... $ .78 $ .83 $ 1.65
========== =========== ===========
Weighted average common shares outstanding................................. 23,413 22,108 16,703
========== =========== ===========
Net income per common share - diluted:
From continuing operations.............................................. $ .17 $ 1.06 $ 1.61
Discontinued operations................................................. .56 (.26) (.02)
Extraordinary item...................................................... .03 .01 .01
Cumulative effect of a change in accounting principle................... - - -
---------- ------------ -----------
Net income per common share - diluted................................... $ .76 $ .81 $ 1.60
========== =========== ===========
Weighted average common shares............................................. 23,828 22,803 17,268
========== =========== ===========
</TABLE>
See accompanying notes to consolidated financial statements
44
<PAGE>
RESOURCE AMERICA, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
YEARS ENDED SEPTEMBER 30, 2000, 1999 AND 1998
<TABLE>
<CAPTION>
2000 1999 1998
---------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Net income................................................................. $ 18,165 $ 18,460 $ 27,611
Other comprehensive income (loss):
Unrealized gain (loss) on investment.................................... 1,201 (2,612) (65)
Tax effect......................................................... (413) 893 22
----------- ----------- -----------
788 (1,719) (43)
---------- ----------- -----------
Comprehensive income....................................................... $ 18,953 $ 16,741 $ 27,568
========== =========== ===========
</TABLE>
See accompanying notes to consolidated financial statements
45
<PAGE>
RESOURCE AMERICA, INC.
CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY
YEARS ENDED SEPTEMBER 30, 2000, 1999, AND 1998
(in thousands, except share data)
<TABLE>
<CAPTION>
Common Stock Additional Treasury Stock ESOP
------------------------- Paid-In --------------------------- Loan
Shares Amount Capital Shares Amount Receivable
-------------------------------------------------------------------------------------
<S> <C> <C> <C> <C> <C> <C>
Balance, September 30, 1997............... 5,410,645 $ 54 $ 56,787 (709,048) $ (13,664) $ (353)
Treasury shares issued.................... 129 9,897 209
Issuance of common stock.................. 4,105,541 41 151,267
Treasury shares acquired.................. (410,000) (4,435)
Net unrealized loss on investment.........
3-for-1 stock split effected in the form
of a 200% stock dividend................. 13,452,922 135
Loan to ESOP.............................. (1,302)
Tax benefit of stock option plan.......... 405
Cash dividends ($.13 per share)...........
Repayment of ESOP loan.................... 64
Net income................................
---------------------------------------------------------------------------------------------------------------------------------
Balance, September 30, 1998............... 22,969,108 $ 230 $ 208,588 (1,109,151) $ (17,890) $ (1,591)
Treasury shares issued.................... (498) 47,719 1,001
Issuance of common stock.................. 1,416,171 14 12,994
Treasury shares acquired.................. (10,000) (113)
Net unrealized loss on investment.........
Cash dividends ($.13 per share)...........
Repayment of ESOP Loan.................... 103
Net income................................
---------------------------------------------------------------------------------------------------------------------------------
Balance, September 30, 1999............... 24,385,279 $ 244 $ 221,084 (1,071,432) $ (17,002) $ (1,488)
Treasury shares issued.................... (917) 66,450 1,396
Issuance of common stock.................. 236,683 2 1,194
Purchase of treasury shares............... (25,000) (172)
Net unrealized gain on investment.........
Cash dividends ($.13 per share)...........
Repayment of ESOP Loan.................... 95
Net income................................
---------------------------------------------------------------------------------------------------------------------------------
Balance, September 30, 2000............... 24,621,962 $ 246 $ 221,361 (1,029,982) $ (15,778) $ (1,393)
========== ========= ============= =========== =========== =========
</TABLE>
<PAGE>
<TABLE>
<CAPTION>
Accumulated
Other Totals
Comprehensive Retained Stockholders'
Income (Loss) Earnings Equity
----------------------------------------------
<S> <C> <C> <C>
Balance, September 30, 1997............... $ - $ 22,005 $ 64,829
Treasury shares issued.................... 338
Issuance of common stock.................. 151,308
Treasury shares acquired.................. (4,435)
Net unrealized loss on investment......... (43) (43)
3-for-1 stock split effected in the form
of a 200% stock dividend................. (135) -
Loan to ESOP.............................. (1,302)
Tax benefit of stock option plan.......... 405
Cash dividends ($.13 per share)........... (2,297) (2,297)
Repayment of ESOP loan.................... 64
Net income................................ 27,611 27,611
------------------------------------------------------------------------------------------
Balance, September 30, 1998............... $ (43) $ 47,184 $ 236,478
Treasury shares issued.................... 503
Issuance of common stock.................. 13,008
Treasury shares acquired.................. (113)
Net unrealized loss on investment......... (1,719) (1,719)
Cash dividends ($.13 per share)........... (2,931) (2,931)
Repayment of ESOP Loan.................... 103
Net income................................ 18,460 18,460
------------------------------------------------------------------------------------------
Balance, September 30, 1999............... $ (1,762) $ 62,713 $ 263,789
Treasury shares issued.................... 479
Issuance of common stock.................. 1,196
Purchase of treasury shares............... (172)
Net unrealized gain on investment......... 788 788
Cash dividends ($.13 per share)........... (3,125) (3,125)
Repayment of ESOP Loan.................... 95
Net income................................ 18,165 18,165
------------------------------------------------------------------------------------------
Balance, September 30, 2000............... $ (974) $ 77,753 $ 281,215
========== ========== ===========
</TABLE>
See accompanying notes to consolidated financial statements
46
<PAGE>
RESOURCE AMERICA, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
YEARS ENDED SEPTEMBER 30, 2000, 1999 AND 1998
<TABLE>
<CAPTION>
2000 1999 1998
---------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income................................................................... $ 18,165 $ 18,460 $ 27,611
Adjustments to reconcile net income to net cash
provided by (used in) operating activities:
Depreciation, depletion and amortization.................................. 9,872 5,985 1,493
Amortization of discount on senior notes and deferred finance costs....... 1,110 1,241 1,045
Provision for possible losses............................................. 936 500 505
Minority interest in Atlas Pipeline Partners L.P.......................... 2,058 - -
Equity in loss of unconsolidated subsidiary............................... 1,132 49 -
(Gain) loss from operations of discontinued subsidiary.................... (476) 5,686 393
(Gain) loss from disposal of discontinued subsidiary...................... (12,944) 275 -
Deferred income taxes..................................................... 5,825 (639) (4,317)
Accretion of discount..................................................... (5,802) (18,965) (6,520)
Collection of interest.................................................... 5,697 13,369 5,229
Extraordinary gain on debt extinguishment................................. (683) (299) (239)
Cumulative effect of change in accounting principle....................... - 59 -
Gain on asset dispositions................................................ (1,628) (4,728) (30,211)
Property impairments and abandonments..................................... 877 (6) 260
Change in operating assets and liabilities:
(Increase) decrease in accounts receivable and other assets............... (6,305) (3,519) 2,338
(Decrease) increase in accounts payable and other liabilities............. (9,287) (9,690) 2,540
---------- ------------ -----------
Net cash provided by operating activities of continuing operations........... 8,547 7,778 127
CASH FLOWS FROM INVESTING ACTIVITIES:
Net cash (paid) acquired in business acquisitions............................ - (15,942) 10,058
Proceeds from sale of subsidiary............................................. 126,276 4,017 -
Capital expenditures......................................................... (11,066) (11,556) (2,331)
Principal payments on notes receivable....................................... 73,259 28,516 76,915
Proceeds from sale of assets................................................. 1,269 192 197,668
(Increase) decrease in other assets.......................................... (10,115) 2,349 (12,903)
Investments in real estate loans and ventures................................ (5,193) (97,594) (343,270)
Increase in other liabilities................................................ 3,388 160 2,003
---------- ----------- -----------
Net cash provided by (used in) investing activities of continuing operations. 177,818 (89,858) (71,860)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings................................................................... 104,292 244,578 16,147
Principal payments on borrowings............................................. (192,569) (153,331) (31,630)
Net proceeds from Atlas Pipeline Partners L.P. public offering............... 15,251 - -
Dividends paid............................................................... (3,125) (2,931) (2,297)
Purchase of treasury stock................................................... (172) (113) (4,435)
Repayment of ESOP loan....................................................... 95 41 -
(Increase)decrease in other assets........................................... (67) 237 (1,149)
Proceeds from issuance of stock.............................................. 858 1,075 119,611
---------- ----------- -----------
Net cash provided by (used in) financing activities of continuing operations. (75,437) 89,556 96,247
---------- ----------- -----------
Net cash used in discontinued operations..................................... (26,325) (48,317) (18,478)
---------- ----------- -----------
Increase (decrease) in cash and cash equivalents............................. 84,603 (40,841) 6,036
Cash and cash equivalents at beginning of year............................... 32,504 73,345 67,309
---------- ----------- -----------
Cash and cash equivalents at end of year..................................... $ 117,107 $ 32,504 $ 73,345
========== =========== ===========
</TABLE>
See accompanying notes to consolidated financial statements
47
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NOTE 1 - NATURE OF OPERATIONS
Resource America, Inc. (the "Company") is involved in two business
segments: energy and real estate finance. In energy, the Company drills for and
sells natural gas and, to a significantly lesser extent, oil. Through Atlas
Pipeline Partners, L.P. a majority owned subsidiary partnership, the Company
transports natural gas from wells it owns and operates to interstate pipelines
and, in some cases, to end users. The Company finances a substantial portion of
its drilling activities through drilling partnerships it sponsors. The Company
typically acts as the general or managing partner of these partnerships and has
a material partnership interest. In real estate finance, the Company manages a
portfolio of real estate loans. These loans were, at the time of acquisition,
typically troubled loans purchased at a discount both to their outstanding loan
balances and to the appraised value of their underlying properties. The loans
are generally secured by junior liens on the underlying property. In some
instances, the Company's loans are secured by devices other than a lien on the
underlying properties. The borrowers on the Company's loans typically have
entered into agreements requiring them to pay all of the net cash flow from the
underlying property to the Company and imposing management controls, including
appointment of Brandywine Construction and Management, Inc., a real estate
manager affiliated with the Company, as property manager or supervisor.
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The consolidated financial statements include the accounts of the
Company and its wholly owned subsidiaries. The Company also owns an individual
interest in the assets and is separately liable for its share of liabilities of
oil and gas partnerships in which it has an ownership interest. In accordance
with established practice in the oil and gas industry, the Company also includes
its prorata share of income and expenses of the oil & gas partnerships in which
the Company has an interest. All material intercompany transactions have been
eliminated.
Reclassifications
In prior years, consistent with the presentation of other specialty
finance companies, the Company presented its consolidated balance sheet on a
non-classified basis, which does not segregate assets and liabilities into
current and non-current categories.
As a result of the sale of its small ticket equipment leasing
subsidiary, the Company believes that it would be more appropriate to present a
classified balance sheet. The consolidated balance sheet at September 30, 1999
has been reclassified to conform with this new presentation. Additionally, the
assets of the small ticket leasing subsidiary at September 30, 1999 have been
reclassified as "Net assets of discontinued operations" (See Note 12). Certain
other reclassifications have also been made to the fiscal years 1999 and 1998
consolidated financial statements to conform with the fiscal 2000 presentation.
48
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (Continued)
Use of Estimates
Preparation of the financial statements in conformity with accounting
principles generally accepted in the United States requires management to make
estimates and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenues and expenses
during the reporting period. Actual results could differ from these estimates.
Allowance for Possible Losses
In establishing its allowance for possible losses, the Company's real
estate finance operation reviews the carrying value of its loans on a quarterly
basis to determine whether it is greater than the sum of the anticipated future
projected cash flows from the loans. It also considers the historic performance
of the Company's loan portfolio, characteristics of the loans in the portfolio
and the properties underlying those loans, experience regarding losses in
similar loans, payment history on specific loans as well as general economic
conditions in the United States, in the borrower's geographic area or in the
borrower's (or its tenants') specific industry. As indicated by these factors,
an appropriate allowance is then provided through charges to operations.
Impairment of Long-Lived Assets
The Company reviews its long-lived assets for impairment whenever
events or circumstances indicate that the carrying amount of an asset may not be
recoverable. If it is determined that an asset's estimated future cash flows
will not be sufficient to recover its carrying amount, an impairment charge will
be recorded to reduce the carrying amount for that asset to its estimated fair
value.
Stock-Based Compensation
As permitted by Statement of Financial Accounting Standards No. 123
(SFAS123), "Accounting for Stock Based Compensation", the Company recognizes
compensation expense with respect to stock option grants to employees using the
intrinsic value method prescribed by Accounting Principles Board Opinion No. 25;
stock-based compensation with respect to non-employees is recognized under the
fair value method prescribed by SFAS 123.
Equity Securities
The Company has classified its investment in RAIT Investment Trust
("RAIT") (formerly Resource Asset Investment Trust), a real estate investment
trust sponsored by the Company, as available-for-sale. As such, it is carried at
market value and the unrealized gain or loss is reported net of tax within
accumulated other comprehensive income.
Comprehensive Income
Comprehensive income includes net income and all other changes in the
equity of a business during a period from transactions and other events and
circumstances from non-owner sources. These changes, other than net income, are
referred to as "other comprehensive income" and for the Company include changes
in the fair value of marketable securities.
49
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (Continued)
Operating Segments
SFAS 131, "Disclosures about Segments of an Enterprise and Related
Information," requires that a public business enterprise report financial and
descriptive information about its reportable operating segments. Operating
segments are components of an enterprise about which separate financial
information is available that is evaluated regularly by the Company's chief
operating decision makers in deciding how to allocate resources and in assessing
performance.
New Accounting Standards
In June 1998, the FASB issued SFAS 133, "Accounting for Derivative
Instruments and Hedging." SFAS 133 will require the Company to recognize all
derivatives as either assets or liabilities in its consolidated balance sheet
and to measure those instruments at fair value. The Company is required to adopt
SFAS 133 effective October 1, 2000. The effect of adopting SFAS 133 on the
Company's consolidated financial position, results of operations and cash flows
will be dependent on the extent of future hedging activities and fluctuations in
interest rates.
In December 1999, the Securities and Exchange Commission ("SEC") issued
Staff Accounting Bulletin No. 101 "Revenue Recognition in Financial Statements"
("SAB 101"). SAB 101, as amended, summarizes certain of the SEC's views in
applying generally accepted accounting principles to revenue recognition in
financial statements. Management does not expect the adoption of SAB 101 to have
a material effect on the Company's operations or financial position. The Company
is required to adopt SAB 101 effective October 1, 2000.
Oil and Gas Properties
The Company follows the successful efforts method of accounting.
Accordingly, property acquisition costs, costs of successful exploratory wells,
all development costs, and the cost of support equipment and facilities are
capitalized. Costs of unsuccessful exploratory wells are expensed when such
wells are determined to be nonproductive. The costs associated with drilling and
equipping wells not yet completed are capitalized as uncompleted wells,
equipment, and facilities. Geological and geophysical costs and the costs of
carrying and retaining undeveloped properties, including delay rentals, are
expensed as incurred.
Production costs, overhead, and all exploration costs other than costs
of exploratory drilling are charged to expense as incurred.
Unproved and proved properties are assessed periodically to determine
whether there has been a decline in value and, if such decline is indicated, a
loss is recognized. The Company compares the carrying value of its proved
developed gas and oil producing properties to the estimated future cash flow,
net of applicable income taxes, from such properties in order to determine
whether their carrying values should be reduced. No adjustment was necessary
during any of the fiscal years in the three year period ended September 30,
2000.
50
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (Continued)
Oil and Gas Properties - (Continued)
On an annual basis, the Company estimates the costs of future
dismantlement, restoration, reclamation, and abandonment of its gas and oil
producing properties. Additionally, the Company estimates the salvage value of
equipment recoverable upon abandonment. At both September 30, 2000 and 1999, the
Company's estimate of equipment salvage values was greater than or equal to the
estimated costs of future dismantlement, restoration, reclamation, and
abandonment.
Depreciation, Depletion and Amortization
Proved developed gas and oil properties, which include intangible
drilling and development costs, tangible well equipment, and leasehold costs,
are amortized on the unit-of-production method using the ratio of current
production to the estimated aggregate proved developed gas and oil reserves.
Depreciation of property and equipment, other than gas and oil
properties, is computed using the straight-line method over the estimated
economic lives, which range from three to 39 years.
Other Assets
Included in other assets are intangible assets that consist primarily
of contracts acquired through acquisitions recorded at fair value on their
acquisition dates, the excess of the acquisition cost over the fair value of the
net assets of a business acquired (goodwill) and deferred financing costs. The
contracts acquired are being amortized on a declining balance method, except for
the syndication network which is being amortized on a straight-line basis, over
their respective estimated lives, ranging from five to 30 years, goodwill is
being amortized on a straight-line basis over periods ranging from 15 to 30
years, deferred financing costs are being amortized over the terms of the
related loans (two to seven years) and other costs are being amortized over
varying periods of up to five years.
<TABLE>
<CAPTION>
Other assets at September 30, 2000 and 1999 were:
2000 1999
---------- -----------
(in thousands)
<S> <C> <C>
Contracts acquired (including syndication network).................. $ 17,378 $ 18,636
Goodwill............................................................ 28,484 25,147
Deferred financing costs............................................ 2,533 4,866
Investments......................................................... 8,581 -
Note and escrow received upon disposal of subsidiary
(net of allowance for possible losses of $8,944).................. 16,080 -
Other (net of allowance for possible losses of $500)................ 3,139 2,520
---------- -----------
$ 76,195 $ 51,169
========== ===========
</TABLE>
Fair Value of Financial Instruments
The following methods and assumptions were used by the Company in
estimating the fair value of each class of financial instruments for which it is
practicable to estimate fair value.
For cash and cash equivalents, receivables and payables, the carrying
amounts approximate fair value because of the short maturity of these
instruments.
51
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (Continued)
For investments in real estate loans, because each loan is a unique
transaction involving a discrete property, it is impractical to determine their
fair values. However, the Company believes the carrying amounts of the loans are
reasonable estimates of their fair value considering the nature of the loans and
the estimated yield relative to the risks involved.
The following table provides information on other financial
instruments:
<TABLE>
<CAPTION>
Carrying Estimated
Amount Fair Value
------------- ----------
(in thousands)
<S> <C> <C>
Energy non-recourse debt............................................ $ 23,165 23,165
Real estate finance non-recourse debt............................... 25,875 25,875
Senior debt......................................................... 80,391 73,960
Other debt.......................................................... 5,501 5,501
------------- ------------
$ 134,932 $ 128,501
============= ============
</TABLE>
Concentration of Credit Risk
Financial instruments which potentially subject the Company to
concentrations of credit risk consist principally of periodic temporary
investments of cash. The Company places its temporary cash investments in high
quality short-term money market instruments and deposits with high quality
financial institutions and brokerage firms. At September 30, 2000, the Company
had $121.3 million in deposits at various banks, of which $119.0 million is over
the insurance limit of the Federal Deposit Insurance Corporation. No losses have
been experienced on such investments.
Revenue Recognition
Energy Operations
The Company conducts certain energy activities through, and a portion
of its revenues are attributable to, sponsored limited partnerships
("Partnerships"). These Partnerships raise money from investors to drill gas and
oil wells. The Company serves as general partner of the Partnerships and assumes
customary rights and obligations for the Partnerships. As the general partner,
the Company is liable for Partnership liabilities and can be liable to limited
partners if it breaches its responsibilities with respect to the operations of
the Partnerships. The income from the Company's general partner interest is
recorded when the gas and oil are produced by a Partnership. The Company also
contracts to drill the gas and oil wells owned by the Partnerships. The income
from a drilling contract relating to a well is recorded upon substantial
completion of the well.
The Company is entitled to receive management fees according to the
respective Partnership agreements. Such fees are recognized as income and are
included in energy services.
The Company sells interests in gas and oil wells and retains a working
interest and/or overriding royalty. The income from the working interests and
overriding royalties is recorded when the gas and oil are produced.
52
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (Continued)
Real Estate Finance
The difference between the Company's cost basis in a real estate loan
and the sum of projected cash flows from that loan is accreted into interest
income over the estimated life of the loan using the interest method which
recognizes a level interest rate over the life at the loan. Projected cash
flows, which include amounts realizable from the underlying properties, are
reviewed on a regular basis, as are property appraisals. Changes to projected
cash flows reduce or increase the amounts accreted into interest income over the
remaining life of the loan.
Gains on the sale of a senior lien interest in a real estate loan are
recognized based on an allocation of the Company's cost basis between the
portion of the loan sold and the portion retained based upon the fair value of
those respective portions on the date of sale. Gains on the refinancing of a
real estate loan only arise when the financing proceeds exceed the cost of the
loan financed. Any gain recognized on a sale of a senior lien interest or a
refinancing is credited to income at the time of such sale or refinancing.
Before January 1, 1999, most of the Company's transactions involving
the sale of senior lien interests in its real estate loans were structured to
meet the criteria for sale under generally accepted accounting principles. Thus,
for transactions that were completed before January 1, 1999, the Company
recorded gainS on sale. Effective January 1, 1999, the Company made a strategic
decision to structure future transactions as financings t rather than as sales.
The cash flows available to the Company, which are generally based on the cash
flows of the properties underlying its loans, are unaffected by these
modifications. The primary effect of this change in structure is a shift from
the recognition of an immediate gain on the sale of a senior lien interest in a
loan receivable to the retention of the full investment in the loan on the
Company's books. The recognition of interest income on that investment over the
life of the loan and the recording the proceeds from the senior lien interest as
debt and recognizing interest expense on that debt.
53
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (Continued)
Cash Flow Statements
The Company considers temporary investments with a maturity at the date
of acquisition of 90 days or less to be cash equivalents.
Supplemental disclosure of cash flow information:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Cash paid during the year for:
Interest............................................................ $ 17,652 $ 17,614 $ 15,090
Income taxes (refunded) paid........................................ (787) 10,622 12,050
Non-cash activities include the following:
Investment in real estate venture received in
exchange for note receivable...................................... - 16,331 -
Stock issued in acquisition(s)...................................... - 12,437 29,534
Details of acquisitions:
Fair value of assets acquired....................................... $ - $ 48,289 $ 74,635
Stock issued........................................................ - (12,437) (29,534)
Liabilities assumed................................................. - (19,910) (45,968)
Amounts due seller.................................................. - - (9,191)
----------- ----------- -----------
Net cash paid (acquired).......................................... $ - $ 15,942 $ (10,058)
=========== =========== ===========
Disposal of business:
Net liabilities assumed by buyer.................................. $ - $ 4,938 $ -
=========== =========== ===========
Other assets received upon disposal of subsidiary................. $ 25,969 $ - $ -
=========== =========== ===========
</TABLE>
Income Taxes
The Company records deferred tax assets and liabilities, as
appropriate, to account for the estimated future tax effects attributable to
temporary differences between the financial statement and tax bases of assets
and liabilities and operating loss carryforwards, using currently enacted tax
rates. The deferred tax provision or benefit each year represents the net change
during that year in the deferred tax asset and liability balances.
54
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 2 - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - (Continued)
Earnings Per Share
Basic earnings per share is determined by dividing net income by the
weighted average number of shares of common stock outstanding during the period.
Earnings per share - diluted are computed by dividing net income by the sum of
the weighted average number of shares of common stock outstanding and dilutive
potential shares issuable during the period. Dilutive potential shares of common
stock consist of the excess of shares issuable under the terms of various stock
option and warrant agreements over the number of such shares that could have
been reacquired (at the weighted average price of shares during the period) with
the proceeds received from the exercise of the options and warrants.
The computations of basic and diluted earnings per share for each year
were as follows:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Income from continuing operations before extraordinary item and
cumulative effect of a change in accounting principle............... $ 4,062 $ 24,181 $ 27,765
Income (loss) from discontinued operations............................. 476 (5,686) (393)
Gain (loss) on disposal of subsidiary.................................. 12,944 (275) -
Extraordinary gain on early extinguishment of debt..................... 683 299 239
Cumulative effect of a change in accounting principle.................. - (59) -
----------- ----------- -----------
Net income........................................................ $ 18,165 $ 18,460 $ 27,611
=========== =========== ===========
Basic average shares of common stock outstanding....................... 23,413 22,108 16,703
Dilutive effective of stock option and award plans..................... 415 695 565
----------- ----------- -----------
Dilutive average shares of common stock................................ 23,828 22,803 17,268
=========== =========== ===========
</TABLE>
NOTE 3 - CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
In the ordinary course of its business operations, the Company has
ongoing relationships with several related entities, primarily a property
management firm, a bank, RAIT and a law firm. As particular opportunities have
arisen, the Company has purchased real estate loans from lenders, or involving
borrowers, which are affiliated with officers of the Company. In two instances
(excluding sales to RAIT) the Company has sold senior or junior lien interests
in real estate loans to purchasers affiliated with officers of the Company. At
September 30, 2000, loans held with respect to related borrowers or acquired
from related lenders constitute 42.9% ($79.8 million), by book value, of the
Company's portfolio loans, while senior or junior lien interests sold to related
purchasers constituted .5% ($1.9 million) of all such interests. Transactions
with affiliates must be approved by the Company's Board of Directors, including
a majority of the outside directors. In addition, loan acquisitions must be
approved by the Investment Committee of the Board of Directors which consists of
three outside directors. A more detailed description of these relationships and
transactions is set forth below.
55
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 3 - CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS - (Continued)
Relationship with Brandywine Construction & Management, Inc. ("BCMI").
The properties underlying 28 of the Company's real estate loans and investments
in real estate ventures are managed by BCMI, a firm in which the Chairman of the
Company is the Chairman of the Board of Directors and a minority stockholder
holding approximately 8% of BCMI's capital stock. The Company has advanced funds
to certain borrowers for improvements on their properties, which have been
performed by BCMI. The President of BCMI (or an entity affiliated with him) has
also acted as the general partner, president or trustee of ten of the borrowers.
In addition, BCMI owns an 11% limited partnership interest in another borrower.
Relationship with Hudson United Bank. The Company maintains a normal
banking and borrowing relationship with Hudson United Bank, formerly Jefferson
Bank. The Company anticipates that it may effect other borrowings in the future
from Hudson United Bank. The Chairman of the Company and his spouse were
officers and directors of Jefferson Bank and its holding company, and were
principal stockholders of that bank's holding company, until its acquisition in
November 1999 by Hudson United Bancorp, the holding company for Hudson United
Bank. The former President of the Company was a director of Jefferson Bank until
its acquisition. Following the acquisition, the Chairman's spouse served as
director of Hudson United Bancorp until July 2000. Hudson United Bank is also a
tenant at one property owned by a partnership in which the Company holds a 50%
interest.
Relationship with RAIT. In January 1998, the Company acquired 15% of
the outstanding common shares of beneficial interest in RAIT, a real estate
investment trust sponsored by the Company for an investment of approximately
$7.0 million. In June 1998, the Company acquired additional common shares in a
second offering for $5.0 million, and currently holds approximately 14% of
RAIT's outstanding common shares. The spouse of the Chairman of the Company is
Chairman and Chief Executive Officer of RAIT. The Company has the right to
nominate one person for election to RAIT's Board of Trustees until such time as
its ownership of RAIT's outstanding common shares is less than 5%. A Senior Vice
President of the Company, who is also the son of the Chairman of the Company and
the brother of its former President, currently serves as the Company's nominee
and as the secretary of RAIT. The former Vice Chairman and Executive Vice
President of the Company is the President of RAIT.
In connection with RAIT's initial offering, the Company sold ten loans,
and senior lien interests in two other loans, to RAIT at an aggregate purchase
price of $20.1 million (including $2.1 million attributable to senior lien
interests acquired by the Company in connection with the sales to RAIT). One of
the loans and one of the senior lien interests were originated for RAIT and sold
to it by the Company at cost. The Company realized a total gain on the sale of
the loans and senior lien interests of $3.1 million during the fiscal year ended
September 30, 1998.
The Company has engaged in the following transactions with RAIT
subsequent to the sale of the initial investments:
Fiscal year ended September 30, 2000
o In December 1999, the Company sold 100% of the common stock in a
wholly-owned subsidiary to RAIT for $9.9 million, recognizing a gain of
$983,000. The subsidiary held a subordinate interest in a loan which was secured
by a retail property located in Centreville, VA. The Company acquired the loan
in 1998 for a net investment of $7.9 million.
o In May 2000, the Company sold 100% of the common stock in a
wholly-owned subsidiary to RAIT for $1.9 million. The subsidiary had a
subordinated interest in a loan which it had originated for $1.3 million. At the
time of the sale, the loan had a carrying value of $1.6 million; consequently, a
gain of $273,000 was recognized by the Company.
o In June 2000, pursuant to a Participation Termination Agreement, the
Company paid to RAIT a $300,000 termination fee. The fee was in connection with
a loan refinancing in which RAIT held a $4.9 million participation interest.
56
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 3 - CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS - (Continued)
Fiscal year ended September 30, 1999
o In June 1999, the Company acquired a first mortgage loan at face
value from RAIT for $2.5 million. The loan is secured by property
in which the Company has held a subordinate interest since 1991.
o In December 1998, the Company sold a senior lien interest in a
loan for $4.0 million to RAIT and recognized a gain of $2.0
million.
o In December 1998, the Company purchased a junior lien interest in
a loan held by RAIT in the amount of $4.0 million. The junior lien
interest was repaid in June 1999 for $4.1 million and the Company
recognized a gain of $135,000.
o The Company and RAIT jointly acquired a loan for $77.0 million of
which $10.0 million was contributed by RAIT.
o A senior lien interest sold by the Company to RAIT in fiscal 1998
was repaid in August 1999.
Fiscal year ended September 30, 1998
o The Company sold senior lien interests in three loans to RAIT for
an aggregate of $18.0 million and recognized aggregate gains of
$5.1 million.
o The Company and RAIT jointly acquired a loan for $85.5 million,
$10.0 million of which was contributed by RAIT.
o The Company sold to RAIT two loans, both of which it had
originated for RAIT in connection with its sponsorship of RAIT, at
their aggregate carrying value of $7.7 million. The Company
retained a $1.3 million junior lien interest in one of these
loans. The retained interest is subordinate both to RAIT's $4.0
million interest in the loan and a $12.0 million interest held by
an unaffiliated party.
o The Company made a first mortgage loan to OSEB Associates, L.P.
("OSEB"), which is owned by RAIT (89%) and BCMI (11%). The loan
bears interest at 10% per annum on stated principal in the amount
of $65.0 million. OSEB obtained outside financing to reduce the
loan by $44.0 million; the balance of the loan is secured by a
second mortgage and pledge of partnership interests in OSEB.
Relationship with The Bancorp.com, Inc. In October and November 1999,
the Company acquired 9.9% of the outstanding shares of The Bancorp.com, Inc.
("TBI") for an investment of approximately $1.8 million. At the time of the
Company's investment, the Chairman of the Company was also Chairman of TBI, the
then-President of the Company (a son of the Chairman of the Company) was the
President of TBI, and a director of the Company, and the wife of the
then-Vice-Chairman of the Company, were directors of TBI. Subsequently, the
Company's Chairman relinquished his position at TBI with his son becoming
Chairman and his spouse becoming Chief Executive officer of TBI. As of September
30, 2000, the Company had $25.4 million on deposit at TBI's banking subsidiary.
Relationship with Law Firm. Until April 1996, the Chairman of the
Company was of counsel to Ledgewood Law Firm, P.C. ("Ledgewood"), which provides
legal services to the Company. Ledgewood was paid $1.6 million, $1.3 million,
and $1.2 million during fiscal 2000, 1999, and 1998, respectively, for legal
services rendered to the Company. The Chairman of the Company receives certain
debt service payments from Ledgewood related to the termination of his
affiliation with such firm and its redemption of his interest therein.
Relationships with Certain Borrowers. The Company has from time to time
purchased loans in which affiliates of the Company are affiliates of the
borrowers.
57
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 3 - CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS - (Continued)
In March 2000, the property securing a loan held by the Company was
purchased by a limited partnership of which the former Executive Vice President
and Vice Chairman of the Company is the president of the general partner. The
Chairman of the Company, two directors of the Company and the President of BCMI
are equal limited partners of a limited partnership which is the sole limited
partner of the borrower.
In July 2000, the Company split an investment in a loan with a balance
of $4.4 million, including unpaid interest and penalties into two distinct
loans, one for $4,450,000 and the other for $1,984,000. The Company sold the
first loan to an unaffiliated third party for face value and exchanged the
second loan for a similar loan from the general partner of the original borrower
for face value. The former Executive Vice President and Vice Chairman of the
Company is the president and a director of, such general partner.
In September 1998, the Company acquired a defaulted loan in the
original principal amount of $91.0 million. In September 2000, in connection
with a refinancing and pursuant to a prior agreement, a newly formed limited
liability company became the borrower. The Chairman, the former Executive Vice
President and Vice Chairman and the former President of the Company and the
President of BCMI are equal limited partners (24.75% each) of a partnership that
is a 59% limited partner of the managing partner which has a 99% interest in the
sole member of the borrower. In addition, the former Executive Vice President
and Vice Chairman of the Company is the President of the general partner of the
managing partner of the sole member of the borrower as well as the operating
manager of the borrower and the general partner of the 59% limited partner
described above. After September 30, 2000, the 59% interest was reduced to 30%.
In March 1998, the Company acquired a loan under a plan of
reorganization in bankruptcy. An order of the bankruptcy court in effect when
the Company acquired the loan required that legal title to the property
underlying the loan be transferred on or before June 30, 1998. In order to
comply with that order and to maintain control of the property, Evening Star
Associates took title to the property on or about June 19, 1998. A subsidiary of
the Company serves as general partner of Evening Star Associates and holds a 1%
interest; the Chairman, former Executive Vice President and Vice Chairman, and
former President of the Company purchased a 94% limited partnership interest in
Evening Star Associates for $200,000.
In August 1997, the Company acquired a loan with a face amount of $2.3
million from Jefferson Bank (now Hudson United Bank) at a cost of $1.6 million.
The loan is secured by a property owned by a partnership in which the Company's
former Executive Vice President and Vice Chairman, and the Chairman, together
with the Chairman's spouse, are limited partners. The former Executive Vice
President and Vice Chairman was previously the general partner of such
partnership. The Company leases its headquarters space at such property. The
Company occupies the space on a month-to-month tenancy at a rent of $9,564 per
month. Ledgewood is a tenant at such property.
In June 1997, the Company acquired a loan with a face amount of $7.0
million from a partnership in which the former Executive Vice President and Vice
Chairman, and the Chairman of the Company, together with the Chairman's wife,
are limited partners. The former Vice Chairman and Executive Vice President was
previously the general partner of such partnership. The Company acquired such
loan at a cost of $3.0 million.
58
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 3 - CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS - (Continued)
In December 1996, the Company acquired a loan with a face amount of
$52.7 million from an unaffiliated third party at a cost of $19.3 million. The
property securing such loan was owned by two partnerships: the Building
Partnership, which owned the office building, and the Garage Partnership, which
owned the parking garage. Pursuant to a loan restructuring agreement entered
into in 1993, an affiliate of the holder of the loan was required to hold, as
additional security for the loan, general partnership interests in both the
Building Partnership and the Garage Partnership. The partnership interests in
the Building Partnership and Garage Partnership were assigned to limited
partnerships affiliated with the Company and certain of its officers. In June
1999, the loan was repaid pursuant to the terms of an existing loan
restructuring agreement. The Company received $29.6 million in cash, plus a 50%
interest in the Building and Garage Partnerships. The interest of the Company's
officers was terminated.
Relationships with Certain Lienholders. The Company holds a first
mortgage lien on a hotel property which in January 1999 was foreclosed upon by
another corporation ("Corporate Owner"). In August 1999, the Company's
then-President (son of the Company's Chairman) became President of the Corporate
Owner, and the Chairman of the Company became Chairman and a minority
shareholder of the Corporate Owner. In addition, the Chairman of the Company is
a limited partner holding a two-thirds interest in a partnership which holds
convertible securities to acquire the common stock of the Corporate Owner.
Furthermore, the President of the Corporate Owner is the sole officer, director
and shareholder of another corporation which is this partnership's general
partner. On a fully converted basis, of the Company's then-President and
Chairman would have a 19% interest in the Corporate Owner.
The Company has sold three senior lien interests and one junior lien
interest in its real estate loans to entities in which officers and/or directors
of the Company have minority interests, as discussed in the following
paragraphs.
In December 1997, the Company purchased from third parties, for an
aggregate of $1.5 million, two loans in the aggregate original principal amount
of $2.0 million and with an aggregate outstanding balance at the time of
purchase of $1.9 million. The loans are secured by an apartment building. The
Company sold a senior lien interest in one of the loans for $1.0 million to a
limited partnership in which the Chairman and the former Executive Vice
President and Vice Chairman of the Company beneficially own a 14.4% interest,
reducing the Company's net investment to $518,000 and leaving the Company with a
retained interest in outstanding loan receivables of $1.0 million (at a book
value of $803,000). The Company recognized a gain of $322,900 on the sale of
this loan.
In fiscal 1999, the Company sold, at book value, an $875,000 senior
lien interest in industrial development revenue bonds it had acquired in a prior
year to a limited partnership in which the Chairman and the former Executive
Vice President and Vice Chairman of the Company beneficially owned a 22.0%
limited partnership interest.
From November 1996 to June 1997 the Company acquired from third parties
loans relating to one property in the aggregate original principal amount of
$5.8 million (and with aggregate outstanding balances at the respective times of
purchase of $7.6 million) for an investment of $2.5 million. The Company sold,
for $2.2 million, a senior lien interest in one of the loans and recognized a
$28,900 gain on the sale. The purchaser was a limited partnership in which the
Chairman and the former Executive Vice President and Vice Chairman of the
Company beneficially own an 18.3% limited partnership interest. The senior lien
interest was paid off in December 1997.
In June 1996, for an investment of $2.4 million, the Company acquired
from third parties a loan in the original principal amount of $3.3 million (and
with a then outstanding balance of $3.3 million). The Company sold, at book
value, a junior lien interest in the loan for $875,000 to a limited partnership
in which the Chairman and the former Executive Vice President and Vice Chairman
of the Company beneficially own a 21.3% limited partnership interest. The junior
lien interest was paid off in May 1999.
Management believes that any other commercial real estate transactions
and balances involving parties that may be considered to be related parties are
not material.
59
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 4 - INVESTMENTS IN REAL ESTATE LOANS
In acquiring real estate loans, the Company focused primarily on the
purchase of income producing loans at a discount from both the face value of
such loans and the appraised value of the properties underlying the loans. The
Company records as income the accretion of a portion of the difference between
its cost basis in a commercial mortgage and the sum of projected cash flows
therefrom. Cash received by the Company for payment on each loan is allocated
between principal and interest. This accretion of discount amounted to $5.8
million, $19.0 million and $6.5 million during the years ended September 30,
2000, 1999, and 1998, respectively. As the Company sells senior lien interests
or receives funds from refinancings of its loans, a portion of the cash received
is employed to reduce the cumulative accretion of discount included in the
carrying value of the Company's investments in real estate loans.
At September 30, 2000 and 1999, the Company held real estate loans
having aggregate face values of $691.4 million and $747.1 million, respectively,
which were being carried at aggregate costs of $183.9 million and $250.2
million, including cumulative accretion.
During fiscal 1999, the Company received, in exchange for its
investment in a real estate loan, cash and a 50% interest in a partnership that
owns a building which secured the loan. The Company also received a deed-in-lieu
of foreclosure with respect to one real estate loan, taking title to the
underlying property. The partnership interest and property have been classified
as investments in real estate ventures.
Amounts receivable, net of senior lien interests and deferred costs,
were $339.5 million and $348.7 million at September 30, 2000 and 1999,
respectively. The following is a summary of the changes in the carrying value of
the Company's investments in real estate loans for the years ended September 30,
2000 and 1999.
<TABLE>
<CAPTION>
Years Ended September 30,
-----------------------------------
2000 1999
------------- --------------
(in thousands)
<S> <C> <C>
Balance, beginning of year...................................................... $ 250,231 $ 188,651
New loans....................................................................... - 88,869
Additions to existing loans..................................................... 4,994 8,558
Provisions for possible losses.................................................. (936) (500)
Accretion of discount (net of collection of interest)........................... 5,802 18,965
Collections of principal........................................................ (63,379) (20,646)
Cost of loans sold.............................................................. (12,785) (17,335)
Loans reclassified to investments in real estate ventures....................... - (16,331)
------------- ------------
Balance, end of year............................................................ $ 183,927 $ 250,231
============= ============
</TABLE>
The following is a summary of activity in the Company's allowance for
possible losses related to real estate loans for the years ended September 30,
2000 and 1999:
<TABLE>
<CAPTION>
Years Ended September 30,
-----------------------------------
2000 1999
------------- --------------
(in thousands)
<S> <C> <C>
Balance, beginning of year...................................................... $ 1,405 $ 1,191
Provision for possible losses................................................... 936 500
Write-down...................................................................... (328) -
Reclassification of possible losses-discontinued subsidiary..................... - (286)
------------- ------------
Balance, end of year............................................................ $ 2,013 $ 1,405
============= ============
</TABLE>
60
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 5 - DEBT
Total debt consists of the following:
<TABLE>
<CAPTION>
Years Ended September 30,
-----------------------------------
2000 1999
------------- --------------
(in thousands)
<S> <C> <C>
Senior debt....................................................................... $ 80,391 $ 101,400
Nonrecourse debt:
Energy:
Revolving and term bank loans................................................ 23,165 44,975
Real estate finance:
Loan facilities.............................................................. - 58,901
Revolving credit facilities.................................................. 18,000 22,000
Other........................................................................ 875 875
----------- -----------
Total non recourse debt.................................................. 42,040 126,751
Other debt........................................................................ 12,501 5,877
----------- -----------
134,932 234,028
Less current maturities........................................................... 7,250 13,333
----------- -----------
$ 127,682 $ 220,695
=========== ===========
</TABLE>
Following is a description of borrowing arrangements in place at
September 30, 2000 and 1999.
Nonrecourse Debt-Energy. The energy subsidiaries owned by the Company
maintain a $40.0 million credit facility at PNC Bank ("PNC"). The facility
permits draws based on the remaining proved developed non-producing and proved
undeveloped natural gas and oil reserves attributable to the subsidiaries' wells
and the subsidiaries' projected fees and revenues from operation of wells and
administration of partnerships. Up to $10.0 million of the facility may be in
the form of standby letters of credit. The facility is secured by the assets of
all of the energy affiliates, and a breach of the loan agreement by any of the
energy affiliates constitutes a default. The revolving credit facility has a
term ending in June 2003 and bears interest at one of two rates (elected at
borrower's option) which increase as the amount outstanding under the facility
increases: (i) PNC prime rate plus between 0 to 75 basis points, or (ii) the
Eurodollar rate plus between 150 and 225 basis points. Draws under any letter of
credit bear interest at the PNC prime rate plus 0 to 75 basis points. The credit
facility contains financial covenants, including covenants requiring the Company
to maintain specified financial notes and imposes the following limits: (a) the
energy subsidiaries' exploration expense can be no more than 20% of capital
expenditures plus exploration expense, without PNC's consent; (b) the amount of
debt that can be incurred cannot exceed specified levels without PNC's consent;
and (c) the energy affiliates may not sell, lease or transfer property without
PNC's consent. At September 30, 2000, $29.5 million was outstanding under this
facility, including the $5.7 million outstanding balance of a letter of credit
issued unnder the facility.
Nonrecourse Debt-Real Estate Finance Loan Facilities. Two loans
outstanding at September 30, 1999, aggregating $58.9 million, were repaid in
October 1999.
Real Estate Finance-Revolving Credit Facilities. In March 1998, the
Company, through certain operating subsidiaries, established an $18.0 million
revolving credit facility with Jefferson Bank (now Hudson United Bank) for its
commercial mortgage loan operations which was amended in August 1999. Credit
availability is currently $7.0 million, all of which is outstanding at September
30, 2000. The credit facility bears interest at the prime rate reported in The
Wall Street Journal (9.50% at September 30, 2000) plus .75%, and is secured by
the borrowers' interests in certain commercial loans and by a pledge of their
outstanding capital stock. Repayment of the credit facility is guaranteed by the
Company. The facility is due February 1, 2001.
61
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 5 - DEBT - (Continued)
In July 1999, the Company established a $15.0 million revolving line of
credit with Sovereign Bank, which was increased to $18.0 million on March 30,
2000. Interest is payable monthly at The Wall Street Journal prime rate (9.50%
at September 30, 2000) and principal is due upon expiration in July 2002.
Advances under this line are to be utilized to acquire commercial real estate or
interests therein, to fund or purchase loans secured by commercial real estate
or interests, or to reduce indebtedness on loans or interests which the Company
owns or holds. The advances are secured by the properties related to these
funded transactions. At September 30, 2000, $18.0 million had been advanced
under this line.
Senior Debt. In July 1997, the Company issued $115.0 million of 12%
Senior Notes (the "12% Notes") due August 2004 in a private placement. These
notes were exchanged in November 1997 with a like amount of 12% Notes which were
registered under the Securities Act of 1933. Provisions of the indenture under
which the 12% Notes were issued limit dividend payments, mergers and
indebtedness, place restrictions on liens and guarantees and require the
maintenance of certain financial ratios. At September 30, 2000, the Company was
in compliance with such provisions. At September 30, 2000 and 1999, $80.4
million and $101.4 million, respectively, of 12% Notes were outstanding.
Other Debt. Other debt includes an amount outstanding under a $5.0
million revolving line of credit with Sovereign Bank which expires July 2002.
Interest accrues at The Wall Street Journal prime rate (9.50% at September 30,
2000) and payment of accrued interest and principal is due upon the expiration
date. Advances under this line are with full recourse to the Company and are to
be utilized to repay bank debt to acquire commercial real estate or interests
therein, to fund or purchase loans secured by commercial real estate or
interests, or to reduce indebtedness on loans or interests which the Company
owns or holds and for other general corporate purposes. At September 30, 2000,
$5.0 million had been advanced under this line.
Annual debt principal payments over the next five fiscal years ending
September 30 are as follows: (in thousands) 2001 - $7.3 million, 2002 - $23.2
million, 2003 - $23.2 million, 2004 - $81.3 million and 2005 - $ 0.
NOTE 6 - INCOME TAXES
The following table details the components of the Company's income tax
expense from continuing operations for the fiscal years 2000, 1999 and 1998.
<TABLE>
<CAPTION>
Years Ended September 30,
-----------------------------------------
2000 1999 1998
---- ---- ----
(in thousands)
<S> <C> <C> <C>
Provision for income tax
Current
Federal......................................................... $ - $ 11,595 $ 14,536
State........................................................... 116 707 -
Deferred.......................................................... 1,522 (1,192) (1,525)
----------- ----------- -----------
$ 1,638 $ 11,110 $ 13,011
=========== =========== ===========
</TABLE>
62
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 6 - INCOME TAXES - (Continued)
The allocation of the fiscal 1999 provision reported above between
current and deferred was based upon the Company's best estimate at the date
reported. The actual current provision was ultimately less than reported while
the actual deferred provision was ultimately greater than reported by a similar
amount. The adjustment is reflected in the fiscal 2000 deferred provision. For
fiscal 2000, there is no current federal tax provision for continuing operations
because of the utilization of the credits and depletion allowance noted in the
table below.
A reconciliation between the statutory federal income tax rate and the
Company's effective income tax rate is as follows:
<TABLE>
<CAPTION>
Years Ended September 30,
-----------------------------------------
2000 1999 1998
---- ---- ----
<S> <C> <C> <C>
Statutory tax rate.................................................. 35% 35% 35%
Statutory depletion................................................. (3) (1) -
Non-conventional fuel and low-income housing credits................ (13) (4) (2)
Excessive employee renumeration..................................... 2 - -
Goodwill............................................................ 10 - -
Tax-exempt interest................................................. (8) (1) (1)
State income tax.................................................... 6 2 -
---- ---- ----
29% 31% 32%
==== ==== ====
</TABLE>
The components of the net deferred tax (liability) asset are as
follows:
<TABLE>
<CAPTION>
Years Ended September 30,
---------------------------------
2000 1999
------------- ------------
(in thousands)
<S> <C> <C>
Deferred tax assets related to:
Tax credit carryforwards................................................ $ 488 $ 669
Alternative minimum tax credit carryforwards............................ - 1,189
Interest receivable..................................................... 883 738
Unrealized losses on investments........................................ 502 910
Accrued expenses........................................................ 2,514 1,562
Net operating loss carryforwards........................................ - 591
Provision for losses.................................................... 704 1,767
------------- ------------
$ 5,091 $ 7,426
------------- ------------
Deferred tax liabilities related to:
Property and equipment basis difference................................. (21,879) (20,084)
Investment in real estate ventures...................................... (2,678) -
ESOP benefits........................................................... (101) (101)
Other................................................................... - (310)
------------- ------------
(24,658) (20,495)
------------- ------------
Net deferred tax liability............................................ $ (19,567) $ (13,069)
============= ============
</TABLE>
SFAS No. 109 requires that deferred tax assets be reduced by a
valuation allowance if it is more likely than not that some portion or all of
the deferred tax asset will not be realized. No valuation allowance was needed
at September 30, 2000 and 1999.
63
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 7 - STOCKHOLDERS' EQUITY
On May 12, 1998, the Board of Directors authorized a three-for-one
stock split effected in the form of a 200% stock dividend. This stock dividend
resulted in the issuance of 13.5 million additional shares of common stock.
In April 1998, the Company completed a public offering of 5.9 million
shares of its common stock. The Company received net proceeds (after
underwriting discounts and commissions) of $120.1 million before offering
expenses of $917,000.
In March 1998, the Company's stockholders authorized an amendment to
the Certificate of Incorporation of the Company to increase the total authorized
capital stock to 50.0 million shares, of which 49.0 million shares were common
stock and 1.0 million shares were preferred stock.
Earnings per share and weighted average shares outstanding reflect the
above transactions.
NOTE 8 - EMPLOYEE BENEFIT PLANS
Employee Stock Ownership Plan. The Company sponsors an Employee Stock
Ownership Plan ("ESOP"), which is a qualified non-contributory retirement plan
established to acquire shares of the Company's common stock for the benefit of
all employees who are 21 years of age or older and have completed 1,000 hours of
service for the Company. Contributions to the ESOP are made at the discretion of
the Board of Directors. In a prior year, the ESOP borrowed funds to purchase
shares from the Company. The Company borrowed the funds for the ESOP loan from a
bank which is payable in semiannual installments through February 1, 2003. The
loan from the Company to the ESOP was fully repaid in August 1996. Both the
Company's loan obligation and the unearned benefits expense (a reduction in
stockholders' equity) will be reduced by the amount of any loan principal
payments made by the Company. On September 28, 1998, the Company loaned $1.3
million to the ESOP, which the ESOP used to acquire 105,000 shares of the
Company's common stock.
The common stock purchased by the ESOP with the money borrowed is held
by the ESOP trustee in a suspense account. On an annual basis, a portion of the
common stock is released from the suspense account and allocated to
participating employees. Any dividends on ESOP shares are used to pay principal
and interest on the loan. As of September 30, 2000, there were 259,000 shares
allocated to participants which constitute substantially all shares prior to the
105,000 shares acquired on September 28, 1998. Compensation expense related to
the plan amounted to $140,200, $156,400 and $50,400 for the years ended
September 30, 2000, 1999 and 1998, respectively.
Employee Savings Plan. The Company sponsors an Employee Retirement
Savings Plan and Trust under Section 401(k) of the Internal Revenue Code which
allows employees to defer up to 15% of their income, subject to certain
limitations, on a pretax basis through contributions to the savings plan. The
Company matches up to 100% of each employee's contribution, subject to certain
limitations. Included in general and administrative expenses are $209,500,
$167,700, and $188,500 for the Company's contributions for the years ended
September 30, 2000, 1999 and 1998, respectively.
Stock Options. The Company has three existing employee stock option
plans, those of 1989, 1997 and 1999. No further grants may be made under the
1989 plan. Options under the 1989, 1997, and 1999 plans become exercisable as to
25% of the optioned shares each year after the date of grant, and expire not
later than ten years after the date of grant.
The 1989 plan authorizes the granting of up to 1,769,670 shares (as
amended during the fiscal year ended September 30, 1996) of the Company's common
stock in the form of incentive stock options ("ISO's"), non-qualified stock
options and stock appreciation rights ("SAR's").
64
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 8 - EMPLOYEE BENEFIT PLANS - (Continued)
In April 1997, the stockholders approved the Resource America, Inc.
1997 Key Employee Stock Option Plan. This plan, for which 825,000 shares were
reserved, provides for the issuance of ISO's, non-qualified stock options and
SAR's. In fiscal 2000, 1999 and 1998, options for 93,885, 10,000 and 669,115
shares were issued under this plan, respectively. On October 20, 1998, 744,115
of the 754,115 options granted under the 1997 Key Employee Stock Option Plan
were canceled. These options were replaced with an identical number of new
options with an exercise price of $8.08 per share, which amount represents the
market value of the Company's common stock at that date. These options vest 25%
per year commencing October 20, 1999.
In March 1999, the stockholders approved the Resource America, Inc.
1999 Key Employee Stock Option Plan. This plan, for which 1,000,000 shares were
reserved, provides for the issuance of ISO's, non-qualified stock options and
SAR's. In fiscal 2000 and 1999, options for 106,115 and 728,500 shares,
respectively, were issued under this plan.
Transactions for the three stock option plans are summarized as
follows:
<TABLE>
<CAPTION>
Years Ended September 30,
--------------- ----------------------------------------------------------------------
2000 1999 1998
------------------------- ------------------------- -------------------------
Weighted Weighted Weighted
Average Average Average
Shares Exercise Price Shares Exercise Price Shares Exercise Price
------ -------------- ------ -------------- ------ --------------
<S> <C> <C> <C> <C> <C> <C>
Outstanding - beginning of year.. 1,870,035 $ 9.77 1,321,366 $ 13.18 685,959 $ 3.85
Granted....................... 200,000 $ 7.49 1,482,615 $ 11.72 669,115 $ 22.21
Exercised..................... (144,568) $ 2.95 (166,831) $ 2.82 (33,708) $ 2.73
Canceled...................... 0 $ - (744,115) $ 21.30 - -
Forfeited..................... (282,500) $ 13.96 (23,000) $ 8.40 - -
--------- ----------- ---------
Outstanding - end of year..... 1,642,967 $ 9.38 1,870,035 $ 9.77 1,321,366 $ 13.18
========= ========= ========== ========= ========= =======
Exercisable, at end of year...... 560,131 $ 7.10 320,456 $ 2.59 292,629 $ 3.22
========= ========= ========== ========= ========= =======
Available for grant.............. 447,885 342,385 80,885
========= ========== =========
Weighted average fair value per
share of options granted
during the year............... $ 4.93 $ 10.46 $ 19.41
========= ========= =======
</TABLE>
The following information applies to options outstanding as of September 30,
2000.
<TABLE>
<CAPTION>
Outstanding Exercisable
---------------------------------------------- ----------------------------
Weighted
Average Weighted Weighted
Range of Contractual Average Average
Exercise Prices Shares Life (Years) Exercise Price Shares Exercise Price
--------------- ------ ------------ -------------- ------ --------------
<S> <C> <C> <C> <C> <C>
$.92 50,562 2.55 $ .92 50,562 $ .92
$2.73-$3.00 215,290 2.66 $ 2.87 215,290 $ 2.87
$7.47-$8.08 873,615 4.07 $ 7.94 168,404 $ 8.08
$15.50 503,500 8.64 $ 15.50 125,875 $15.50
--------- ----------
1,642,967 560,131
========= ==========
</TABLE>
65
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 8 - EMPLOYEE BENEFIT PLANS - (Continued)
In connection with the acquisition of Atlas (see Note 11), options for
91,693 shares were issued at an exercise price of $.11 per share to certain
employees of Atlas who had held options of Atlas before its acquisition by the
Company.
As referred to in Note 2, the Company accounts for its stock-based
awards using the intrinsic value method in accordance with Accounting Principles
Board Opinion No. 25, "Accounting for Stock Issued to Employees," and its
related interpretations. Accordingly, no compensation expense has been
recognized in the financial statements for these employee stock arrangements.
SFAS No. 123, "Accounting for Stock-Based Compensation," requires the
disclosure of pro forma net income and earnings per share as if the Company had
adopted the fair value method for stock options granted after June 30, 1996. No
such options were granted in fiscal 1996. Under SFAS No. 123, the fair value of
stock-based awards to employees is calculated through the use of option pricing
models, even though such models were developed to estimate the fair value of
freely tradable, fully transferable options without vesting restrictions, which
significantly differ from the Company's stock option awards. These models also
require subjective assumptions, including future stock price volatility and
expected time to exercise, which greatly affect the calculated values. The
Company's calculations were made using the Black-Scholes option pricing model
with the following weighted average assumptions: expected life, 5 or 10 years
following vesting; stock volatility, 60%, 125% and 99% in 2000, 1999 and 1998,
respectively; risk free interest rate, 6.2%, 5.2% and 5.8% in 2000, 1999 and
1998, respectively; and no dividends during the expected term. If the computed
fair values of the awards had been amortized to expense over the vesting period
of the awards, pro forma net income would have been $16.4 million ($.69 per
share), $16.7 million ($0.73 per share) and $26.2 million ($1.52 per share) in
fiscal 2000, 1999 and 1998, respectively.
In addition to the various stock option plans, in May 1997 the
stockholders approved the Resource America, Inc. Non-Employee Director Deferred
Stock and Deferred Compensation Plan (the "Non-Employee Director Plan") for
which a maximum of 75,000 shares were reserved for issuance. Under the
Non-Employee Director Plan, non-employee directors of the Company are awarded
units representing the right to receive one share of Company common stock for
each unit awarded. Units do not vest until the fifth anniversary of their grant,
except that units will vest sooner upon a change of control of the Company or
death or disability of a director, provided the director completed at least six
months of service. Upon termination of service by a director, all unvested units
are forfeited. In fiscal 2000, 15,000 units were granted under the Non-Employee
Director Plan to the Company's five non-employee directors. The fair value of
the grants (average $7.94 per unit, $119,100 in total) is being charged to
operations over the five-year vesting period. At September 30, 2000, 57,000
units are outstanding under this plan.
The tax benefit associated with the exercise of non-statutory stock
options and disqualifying dispositions by employees of shares issued reduced
taxes payable $405,000 in fiscal 1998; no such reduction was realized in fiscal
1999 or 2000. Such benefits are reflected as additional paid-in capital.
66
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 9 - COMMITMENTS AND CONTINGENCIES
The Company leases office space and equipment under leases with varying
expiration dates through 2005. Rental expense was $1.6 million, $1.7 million and
$749,800 for the years ended September 30, 2000, 1999 and 1998, respectively. At
September 30, 2000, future minimum rental commitments for the next five fiscal
years were as follows (in thousands):
2001........................... $ 1,386
2002........................... 1,212
2003........................... 895
2004........................... 359
2005........................... 313
The Company is party to employment agreements with certain executives
which provide for compensation and certain other benefits. The agreements also
provide for severance payments under certain circumstances.
The Company has an employment agreement with its Chairman pursuant to
which the Company has agreed to provide him with a supplemental employment
retirement plan ("SERP") and with certain financial benefits upon termination of
his employment. Under the SERP, he will be paid an annual benefit of 75% of his
average income after he has reached retirement age (each as defined in the
employment agreement). Upon termination, he is entitled to receive lump sum
payments in various amounts of between 25% and five times average compensation
(depending upon the reason for termination) and, for termination due to
disability, a monthly benefit equal to the SERP benefit (which will terminate
upon commencement of payments under the SERP). During fiscal 2000, 1999 and
1998, operations were charged $2.5 million, $556,000 and $204,000, respectively,
with respect to these commitments.
The Company is a defendant, together with certain of its officers and
directors and its independent auditor, Grant Thornton LLP, in consolidated
actions that were instituted on October 14, 1998 in the U.S. District Court for
the Eastern District of Pennsylvania by stockholders of the Company, putatively
on their own behalf and on behalf of similarly situated stockholders, who
purchased shares of the Company's common stock between December 17, 1997 and
February 22, 1999. The complaint seeks damages in an unspecified amount for
losses allegedly incurred as the result of misstatements and omissions allegedly
contained in our periodic reports and a registration statement filed with the
SEC. The asserted misstatements and omissions relate, among other matters, to
(i) use of the accretion of discount method of recognizing revenue on distressed
loans the Company purchased at a discount and (ii) accounting for the profit we
realized on its sale of senior lien interests in such loans. The Company
believes that the complaint is without merit and is defending itself.
The Company is also a defendant in a suit filed in February 2000 in the
New York Supreme Court, Chautauqua County, by individuals, putatively on their
own behalf and on behalf of similarly situated individuals, who leased property
to the Company. The complaint alleges that the Company is not paying lessors the
proper amount of royalty revenues derived from the natural gas produced from the
wells on the leased property. The complaint seeks damages in an unspecified
amount for the alleged difference between the amount of royalties actually paid
and the amount of royalties that should have been paid to the plaintiffs and
other royalty owners. The Company believes the compliant is without merit and
intend to defend itself vigorously.
The Company is also party to various routine legal proceedings arising
out of the ordinary course of its business. Management believes that none of
these actions, individually or in the aggregate, will have a material adverse
effect on the Company's financial condition or operations.
67
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 10 - HEDGING ACTIVITIES
The Company, through its energy subsidiaries, enters into natural gas
futures and option contracts to hedge its exposure to changes in natural gas
prices. At any point in time, such contracts may include regulated New York
Mercantile Exchange ("NYMEX") futures and options contracts and non-regulated
over-the-counter futures contracts with qualified counterparties. NYMEX
contracts are generally settled with offsetting positions, but may be settled by
the delivery of natural gas.
At September 30, 2000, the Company had 76 open natural gas futures
contracts related to natural gas sales covering 205,200 dekatherms ("Dth") (net
to the Company) maturing through March 2001 at a combined average settlement
price of $3.05 per Dth. As these contracts qualify and have been designated as
hedges, any gains or losses resulting from market price changes are deferred and
recognized as a component of sales revenues in the month the gas is sold. Gains
or losses on futures contracts are determined as the difference between the
contract price and a reference price, generally prices on NYMEX. The Company's
net unrealized loss related to open NYMEX contracts was approximately $435,000
at September 30, 2000, and its net unrealized gain was approximately $83,000 at
September 30, 1999. The Company recognized a loss of $832,000 on settled
contracts covering natural gas production for the year ended September 30, 2000,
and gains of $35,000 and $161,000 for the years ended September 30, 1999 and
1998, respectively.
Although hedging provides the Company some protection against falling
prices, these activities could also reduce the potential benefits of price
increases, depending upon the instrument.
NOTE 11 - ACQUISITIONS
On August 31, 1999, the Company acquired all of the common stock of
Viking Resources in exchange for 1,243,684 shares of the Company's common stock
and the assumption of Viking Resources' debt as described below. Viking
Resources is a company primarily involved in the energy finance business through
the syndication of oil and gas properties in the Appalachian Basin.
The Viking Resources acquisition was recorded under the purchase method
of accounting and, accordingly, the results of operations of Viking Resources
are included in the Company's consolidated financial statements commencing
September 1, 1999. The purchase price has been allocated to assets acquired and
liabilities assumed based on the fair market value at the date of acquisition as
summarized below (in thousands).
<TABLE>
<S> <C>
Estimated fair value of assets acquired................................................. $ 48,289
Liabilities assumed..................................................................... (19,910)
Common stock issued..................................................................... (12,437)
---------------
Net cash (paid)......................................................................... $ (15,942)
===============
</TABLE>
This acquisition was immaterial to the results of operations of the
Company, and therefore pro forma information is excluded.
On September 29, 1998, the Company acquired all the common stock of
Atlas Group (now Atlas America) in exchange for 2,063,496 shares of the
Company's common stock and the assumption of Atlas Group's debt as described
below. Atlas Group is a company primarily involved in the energy finance
business through the syndication of oil and gas properties in the Appalachian
Basin.
68
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 11 - ACQUISITIONS - (Continued)
The Atlas Group acquisition was recorded under the purchase method of
accounting and, accordingly, the results of operations of Atlas Group are
included in the Company's consolidated financial statements commencing September
29, 1998. The effect on the Company's operations for fiscal 1998 was immaterial.
The purchase price has been allocated to assets acquired and liabilities assumed
based on their fair market values, at the date of acquisition as summarized
below (in thousands).
<TABLE>
<S> <C>
Estimated fair value of assets acquired................................................... $ 74,635
Liabilities assumed....................................................................... (45,968)
Amounts due seller........................................................................ (9,191)
Common stock issued....................................................................... (29,534)
------------
Net cash acquired......................................................................... $ 10,058
===========
</TABLE>
The following table reflects unaudited pro forma combined results of
operations of the Company and Atlas Group presented as if that the acquisition
had taken place on October 1, 1997:
<TABLE>
<CAPTION>
Year Ended
September 30,
-------------
1998
(unaudited)
(in thousands,
except per share amounts)
<S> <C>
Revenues................................................................................ $ 107,653
Net income before extraordinary item.................................................... 26,584
Net income.............................................................................. 26,823
Basic earnings per share:
Net income before extraordinary item.................................................. $ 1.42
Net income............................................................................ $ 1.43
Diluted earnings per share:
Net income before extraordinary item.................................................. $ 1.38
Net income............................................................................ $ 1.38
</TABLE>
These unaudited pro forma results have been prepared for comparative
purposes only and include certain adjustments to: (i) depletion, depreciation
and amortization expense attributable to allocation of the purchase price; (ii)
general and administrative expenses for certain cost reductions realized from
the combining of operations; and (iii) interest expense for additional
borrowings. They do not purport to be indicative of the results of operations
which actually would have resulted had the combination been consummated on
October 1, 1997, or of future results of operations of the consolidated
entities.
69
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 12 - DISCONTINUED OPERATIONS
In February 2000, the Company adopted a plan to sell Fidelity Leasing,
Inc. and subsidiaries ("FLI"), its small ticket equipment leasing business which
was sold August 2000. Accordingly, FLI is reported as a discontinued operation
for the three years ended September 30, 2000, 1999 and 1998. In connection with
the sale, the Company received a non-interest bearing note that is payable to
the extent that payments are made on a pool of FLI lease receivables and refunds
are received with respect to certain tax receivables. The lease receivables pool
consists of receivables that, as of June 30, 2000, were aged more than 90 days
or on FLI's "watch list", or had an outstanding balance of $200,000 or more that
would have rated "not pass" under purchaser's credit policy. In addition, $10.0
million was placed in escrow until March 31, 2004 as security for the Company's
indemnification obligations to the purchaser. Under certain circumstances up to
$5.0 million can be released from the escrow prior to March 31, 2004. The
Company recorded a discount and an allowance for possible losses aggregating
$8.9 million against the note and escrow. This allowance is reviewed
periodically so that it is maintained at a level that is estimated by the
Company to be necessary to provide for additional possible losses on the note
and escrow. Net assets of FLI at September 30, 1999 were $79.9 million and are
summarized in the following table (in thousands):
<TABLE>
<S> <C>
Cash and cash equivalents............................................................................ $ 10,139
Investment in leases and notes receivable, net of $10,017 allowance.................................. 407,904
Net fixed assets..................................................................................... 4,040
Other assets......................................................................................... 19,084
Debt................................................................................................. (343,794)
Accounts payable and accrued liabilities............................................................. (17,461)
-------------
Net assets of discontinued FLI operations............................................................ $ 79,912
=============
</TABLE>
Summarized operating results of discontinued FLI operation are as
follows:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Net revenues........................................................... $ 29,552 $ 41,129 $ 13,561
=========== =========== ===========
Income from operations before income tax provision..................... $ 775 $ 3,738 $ 4,207
Income tax provision................................................... (299) (1,737) (1,800)
----------- ----------- -----------
Income from discontinued operations.................................... $ 476 $ 2,001 $ 2,407
=========== =========== ===========
Gain on disposal before income taxes................................... $ 24,259 $ - $ -
Income tax provision................................................... (9,352) - -
----------- ----------- -----------
Gain on disposal of discontinued operations............................ $ 14,907 $ - $ -
=========== =========== ===========
</TABLE>
On September 28, 1999 the Company adopted a plan to discontinue
Fidelity Mortgage Funding, Inc. ("FMF"), its residential mortgage lending
business. The business was disposed of in November 2000. Accordingly, FMF is
reported as a discontinued operation for the years ended September 30, 2000,
1999 and 1998. Net assets of FMF were $779,000 and $2,394,000 at September 30,
2000 and 1999, respectively, and consist primarily of loan receivables.
70
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 12 - DISCONTINUED OPERATIONS - (Continued)
Summarized operating results of the discontinued FMF operation are as
follows:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Net revenues........................................................... $ - $ 1,907 $ 7,022
Loss from operations before income tax benefit......................... - (9,877) (4,243)
Income tax benefit..................................................... - 2,190 1,443
----------- ----------- -----------
Loss from discontinued operations...................................... - (7,687) (2,800)
Loss on disposal before income tax benefit............................. (2,952) (423) -
Income tax benefit..................................................... 989 148 -
----------- ----------- -----------
Loss on disposal of discontinued operations............................ $ (1,963) $ (275) $ -
=========== =========== ===========
Summarized results of the discontinued FLI and FMF operations are:
Income (loss) from operations of subsidiaries.......................... $ 476 $ (5,686) $ (393)
=========== =========== ===========
Gain (loss) on disposal of subsidiaries................................ $ 12,944 $ (275) $ -
=========== =========== ===========
</TABLE>
NOTE 13 -TERMINATION CHARGE
As a result of the sale of the Company's equipment leasing operations
on August 1, 2000 and its reduced emphasis on real estate finance, two of the
Company's officers separated from the Company on September 13, 2000. One officer
was the Company's president and chief operating officer and the other was the
Company's executive vice President and vice chairman as well as the president of
the commercial real estate finance business. Both officers were parties to
employment agreements and were terminated in accordance with the terms of those
agreements. Accordingly, continuing operations were charged $1.8 million and
discontinued operations were charged $2.3 million in the year ended September
30, 2000.
NOTE 14 - PUBLIC OFFERING OF UNITS BY PARTNERSHIP
In February 2000, the Company's natural gas gathering operations were
sold to Atlas Pipeline in connection with a public offering by Atlas Pipeline of
1,500,000 common units. The Company received $16.6 million for the gathering
systems, and Atlas Pipeline issued to the Company 1,641,026 subordinated units
constituting a 51% limited partner interest in Atlas Pipeline. Because the
Company owns more than 50% of Atlas Pipeline, the assets, liabilities, revenues
and expenses of Atlas Pipeline are consolidated with those of the Company, and
the value represented by non-subordinated common units are shown as a minority
interest on the Company's consolidated balance sheet.
Our subordinated units are a special class of limited
partnership interest in Atlas Pipeline under which our rights to distributions
are subordinated to those of the publicly-held common units. The subordination
period extends until December 31, 2004 and will continue beyond that date if
financial tests specified in the partnership agreement are not met. Our interest
also includes a right to receive incentive distributions if the partnership
meets or exceeds its minimum operating distribution obligations.
71
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 14 - PUBLIC OFFERING OF UNITS BY PARTNERSHIP - (Continued)
In connection with our sale of the gathering systems to Atlas Pipeline,
we entered into agreements that:
o Require us to connect wells owned or controlled by us that are
within specified distances of Atlas Pipeline's gathering systems
to those gathering systems and to drill and connect a minimum of
225 wells.
o Require us to provide stand-by construction financing to Atlas
Pipeline for gathering system extensions and additions to a
maximum of $1.5 million per year for five years.
o Require us to pay gathering fees to Atlas Pipeline for natural gas
gathered by the gathering systems equal to the greater of $.35 per
mcf ($.40 per mcf in certain instances) or 16% of the gross sales
price of the natural gas transported.
o Require us to support a minimum quarterly distribution by Atlas
Pipeline to holders of non-subordinated units of $0.42 per unit
(an aggregate of $1.68 per fiscal year) until February 2003. We
have established a letter of credit administered by PNC Bank to
support our obligation. The current face amount of the letter of
credit is $5.7 million. The required face amount of the letter of
credit reduces $630,000 per quarter.
Through September 30, 2000, we had drilled all of the 225 wells
required under our agreements with Atlas Pipeline. We have not been required to
provide any construction financing. We provided $443,000 in distribution support
for the initial quarter of Atlas Pipeline's operations. No distribution support
has been required for any subsequent quarter.
NOTE 15 - EXTRAORDINARY ITEM
During fiscal 2000, 1999, and 1998 the Company acquired $21.0 million,
$3.0 million, and $10.6 million, respectively, of its 12% Senior Subordinated
Notes Payable at a discount. These transactions resulted in an extraordinary
gain of $683,000 (net of taxes of $367,000) in fiscal 2000, $299,000 (net of
taxes of $142,000) in fiscal 1999 and $239,000 (net of taxes of $112,000) in
fiscal 1998.
NOTE 16 - CUMULATIVE EFFECT OF A CHANGE IN ACCOUNTING PRINCIPLE
The Company elected early adoption of the provisions of Statement of
Position 98-5 effective October 1, 1998 and, accordingly, start-up costs of
$59,000 (net of taxes of $28,000) which had been capitalized at September 30,
1998 were charged to operations on October 1, 1998 and are reflected in the
consolidated statements of income for the year ended September 30, 1999 as a
cumulative effect of a change in accounting principle.
NOTE 17 - SUBSEQUENT EVENT
In October 2000, the Company completed a dutch auction tender offer
acquiring 5,472,021 shares of common stock for approximately $49.2 million,
representing approximately 24% of the then outstanding common stock. The
acquisition was funded through cash received upon the sale of its small ticket
leasing subsidiary. Expenses related to this offer are expected to total
approximately $500,000. The effect of this transaction on the September 30, 2000
financial statements would have been to decrease cash from $117.1 million to
$67.4 million, to decrease stockholders' equity from $281.2 million to $231.5
million and to decrease outstanding shares from 23,591,980 to 18,119,959.
72
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 18 - OPERATING SEGMENT INFORMATION AND MAJOR CUSTOMERS
The Company operates in two principal industry segments: energy and
real estate finance. Segment data for the years ended September 30, 2000, 1999
and 1998 are as follows:
<TABLE>
<CAPTION>
Years Ended September 30,
-----------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Revenues:
Energy.............................................................. $ 70,552 $ 55,093 $ 6,734
Real estate finance................................................. 18,649 45,907 55,834
Corporate........................................................... 10,410 8,089 6,912
----------- ----------- -----------
$ 99,611 $ 109,089 $ 69,480
=========== =========== ===========
Depreciation, depletion and amortization:
Energy.............................................................. $ 9,781 $ 5,512 $ 1,273
Real estate finance................................................. 195 136 50
Corporate........................................................... (104) 337 170
----------- ----------- -----------
$ 9,872 $ 5,985 $ 1,493
=========== =========== ===========
Operating profit (loss):
Energy.............................................................. $ 7,013 $ 8,619 $ 1,659
Real estate finance................................................. 6,914 35,306 43,710
Corporate........................................................... (8,227) (8,634) (4,593)
----------- ----------- -----------
$ 5,700 $ 35,291 $ 40,776
=========== =========== ===========
Identifiable assets:
Energy.............................................................. $ 153,840 $ 139,098 $ 88,552
Real estate finance................................................. 202,335 273,922 211,251
Corporate........................................................... 153,029 127,112 92,280
----------- ----------- -----------
$ 509,204 $ 540,132 $ 392,083
=========== =========== ===========
Capital expenditures (excluding assets acquired in business acquisitions):
Energy.............................................................. $ 10,936 $ 11,456 $ 2,095
Real estate finance................................................. 130 100 143
Corporate........................................................... - - 93
----------- ----------- -----------
$ 11,066 $ 11,556 $ 2,331
=========== =========== ===========
</TABLE>
Operating profit (loss) represents total revenues less costs
attributable thereto, including interest and provision for possible losses, and
less depreciation, depletion and amortization, excluding general corporate
expenses. The information presented above does not eliminate intercompany
transactions of $68,000 and $161,000 in the years ended September 30, 2000 and
1999, respectively.
The Company's natural gas is sold under contract to various purchasers.
For the year ended September 30, 2000, gas sales to three purchases accounted
for 37%, 11% and 11%, respectively, of our total production revenues. Also
during fiscal 2000, oil sales to one purchaser accounted for 17% of such
revenues. During 1999 and 1998, gas sales to two purchasers accounted for,
respectively, 26% and 14%, and 35% and 14% of the Company's total production
revenues, respectively.
In real estate finance, no revenues from a single borrower exceeded 10%
of total revenues.
73
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 19 - SUPPLEMENTAL OIL AND GAS INFORMATION(UNAUDITED)
Results of operations for oil and gas producing activities:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Revenues............................................................ $ 25,231 $ 12,233 $ 4,682
Production costs.................................................... (7,229) (4,806) (2,022)
Exploration expenses................................................ (1,110) (560) (503)
Depreciation, depletion, and amortization........................... (6,305) (2,897) (809)
Income taxes........................................................ (3,759) (635) (263)
------------ ----------- -----------
Results of operations producing activities.......................... $ 6,828 $ 3,335 $ 1,085
=========== =========== ===========
</TABLE>
Capitalized Costs Related to Oil and Gas Producing Activities. The
components of capitalized costs related to the Company's oil and gas producing
activities are as follows:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Proved properties................................................... $ 84,307 $ 77,207 $ 42,458
Unproved properties................................................. 1,003 847 1,164
Pipelines, equipment and other interests............................ 19,493 18,931 7,645
----------- ----------- -----------
Total........................................................... 104,803 96,985 51,267
Accumulated depreciation, depletion and amortization................ (26,966) (19,019) (15,611)
----------- ----------- -----------
Net capitalized costs........................................... $ 77,837 $ 77,966 $ 35,656
=========== =========== ===========
</TABLE>
Costs Incurred in Oil and Gas Producing Activities. The costs incurred
by the Company in its oil and gas activities during fiscal years 2000, 1999 and
1998 are as follows:
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Property acquisition costs:
Unproved properties............................................... $ 168 $ 17 $ 378
Proved properties................................................. 1,017 37,454 19,436
Exploration costs................................................. 1,095 658 816
Development costs................................................. 9,422 9,008 416
</TABLE>
Oil and Gas Reserve Information (unaudited). The Company's estimates of
net proved oil and gas reserves and the present value thereof have been verified
by Wright & Company, Inc. a petroleum engineering firm.
The Company's oil and gas reserves are located within the United
States. There are numerous uncertainties inherent in estimating quantities of
proved reserves and in projecting future net revenues and the timing of
development expenditures. The reserve data presented represent estimates only
and should not be construed as being exact. In addition, the standardized
measures of discounted future net cash flows may not represent the fair market
value of the Company's oil and gas reserves or the present value of future cash
flows of equivalent reserves, due to anticipated future changes in oil and gas
prices and in production and development costs and other factors for which
effects have not been provided.
74
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 19 - SUPPLEMENTAL OIL AND GAS INFORMATION(UNAUDITED) - (Continued)
The standardized measure of discounted future net cash flows is
information provided for the financial statement user as a common base for
comparing oil and gas reserves of enterprises in the industry.
<TABLE>
<CAPTION>
Gas Oil
------------ -----------
(mcf) (bbls)
------------ -----------
<S> <C> <C>
Balance at September 30, 1997....................................... 15,157,535 358,013
Purchase of reserves in-place....................................... 74,894,968 194,270
Current additions................................................... 217,508 41,406
Sales of reserves in-place.......................................... (53,320) (2,523)
Revision to previous estimates...................................... 1,151,890 29,461
Production.......................................................... (1,485,008) (48,113)
------------ -----------
Balance September 30, 1998.......................................... 89,883,573 572,514
Current additions................................................... 29,705,025 -
Purchase of reserves in place....................................... 18,786,968 1,187,326
Transfer to limited partnerships.................................... (18,221,632) -
Revisions........................................................... (7,639,494) 10,196
Production.......................................................... (4,342,430) (85,045)
------------ -----------
Balance September 30, 1999.......................................... 108,172,010 1,684,991
Current additions................................................... 24,046,850 16,031
Sales of reserves in-place.......................................... (304,428) (14,200)
Purchase of reserves in place....................................... 1,047,931 -
Transfer to limited partnerships.................................... (18,039,097) -
Revisions........................................................... 4,659,432 275,806
Production.......................................................... (6,440,154) (195,974)
------------- ------------
Balance September 30, 2000.......................................... 113,142,544 1,766,654
============ ===========
Proved developed reserves at
September 30, 2000................................................ 74,332,754 1,766,654
September 30, 1999................................................ 66,215,748 1,684,991
September 30, 1998................................................ 49,868,113 572,514
</TABLE>
75
<PAGE>
RESOURCE AMERICA, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS - (Continued)
NOTE 19 - SUPPLEMENTAL OIL AND GAS INFORMATION(UNAUDITED) - (Continued)
Presented below is the standardized measure of discounted future net
cash flows and changes therein relating to proved oil and gas reserves. The
estimated future production is priced at year-end prices. The resulting
estimated future cash inflows are reduced by estimated future costs to develop
and produce the proved reserves based on year-end cost levels. The future net
cash flows are reduced to present value amounts by applying a 10% discount
factor.
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Future cash inflows................................................. $ 555,121 $ 349,953 $ 240,922
Future production and development costs........................... (208,451) (156,853) (102,557)
Future income tax expense......................................... (104,004) (46,232) (14,278)
----------- ----------- -----------
Future net cash flows............................................... 242,666 146,868 124,087
Less 10% annual discount for estimated
timing of cash flows............................................ (144,067) (88,093) (80,313)
----------- ----------- -----------
Standardized measure of discounted
future net cash flows............................................. $ 98,599 $ 58,775 $ 43,774
=========== =========== ===========
</TABLE>
The following table summarizes the changes in the standardized measure
of discounted future net cash flows from estimated production of proved oil and
gas reserves after income taxes.
<TABLE>
<CAPTION>
Years Ended September 30,
------------------------------------------
2000 1999 1998
----------- ----------- -----------
(in thousands)
<S> <C> <C> <C>
Balance, beginning of year............................................. $ 58,775 $ 43,774 $ 10,123
Increase (decrease) in discounted future net cash flows:
Sales and transfers of oil and gas net of related costs............. (18,002) (7,427) (2,660)
Net changes in prices and production costs.......................... 47,046 6,173 171
Revisions of previous quantity estimates............................ (1,204) (6,197) 597
Extensions, discoveries, and improved
recovery less related costs....................................... 22,255 11,006 194
Purchases of reserves in-place...................................... 1,509 26,276 34,935
Sales of reserves in-place, net of tax effect....................... (293) - (30)
Accretion of discount............................................... 7,522 4,915 1,012
Net change in future income taxes................................... (23,757) (15,814) (3,770)
Other............................................................... 4,748 (3,931) 3,202
----------- ----------- -----------
Balance, end of year................................................... $ 98,599 $ 58,775 $ 43,774
=========== =========== ===========
</TABLE>
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE
None.
76
<PAGE>
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS, PROMOTERS AND CONTROL PERSONS OF
THE REGISTRANT
The information required by this item will be set forth in our
definitive proxy statement with respect to our 2001 annual meeting of
stockholders, to be filed on or before January 29, 2001 and is incorporated
herein by reference.
ITEM 11. EXECUTIVE COMPENSATION
The information required by this item will be set forth in our 2001
proxy statement, and is incorporated herein by reference.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
The information required by this item will be set forth in our 2001
proxy statement, and is incorporated herein by reference.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
The information required by this item will be set forth in our 2001
proxy statement, and is incorporated herein by reference.
77
<PAGE>
PART IV
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) The following documents are filed as part of this Annual Report
on Form 10-K:
1. Financial Statements
Report of Independent Certified Public Accountants
Consolidated Balance Sheets Consolidated Statements
of Income Consolidated Statements of Comprehensive
Income Consolidated Statements of Changes in
Stockholders' Equity Consolidated Statements of Cash
Flows Notes to Consolidated Financial Statements
2. Financial Statement Schedules
Schedule IV - Mortgage Loans on Real Estate
78
<PAGE>
SCHEDULE IV
RESOURCE AMERICA, INC. & SUBSIDIARIES
MORTGAGE LOANS ON REAL ESTATE
September 30, 2000
<TABLE>
<CAPTION>
Final Periodic
Maturity Payment
Description Interest Rate Date Terms
----------- ------------- ---- -----
<S> <C> <C> <C>
FIRST MORTGAGES
Hotel/Commercial Office, GA Fixed interest rate of 14% 12/31/15 (a)
Hotel, NE Fixed interest rate of 14.5% 09/30/02 (a)
Condominium units, NC Fixed interest rate of 8% 03/31/02 (a)
Apartment bldg. PA Fixed interest rate of 14% 10/01/02 (a)
Office bldg., PA (3 loans) Interest at 85% of prime 09/30/14 (a)
Apartment bldg., IL (3 loans) Fixed interest rate of 7.5% 09/30/02 (a)
Apartment bldg., CT Fixed interest rate of 13% 09/30/11 (a)
JUNIOR LIEN LOANS
Apartment bldg., FL Fixed interest rate of 13% 06/01/10 (a)
Office bldg., NC Fixed interest rate of 11.5% 12/31/11 (a)
Apartment bldg. NJ Fixed interest rates of 11.25% 09/01/05 (a)
Apartment bldg., CT Fixed interest rate of 15% 01/01/14 (a)
Apartment bldg., PA Fixed interest rate of 14.5% 12/31/02 (a)
Apartment bldg., NJ Fixed interest rate of 9% 01/01/03 (a)
Apartment bldg., NJ Fixed rates of 8% 10/31/08 (a)
Apartment bldg., IL Fixed interest rate of 7.5% 04/30/03 (a)
Office bldg. MD Fixed at 8.8% 10/01/03 (a)
Office bldg., PA (3 loans) Fixed rates ranging from 6.85% to 12% 08/01/08 (a)
Office bldg., PA Fixed interest rate of 10.6% 02/07/01 (a)
Office bldg., DC Interest rate of prime plus 3% 06/01/00 (a)
Office bldg., NJ (3 loans) Fixed interest rate of 9.75% 02/07/01 (a)
Office bldg., PA (3 loans) Rate ranging from 12% to 85% of the rate for 09/30/03 (a)
$100,000 CD's
Apartment bldg. CT Fixed interest rate of 7.5% 07/01/03 (a)
Apartment bldg., PA (2 loans) Interest rates of 7% and 15% 12/17/02 (a)
Apartment bldg., PA Fixed interest rate of 9% 12/31/02 (a)
Apartment bldg., PA (31 loans) Fixed interest rate of 12% 07/01/16 (a)
Apartment bldg., PA 85% of 30 day $100,000 rate CD plus 2.75% 05/03/29 (a)
Apartment bldg., PA Fixed interest rate of 9.28% 11/01/22 (a)
Condominium Units, NC Fixed interest rate of 10% 03/23/09 (a)
Office bldg., Washington, DC (2 loans) Fixed interest rate of 12% and two thirds of the 30 11/30/98 (a)
day treasury rate
Office bldg., PA Fixed interest rate of 9% 09/25/02 (a)
Industrial bldg., Pasadena, CA 2.75% over the average cost of funds to FSLIC- 05/01/01 (a)
insured savings and loan institutions
Office bldg., Washington, DC Fixed interest rate of 15% 08/01/08 (a)
Retail bldg., VA Fixed interest rate of 9% 02/01/21 (a)
Retail bldg., MN Fixed interest rate of 10% 12/31/14 (a)
Retail bldg., WVA Fixed interest rate of 12% 12/31/16 (a)
Retail bldg., CA Fixed interest rate of 9% 12/01/00 (a)
Office/Retail bldg., PA Interest rate of 5% plus 90% of prime 07/01/02 (a)
Office bldg., MD Fixed interest rate of 10.635% 04/01/04 (a)
----------
(a) All net cash flows from the property
</TABLE>
79
<PAGE>
SCHEDULE IV - (Continued)
RESOURCE AMERICA, INC. & SUBSIDIARIES
MORTGAGE LOANS ON REAL ESTATE
September 30, 1999
(in thousands)
<TABLE>
<CAPTION>
Face Carrying Subject
Prior Amount of Amount of Delinquent
Description Liens Mortgages Mortgages Interest
----------- ----- --------- --------- --------
<S> <C> <C> <C> <C>
FIRST MORTGAGES
Hotel/Commercial Office, GA $ - $ 5,800 $ 7,901 $ -
Hotel, NE - 6,005 3,383 -
Condominium units, NC - 1,670 486 -
Apartment bldg., PA - 400 424 -
Office bldg., PA - 6,000 4,055 -
Apartment bldg., IL (3 loans) - 17,460 19,282 -
Apartment bldg., CT - 1,600 1,600 -
JUNIOR LIEN LOANS
Apartment bldg., FL 2,096 4,100 1,206
Office bldg., NC 1,750 3,500 2,009 -
Apartment bldg., NJ 5,962 11,615 5,411 -
Apartment bldg., CT 9,375 2,973 1,628 -
Apartment bldg., PA 2,570 4,500 5,253 -
Apartment bldg., NJ 625 1,798 102 139
Apartment bldg., NJ 2,136 2,600 1,020 -
Apartment bldg., IL 10,000 24,083 7,922 -
Office bldg., MD 60,000 31,000 38,282 -
Office bldg., PA (3 loans) 43,925 44,000 19,613 -
Office bldg., PA 840 5,400 952 -
Office bldg., DC 685 900 762 -
Office bldg., NJ (3 loans) 2,387 4,800 2,503 -
Office bldg., PA (3 loans) 2,213 3,116 1,825 -
Apartment bldg., CT 11,942 14,500 7,176 -
Apartment bldg., PA (2 loans) 1,000 1,454 1,045 -
Apartment bldg., PA 2,997 5,000 1,291 -
Apartment bldg., PA (31 loans) 2,860 - 757 -
Apartment bldg., PA 3,435 2,435 987 -
Apartment bldg., PA 2,478 3,155 796 -
Condominium Units, NC 3,000 2,064 2,356 -
Office bldg., Washington, DC (2 loans) 6,548 13,283 7,547 -
Office bldg., PA 1,750 1,150 790 -
Industrial bldg., Pasadena, CA 2,000 3,000 516 -
Office bldg., Washington, DC 80,684 100,971 20,693 -
Retail bldg., VA 1,413 3,961 951 -
Retail bldg., MN 2,088 1,776 720 -
Retail bldg., WVA 994 1,400 568 -
Retail bldg., CA 1,969 2,271 976 -
Office/Retail bldg., PA 2,611 3,400 1,385 -
Office bldg., MD 75,000 92,000 11,769 -
----------- ----------- -------- ---------
Balance at September 30, 1999 $ 410,693 $ 487,839 $184,342 $ 139
=========== =========== ======== =========
</TABLE>
80
<PAGE>
3. Exhibits
2.1 Stock Purchase Agreement, dated as of May 17, 2000, among
European American Bank, AEL Leasing Co., Inc.,
Resource America, Inc. and FLI Holdings, Inc. (1)
2.1(a) Amendment to Stock Purchase Agreement, dated May 17, 2000
3.1 Restated Certificate of Incorporation of Resource America (2)
3.2 Amended and Restated Bylaws of Resource America (2)
4.1 Indenture, dated as of July 22, 1997, between Resource America and
The Bank of New York, as trustee, with respect to Resource
America's 12% Senior Notes due 2004 (3)
10.1 Resource America's 1989 Key Employee Stock Option Plan, as
amended (4)
10.2 Resource America's 1997 Key Employee Stock Option Plan (5)
10.3 Resource America's 1997 Non-Employee Director Deferred Stock
and Deferred Compensation Plan (5)
10.4 Resource America's 1999 Key Employee Stock Option Plan (6)
10.5 Employment Agreement between Edward E. Cohen and Resource
America (7)
10.6 Employment Agreement between Scott Schaeffer and Resource
America(1)
10.6(a) Separation Agreement and General Release
10.7 Employment Agreement between Daniel G. Cohen and Resource
America(1)
10.7(a) Separation Agreement and General Release
10.8 Employment Agreement between Steven J. Kessler and Resource
America (1)
10.9 Employment Agreement between Nancy J. McGurk and Resource
America(1)
10.10 Employment Agreement between Jonathan Z. Cohen and Resource
America
10.11 Loan Agreement, dated as of September 28, 1999, among Atlas
America, Inc., Resource Energy, Inc., Viking Resources
Corporation, PNC Bank, National Association, as Issuing Bank and
Agent, First Union National Bank, as Syndication Agent, and
others(8)
10.11(a) First Amendment to Loan Agreement, dated as of January 24, 2000
10.12 Amended and Restated Loan Agreement, dated December 14, 1999,
among Resource Properties XXXII, Inc., Resource Properties
XXXVIII, Inc., Resource Properties II, Inc., Resource Properties
51, Inc., Resource Properties, Inc., Resource America and
Jefferson Bank
10.13 Revolving Credit Loan and Security Agreement dated July 27, 1999
by and between Resource Properties, Inc., Resource Properties 53,
Inc., Resource Properties XXIV, Inc., Resource Properties XL,
Inc. and Sovereign Bank
10.13(a) Modification of Revolving Credit Loan and Security Agreement
dated March 30, 2000
81
<PAGE>
10.14 Revolving Credit Loan Agreement dated July 27, 1999 be and between
Resource America, Inc. and Sovereign Bank
12 Computation of ratios
21 List of subsidiaries
23 Consent of Wright & Company, Inc.
27 Financial data schedule
82
<PAGE>
(b) Reports on Form 8-K
We filed a Form 8-K dated August 10, 2000 reporting, in Item 2, the completion
of the sale of Fidelity Leasing.
---------------
(1) Filed previously as an exhibit to our Current Report on Form 8-K filed on
May 18, 2000 and by this reference incorporated herein.
(2) Filed previously as an exhibit to our Quarterly Report on Form 10-Q for the
quarter ended December 31, 1999 and by this reference incorporated herein.
(3) Filed previously as an exhibit to our Registration Statement on Form S-4
(Registration No. 333-40231) and by this reference incorporated herein.
(4) Filed previously as an exhibit to our Registration Statement S-1
(Registration No. 333-03099) and by this reference incorporated herein.
(5) Filed previously as an exhibit to our Quarterly Report on Form 10-Q for the
quarter ended June 30, 1997 and by this reference incorporated herein.
(6) Filed previously as an exhibit to our Definitive Proxy Statement for the
1999 annual meeting of stockholders and by this reference incorporated
herein.
(7) Filed previously as an exhibit to our Quarterly Report on Form 10-Q for the
quarter ended March 31, 1997 and by this reference incorporated herein.
(8) Filed previously as an exhibit to our Annual Report on Form 10-K for the
year ended September 30, 1999 and by this reference incorporated herein.
83
<PAGE>
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities
Exchange Act of 1934 the registrant has duly caused this report to be signed on
its behalf by the undersigned, thereunto duly authorized.
RESOURCE AMERICA, INC. (Registrant)
December 28, 2000 By: /s/ Edward E. Cohen
--------------------------------------
Chairman of the Board, President
and Chief Executive Officer
Pursuant to the requirements of the Securities Exchange Act of 1934,
this report has been signed below by the following persons on behalf of the
registrant and in the capacities indicated as of December 28, 2000.
/s/ Edward E. Cohen Chairman of the Board, President and Chief
--------------------------- Executive Officer
EDWARD E. COHEN
/s/ Carlos C. Campbell Director
---------------------------
CARLOS C. CAMPBELL
/s/ Daniel G. Cohen Director
---------------------------
DANIEL G. COHEN
/s/ Andrew M. Lubin Director
---------------------------
ANDREW M. LUBIN
/s/ P. Sherrill Neff Director
---------------------------
P. SHERRILL NEFF
/s/ Scott F. Schaeffer Director
---------------------------
SCOTT F. SCHAEFFER
/s/ Alan D. Schreiber Director
---------------------------
ALAN D. SCHREIBER
/s/ John S. White Director
---------------------------
JOHN S. WHITE
/s/ Steven J. Kessler Senior Vice President and Chief Financial
--------------------------- Officer
STEVEN J. KESSLER
/s/ Nancy J. McGurk Vice President-Finance and Chief Accounting
--------------------------- Officer
NANCY J. McGURK
84
<PAGE>
EXHIBIT INDEX
2.1 Stock Purchase Agreement, dated as of May 17, 2000, among
European American Bank, AEL Leasing Co., Inc.,
Resource America, Inc. and FLI Holdings, Inc. (1)
2.1(a) Amendment to Stock Purchase Agreement, dated May 17, 2000
3.1 Restated Certificate of Incorporation of Resource America (2)
3.2 Amended and Restated Bylaws of Resource America (2)
4.1 Indenture, dated as of July 22, 1997, between Resource America and
The Bank of New York, as trustee, with respect to Resource
America's 12% Senior Notes due 2004 (3)
10.1 Resource America's 1989 Key Employee Stock Option Plan, as
amended (4)
10.2 Resource America's 1997 Key Employee Stock Option Plan (5)
10.3 Resource America's 1997 Non-Employee Director Deferred Stock
and Deferred Compensation Plan (5)
10.4 Resource America's 1999 Key Employee Stock Option Plan (6)
10.5 Employment Agreement between Edward E. Cohen and Resource
America (7)
10.6 Employment Agreement between Scott Schaeffer and Resource
America(1)
10.6(a) Separation Agreement and General Release
10.7 Employment Agreement between Daniel G. Cohen and Resource
America(1)
10.7(a) Separation Agreement and General Release
10.8 Employment Agreement between Steven J. Kessler and Resource
America (1)
10.9 Employment Agreement between Nancy J. McGurk and Resource
America(1)
10.10 Employment Agreement between Jonathan Z. Cohen and Resource
America
10.11 Loan Agreement, dated as of September 28, 1999, among Atlas
America, Inc., Resource Energy, Inc., Viking Resources
Corporation, PNC Bank, National Association, as Issuing Bank and
Agent, First Union National Bank, as Syndication Agent, and
others(8)
10.11(a) First Amendment to Loan Agreement, dated as of January 24, 2000
10.12 Amended and Restated Loan Agreement, dated December 14, 1999,
among Resource Properties XXXII, Inc., Resource Properties
XXXVIII, Inc., Resource Properties II, Inc., Resource Properties
51, Inc., Resource Properties, Inc., Resource America and
Jefferson Bank
10.13 Revolving Credit Loan and Security Agreement dated July 27, 1999
by and between Resource Properties, Inc., Resource Properties 53,
Inc., Resource Properties XXIV, Inc., Resource Properties XL,
Inc. and Sovereign Bank
10.13(a) Modification of Revolving Credit Loan and Security Agreement
dated March 30, 2000
85
<PAGE>
10.14 Revolving Credit Loan Agreement dated July 27, 1999 be and between
Resource America, Inc. and Sovereign Bank
12 Computation of ratios
21 List of subsidiaries
23 Consent of Wright & Company, Inc.
27 Financial data schedule
86
