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SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K/A
|X| ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended September 30, 1995
OR
|_| TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from _______________ to _________________
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Commission file number: 0-10990
CASTLE ENERGY CORPORATION
(Exact name of registrant as specified in its charter)
Delaware 76-0035225
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification Number)
One Radnor Corporate Center
Suite 250
100 Matsonford Road 19087
Radnor, Pennsylvania (Zip Code)
(Address of principal executive offices)
Registrant's telephone number: (610) 995-9400
Securities registered pursuant to Section 12(b) of the Act: None
Securities registered pursuant to Section 12(g) of the Act: Common Stock-- $.50
par value and related Rights
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes No X
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Indicate by check mark if disclosure of delinquent filers pursuant to
Item 405 of Regulation S-K is not contained herein, and will not be contained,
to the best of registrant's knowledge, in definitive proxy or information
statements incorporated by reference in Part III of this Form 10-K or any
amendment to this Form 10-K. [ ].
As of February 29, 1996, there were 6,693,646 shares of the
registrant's Common Stock ($.50 par value) outstanding. The aggregate market
value of voting stock held by non-affiliates of the registrant as of such date
was $49,166,484 (6,243,363 shares at $7.875 per share).
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CASTLE ENERGY CORPORATION
1995 FORM 10-K
TABLE OF CONTENTS
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Item Page
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PART I
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1. and 2. Business and Properties................................................................ 1
3. Legal Proceedings...................................................................... 8
4. Submission of Matters to a Vote of Security Holders.................................... 11
PART II
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5. Market for the Registrant's Common Stock and Related Stockholder Matters............... 12
6. Selected Financial Data................................................................ 13
7. Management's Discussion and Analysis of Financial Condition and Results of
Operations............................................................................. 15
8. Financial Statements and Supplementary Data............................................ 23
9. Changes in and Disagreements with Accountants on Accounting and Financial
Disclosure............................................................................. 67
PART III
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10. Directors and Executive Officers of the Registrant...................................... 67
11. Executive Compensation.................................................................. 69
12. Security Ownership of Certain Beneficial Owners and Management.......................... 75
13. Certain Relationships and Related Transactions.......................................... 77
PART IV
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14. Exhibits, Financial Statement Schedules and Reports on Form 8-K......................... 80
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PART I
ITEMS 1. AND 2. BUSINESS AND PROPERTIES
INTRODUCTION
Castle Energy Corporation (the "Company") is primarily engaged in
natural gas marketing and transmission and oil and gas exploration and
production in the United States. During the period from 1989 through September
30, 1995, the Company, through certain subsidiaries, was primarily engaged in
petroleum refining. Indian Refining I Limited Partnership (formerly Indian
Refining Limited Partnership) ("IRLP"), an indirect wholly-owned subsidiary of
the Company, owned the Indian Refinery, an 86,000 barrel per day (B/D) refinery
located in Lawrenceville, Illinois. Powerine Oil Company ("Powerine") , another
subsidiary of the Company, owned and operated a 49,500 B/D refinery located in
Santa Fe Springs, California. By September 30, 1995, the Company had terminated
and discontinued all of its refining operations.
The Company engages in natural gas marketing operations which provide
gas to Lone Star Gas Company, a division of ENSERCH Corporation ("Lone Star"),
pursuant to a take-or-pay contract for natural gas through May 31, 1999 ("Lone
Star Contract"). At February 29, 1996, 53 billion cubic feet of natural gas were
to be provided to Lone Star. The Company has proved reserves and fixed price gas
purchase contracts in place for the supply of all of the natural gas necessary
to fulfill commitments under the Lone Star Contract and, accordingly, has fixed
a substantial portion of its gross margin with respect to its gas marketing
operation. The Company delivers natural gas to Lone Star through the Company's
77-mile intrastate pipeline located in Rusk County, Texas. At September 30,
1995, the Company's exploration and production operations had proved reserves of
approximately 56.6 billion cubic feet of natural gas and 351,000 barrels of oil.
During the period from September 1989 to October 14, 1994, a substantial
portion of the Company's stock was owned by Metallgesellschaft Corp. ("MG"), a
wholly-owned subsidiary of Metallgesellschaft A.G. ("MG AG"), a German
conglomerate. During this period, MG provided financing and crude supplies to
IRLP and Powerine and entered into processing and product offtake agreements
with them. These and other transactions with MG and its affiliates are
summarized in footnote 21 to the financial statements, which are included as
Item 8 to this Form 10-K. In December 1993, it was reported that MG AG had
incurred substantial losses as a result of hedging and other related activities.
Thereafter, MG sought to terminate its on-going relationships with the Company.
In October 1994, the Company and MG completed the restructuring of such
relationships ("MG Settlement"). As a result, substantially all of the Company's
contractual relationships with MG and its affiliates were amended or terminated.
Subsequent to the MG Settlement, the Company sought to dispose of its two
refineries and to expand its natural gas marketing and transmission and
exploration and production businesses. Operations at the Powerine Refinery
ceased in July 1995 and operations at the Indian Refinery ceased by September
30, 1995. On September 29, 1995, Powerine sold (for legal purposes) the Powerine
Refinery to Kenyen Projects Limited ("Kenyen"). On January 16, 1996, Powerine
merged into a subsidiary of Energy Merchant Corp. ("EMC"). On December 12, 1995,
IRLP sold the Indian Refinery to American Western Refining L.P. ("American
Western"), a subsidiary of Gadgil Western Corporation ("Gadgil"). For accounting
purposes, refining operations were classified as discontinued operations in the
Company's financial statements as of September 30, 1995 and retroactively for
the fiscal years ended September 30, 1994 and 1993 (see Note 3 to the
consolidated financial statements included as Item 8 to this Form 10-K).
See Note 22 to the Company's Consolidated Financial Statements for
information with respect to the Company's identifiable industry segments for the
years ended September 30, 1995, 1994 and 1993.
On March 5, 1996, the Company engaged an investment banking firm to
explore strategic alternatives to enhance stockholder value and to act as the
Company's exclusive advisor.
NATURAL GAS MARKETING AND TRANSMISSION
General
On December 3, 1992, the Company, through three wholly-owned subsidiary
limited partnerships, CEC Gas Marketing Limited Partnership ("Marketing"),
Castle Texas Pipeline Limited Partnership ("Pipeline") and Castle Texas
Production Limited Partnership ("Production"), acquired from Atlantic Richfield
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Company ("ARCO"), a gas contract with Lone Star Gas Company, a 77-mile pipeline
in Rusk County, Texas (the "Castle Pipeline"), majority working interests in
approximately 100 producing oil and gas wells and several gas supply contracts
for an aggregate purchase price of approximately $103.7 million, including cash,
assumption of debt and certain transaction costs. Upon acquiring these assets,
the Company entered a new segment of the oil and gas business, natural gas
marketing and transmission. The Company, through Marketing, sells 69% of its
natural gas production to Lone Star and the balance to a variety of customers
pursuant to fixed price contracts and in spot markets.
Assets
Gas Contract
Pursuant to the terms of the Lone Star Contract, Marketing sells natural
gas to Lone Star at a fixed price per thousand Btu ("MBtu"), plus transportation
and certain other charges. The Lone Star Contract, which expires in May 1999,
provides for minimum deliveries averaging 45.2 million cubic feet per day. The
contract also includes a take-or-pay provision whereby Lone Star must pay for
60% of the monthly contract volume whether or not it takes such volume (although
deficiencies in one month may, subject to certain limitations, be taken in
subsequent months without additional payments). Company management anticipates
that 19% of annual contract volumes can be supplied from wells currently
operated by Production. Pursuant to a gas purchase contract between Marketing
and MG Natural Gas Corp. ("MGNG"), a wholly-owned subsidiary of MG, MGNG is
required to supply the remaining 81% of the natural gas required to meet the
requirements of the Lone Star Contract at pre-established prices.
The fixed price received by Marketing for gas sold to Lone Star is
substantially in excess of the spot (market) price. It also exceeds the fixed
price of gas purchased from MGNG to meet the requirements of the Lone Star
Contract. As a result, Marketing has substantially locked in a gross margin
equal to the excess of the price received from Lone Star over the price paid to
MGNG with respect to the 81% of its natural gas requirement that it must
purchase. Such "locked up" gross margins are, however, subject to the supply
risk of MGNG, the credit risks of Lone Star and other contractual risks in the
Lone Star Contract.
The Castle Pipeline
The Castle Pipeline is an intrastate pipeline system located in Rusk
County, Texas, which gathers natural gas produced primarily from the Oak Hill
Field located north of Henderson, Texas for delivery to Lone Star through ten
different interconnects with a Lone Star pipeline in north Rusk County. The
Castle Pipeline is the principal means by which Marketing delivers gas to Lone
Star. Other sources of natural gas are accessible through interconnects with six
other pipelines.
The Castle Pipeline consists of 77 miles of pipeline with diameters
ranging from two to six inches and six compressor stations. The Castle Pipeline
has maximum allowable working pressures of 1040 pounds per square inch ("psi")
to 1264 psi with the exception of a low pressure gathering system which has
maximum allowable working pressure of 323 psi. The combined delivery capacities
of the components are in excess of 90 million cubic feet per day. The actual
deliveries made on the Castle Pipeline by Marketing during the periods shown
were as follows:
Twelve Months Ended September 30,
---------------------------------
1993 1994 1995
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MCF(1)....................... 21,050,592 18,208,312 19,504,735
MCFPD(2)..................... 57,673 49,886 53,438
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(1) Thousand cubic feet
(2) Average throughput per day in thousand cubic feet
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OIL AND GAS EXPLORATION AND PRODUCTION
General
The Company's oil and gas exploration and production business, conducted
through Production and Castle Exploration Company, Inc. ("CECI"), a wholly-owned
subsidiary, includes interests in approximately 450 producing oil and gas wells
located in eight states. Until June 1993, the Company also administered a number
of oil and gas partnerships.
Properties
Proved Oil and Gas Reserves
The following is a description of the Company's oil and gas reserves as
of September 30, 1995. All estimates of reserves are based upon engineering
evaluations prepared by Ryder Scott and Company and Huntley and Huntley,
independent petroleum reservoir engineers, in accordance with the requirements
of the Securities and Exchange Commission. Such estimates include only proved
reserves. The Company reports its reserves annually to the Department of Energy.
The Company's estimated reserves as of September 30, 1995 are as follows:
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Location of Reserves
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Texas Other States (2) Total
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Net MCF (1) of gas:
Proved developed producing................................. 14,402,122 6,774,647 21,176,769
Proved developed non-producing............................. 10,002,036 356,074 10,358,110
Proved undeveloped......................................... 22,287,080 2,746,260 25,033,340
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Total...................................................... 46,691,238 9,876,981 56,568,219
========== ========= ==========
Net barrels of oil:
Proved developed producing................................. 68,838 133,320 202,158
Proved developed non-producing............................. 46,070 46,070
Proved undeveloped......................................... 102,652 102,652
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Total...................................................... 217,560 133,320 350,880
========== ========== ==========
</TABLE>
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(1) Thousand cubic feet
(2) Alabama, California, Illinois, Louisiana, Mississippi, Oklahoma and
Pennsylvania
The Texas reserves were acquired on December 3, 1992 when Production
acquired majority working interests in 100 producing oil and gas wells from
ARCO.
Oil and Gas Production
The following table summarizes the net quantities of oil and gas
production of the Company for the three fiscal years ended September 30, 1995,
including production from acquired properties since the date of acquisition.
Fiscal Years Ended September 30,
--------------------------------
1995 1994 1993
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Oil -- Bbls (barrels).......... 51,000 52,000 45,000
Gas -- MCF..................... 3,721,000 3,606,000 3,472,000
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Average Sales Price and Production Cost Per Unit
The following table sets forth the average sales price per barrel of oil
and MCF of gas produced by the Company and the average production cost (lifting
cost) per equivalent unit of production for the periods indicated. Production
costs include applicable operating costs and maintenance costs of support
equipment and facilities, labor, repairs, severance taxes, property taxes,
insurance, materials, supplies and fuel consumed in operating the wells and
related equipment and facilities.
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Fiscal Years Ended September 30,
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1993 1994 1995
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Average Sales Price per Barrel of Oil................................... $17.69 $16.03 $15.59
Average Sales Price per MCF of Gas...................................... $ 2.44 $ 2.02 $ 2.13
Average Production Cost per Equivalent MCF(1)........................... $ 0.71 $ 0.67 $ 0.59
</TABLE>
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(1) For purposes of equivalency of units, a barrel of oil is assumed equal to
six MCF of gas, based upon relative energy content.
Productive Wells and Acreage
The following table presents the oil and gas properties in which the
Company held an interest as of September 30, 1995. The wells and acreage owned
by the Company and its subsidiaries are located in Alabama, California,
Illinois, Louisiana, Mississippi, Oklahoma, Pennsylvania and Texas.
As of
September 30, 1995
-------------------------
Gross(2) Net (3)
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Productive Wells:(1)
Gas Wells............................... 375 189
Oil Wells............................... 75 26
Acreage:
Developed Acreage....................... 81,142 33,801
Undeveloped Acreage..................... 10,534 9,217
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(1) A "productive well" is a producing well or a well capable of production.
Sixty wells are dual wells producing oil and gas. Such wells are classified
according to the dominant mineral being produced.
(2) A gross well or acre is a well or acre in which a working interest is
owned. The number of gross wells is the total number of wells in which a
working interest is owned.
(3) A net well or acre is deemed to exist when the sum of fractional working
interests owned in gross wells or acres equals one. The number of net wells
or acres is the sum of the fractional working interests owned in gross
wells or acres.
Drilling Activity
The table below sets forth for the three fiscal years ended September
30, 1995 the number of gross and net productive and dry developmental wells
drilled including wells drilled on acquired properties since the dates of
acquisition. The Company did not drill any exploratory wells during these
periods.
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Fiscal Year Ended September 30,
-------------------------------
1993 1994 1995
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Productive Dry Productive Dry Productive Dry
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Developmental:
Gross.................................. 8 -- -- -- -- --
Net.................................... 0.48 -- -- -- -- --
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Sale of Partnership Administration Business
Until June 1993, the Company was in the business of oil and gas
partnership administration. As a result of depressed oil and gas prices and tax
legislation during the last nine years, the number of oil and gas partnerships
in existence and the number of oil and gas partnerships being formed have
decreased. These developments significantly limited the number of opportunities
for the Company to obtain new sources of administrative revenue. Therefore, the
Company discontinued its business of administration of oil and gas partnerships
effective as of June 1993 and sold the business to a former officer of the
Company who in November 1994 rejoined the Company as an officer.
REFINING
The Company, through its subsidiaries, owned and operated the Indian
Refinery and the Powerine Refinery. The Refineries had combined refining
(distillation) capacity of 135,500 (B/D).
Indian Refinery
Overview
The Company's subsidiary, IRLP, purchased the Indian Refinery in August
1989 and after an extensive refurbishment program, reopened it in November 1990.
IRLP operated the Indian Refinery from November 1990 through September 1995. In
September 1995, IRLP ceased operations and retired the refining assets of the
Indian Refinery.
The Indian Refinery is located on 834 acres of land in Lawrenceville,
Illinois with a capacity of 86,000 B/D. The Refinery also has a terminalling
facility located in Mt. Vernon, Indiana.
On December 12, 1995, the Company and certain of its subsidiaries closed
a Purchase and Sale Agreement with American Western whereby the Company sold
substantially all of the operating assets, including land, of the Indian
Refinery to American Western for $3 million cash and a $5 million note due upon
the earlier of American Western's completion of its second stage financing or
October 31, 1996. Concurrently, the Company sold certain precious metal catalyst
to American Western for a $1.8 million note due February 11, 1996. The note
repayment date was later extended to March 22, 1996. Further, as part of the
sale, American Western assumed all environmental liabilities related to the
Indian Refinery, all pension liabilities of IRLP, certain litigation between
IRLP and Shell Canada (see Item 3), and a transportation commitment with Mobil
Corp. See Item 7 "Management's Discussion and Analysis of Financial Condition
and Results of Operations."
Powerine
Overview
The Company acquired the Powerine Refinery from MG in October 1993 by
acquiring the stock of Powerine.
The Powerine Refinery is located on 88 acres in Santa Fe Springs,
California and has a capacity of 49,500 B/D. In addition, Powerine owned a
terminal in Phoenix, Arizona and leased a terminal in Long Beach, California.
The Powerine Refinery was shut down in early July 1995 after several
attempts to sell the Powerine Refinery failed. On September 29, 1995, Powerine
sold the Powerine Refinery to Kenyen for $3 million cash and a note in the
principal amount of $19.76 million, which is due in three installments on April
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30, June 30 and September 30, 1996. The note bears interest at 10% and is
secured by the assets sold to Kenyen. Powerine retained the terminals, water
rights, emissions trading credits and certain other assets. In addition,
Powerine retained all on-site and off-site environmental liabilities and was
responsible for clean up of the land once the assets sold were removed.
On January 16, 1996, Powerine merged into a subsidiary of EMC. For tax
purposes the transaction is accounted for as the sale of substantially all of
Powerine's assets for $1 million cash and the assumption of all Powerine's
liabilities, including its environmental liabilities. As a result of the
transactions with Kenyen and EMC, the Company has disposed of all of its
interests in Powerine.
REGULATIONS
Since the Company has disposed of its refineries and third parties have
assumed environmental liabilities associated with the refineries, the Company's
current activities are not subject to environmental regulations that generally
pertain to refineries, e.g., the generation, treatment, storage, transportation
and disposal of hazardous wastes, the discharge of pollutants into the air and
water and other environmental laws. Nevertheless, the natural gas marketing and
transmission and oil and gas exploration and production operations of the
Company are subject to a number of local, state and federal environmental laws
and regulations. To date, compliance with such regulations by the Company's
natural gas marketing and transmission and exploration and production segments
has not resulted in material expenditures.
The Castle Pipeline is an intrastate pipeline system and is primarily
regulated by the Texas Railroad Commission (the "Railroad Commission"). Under
Texas statutes, the Railroad Commission, whose members are elected, has
authority to regulate the intrastate transportation, sale, delivery and pricing
of natural gas by intrastate pipelines in Texas, including the Castle Pipeline.
In its conservation and production regulations, the Railroad Commission has
adopted the Market Demand Rule, which provides, in general, that the production
of gas in excess of reasonable demand is prohibited, and requires that producers
tender and deliver, and gas purchasers, including pipelines, take only volumes
of gas equal to their market demand. The Railroad Commission further requires
that such purchasers must adhere to the Ratable Take Rule and take gas by
priority categories, ratably among producers, without undue discrimination, and
with high-priority gas (defined as casinghead gas, or gas from wells primarily
producing oil, and certain special allowable gas that are the last to be shut-in
during periods of reduced market demand), having greater priority than gas well
gas (defined as gas from wells primarily producing gas), notwithstanding any
contractual commitments.
The Company's activities in connection with the operation of pipelines
and other facilities for transporting natural gas are subject to environmental
regulation by federal and state authorities, including the United States
Environmental Protection Agency (the "USEPA"), the Texas Air Control Board (the
"TACB"), the Texas Water Commission (the "TWC") and the Railroad Commission.
Compliance with regulations promulgated by these various governmental
authorities increases the cost of planning, designing, installing and operating
such facilities. In most instances, the regulatory requirements relate to water,
air and land pollution and control measures. The Company believes it is
currently in material compliance with the measures set forth by the USEPA, the
TACB, the TWC and the Railroad Commission.
All states in which the Company conducts oil and gas exploration and
production activities have laws regulating the production and sale of oil and
gas. Such laws and regulations generally are intended to prevent waste of oil
and gas and to protect correlative rights and opportunities to produce oil and
gas as between owners of interests in a common reservoir. Some state regulatory
authorities also regulate the amount of oil and gas produced by assigning
allowable rates of production to each well or unit. Recently there has been a
significant increase in the amount of state regulation, including increased
bonding, plugging and operational requirements. Such increased state regulation
has resulted in, and is anticipated to continue to result in, increased legal
and compliance costs being incurred by the Company. Based on past costs, even
considering recent increases, management of the Company does not believe such
legal and compliance costs will have a material adverse effect on the financial
condition or operations of the Company.
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EMPLOYEES AND OFFICE FACILITIES
As of February 29, 1996, the Company, through its subsidiaries, employed
approximately 25 personnel.
The Company owns certain office facilities as follows:
Office Location Function
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Henderson, TX Oil and Gas Exploration and Production Office
Henderson, TX Natural Gas Pipeline and Marketing Office
The Company also leases certain offices as follows:
Office Location Function
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Radnor, PA Corporate Headquarters
Mt. Pleasant, PA Oil and Gas Production Office
Pittsburgh, PA Drilling and Exploration Office
Tulsa, OK Oil and Gas Production Office
Calgary, Canada Marketing Office
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ITEM 3. LEGAL PROCEEDINGS
Environmental Liabilities - Refining
Until September 30, 1995, the Company, through its subsidiaries,
operated in the refining segment of the petroleum business. As operators of
refineries, certain of the Company's subsidiaries were potentially liable for
environmental costs related to air emissions, ground and water contamination,
hazardous waste disposal and third party claims related to the foregoing.
In July 1995 operations of the Company's Powerine Refinery ceased. On
September 29, 1995, Powerine sold substantially all the assets of the Powerine
Refinery to Kenyen. Kenyen has advised the Company that it plans to dismantle
the Powerine Refinery and ship it to India. In conjunction with that sale,
Kenyen assumed liability for asbestos abatement and sludge removal.
Substantially all of the remaining assets of Powerine were acquired by EMC for
$1 million cash and the assumption of substantially all of Powerine's
liabilities, including all of its environmental liabilities. At September 30,
1995, Powerine had a $23.6 million reserve for environmental liabilities. The
reserve did not change significantly through January 16, 1996, the date of
Powerine's transaction with EMC.
In September 1995, operations ceased at the Company's other refinery,
the Indian Refinery. On December 12, 1995, IRLP sold the Indian Refinery to
American Western for $8 million. In addition, American Western assumed all
environmental liabilities related to the Indian Refinery. IRLP's management
estimated the gross amount of such environmental liabilities to be approximately
$12.5 million. Because the Company has terminated and discontinued its refining
operations and as a result of the transactions with EMC and American Western,
the discontinued net refining assets, including environmental liabilities, have
been reflected in the September 30, 1995 consolidated balance sheet at estimated
realizable value.
Although the environmental liabilities related to both of the Company's
refineries have been assumed by others, there can be no assurance that the
Company or one of its subsidiaries will not be sued for matters related to
environmental liabilities of the refineries. All three of the companies to which
the refining assets and refining subsidiary stock were sold are thinly
capitalized and without significant financial resources. Two are currently
seeking to raise financing for restarting a refinery or for payment of notes
related to the purchase of one refinery. If any of these companies fails in such
endeavors and cannot pay such notes or environmental liabilities, it is possible
that the Company or IRLP (still a subsidiary of the Company) would be a party in
related legal actions. Although the Company does not believe it has any
liability with respect to such environmental liabilities, a court of competent
jurisdiction may find otherwise and the Company may be required to fund portions
of such liabilities. In recent years, government and other plaintiffs have often
sought redress for environmental damage from the party most capable of payment
without regard to responsibility and fault. Whether or not the Company is
ultimately held liable in such a circumstance, should litigation involving the
Company and/or IRLP occur, the Company would incur substantial legal fees and
experience the diversion of management resources from other operations.
General
MGNG
In April 1995, IRLP terminated a Natural Gas Swap Agreement (the "Swap
Agreement"), dated October 14, 1994 between MGNG and IRLP, claiming the right to
do so based on breaches of other agreements by MG and its affiliates. MGNG
disregarded IRLP's termination notice and sent IRLP a termination notice
alleging IRLP was the defaulting party and claiming approximately $1.2 million
of losses. IRLP has refused to pay MGNG's claim. In June 1995, MGRM, as MGNG's
assignee, filed a complaint in Delaware state court, claiming $1.356 million
plus interest under the Swap Agreement. IRLP has answered the complaint. The
Company's management believes that IRLP has good defenses to that claim, expects
to prevail and expects to recover its $707,000 receivable.
Stockholder Litigation
In January 1994, the Company was served with one complaint filed in the
United States District Court for the Central District of California (the
"District Court") and five complaints filed in the United States District Court
for the Eastern District of Pennsylvania, each of which alleged certain
violations of federal securities laws relating to developments regarding MG and
its affiliates. The lawsuit filed in California, entitled Leslie Susser and
Robert Susser v. Castle Energy Corporation, et. al., and the lawsuits filed in
Philadelphia, which were consolidated as a single action under the title In re
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Castle Energy Corp. Securities Litigation (the "Pennsylvania Action"), were
filed as class action complaints on behalf of either all persons who purchased
the Company's Common Stock in its November 1993 public offering or all persons
who purchased the Company's Common Stock during various periods from February 3,
1993 through January 14, 1994. The complaints sought unquantified damages and
other relief from the Company, MG and certain of the Company's officers and
directors. On June 7, 1994, the Judicial Panel on Multidistrict Litigation
ordered the Pennsylvania Action to be transferred to the District Court for
coordinated or consolidated pre-trial procedures under the caption In re Castle
Energy Corporation Securities Litigation (the "Stockholder Litigation"). The
District Court certified a class of persons who purchased the Company's Stock
during the period from February 3, 1993 through and including January 14, 1994.
In October 1994, the parties reached a settlement of the claims in the
Stockholder Litigation, including certain added derivative claims. On December
6, 1994, after notice to class members and the Company's stockholders, the
District Court entered an order approving the settlement (the "Settlement
Order"), including approval of: (i) a payment to the plaintiff class and its
attorneys of $15 million, of which the Company's portion will not exceed
$500,000 after contribution by MG and application of insurance proceeds; and
(ii) the MG Settlement as fair and reasonable to the Company and its
stockholders. On the same date the District Court issued orders dismissing the
Stockholder Litigation (including the Pennsylvania Action) with prejudice. No
appeals were filed challenging the Settlement Order and, accordingly, the order
became final on January 5, 1995.
On December 11, 1995, the Company received a $2.725 million refund from
the payment to the plaintiff class, representing unclaimed funds that were to
revert to the Company pursuant to the Settlement Order. Approximately $2.275
million was paid to class members and the remaining $10 million to attorneys.
Securities and Exchange Commission Investigation
On April 17, 1994, the Securities and Exchange Commission (the "SEC")
entered an Order of Investigation relating to the Company's November 1993 public
offering. Subsequently, the Company received a document subpoena, pursuant to
which the Company has produced documents to the SEC. On May 31, 1994, the
Company's former general counsel met informally with the SEC staff at the
Philadelphia District office. The SEC has taken testimony from certain current
and former directors of the Company. To date, the Company has not been informed
by the investigators of any claims of wrongdoing against the Company or its
directors and officers.
Grand Jury Investigation, New York County
On February 2, 1994, the Company received a subpoena for documents from
a grand jury in New York County, New York. The requested documents appear to
relate to the Company's 1993 public offering and MG's alleged financial
difficulties. The Company has produced documents pursuant to that subpoena. On
March 25, 1994, the Company's former general counsel and the Company's New York
counsel met informally with Assistant District Attorneys of New York County to
discuss the investigation. Other parties or their attorneys, including MG, have
also spoken with the Assistant District Attorneys. To date, the Company has not
been informed by the investigators of any claims of wrongdoing against the
Company or its directors and officers.
Mechanics Liens - IRLP
A total of approximately $3.7 million of mechanics liens has been filed
by vendors against IRLP. Of this amount, approximately $2.0 million has been
settled by IRLP using proceeds from the $3 million cash payment from American
Western. IRLP anticipates paying the remaining amount with the proceeds of the
American Western note (see footnote 3 to the consolidated financial statements
included in Item 8).
Powerine Arbitration
On April 14, 1995, Powerine repaid all of the indebtedness owed by it to
MGTFC, including $10.8 million of disputed amounts (the "Disputed Amount"). On
the same day, the Company and two of its subsidiaries and MG and two of its
subsidiaries entered into the Payoff Loan and Pledge Agreement ("Payoff
Agreement"), which provided the following:
a. MG released Powerine from all liens and claims.
b. MG loaned the Company $10 million.
-9-
<PAGE>
c. Powerine transferred its claim with respect to the Disputed Amount to
the Company.
d. The claim with respect to the Disputed Amount was agreed to be
submitted to binding arbitration (the "Powerine Arbitration").
e. MG can offset the $10 million loan to the Company against the $10
million note it issued to the Company as part of the MG Settlement,
to the extent the arbitrator decides the claim with respect to the
Disputed Amount in MG's favor.
The Disputed Amount relates primarily to disputes over the prices paid
by subsidiaries of MG for 388,500 barrels of refined products lifted by MG's
subsidiary, MGRM, and nonpayment for refined products that were processed after
January 31, 1995 and that MGRM was obligated to, but did not, lift and pay for.
To the extent that the arbitrator decides in favor of the Company, the Company's
note to MG will be reduced and the net amount due to the Company from MG will be
increased. If the arbitrator settles the Disputed Amount entirely in the
Company's favor, the Company's note to MG will be cancelled and MG will still
owe the Company its $10 million note (due October 14, 1997). If the arbitrator
settles the Disputed Amount entirely in MG's favor, the Company's note from MG
will be discharged. In such case the Company's future earnings will also be
adversely impacted since the Company has not recorded any reserve against the
note.
On September 8, 1995, the Company filed its Statement of Claim and
Memorandum. On December 6, 1995, MG filed its Notice of Defense and Response to
Claimant's Statement of Claim and Memorandum. The Company filed its reply brief
on February 14, 1996 and the parties are proceeding with discovery as to the
amount of damages.
In January 1996, MG did not pay interest on the $10,000,000 note, when
such interest was due. As a result, the entire note is due to be paid to the
escrow account for the Powerine Arbitration. The Company has demanded that MG
pay the entire note.
Long-Term Supply Agreement
In 1993, IRLP entered into a Long-Term Supply Agreement (the "LTSA")
with Shell Canada Limited and Salmon Resources Ltd. (collectively "Shell") for
the supply of Caroline Condensate feedstock to the Indian Refinery. MGRM agreed
to be the alternate purchaser under the LTSA in the event IRLP should fail to
perform. On December 23, 1994, Shell filed suit in the United States District
Court for the Northern District of Illinois against IRLP and MGRM (the "Shell
Litigation"). The complaint alleged that MGRM failed to provide Shell with
adequate assurances, pursuant to a request under the Illinois Commercial Code,
concerning its role as "alternate purchaser" under the LTSA, and that as a
result, MGRM repudiated the LTSA pursuant to provisions of the Illinois
Commercial Code. The complaint further alleged that the LTSA should be
terminated because its purpose has been frustrated and the performance has
become impossible.
On October 2, 1995, Shell unilaterally terminated its performance under
the LTSA and ceased delivering Caroline Condensate to the Indian Refinery. On
January 16, 1996, Shell filed an amended complaint, which adds a claim for
$10,000,000 in damages based upon alleged undercharges and other breaches of the
LTSA. Management believes the claim of Shell is without merit.
On December 12, 1995, IRLP sold the Indian Refinery to American
Western. As part of the sale, American Western assumed all liabilities and
expenses associated with the LTSA litigation. It is currently pursuing this
litigation against Shell.
-10-
<PAGE>
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
The Company did not hold a meeting of stockholders or otherwise submit
any matter to a vote of stockholders during the fourth quarter of fiscal 1995.
-11-
<PAGE>
PART II
ITEM 5. MARKET FOR THE COMPANY'S COMMON STOCK AND RELATED STOCKHOLDER MATTERS
Principal Market
The Company's Common Stock is quoted on the Nasdaq National Market
("NNM") under the trading symbol "CECX".
Stock Price and Dividend Information
Stock Price:
The table below presents the high and low sales prices of the Company's
Common Stock as reported by the NNM for each of the quarters during the two
fiscal years ended September 30, 1995.
<TABLE>
<CAPTION>
1994 1995
------------------------- -------------------
High Low High Low
<S> <C> <C> <C> <C>
First Quarter (December 31).................................. $25.00 $11.00 $16.00 $11.25
Second Quarter (March 31).................................... 14.50 7.25 14.25 8.00
Third Quarter (June 30)...................................... 15.00 9.75 10.75 7.00
Fourth Quarter (September 30)................................ 19.00 11.50 11.00 8.00
</TABLE>
The final sale of the Company's Common Stock as reported by the NNM on
February 29, 1996 was $7.875.
Dividends:
The Company has not adopted a formal dividend policy and has not
declared a dividend since 1989. The loan agreements in place with subsidiaries
of the Company restrict the subsidiaries from distributing cash to the Company
until the debt obligations are satisfied. Accordingly, the subsidiaries' profits
are generally not available for dividends.
Approximate Number of Holders of Common Stock
As of February 29, 1996, the Company's Common Stock was held by
approximately 2,000 stockholders.
-12-
<PAGE>
ITEM 6. SELECTED FINANCIAL DATA
During the Company's five fiscal years ended September 30, 1995, the
Company consummated a number of transactions affecting the comparability of the
financial information set forth below. In August 1989, the Company acquired the
Indian Refinery. From April 1990 until November 1990, the Company performed
refurbishment work on the Indian Refinery and recommenced operations in November
1990. In February 1992, the Company entered into a product offtake agreement
with MGR&M ("Indian Offtake Agreement") which was restructured and extended in
May 1993. In December 1992, the Company acquired certain assets from ARCO. In
June 1993, the Company sold its business of administration of oil and gas
partnerships. In October 1993, the Company acquired the Powerine Refinery.
During 1995, the Company reached a settlement with MG and its affiliates which
would affect the results of operations for all future periods. In September
1995, the Company discontinued its refining operations. See Item 7 -
"Management's Discussion and Analysis of Financial Condition" and Note 3 to the
Company's Consolidated Financial Statements included in Item 8, to this Form
10-K.
The following selected financial data has been derived from the
Consolidated Financial Statements of the Company for each of the five years
ended September 30, 1995 and all such income statement information has been
reclassified to give effect to the discontinuance of the refining operations.
The information should be read in conjunction with the Consolidated Financial
Statements and notes thereto included in Item 8. Financial Statements and
Financial Statement Schedules and Item 7. "Management's Discussion and Analysis
of Financial Condition."
<TABLE>
<CAPTION>
For the Fiscal Years Ended September 30,
----------------------------------------
(in Thousands, except per share amounts)
1995 1994 1993 1992 1991
---- ---- ---- ---- ----
<S> <C> <C> <C> <C> <C>
Revenues:
Natural gas marketing and transmission................ $70,402 $61,259 $ 56,676 - -
Exploration and production............................ 9,197 8,552 10,124 $ 5,165 $ 7,709
Gross Margin:
Natural gas marketing and transmission................ 30,242 24,199 22,200 - -
Exploration and production............................ 6,831 5,923 7,469 3,372 5,379
Earnings (loss) before interest, taxes, depreciation, and
amortization:
Natural gas marketing and transmission................ 28,252 22,003 20,361 - -
Exploration and production............................ 5,761 4,494 5,940 2,181 4,189
Corporate general and administrative expenses............. (4,995) (5,499) (2,191) (1,706) (1,707)
Depreciation, depletion and amortization.................. (14,155) (13,452) (12,191) (1,453) (1,499)
Interest expense.......................................... (4,046) (9,233) (9,117) (2,919) (3,155)
Interest income and other income (expense)................ 966 950 85 (476) 380
---------- ----------- ------------ ----------- ----------
Income (loss) from continuing operations before
income taxes and cumulative effect of a change in
accounting............................................ 11,783 (737) 2,887 (4,373) (1,792)
Provision for (benefit of) income taxes related to
continuing operations................................. 37,823 (17,077) (44,081) 81 (17)
---------- ----------- ------------ ----------- ----------
Income (loss) from continuing operations (26,040) 16,340 46,968 (4,454) (1,775)
Income (loss) from discontinued refining operations
net of applicable income taxes........................ 40,937 22,577 12,355 (47,815) (97,309)
---------- ----------- ------------ ----------- ----------
Income (loss) before cumulative effect of a change in
accounting principle.................................. 14,897 38,917 59,323 (52,269) (99,084)
Cumulative effect on prior years of change in
accounting principle - adoption of FAS 109............ 8,514
---------- ----------- ------------ ----------- ----------
Net income (loss)......................................... $14,897 $38,917 $67,837 ($52,269) ($99,084)
========== =========== ============ =========== ==========
Net income (loss) per share (fully diluted):
Continuing operations................................. ($ 3.84) $ 1.44 $ 6.20 ($ 0.35) ($ 0.19)
Discontinued operations............................... 6.04 1.99 1.64 (3.76) (10.41)
Cumulative effect of a change in accounting........... 1.12
---------- ----------- ------------ ----------- ----------
$ 2.20 $ 3.43 $ 8.96 ($ 4.11) ($ 10.60)
========== =========== ============ =========== ==========
</TABLE>
(continued on next page)
-13-
<PAGE>
<TABLE>
<CAPTION>
September 30,
----------------------------------------
(in Thousands)
1995 1994 1993 1992 1991
---- ---- ---- ---- ----
<S> <C> <C> <C> <C> <C>
Balance Sheet Data (at end of Period):
Working capital (deficit).............................. ($12,474) ($ 22,769) ($ 47,462) $ 6,451 ($ 88,952)
Property, plant and equipment, net, including oil
and gas properties.................................. 40,406 339,876 150,299 85,420 82,818
Total assets........................................... 116,904 646,491 392,738 167,873 110,732
Long-term debt, including current maturities........... 35,946 394,123 199,020 202,860 127,364
Stockholders' equity (deficit)......................... 41,637 37,920 (9,387) (89,124) (37,749)
</TABLE>
(continued from previous page)
-14-
<PAGE>
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
GENERAL
Until August 1989, the Company was involved in only one segment of the
petroleum industry - oil and gas exploration and production, including the
administration of related oil and gas partnerships. At that time the Company
made a material investment in the refining segment of the petroleum industry by
acquiring the Indian Refinery in August 1989. The Indian Refinery commenced
operation in November 1990 and, as a result, refining operations first impacted
the Company in the fiscal year ended September 30, 1991. On December 3, 1992,
the Company acquired from ARCO the Lone Star Contract, a 77-mile intrastate gas
pipeline located in Rusk County, Texas and majority working interests in 100
producing oil and gas wells for an aggregate purchase price of approximately
$103.7 million including liabilities assumed and transaction costs. As a result
of this acquisition, the Company entered a third segment of the oil and gas
business - natural gas transmission and marketing.
In June 1993, the Company sold its business of administration of oil and
gas partnerships to a former officer of the Company. The former officer rejoined
the Company in November 1994. Nevertheless, through its ownership of
non-partnership oil and gas properties, including those acquired from ARCO, the
Company remained active in the oil and gas exploration and production segment of
the oil and gas business.
As of October 1, 1993, the Company acquired Powerine, which owned a
49,500 B/D refinery in Santa Fe Springs, California. The results of operations
of Powerine are included in the refining segment commencing October 1, 1993. The
acquisition of Powerine increased the dominance of refining in the Company's
consolidated operations.
Most of the Company's acquisitions were financed by MG, which was also
the principal shareholder of the Company until September 1994. Many of the
Company's transactions were with MG or its subsidiaries (see footnote 21 to the
consolidated financial statements included in this Form 10-K). In December 1993,
the financial press reported that MG AG and MG had incurred substantial losses
related to hedging activities. Thereafter, MG sought to restructure or terminate
its relationships with the Company and its subsidiaries. In August 1994, the
Company entered into the MG Settlement. The MG Settlement closed on October 14,
1994 (see footnote 3 to the consolidated financial statements included in this
Form 10-K). As a result of the MG Settlement, the Company realized a $391
million gain and MG returned to the Company all of the Company's stock that it
owned.
The Company began to explore its options for dealing with its refining
operations before and during the negotiation of the MG Settlement. The Company
considered a number of alternatives, ranging from continuing refining operations
on substantially the same basis as prior to the MG Settlement, but obtaining new
working capital financing and a new customer base, to selling or closing the
refineries. The Company believed, however, that it would need to raise
substantial new equity for the payment of its income taxes, in addition to
raising the working capital financing for the refineries, if it decided to
continue refinery operations. Further, continuing the refinery operations would
require the Company to add significant marketing personnel, expertise and
expense. On the other hand, closing the refineries would result in substantial
shut-down costs, including severance obligations to employees and potential
environmental clean-up costs, although it would allow the Company to write-off
the costs of its refineries to substantially reduce its taxes. Based upon these
factors, the Company sought to sell its refining operations. As of December 31,
1994, the Company had written down its refining assets to their estimated net
realizable values and booked accruals for anticipated closing costs. The first
quarter impairment reserve of $345,008,000 was revised in the third and fourth
quarters based on changes in facts and circumstances. For the year ended
September 30, 1995, the Company recorded impairment reserves of $323,078,000.
During the period October 14, 1994 to September 30, 1995, the Company
sought to sell both Refineries. An initial attempt to sell both refineries and
then additional attempts to sell one refinery to management failed because of
the lack of financing and market conditions. The Company believes that the
filing of a lawsuit by Shell Canada Limited ("Shell") against IRLP during
financing negotiations contributed to this failure (see Item 3 to this Form
10-K). (Liabilities, if any, resulting from the lawsuit were later assumed by
American Western.) During the spring, summer and fall of 1995, the Company
sought to sell the refineries separately. Although several agreements were
negotiated, the potential purchasers were not able to raise the financing
required. In September 1995 an effort to sell the Indian Refinery to CORE
Refining Corporation, a company formed by William Sudhaus, an executive officer
and director of the Company ("CORE"), failed when CORE's investment banker
-15-
<PAGE>
failed to perform in raising a substantial amount of debt. As a result of
continued failure to sell the refineries, the Company caused operations at each
refinery to cease. Operations at the Powerine Refinery ceased in July 1995 and
operations at the Indian Refinery ceased in September 1995.
On September 29, 1995, the Company sold the Powerine Refinery to Kenyen.
Kenyen has advised the Company that it plans to dismantle the refinery and ship
it to India. On January 16, 1996, Powerine merged into a subsidiary of EMC. As a
result of the transactions with Kenyen and EMC, the Company no longer owns any
interest in Powerine.
On September 30, 1995, the Indian Refinery ceased operations and retired
its assets. On December 12, 1995, IRLP sold the Indian Refinery to American
Western, a wholly-owned subsidiary of Gadgil for $8 million. $3 million was paid
in cash; the remaining $5 million (represented by a note) is payable the earlier
of a) Gadgil's raising of financing to restart the Refinery b) October 31, 1996.
The note is secured by the refining plant. In addition, American Western assumed
certain liabilities of IRLP, including all environmental liabilities. IRLP,
however, remained responsible for liabilities not assumed by American Western -
primarily trade payables. IRLP intends to use the $5 million note proceeds to
pay the trade payables.
As a result of the sales to Kenyen, EMC and American Western, the
Company has divested its refining operations. Nevertheless, should Kenyen, EMC,
and/or American Western fail in their efforts with respect to the refineries
they purchased or to pay notes due to the Company, it is possible that the
Company and/or its subsidiaries could be included in efforts by vendors to
collect trade payables and/or by environmental authorities in efforts to pursue
environmental claims. All of the aforementioned entities have limited capital.
See footnote 3 to the consolidated statements for further information
concerning the disposition of the refineries.
As a result of the foregoing, the Company discontinued its refining
operations by September 30, 1995 and such refining operations are accounted for
currently and retroactively as discontinued operations. Accordingly, discussion
of results of operations has been confined to results of continuing operations -
exploration and production and natural gas marketing and transmission.
RESULTS OF OPERATIONS
($ "000's" Omitted)
- --------------------------------------------------------------------------------
Fiscal 1995 vs Fiscal 1994
Revenues
Gas sales from natural gas marketing increased $9,174 or 15% from fiscal
1994 to fiscal 1995. Under the Company's long-term gas sale contract with Lone
Star, the price received for gas is essentially fixed through May 31, 1999. The
variance in gas sales, therefore, is almost entirely attributable to the volumes
of gas delivered. Although the volumes sold to Lone Star annually are
essentially fixed (the Lone Star Contract has a take-or-pay provision), the Lone
Star contract year is from February 1 to January 31 whereas the Company's fiscal
year is from October 1 to September 30. Furthermore, although the volumes to be
taken by Lone Star in a given contract year are fixed, there is no provision
requiring fixed monthly or daily volumes and deliveries accordingly vary with
Lone Star's seasonal and peak demands. Such variances have been significant. As
a result, Lone Star deliveries, although fixed for a contract year, may be
skewed and not proportional for the Company's fiscal year. Lone Star deliveries
and sales for 1995 approximated those which would have occurred if daily takes
under the Lone Star Contract had been fixed and equal. Except for $84, all
fiscal 1995 sales by the natural gas marketing and transmission segment were to
Lone Star.
The Lone Star Contract provides for a 8.6% reduction in annual
deliveries commencing February 1, 1996. Assuming average monthly deliveries for
the contract year ended January 31, 1997, this would result in a decrease in gas
sales of approximately $4,007 in fiscal 1996. For the Company, the required gas
volume decreases another 1.5% for the contract year beginning February 1, 1997
and remains constant thereafter. As a result , the Company expects average sales
under the Lone Star Contract to be 8.6% - 10% less in each of the two fiscal
years ending September 30, 1998 when compared to fiscal 1995.
Exploration and production revenues increased $645 or 7.5% from fiscal
1994. The increase is primarily attributable to increased gas prices. Production
for fiscal 1994 consisted of 3,918,000 equivalent mcf (consisting of 52,000
barrels of crude and 3,606,000 mcf of gas) versus 4,027,000 equivalent mcf
-16-
<PAGE>
(consisting of 51,000 barrels of crude and 3,721,000 mcf of gas) for fiscal
1995. The net increase in equivalent mcf was 109,000 equivalent mcf or 2.8%.
Average gas prices increased $.11 per mcf or 5.4% from $2.02 in fiscal 1994 to
$2.13 in fiscal 1995. The increase in production consisted of two factors: an
increase resulting from the purchase of the production payment from ARCO in
October 1994 (see footnote 4 to the consolidated financial statements) offset by
a similar decline in production from the Company's other depleting wells. With
the exception of the ARCO production payment purchase, only $199 was invested in
oil and gas properties in fiscal 1995.
Expenses
Gas purchases increased $3,131 or 8.5% from fiscal 1994. In fiscal 1994
gas purchases constituted 60.5% of gas sales versus 57% of gas sales in fiscal
1995. The decrease in the gas purchase cost percentage is primarily attributable
to the elimination of deferred gas purchase cost. In fiscal 1994, a deferred gas
purchase cost of $2,400 was included in gas purchase cost. This cost represented
additional deferred gas purchase costs that the Company expected to pay after
the GECC Loan was repaid. As a result of the MG Settlement on October 14, 1994
the deferred gas purchase obligation was discharged and did not apply to most of
fiscal 1995.
Operating costs of the natural gas transmission segment increased $69 or
6.1% from 1994 to 1995. This increase consists primarily of wage increases given
to pipeline personnel.
General and administrative expenses applicable to natural gas marketing
and transmission decreased $306 or 28.1% from fiscal 1994 to fiscal 1995. The
decrease occurred primarily because of a decrease in insurance and legal costs.
Operating (oil and gas production) expenses in the exploration and
production segment decreased $263 or 10% from fiscal 1994 to fiscal 1995. The
decrease results primarily from decreased operating costs applicable to
non-operated wells and significantly decreased property taxes.
General and administrative costs applicable to exploration and
production decreased $359 or 25.1% from 1994 to 1995. The decrease results
primarily from decreased insurance expense, administrative fees and legal costs.
Interest expense decreased $5,187 or 56.2% from fiscal 1994 to fiscal
1995. The decrease results entirely from the decrease in the GECC Loan and the
discharge of a $9.5 million subordinated loan due to MGTFC on October 14, 1994
as part of the MG Settlement.
The tax provision allocation applicable to continuing operations has
been determined pursuant to "Financial Accounting Standards Number 109 -
Accounting for Income Taxes" ("FAS 109"). The management of the Company believes
that the intraperiod tax provision allocation between continuing and
discontinued operations is misleading because the tax rate applicable to
continuing operations does not approximate the tax rate expected by the Company
in future years.
Fiscal 1994 vs Fiscal 1993
Revenues
Revenues from natural gas marketing increased by $4,583 or 8.1% for the
year ended September 30, 1994, principally as a result of the Company's
acquisition of the Lone Star Contract from ARCO on December 3, 1992. The
increased sales for the additional two months in fiscal 1994 were slightly
offset by decreased average daily quantities sold to Lone Star during the year
ended September 30, 1994. The average daily takes of gas under the Lone Star
Contract decreased 14% in 1994. The decrease in daily takes is attributable to
small decreases in the annual contractual volumes under the Lone Star Contract
and seasonal requirements of Lone Star within a contract year.
Exploration and production revenues decreased $1,572 or 15.5% for the
year ended September 30, 1994 as compared to the prior year primarily as a
result of the June 30, 1993 sale of certain exploration and production
properties, as well as the general depletion of other Company wells.
Furthermore, the Company drilled no new wells in fiscal 1994 and made minimal
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<PAGE>
capital investments to enhance existing production. This was partially offset by
the addition of 100 working oil and gas wells on December 3, 1992.
Operating Income and Expenses
Natural gas marketing earned operating income of approximately $10.6
million in fiscal 1994 versus $10.9 million in fiscal 1993. The decrease is
primarily attributable to the decreased average daily quantities sold to Lone
Star which was offset by an increase attributable to twelve months of operations
in 1994 as compared with ten months in 1993.
Operating income for the exploration and production operations was
approximately $2.4 million in 1994 as compared with $3.2 million in fiscal 1993.
The decrease results from the sale of certain properties in June 1993 and the
loss of administrative revenues as a result of the sale of the Company's
partnership management business in June 1993. This is partially offset by the
addition of 100 working oil and gas wells on December 3, 1992.
Corporate general and administrative expenses increased $3.3 million
over the corresponding period in 1993. This increase is primarily attributable
to legal fees associated with defending the Stockholder Litigation and related
matters.
Other Expenses
Interest expense increased $116 or 1.3% from fiscal 1993. The net
increase is the result of two offsetting factors. Interest expense decreased
because the loan principal of the GECC Loan and a subordinated loan to MGTFC
decreased in 1994. Interest expense increased in 1994 because the loans, which
were used to finance the acquisition of the ARCO assets, were not made until
December 1992 hence such loans were outstanding for less than a whole year in
fiscal 1993.
Income Taxes
The Company allocated the 1994 tax provision between continuing and
discontinued operations retroactively pursuant to FAS 109. The Company believes
such allocation is misleading for the reason noted above.
Fiscal 1993 vs Fiscal 1992
Revenues
Revenues from natural gas marketing to Lone Star aggregated
approximately $56,600 for the period from December 3, 1992, the date the
natural gas marketing assets were acquired, to September 30, 1993. Lone Star's
gas purchases in the ten month period ending September 30, 1993 approximated
66.3% of the contract volume required to be taken by Lone Star for the contract
year ended January 31, 1994.
Exploration and production revenues during fiscal 1993 increased
approximately $5,000, or 96%, because of the production related to the
purchase of majority working interests in 100 producing oil and gas wells from
ARCO on December 3, 1992. If the producing wells had not been acquired,
exploration and production revenues would have decreased approximately $1,400.
Operating Income and Expenses
Natural gas marketing had operating income of approximately $10,900
for the fiscal year 1993. Such operating income was derived from ten months
of operations.
Operating income of exploration and production was approximately $3,200
for the fiscal year ended September 30, 1993 compared to operating income of
$700 for fiscal year 1992. This increase is due to the addition of majority
working interests in 100 wells on December 3, 1992.
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<PAGE>
Income Taxes
The Company allocated the 1993 provision between continuing and
discontinued operations retroactively pursuant to FAS 109. The Company believes
such allocation is misleading for the reason noted above.
LIQUIDITY AND CAPITAL RESOURCES
As of September 30, 1995
Subsequent to September 30, 1995, the Company sold the Indian Refinery
to American Western, the Powerine Refinery to Kenyen, and merged Powerine into a
subsidiary of EMC. As a result its financial condition changed significantly.
The discussion of liquidity and capital resources is, accordingly, focused on
the Company's financial condition as of February 29, 1996.
As of February 29, 1996
As noted previously, the Company completed the following material
transactions between September 30, 1995 and February 29, 1996:
a. IRLP sold the Indian Refinery to American Western on December 12,
1995 for $8,000. In addition, American Western assumed all of IRLP's
environmental liabilities.
b. On January 16, 1996, Powerine merged into a subsidiary of EMC.
As a result of the American Western, Kenyen and EMC transactions, the
Company had disposed of all of its refining assets. In the case of the Indian
Refinery the purchaser also assumed all pension and environmental liabilities of
IRLP. Nevertheless, IRLP remains liable for vendor payables, unpaid severance
costs and other accrued costs which approximate $7,150 million at February 29,
1996. IRLP anticipates settling these liabilities with the proceeds of the
American Western note. In addition, the Company is liable for any shortfall in
the liquidation of a revolving credit facility of IRLP with a major financial
institution ("Bankers Trust Replacement Credit Facility") by virtue of pledging
its exploration and production collateral. At February 29, 1996, the amount due
to Bankers Trust was $4,540. Most of the inventory collateral securing the
Replacement Credit Facility has been liquidated but approximately $800 of
receivables and $1,803 from the sale of platinum to American Western remain to
be collected. As a result, the Company expects the shortfall to approximate
$2,000.
In the case of Powerine all of Powerine's liabilities, including all
environmental liabilities, have been assumed as a result of the EMC transaction.
Powerine's refining assets were previously sold to Kenyen. A description of both
transactions is found in footnote 3 to the consolidated financial statements.
As a result of the foregoing, the Company's expected cash obligations
and cash resources from March 1, 1996 to September 30, 1996, the Company's next
fiscal year end, are as follows:
-19-
<PAGE>
<TABLE>
<CAPTION>
Dedicated
to
GECC Loan Not Dedicated Total
--------- ------------- -----
<S> <C> <C> <C>
Cash Resources:
Cash on hand............................................ $2,000 $ 2,000
Cash flow - natural gas marketing...................... $12,450 12,450
Cash flow - exploration and production................. 2,625 1,750 4,375
Interest - MG Note and other........................... 1,000 1,000
-------- ------- ---------
15,075 4,750 19,825
-------- ------- --------
Cash Obligations:-
Repayment of long-term debt:
GECC Loan......................................... 15,075 (1) 15,075
Loan from former stockholder...................... 1,250 1,250
Loan from stockholder............................. 125 125
Repayment of Replacement Credit Facility shortfall..... 2,000 2,000
Repayment of officer severance and other
obligations related to discontinued refining
operations........................................ 2,500 2,500
Corporate general and administrative expenses..... 1,750 1,750
------- ------- --------
15,075 7,625 22,700
------- ------- -------
Excess Cash (Obligations)................................. -- ($2,875) ($ 2,875)
======= ======= =======
</TABLE>
(1) The required repayment of the GECC Loan is $6,706 but all cash flow,
including amounts in excess of $6,706 are dedicated to repayment. The GECC
Loan had been reduced to $22,109 by February 29, 1996 and the Company
expects complete repayment not later than January 31, 1997.
Although the Company has reduced the GECC Loan approximately $12,000
below the minimum required principal, essentially all cash flow from the oil and
gas wells, pipeline and gas contracts purchased from ARCO are dedicated to the
GECC Loan and cannot be used for other purposes. As a result the Company faces a
$2,875 cash flow shortfall. Accordingly, on March 14, 1996, the Company entered
into a $3,800 credit commitment with a financial institution. Funds borrowed
will be secured by the Company's exploration and production assets. Such
financing allows the Company to meet the projected deficit of $2,875 until the
GECC Loan is repaid. Such repayment is expected in January 1997. At such time,
the Company would receive the cash flow now dedicated to repayment of the GECC
Loan - approximately $24,000 annually. The Company anticipates closing the new
credit facility by April 1, 1996. If, for any reason, the Company is unable to
close the new credit facility, the Company believes that it could raise the
required capital by obtaining a $5,000 credit facility with another financial
institution based upon its exploration and production collateral or by selling
certain of its exploration and production assets - if needed. The Company also
believes that it could obtain financing by selling its Lone Star Contract or
borrowing from an energy lender based upon the remaining value in such contract.
Although the Company anticipates that it will be able to obtain
financing based upon the fair market value of its gas contracts and exploration
and production assets, there can be no assurance that such financing will be
obtained or that it will be obtained in a timely manner. Furthermore, although
the Company has exited the refining business, it is still subject to certain
material risks related to the refinery segment as follows:
a. Kenyen, American Western and EMC are all small, thinly capitalized
companies. If any or all of them fail in their endeavors to restart
or transport either of the refineries, interested parties could seek
redress from the Company for vendor or environmental liabilities. In
the past government and other plaintiffs have often named the most
financially capable parties in such cases regardless of the existence
or extent of actual liability. Although the Company's management does
not believe the Company would ultimately be held liable, there can be
no assurance such will be the case. Even if the Company were to
prevail in such litigation, the related legal costs and distraction
of the Company's management resources from continuing operations
could be significant.
-20-
<PAGE>
b. In the case of the Indian Refinery transaction, IRLP remains
responsible for its liabilities to the extent such liabilities were
not assumed by the purchaser, American Western. Such liabilities are
approximately $7,150 at February 29, 1996. If American Western does
not pay the $5,000 note, IRLP's only recourse is to foreclose on its
collateral, the Indian Refinery. It would then have to sell the
Refinery in order to use the proceeds to pay vendors. In fiscal 1995,
the Company was unable to sell the Indian Refinery. Moreover, claims
by environmental authorities could also be made and could supersede
those of vendors. If such were the case, the Company could decide to
put IRLP into a liquidation proceeding. Although the Company does not
expect any additional significant cash outlays for the Indian
Refinery and believes such outlays would not legally be required,
attempts may be made to impose such liabilities on the Company.
On March 5, 1996, the Company engaged an investment banking firm to
explore strategic alternatives to enhance stockholder value and to act as the
Company's exclusive advisor. The alternatives that may be recommended include
the sale of assets, the sale of the Company, a merger with or joint venture with
another Company or other restructuring measures. If such is the case, future
operations of the Company may be different from that herein contemplated.
INFLATION AND CHANGING PRICES
Natural Gas Marketing and Transmission
The Company's gas sales contract with Lone Star is essentially a fixed
price contract. It continues through May 1999. The Company's gas supply contract
is also a fixed price contract. The result is that the Company's gross margin is
essentially "locked in" and does not increase with inflation. Although there are
some operating costs applicable to the natural gas marketing and pipeline
transmission segment, which tend to increase with inflation, they are minor and
inflation of such costs without concomitant inflation in revenues does not
significantly impact operating profits.
Exploration and Production
Oil and gas sales are determined by markets locally and worldwide and
often move inversely to inflation. Whereas operating expenses related to oil and
gas sales may be expected to parallel inflation, such costs have often tended to
move more in response to oil and gas sales prices than in response to inflation.
General
Since the Company currently has virtually no variable rate debt, it is
not sensitive to fluctuations in interest rates.
NEW ACCOUNTING PRONOUNCEMENTS
The Financial Accounting Standards Board has released several
pronouncements that are not effective until future years. The Company believes
that such pronouncements, when effective, will not materially affect the
Company's financial condition or results of operations.
RISK FACTORS
The Company desires to take advantage of the new "safe harbor"
provisions of the Private Securities Litigation Reform Act of 1995 and is
including this section of Item 7 to this Form 10-K to do so. The Company
cautions readers that the following important risk factors could affect the
Company's future results of operations and financial condition and could cause
the Company's actual future results of operations and financial condition to
differ materially from those expressed in forward looking statements made by or
on behalf of the Company.
Refinery Matters
Although the Company has disposed of its two refineries, the Company's
future results of operations and cash flow could be adversely affected by
liabilities related to such refineries if the purchasers are unable to satisfy
such liabilities as discussed above. In addition, one purchaser is obligated to
the Company for an aggregate of $6,803 in notes, which may not be paid if such
purchaser is unable to raise financing to restart the refineries. See "Liquidity
and Capital Resources," above and Item 1 - "Business and Properties - Refining"
and Item 3. "Legal Proceedings."
-21-
<PAGE>
Supply Risk - MGNG Supply Contract
Approximately 84% of the gas delivered to Lone Star pursuant to the Lone
Star Contract is provided by MGNG. The Lone Star Contract expires on May 31,
1999. MGNG is a wholly-owned subsidiary of MG, which, in turn, is indirectly
owned by MG AG. If spot gas prices increase significantly and MGNG has not
hedged its future commitment to supply gas to the Company or if MGNG experiences
financial problems, MGNG may be unable to meet its gas supply commitments to the
Company. If MGNG does not fulfill its gas supply commitment to the Company, the
Company may not be able to fulfill its gas delivery commitment to Lone Star
which would adversely impact the Company's results of operations and cash flow.
Under such circumstances the Company may not be able to recover lost profits and
cash flow from MGNG despite provisions providing for such recovery.
Credit Risk - Lone Star
At the current time, virtually all of the Company's gas marketing
volumes and approximately 69% of the Company's own gas production is sold to a
single customer, Lone Star, under a long-term gas sales contract which
terminates on May 31, 1999. Although Lone Star has paid for all gas purchased
when such payments were due, any inability of Lone Star to continue to pay for
gas purchased would adversely affect the Company.
Drilling Risk
After obtaining the requisite financing, the Company anticipates
spending as much as $25,000 during the next three years to drill new wells
primarily on acreage acquired from ARCO. Drilling is inherently risky and there
can be no assurance that any wells drilled will be economically viable or enable
the Company to recover the costs of drilling. If the initial wells drilled by
the Company do not find the reserves expected, the Company may not drill
additional wells and the revenues and cash flow expected from such drilling may
never materialize.
Public Market for the Company's Stock
Although there presently exists a market for the Company's stock, such
market is volatile. In addition, the Company's earnings history is sporadic and
the Company has not paid dividends since 1989. Although the Company believes
that its earnings and cash flow will be more predictable in the future, there
can be no assurance that such will be the case. Such volatility may adversely
effect the market price and liquidity of the Company's common stock. In
addition, there are presently, to the Company's knowledge, several brokerage
firms making a market in the Company's common stock. Any cessation of such
market making activities by such brokerage firms could adversely affect the
market for the Company's common stock.
Operational Consideration
The Company's operations are subject to the risks inherent in the
pipeline and oil and gas industries, including the risks of fire, explosion,
pipe failure and environmental accidents such as oil spills, gas leaks and
ruptures or discharges of toxic gases, the occurrence of any of which could
result in substantial losses to the Company due to injury or loss of life,
severe damage to or destruction of property, natural resources and equipment,
pollution or other environmental damage, clean-up responsibilities, regulatory
investigation and penalties and suspension of operations. The Company's
operations could be subject to significant interruption in the event any of
these or other problems developed. In accordance with customary industry
practice, the Company maintains liability, property and business interruption
insurance against some, but not all, of the risks described above. There can be
no assurance that such an adverse event will not happen, that the Company's
insurance will be adequate to cover any losses or liabilities or that it would
not have a material adverse affect on the Company's financial condition or
operations.
-22-
<PAGE>
ITEM 8. FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES
<TABLE>
<CAPTION>
Page
----
<S> <C>
CONSOLIDATED FINANCIAL STATEMENTS:
Consolidated Statements of Operations for the years ended September 30, 1995, 1994 and 1993............ 24
Consolidated Balance Sheets, as of September 30, 1995 and 1994......................................... 26
Consolidated Statements of Cash Flows for the years ended September 30, 1995, 1994 and 1993............ 27
Consolidated Statements of Stockholders' Equity (Deficit) for the years ended September 30, 1995,
1994 and 1993....................................................................................... 29
Notes to the Consolidated Financial Statements......................................................... 30
FINANCIAL STATEMENT SCHEDULE:
III. Condensed Financial Information - Parent Company Only............................................ 63
REPORT OF INDEPENDENT ACCOUNTANTS...................................................................... 66
All other schedules are omitted because they are not applicable or the
required information is shown in the financial statements or notes thereto.
</TABLE>
-23-
<PAGE>
CASTLE ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
("000's" Omitted Except Per Share Amounts)
<TABLE>
<CAPTION>
Year Ended September 30,
--------------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Revenues:
Natural gas marketing and transmission:
Gas sales.............................................. $70,402 $61,228 $56,641
Transportation......................................... 31 35
-------- -------- --------
70,402 61,259 56,676
-------- -------- --------
Exploration and production:
Oil and gas sales...................................... 8,720 8,069 9,268
Administrative fees.................................... 423
Well operations........................................ 477 483 433
-------- -------- --------
9,197 8,552 10,124
-------- -------- --------
79,599 69,811 66,800
-------- -------- --------
Expenses:
Natural gas marketing and transmission:
Gas purchases.......................................... 40,160 37,029 34,441
Operating costs........................................ 1,208 1,139 961
General and administrative............................. 782 1,088 913
Depreciation and amortization.......................... 11,385 11,360 9,495
-------- -------- --------
53,535 50,616 45,810
-------- -------- --------
Exploration and production:
Oil and gas production................................. 2,366 2,629 2,655
General and administrative............................. 1,070 1,429 1,529
Depreciation, depletion and amortization............... 2,770 2,092 2,696
-------- -------- --------
6,206 6,150 6,880
-------- -------- --------
Corporate general and administrative expenses............ 4,995 5,499 2,191
-------- -------- --------
64,736 62,265 54,881
-------- -------- --------
Operating income............................................. 14,863 7,546 11,919
-------- -------- -------
</TABLE>
(Continued on next page)
The accompanying notes are an integral part of these financial statements
-24-
<PAGE>
CASTLE ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS
("000's" Omitted Except Per Share Amounts)
(continued from previous page)
<TABLE>
<CAPTION>
Year Ended September 30,
------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Other income (expenses):
Interest income................................................... 685 528 31
Other income...................................................... 281 422 54
Interest expense.................................................. (4,046) (9,233) (9,117)
--------- --------- ---------
(3,080) (8,283) (9,032)
--------- --------- ---------
Income (loss) from continuing operations before income taxes and
cumulative effect of a change in accounting principle............. 11,783 (737) 2,887
--------- --------- ---------
Provision for (benefit of) income taxes related to continuing
operations:
State......................................................... 4,728 (68) (43,511)
Federal....................................................... 33,095 (17,009) (570)
--------- --------- ---------
37,823 (17,077) (44,081)
--------- --------- ---------
Income (loss) from continuing operations.............................. (26,040) 16,340 46,968
Income from discontinued refining operations less applicable
income taxes of $19,850, $17,603, and $8,111 in 1995, 1994
and 1993, respectively............................................ 40,937 22,577 12,355
--------- --------- ---------
Income before cumulative effect of a change in accounting
principle......................................................... 14,897 38,917 59,323
Cumulative effect on prior years of change in accounting principle
- adoption of FAS 109............................................. 8,514
--------- --------- ---------
Net income............................................................ $14,897 $38,917 $67,837
========= ========= =========
Net income (loss) per share:
Income (loss) per share from continuing operations - primary...... ($ 3.84) $ 1.46 $ 6.42
========= ========= =========
- fully diluted............................................. ($ 3.84) $ 1.44 $ 6.20
========= ========= =========
Income per share from discontinued refining operations -
primary....................................................... $ 6.04 $ 2.02 $ 1.70
========= ========= =========
- fully diluted............................................. $ 6.04 $ 1.99 $ 1.64
========= ========= =========
Income per share before cumulative effect of a change in
accounting principle - primary................................ $ 2.20 $ 3.48 $ 8.12
========= ========= =========
- fully diluted............................................. $ 2.20 $ 3.43 $ 7.84
========= ========= =========
Cumulative effect of change in accounting principle - primary..... $ 1.16
=========
- fully diluted............................................. $ 1.12
=========
Net income per share - primary.................................... $ 2.20 $ 3.48 $ 9.28
========= ========= =========
- fully diluted............................................. $ 2.20 $ 3.43 $ 8.96
========= ========= =========
Weighted average number of common and common equivalent
shares outstanding - primary.................................. 6,778 11,209 7,316
========= ======== =========
- fully diluted............................................. 6,768 11,397 7,581
========= ======== =========
</TABLE>
The accompanying notes are an integral part of these financial statements
-25-
<PAGE>
CASTLE ENERGY CORPORATION
CONSOLIDATED BALANCE SHEETS
("000's" Omitted Except Share Amounts)
<TABLE>
<CAPTION>
September 30,
1995 1994
-------- --------
ASSETS
<S> <C> <C>
Current assets:
Cash and cash equivalents................................................... $ 5,341 $ 18,118
Restricted cash............................................................. 4,959 12,525
Temporary investments....................................................... 4,436
Accounts receivable......................................................... 5,641 22,413
Accounts receivable - related party......................................... 19,941
Inventories................................................................. 83,711
Prepaid expenses and other current assets................................... 153 7,341
Deferred income taxes....................................................... 4,623 68,088
Estimated realizable value of discontinued net refining assets.............. 10,803
-------- --------
Total current assets...................................................... 31,520 236,573
Property, plant and equipment, net:
Refining.................................................................... 295,950
Natural gas transmission.................................................... 22,720 24,535
Furniture, fixtures and equipment........................................... 276 3,245
Oil and gas properties, net..................................................... 17,410 16,146
Gas contracts, net.............................................................. 34,515 43,889
Goodwill, net................................................................... 5,413
Other assets, net............................................................... 463 20,740
Note receivable................................................................. 10,000
-------- --------
Total assets.............................................................. $116,904 $646,491
======== ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Current portion of long-term debt........................................... $ 12,080 $84,297
Current portion of long-term debt - related party........................... 250 9,974
Accounts payable............................................................ 4,715 53,999
Accrued expenses............................................................ 3,284 27,169
Due to related parties...................................................... 17,663
Deferred revenue............................................................ 62,333
Income taxes payable........................................................ 136
Other liabilities........................................................... 3,323 3,771
Net refining liabilities retained........................................... 20,342
-------- --------
Total current liabilities................................................. 43,994 259,342
Long-term debt.................................................................. 23,616 51,361
Long-term debt - related parties................................................ 248,491
Other long-term liabilities..................................................... 83 34,191
Deferred income taxes........................................................... 7,574 15,186
-------- --------
Total liabilities......................................................... 75,267 608,571
-------- --------
Commitments and contingencies
Stockholders' equity:
Series B participating preferred stock; par value - $1.00; 10,000,000 shares
authorized; no shares issued
Common stock; par value - $0.50; 25,000,000 shares authorized; 6,693,646 and
7,627,646 shares issued and outstanding in 1995 and 1994, respectively.... 3,347 3,814
Additional paid-in capital...................................................... 66,316 75,754
Accumulated deficit............................................................. (28,026) (41,648)
-------- --------
41,637 37,920
-------- --------
Total liabilities and stockholders' equity $116,904 $646,491
======== ========
</TABLE>
The accompanying notes are an integral part of these financial statements
-26-
<PAGE>
CASTLE ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
("000's" Omitted)
<TABLE>
<CAPTION>
Year Ended September 30,
---------------------------------------------
1995 1994 1993
---------- -------- --------
<S> <C> <C> <C>
Cash flows from operating activities:
Net income ............................................................... $ 14,897 $ 38,917 $ 67,837
---------- -------- --------
Adjustments to reconcile net income to cash provided by operating
activities:
Depreciation, depletion and amortization............................... 19,238 43,774 22,185
Amortization of deferred debt issue costs.............................. 2,732 8,885 2,054
Cumulative effect of a change in accounting principle - adoption of
FAS 109............................................................. (8,514)
Deferred income taxes.................................................. 55,799 (2,900) (38,976)
Gain on MG Settlement.................................................. (396,166)
Provision for impairment loss.......................................... 323,078
Changes in assets and liabilities:
(Increase) decrease in restricted cash.............................. 4,750 1,185 (9,153)
(Increase) decrease in temporary investments........................ 4,436 2,811 (65)
(Increase) in accounts receivable................................... 27,685 (6,178) (19,512)
(Increase) decrease in inventory.................................... 57,401 (18,787) (7,942)
(Increase) decrease in prepaid expenses and other current assets.... 6,366 (4,762) (454)
(Increase) decrease in other assets................................. (1,793) (1,523) (970)
Increase (decrease) in accounts payable............................. (29,660) 23,448 24,126
Increase (decrease) in accrued expenses............................. (29,936) 1,958 8,573
Increase in other current liabilities............................... 283 41 3,071
Increase (decrease) in other long-term liabilities.................. (630) 927 906
(Decrease) in due to related parties................................ (9,014) (9,046) (17,014)
Increase (decrease) in deferred revenues............................ (12,124) (65,807) 121,046
---------- -------- --------
Total adjustments............................................... 22,445 (25,974) 79,361
---------- -------- --------
Net cash flow provided by (used in) operating activities........ 37,342 12,943 147,198
---------- -------- --------
Cash flows from investment activities:
Decrease in deposit made on account of acquisition........................ 6,250
Proceeds from sale of furniture, fixtures and equipment................... 4,723 75 265
Investment in refining operations......................................... (35,355) (63,819) (34,394)
Investment in oil and gas properties...................................... (4,022) (956) (13,592)
Investment in pipelines................................................... (47) (21) (27,909)
Purchase of furniture, fixtures and equipment............................. (288) (1,670) (1,265)
Purchase of gas contracts................................................. (63,049)
Purchase of minority interest............................................. (117)
Business acquisition, net of cash acquired................................ (8,230)
---------- -------- --------
Net cash used in investing activities........................... (34,989) (74,621) (133,811)
---------- -------- --------
</TABLE>
(continued on next page)
The accompanying notes are an integral part of these financial statements
-27-
<PAGE>
CASTLE ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS
("000's" Omitted)
(continued from previous page)
<TABLE>
<CAPTION>
Year Ended September 30,
------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Cash flows from financing activities:
Proceeds of long-term debt - related party................................ $ 530 $ 67,915 $ 15,115
Proceeds of long-term debt................................................ 25,108 12,114 168,735
Proceeds from issuance of common stock, net............................... 202 48,207 20
Repayment of long-term debt - related party............................... (4,388) (142,112)
Repayment of long-term debt............................................... (38,781) (48,356) (51,129)
Payment of debt issuance costs............................................ (3,309)
Purchase of treasury stock................................................ (175)
--------- ---------- ---------
Net cash provided by (used in) financing activities................. (12,941) 75,492 (12,855)
--------- ---------- ---------
Net increase (decrease) in cash and cash equivalents......................... (10,588) 13,814 532
Cash and cash equivalents - beginning of period.............................. 18,118 4,304 3,772
--------- ---------- ---------
Cash and cash equivalents - end of period.................................... $ 7,530 $ 18,118 $ 4,304
========= ========== =========
Supplemental disclosures of cash flow information are as follows:
Cash paid during the period:
Interest.................................................................. $ 10,207 $ 16,583 $ 18,263
========= ========== =========
Income taxes.............................................................. $ 1,080 $ 8,802 $ 8
========= ========== =========
Interest capitalized during the period....................................... -- $ 1,519 $ 723
========= ========== =========
Supplemental schedule of noncash investing and financing activities..........
Purchase of Powerine Oil Company:
Basis in assets acquired............................................... $ 186,867
Cash paid for capital stock and transaction costs...................... (8,230)
----------
Basis in liabilities assumed........................................ $ 178,637
==========
Payment of related party payables in exchange for reduction in cash
participations........................................................ $ 6,862
=========
MG Settlement, including surrender of 969,000 common shares, cancellation of
debt obligations and the assumption by MG of the
forward sale obligations and Societe Generale loan $ 396,166
=========
Exchange of common stock:
Fair value of debt issuance/extension, processing agreement issuance
costs, and offtake agreement amendments............................. $ 11,855
=========
Acquisition of common stock in exchange for reduction in cash
participations......................................................... $ 39,817
========
Debt issued in exchange for debt extensions and offtake amendments........ $ 5,500
=========
Sale of properties for note............................................... $ 600
=========
Options exercised for short-term receivable............................... $ 45
=========
</TABLE>
The accompanying notes are an integral part of these financial statements
-28-
<PAGE>
CASTLE ENERGY CORPORATION
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (DEFICIT)
("000's" Omitted Except Share Amounts)
<TABLE>
<CAPTION>
Common Stock Additional Accumulated Treasury Stock
------------ Paid-In ----------- -----------------
Shares Amount Capital (Deficit) Shares Amount Total
------ ------ ------- ----------- ------ ------ -----
<S> <C> <C> <C> <C> <C> <C> <C>
Balance-September 30, 1992............ 6,431,264 $3,215 $53,988 ($146,138) 47,376 ($189) ($89,124)
Warrants exercised.................... 20,000 10 10 20
Options exercised..................... 7,500 4 41 45
Treasury stock acquired............... 12,484 (175) (175)
Shares issued for Long-Term
Supply Agreement guaranty.......... 300,000 150 705 855
Shares issued in return for debt
extension and Indian Offtake
Agreement extension............ 1,000,000 500 10,500 11,000
Other................................. 23,742 12 143 155
Net income............................ 67,837 67,837
--------- ------ ------- --------- --------- -------- -------
Balance - September 30, 1993.......... 7,782,506 3,891 65,387 (78,301) 59,860 (364) (9,387)
Treasury stock reissued............... (59,860) (30) (334) (59,860) 364
Shares issued for cash................ 3,500,000 1,750 46,428 48,178
Options exercised..................... 5,000 3 26 29
Shares repurchased with cash
participations..................... (3,600,000) (1,800) (35,753) (2,264) (39,817)
Net income............................ 38,917 38,917
--------- ------ ------- --------- --------- -------- -------
Balance - September 30, 1994.......... 7,627,646 3,814 75,754 (41,648) 37,920
Stock acquired........................ (969,000) (485) (9,622) (1,275) (11,382)
Options exercised..................... 35,000 18 184 202
Net income............................ 14,897 14,897
--------- ------ ------- --------- --------- -------- -------
Balance - September 30, 1995.......... 6,693,646 $3,347 $66,316 ($ 28,026) $41,637
========= ====== ======= ========= ========= ======== =======
</TABLE>
The accompanying notes are an integral part of these financial statements
-29-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
NOTE 1 -- BUSINESS AND ORGANIZATION
Settlement with Principal Shareholder
Castle Energy Corporation ("Castle" or "the Company") is a Delaware
Corporation. From September 1989 until October 14, 1994, its principal
shareholder was Metallgesellschaft Corporation ("MG"), an indirect wholly-owned
subsidiary of Metallgesellschaft AG ("MG AG"), a German Conglomerate which had,
in the past, owned as much as 49% of the Company. In addition, the Company had
extensive transactions and agreements with MG and its affiliates as described in
Notes 18 and 21. On August 31, 1994, the Company entered into two agreements
with MG and its affiliates which terminated most relations with MG and
significantly restructured the remaining relationships in fiscal 1995 (the "MG
Settlement") (see Note 3). All amounts related to transactions with MG and its
affiliates are not reported as related party transactions subsequent to October
14, 1994.
Business Segments
Castle's principal lines of business are natural gas marketing and
transmission and oil and gas exploration and production. Until September 30,
1995, the Company was involved in refining operations (see Note 3). The
Company's operations are conducted within the United States.
Natural Gas Marketing and Transmission
On December 3, 1992, the Company acquired from Atlantic Richfield
Company ("ARCO") a long-term natural gas sales agreement (the "Lone Star
Contract") with the Lone Star Gas Company ("Lone Star"), a 77-mile pipeline in
Rusk County, Texas (the "Castle Pipeline"), majority working interests in
approximately 100 producing oil and gas wells and several gas supply contracts.
The acquisition of the Castle Pipeline and the gas contracts created a new
business segment for the Company.
At present the principal use of the Castle Pipeline is to deliver gas
pursuant to the Lone Star Contract. The Company has entered into a management
service contract with MG Gathering Corp. ("MGG"), a subsidiary of MG, to operate
the Castle Pipeline.
The Lone Star Contract expires in June 1999. This contract provides for
minimum daily deliveries of gas at specific fixed prices, and also includes
certain minimum amounts under take-or-pay provisions. Based on reserve reports,
management believes approximately 19% of the annual contract volumes can be
supplied from Company-operated wells; the Company has entered into a long-term
contract with MG Natural Gas Corp. ("MGNG"), a subsidiary of MG, to supply the
remaining gas. At the present time, virtually all gas sales by the natural gas
marketing and transmission segment are to Lone Star.
Oil and Gas Exploration and Production
The Company's oil and gas exploration and production operations
currently include interests in approximately 450 producing oil and gas wells
located in nine states, including the Texas reserves acquired in connection with
the acquisition of the natural gas marketing and transmission assets. At
present, approximately 69% of the Company's production is sold to Lone Star as
described above.
The Company discontinued its oil and gas partnership administration
business effective June 30, 1993 (see Note 21).
-30-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Refining
IRLP
The Company entered the refining business in 1989 when it acquired the
operating assets of an idle refinery located in Lawrenceville, Illinois (the
"Indian Refinery"), which was owned and operated by the Company's subsidiary,
Indian Refining I Limited Partnership ("IRLP"), until September 30, 1995 when it
was shut down. On December 12, 1995, the Indian Refinery assets were sold (for
legal purposes) to American Western Refining, L.P. ("American Western") (see
Note 3).
Powerine
In October 1993, the Company purchased Powerine Oil Company
("Powerine"), the owner of a refinery located in Santa Fe Springs, California
(the "Powerine Refinery") from MG (see Note 4). From October 1, 1993 to February
1, 1995, Powerine sold all of its refined products to MGRM under a product
offtake agreement (the "Powerine Offtake Agreement") subject to MGRM's
obligation to purchase refined products from raw materials on hand at the
Powerine Refinery at (or subject to contracts calling for delivery to the
Powerine Refinery by) February 1, 1995. MGRM's failure to purchase products
refined after February 1, 1995 is at issue in the Powerine Arbitration (see Note
16). On September 29, 1995, Powerine sold (for legal purposes) substantially all
of its refining plant to Kenyen Project Limited ("Kenyen"). On January 16, 1996,
Powerine merged into a subsidiary of Energy Merchant Corp. ("EMC") (see Note 3).
Results of Powerine's operations are included in these financial statements
(discontinued operations - refining) commencing October 1, 1993.
As a result of the transactions with Kenyen, American Western and EMC,
the Company had disposed of its interests in the refining segment. The results
of refining operations are shown as discontinued operations in the Consolidated
Statement of Operations.
NOTE 2 -- SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Principles of Consolidation
The consolidated financial statements presented include the accounts of
the Company and its subsidiaries. All significant intercompany transactions have
been eliminated in consolidation.
Cash and Cash Equivalents; Temporary Investments
The Company considers all highly liquid investments, such as time
deposits, money market instruments, commercial paper and United States
securities, purchased with a maturity of three months or less, to be cash
equivalents. Temporary investments consist of similar investments, as well as
United States government security funds, maturing more than three months from
the date of purchase and are carried at the lower of cost or market. Treasury
Bills which are used to collateralize margin accounts are considered temporary
investments regardless of the maturity date. The Company invests only in AA
rated or better fixed income marketable securities or the short-term rated
equivalent.
Inventories
Inventories are applicable only to the Company's refining segment. Crude
oil, unfinished products and finished products are stated at the lower of cost,
adjusted for hedging gains and losses, or market value. Cost is determined on an
average cost method. Materials and supplies are stated at cost. Cost is
determined using the first-in, first-out ("FIFO") method. Amounts paid to
suppliers for purchases of product prior to the title passing to the Company are
reported as prepaid inventory. At September 30, 1995, all inventories are
classified as "Net refining liabilities retained" in the consolidated balance
sheet and were written down to market value consistent with the Company's
disposition of refining operations.
-31-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Property, Plant and Equipment
Property, plant and equipment are stated at the lower of cost or
impaired (fair market) value. Depreciation is recorded on a straight-line basis
over the estimated useful lives of the assets, as follows:
Property, plant and equipment (excluding
buildings).............................. 3-15 years, primarily 15 years
Buildings................................. 30 years
Natural gas pipeline systems.............. 15 years
Furniture and fixtures.................... 3-10 years
Refining
Interest costs incurred during IRLP's refurbishment stage were
capitalized and were depreciated over the estimated useful lives of the
property, plant and equipment to which such costs were allocated. Environmental
costs required to remediate property, plant and equipment were capitalized
during the pre-operating phase and were depreciated over the estimated useful
lives of the related property, plant and equipment. Ongoing environmental
expenditures were reviewed to determine if they extended the life, increased the
capacity, improved the safety or mitigated future environmental risks at the
Indian and Powerine Refineries. If any of these conditions were satisfied, the
costs were capitalized. Otherwise, such costs were expensed as incurred.
Commencing in the first quarter of fiscal 1995, the Company decided to dispose
of its refining segment. At that time all refining property, plant and equipment
was written down to its estimated fair market value.
Costs for precious metal catalysts were included in refining property,
plant and equipment and were not amortized. Such catalyst was reduced to its
fair market value in October 1994.
Refining property, plant and equipment and catalyst as of September 30,
1995 are included in the balance sheet classification "Estimated realizable
value of discontinued net refining assets."
Oil and Gas Properties
The Company follows the full-cost method of accounting for oil and gas
properties and equipment costs. Under this method of accounting, all productive
and nonproductive costs incurred in the acquisition, exploration and development
of oil and gas reserves are capitalized. Capitalized costs are amortized on a
composite unit-of-production method using estimates of proved reserves.
Capitalized costs which relate to unevaluated oil and gas properties are not
amortized until proved reserves are associated with such costs or impairment of
the property occurs. Management and drilling fees earned in connection with the
transfer of oil and gas properties to a joint venture and proceeds from the sale
of oil and gas properties are recorded as reductions in capitalized costs unless
such sales are material and involve a significant change in the relationship
between cost and the value of proved reserves in which case a gain or loss is
recognized. Expenditures for repairs and maintenance of wellhead equipment are
expensed as incurred. Net capitalized costs in excess of the estimated present
value of future cash inflows from proved oil and gas reserves, reduced by
operating expenses and future development expenditures, if any, are charged to
current expense.
Impairment of Long-Term Assets
The Company adopted Financial Accounting Standard No. 121, "Accounting
for the Impairment of Long-Lived Assets and Long-Lived Assets to Be Disposed Of"
during the second quarter of fiscal 1995. The effect of adoption was not
significant. Accordingly, the Company reviews its long-term assets other than
oil and gas properties for impairment whenever events or changes in circumstance
indicate that the carrying amount of an asset may not be recoverable. If the sum
of the expected future cash flows expected to result from the use of the asset
and its eventual disposition is less than the carrying amount of the asset, an
impairment loss is recognized. Measurement of an impairment loss would be based
-32-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
on the fair market value of the asset. Impairment for oil and gas properties is
computed in the manner described above under "Oil and Gas Properties."
Hedging Activities
Refining
The Company employed several hedging strategies to minimize the impact
of the volatility in feedstock costs. These strategies generally involved the
purchase and sale of exchange-traded, energy-related futures and options with a
duration of 12 months or less. The Company hedged current inventory and future
commitments. The number of barrels of crude oil and refined products covered by
such contracts varied from time to time. Such purchases and sales were closely
managed, balanced daily and subject to internally established risk standards.
Gains and losses from hedging activities were credited or debited to the value
of the inventory being hedged. The Company's crude oil hedging activities ceased
by September 30, 1995 by which time the Company's two refineries had ceased
operations.
Natural Gas Marketing and Transmission
Subsequent to September 30, 1995, the Company commenced hedging
operations related to its natural gas marketing operations using swap agreements
(see Note 16). Gains and losses from natural gas hedging operations will be
debited or credited to gas sales or purchases, as applicable.
Other Assets
Costs incurred related to the initial issuance or extension of debt or
other long-term agreements are capitalized and amortized over a) the stated term
of the related agreement or b) the expected term of benefit of the agreement, if
shorter than the stated term. Unamortized costs are written-off when the related
agreement is terminated. Costs for long-term catalysts were capitalized and
amortized on a straight-line basis over the estimated useful lives of such
catalysts - generally 2.5 to 10 years (See Note 12). As of September 30, 1995,
the Company had discontinued the refining operations in which the catalyst was
used.
Goodwill
Goodwill was recorded in conjunction with the acquisition of Powerine
and was amortized on a straight-line basis (15 years). The remaining book value
of goodwill was subject to the impairment considerations discussed in Note 3.
Gas Contracts
The purchase price allocated to the Lone Star Contract (see Note 4) was
capitalized and is being amortized over the term of the related contract (6.5
years).
Deferred Revenue
Commitments related to forward sales were recorded at their fulfillment
value at the date of the transaction. The difference between the cash proceeds
and the future commitments were amortized over the lives of the agreements using
the interest method. As part of the MG Settlement, liabilities related to a
forward sale were assumed by MG and such amount was included in the $391,135
gain to the Company on the MG Settlement.
Gas Balancing
The Company operates under several natural gas sales contracts where it
is entitled to sell other owners' shares of natural gas produced from a well if
such other owners do not elect to sell their shares of production. Under the
terms of the related gas sales contracts, the non-selling owners are entitled to
make up gas sales from the Company's share of production in the future. The
-33-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Company records sales of other owners' production as deferred revenue and
recognizes such deferred revenue when the other owners make up their gas
balancing deficiency from the Company's share of production.
Income Taxes
In October 1992, the Company adopted Statement of Financial Accounting
Standards No. 109 (FAS 109), Accounting for Income Taxes. FAS 109 is an
accounting approach that requires the recognition of deferred tax assets and
liabilities for the expected future tax consequences of events that have been
recognized in the Company's financial statements or tax returns. In estimating
future tax consequences, FAS 109 generally considers all expected future events
other than anticipated enactments of changes in the tax law or rates.
Previously, the Company used the FAS 96 asset and liability approach that gave
no recognition to future events other than the recovery of assets and settlement
of liabilities at their carrying amounts (see Note 20). FAS 109 also requires
that tax provisions and recoveries related to changes in the valuation reserve
for deferred tax assets because of a change in circumstances that causes a
change in judgement about the realizability of the related deferred tax asset in
future years be allocated entirely to continuing operations.
Earnings Per Share
Primary earnings per common share are based upon the weighted average
number of common and common equivalent (if considered dilutive) shares
outstanding using either the treasury stock or modified treasury stock method.
Fully diluted earnings per common share are presented for all succeeding annual
periods where the dilution in earnings per share resulting from full dilution is
greater than 3%. All share and per share amounts have been restated to give
affect to the 1-for-2 reverse split which was effective November 12, 1993.
Reclassifications
Certain reclassifications have been made to make the periods presented
comparable.
Use of Estimates
The preparation of financial statements in accordance with generally
accepted accounting principles requires management to make estimates and
assumptions that affect the reported amounts of assets and liabilities and
disclosures 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.
NOTE 3 -- MG SETTLEMENT AND DISCONTINUED OPERATIONS - REFINING
On August 31, 1994, the Company entered into agreements with MG and
certain of its affiliates pursuant to which the parties thereto agreed to amend
or terminate a number of contractual relationships between them. In the first
step of the MG Settlement, which closed on September 9, 1994, MG transferred
3,600,000 shares of common stock of the Company to the Company in exchange for
$39,817 of participations the Company held in debt obligations of the Company
and its affiliates to MG Trade Finance Corp. ("MGTFC"), a wholly-owned
subsidiary of MG.
In the second step of the MG Settlement, which closed on October 14,
1994, MG (a) cancelled certain debt obligations owed to MGTFC by the Company and
its affiliates and assumed IRLP's obligations under its $120,000 Senior Facility
with Societe Generale, together totaling $321,282, (b) transferred back to the
Company the remaining 969,000 shares of common stock held by MG and a $5,500
debenture convertible into 500,000 shares of common stock, (c) issued to the
Company a $10,000 note payable in three years, (d) terminated all of its
interests in the Company's natural gas operations and (e) agreed to supply all
crude oil necessary for the Company to meet its delivery obligations under a
forward sale contract with a third party entered into during September 1993. In
exchange for the foregoing, IRLP and Powerine (i) amended their Offtake
Agreements to terminate effective February 1, 1995 although sales under the
Powerine Offtake Agreement were to continue subsequently, (ii) amended their
-34-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
working capital facilities to terminate on March 31, 1995, and (iii) transferred
to MG certain of the Company's participations in debt obligations of the Company
and its affiliates to MGTFC. In connection with the MG Settlement, IRLP and MGNG
also entered into a four-year natural gas swap agreement and MG agreed that the
Company, through March 31, 1995, could unilaterally terminate its gas supply
agreement with MGNG ("MGNG Gas Supply Agreement"). As a result of the MG
Settlement, the Company realized a gain of $391,135, consisting of $396,166
gross proceeds less $5,031 of investment banking fees and related expenses.
The completion of the transactions contemplated by the MG Settlement had,
among others, three consequences for the Company. First, the offtake agreements
with MG terminated and the Company, until it sold the Refineries, was required
to market its own products and was subject to market risks. Second, also in
1995, the working capital facilities provided by MGTFC terminated. Third, for
Federal and state income tax purposes, the Company recognized income of
approximately $391 million, on which, after giving effect to applicable net
operating loss and other tax carryforwards and other items of expense and
deduction, Federal and state income taxes of approximately $91 million would
have been owed had the Company not disposed of or discontinued the Refinery
operations.
After the MG Settlement was consummated, the Company decided to
discontinue the operations of its refining business and to sell or retire its
two refineries. At December 31, 1994, the Company provided $345,008 for the
estimated impairment of the related assets.
In July 1995, operations ceased at the Powerine Refinery and the Company
retired the assets of the Powerine Refinery. On September 29, 1995, Powerine
sold substantially all of the refining plant assets to Kenyen, retaining certain
rack facilities and the land on which the Powerine Refinery is situated. The
purchase price was $22,763 consisting of $3,000 cash and a note for $19,763. The
note is secured by the Powerine refining plant and bears interest at 10%. The
note is due in three equal installments of principal and interest of $7,108 (of
which $19,763 is principal) on April 30, June 30 and September 30, 1996. On
January 16, 1996 Powerine merged into a subsidiary of EMC. As part of the sale,
EMC also indemnified Powerine and the Company for any and all environmental
liabilities of Powerine.
On September 30, 1995, operations also ceased at the Indian Refinery and
the Company retired the plant assets of the Indian Refinery. On December 12,
1995, the Company sold the plant assets of the Indian Refinery to American
Western, a subsidiary of Gadgil Western Corporation ("Gadgil"). The purchase
price was $8,000, including $3,000 cash and a note for $5,000. The note bears
interest at 8% and is due on the earlier of October 31, 1996 or the date
American Western obtains financing to restart the Indian Refinery. The note is
secured by the real property and the Indian Refinery. American Western also
assumed certain liabilities of IRLP, including employee pension and all
environmental liabilities, in conjunction with the sale. The Company also sold
certain precious metal catalysts to American Western for a note for $1,803. The
note bears interest of 8% and was due February 11, 1996. The parties extended
the due date of the note to March 22, 1996.
As a result of the discontinuance of refining operations, all assets and
liabilities related to the refining segment have been netted. The realizable
value of net refining assets sold subsequent to September 30, 1995 is shown
under the caption "Estimated realizable value of discontinued net refining
assets" on the accompanying Consolidated Balance Sheet. The estimated value of
the refining liabilities retained is shown under the caption "Net refining
liabilities retained." At September 30, 1995, the assets and liabilities
applicable to the refining segment consisted of the following:
-35-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Estimated realizable value of discontinued net refining assets:-
Carrying value prior to write down to net realizable value:
September 30,
1995
-------------
Property, plant and equipment, net....................... $340,280
Goodwill, net............................................ 5,413
Catalyst, net............................................ 4,191
Environmental liabilities................................ (36,061)
Other, net .............................................. 20,058
---------
333,881
Impairment reserve............................................... (323,078)
---------
$ 10,803
=========
Net refining liabilities retained:
Revolving credit loan (see Note 15)......................... $13,249
Other working capital deficit, net.......................... 7,093
---------
$20,342
"Estimated realizable value of discontinued net refining assets" is
based on the transactions consummated with American Western and EMC and includes
management's best estimates of the amounts expected to be realized on the
disposal of the refining segment. The amounts the Company ultimately realizes
could differ materially in the near term from such amounts. "Net refining
liabilities retained" includes management's best estimates of amounts expected
to be paid and amounts expected to be realized on the settlement of this net
liability.
Summary operating results of discontinued operations are as follows and
include the $391,135 gain realized on the settlement with MG and the $323,078
impairment writedown.
<TABLE>
<CAPTION>
September 30,
-----------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Revenues.................................................................... $711,976 $940,514 $532,011
======== ======== ========
Income before income taxes.................................................. $ 60,787 $ 40,180 20,466
Provision for income taxes.................................................. 19,850 17,603 8,111
--------- ---------- ---------
Net earnings from discontinued operations................................... $ 40,937 $ 22,577 $ 12,355
========= ========= =========
</TABLE>
In computing the operating results of discontinued operations, interest
expense specifically associated with refining debt has been included in
discontinued operations.
NOTE 4 -- ACQUISITIONS
As described in Note 1, on December 3, 1992, the Company acquired
certain oil and gas assets from ARCO. The purchase price of $103,680 consisted
of $95,934 in cash paid for assets, $5,634 cash paid for transaction costs and
$2,112 in liabilities assumed. The asset acquisition was accounted for as a
purchase. The Company's allocation of the purchase price is as follows:
-36-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Gas contracts............................... $ 61,348
Gas pipeline................................ 27,439
Oil and gas properties...................... 13,193
Deferred tax asset.......................... 1,700
----------
$103,680
==========
As of October 1, 1993, the Company acquired from MG an option to acquire
Powerine, the owner of the Powerine Refinery, a 49,500 barrel per day refinery
located in Santa Fe Springs, California in consideration of (i) the payment of
$8,000; (ii) the assumption of a $3,027 indemnity obligation related to yield
losses incurred by Powerine under a processing arrangement with MG, (iii) the
assumption of a $2,675 tax indemnification to the previous owner of Powerine;
(iv) the assumption of debt obligations to MG of $128,002 and other liabilities
of $44,933; and (v) the payment of transaction costs of $980. In addition, the
Company borrowed $2,971 from MGTFC to purchase feedstocks. The acquisition was
accounted for as a purchase at predecessor basis due to the significant related
party relationship. The Company recorded $160,106 of refinery assets, $14,151 of
other tangible assets and the remaining $13,360 of goodwill and deferred tax
assets. The Company immediately exercised the option to acquire Powerine for a
nominal amount, and concurrently (a) entered into the Powerine Offtake Agreement
with MG (b) amended Powerine's loan agreement with MGTFC and (c) amended the
Company's crude oil supply agreement with MG to include Powerine as a party. To
finance the acquisition, a subsidiary company resold to MGTFC a cash
participation in the revolving credit facility provided by MGTFC to IRLP. The
results of operations of Powerine are included in the statement of operations
(discontinued operations - refining) commencing October 1, 1993.
Purchase of ARCO Royalty
In October 1994, one of the Company's exploration and production
subsidiaries purchased certain royalty interests held by ARCO in wells purchased
by another of the Company's exploration and production subsidiaries from ARCO in
December 1992. The purchase price was $3,823.
NOTE 5 - RESTRICTED CASH
Restricted cash consists of the following:
September 30,
-----------------
1995 1994
---- ----
Gas revenues deposited in lender's escrow account..... $4,143
Environmental escrow funds............................ $ 5,589
Funds supporting letters of credit.................... 362 1,365
Capital funding accounts.............................. 4,017
Other................................................. 454 1,554
------ -------
$4,959 $12,525
====== =======
NOTE 6 - TEMPORARY INVESTMENTS
Temporary investments consist of the following:
September 30, 1994
------------------
Treasury bills.......................................... $2,490
Commercial paper........................................ 1,946
-------
$4,436
=======
-37-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
The Company invested in United States Treasury Bills with a maturity of
less than 90 days and had pledged this investment as collateral for NYMEX margin
activity. In addition, commercial paper purchased through a major bank had been
pledged as collateral against letters of credit held by the Illinois
Environmental Protection Agency (see Note 14).
NOTE 7 - ACCOUNTS RECEIVABLE
Based upon past customer experiences combined with the limited number of
customer accounts receivable relationships, management believes all receivables
to be collectible. Accounts receivable consist of the following:
September 30,
-------------------------
1995 1994
---- ----
Natural gas marketing......................... $4,450 $11,472
Unrealized gain on forward commitments........ 847
Insurance claims and refunds.................. 3,160
Oil and gas................................... 991 1,485
Income tax refunds............................ 4,770
Refined products.............................. 342
Other......................................... 200 337
------- -------
$5,641 $22,413
====== =======
NOTE 8 -- INVENTORIES
Inventories consisted of the following:
September 30, 1994
------------------
Crude oil................................................... $49,029
Unfinished products......................................... 19,549
Finished products........................................... 4,458
Materials and supplies...................................... 10,675
--------
$83,711
========
NOTE 9 - PROPERTY, PLANT AND EQUIPMENT
Refining property, plant and equipment consisted of the following:
September 30, 1994
------------------
Refining plant............................................... $260,379
Refining plant - capitalized turnaround costs................ 23,218
Land......................................................... 10,550
Precious metal catalyst...................................... 3,338
Transportation and heavy equipment........................... 1,789
Maintenance and technical equipment.......................... 1,892
Buildings.................................................... 1,332
Construction in progress..................................... 40,238
--------
342,736
Less: Accumulated depreciation and amortization of capitalized
turnaround costs ................................................ (46,786)
--------
$295,950
========
-38-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Natural gas transmission consists of the following:
September 30,
-------------
1995 1994
---- ----
Natural gas pipeline........................... $27,977 $27,930
Less: Accumulated depreciation................. (5,257) (3,395)
------- -------
$22,720 $24,535
======= =======
Furniture, fixtures and equipment are as follows:
September 30,
---------------------
1995 1994
---- ----
Furniture, fixtures and equipment............... $467 $4,177
Less: Accumulated depreciation.................. (191) (932)
----- --------
$276 $3,245
==== ======
Gas contracts consist of the following:
September 30,
---------------------
1995 1994
---- ----
Gas contracts................................ $61,151 $61,151
Less: Accumulated amortization............ (26,636) (17,262)
------- -------
$34,515 $43,889
======= =======
NOTE 10 - OIL AND GAS PROPERTIES
September 30,
-------------
1995 1994
---- ----
Evaluated properties............................... $28,175 $24,153
Less: Accumulated depreciation, depletion and
amortization...................................... (10,668) (7,910)
Accumulated full cost ceiling reserve............ (97) (97)
------- -------
17,410 16,146
Unevaluated properties.............................
------- -------
$17,410 $16,146
======= =======
Capital costs incurred by the Company in oil and gas activities, all of
which are located in the United States, are as follows:
September 30,
-------------------------
1995 1994 1993
---- ---- ----
Property acquisition costs - proved properties...... $3,823 $13,616
Development costs................................... 199 $956 (24)
------ ---- -------
$4,022 $956 $13,592
====== ==== =======
Results of operations, excluding corporate overhead and interest
expense, from the Company's oil and gas producing activities are as follows:
-39-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
<TABLE>
<CAPTION>
September 30,
---------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Revenues:
Crude oil, condensate, natural gas liquids and natural gas sales.......... $8,720 $8,069 $9,268
------ ------ ------
Costs and expenses:
Production costs.......................................................... $2,366 $2,629 2,655
Depreciation, depletion and amortization.................................. 2,757 2,014 2,657
------- ------- -------
Total costs and expenses.................................................. 5,123 4,643 5,312
------- ------- -------
Income tax provision........................................................ 1,439 1,370 1,582
------- ------- -------
Income from oil and gas producing activities................................ $2,158 $2,056 $2,374
====== ====== ======
</TABLE>
The income tax provision is computed at the blended rate (Federal and
state combined) of 40%.
Assuming conversion of oil and gas production into common equivalent
units of measure on the basis of energy content, depletion rates per equivalent
MCF (thousand cubic feet) of natural gas were as follows:
<TABLE>
<CAPTION>
September 30,
----------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Depreciation, depletion and amortization.................................... $2,757 $2,014 $2,657
====== ====== ======
Depletion rate per equivalent MCF of natural gas............................ $0.68 $0.51 $0.71
====== ====== ======
</TABLE>
NOTE 11 - PROVED OIL AND GAS RESERVES AND RESERVE VALUATION (UNAUDITED)
Reserve estimates are based upon subjective engineering judgements made
by the Company's independent petroleum reservoir engineers, Ryder Scott and
Huntley & Huntley, and may be affected by the limitations inherent in such
estimations. The process of estimating reserves is subject to continuous
revisions as additional information is made available through drilling, testing,
reservoir studies and production history. There can be no assurance such
estimates will not be materially revised in subsequent periods.
Estimated quantities of proved reserves and changes therein, all of which
are domestic reserves, are summarized below:
Oil (BBLS) Natural Gas (MCF)
---------- ----------------
Proved developed and undeveloped reserves:
As of October 1, 1992............................ 199,863 13,699,197
Revisions of previous estimates.............. 17,686 17,401,101
Extensions, discoveries and other additions.. 334,625
Sales of minerals in place................... (36,544) (860,224)
Acquisition of minerals in place............. 102,524 18,376,189
Production................................... (45,175) (3,472,133)
-------- -----------
As of September 30, 1993......................... 238,354 45,478,755
Revisions of previous estimates.............. 136,132 13,051,146
Production................................... (52,078) (3,605,915)
-------- -----------
As of September 30, 1994......................... 322,408 54,923,986
Revisions of previous estimates.............. 65,562 2,537,310
Acquisition of minerals in place............. 13,882 2,828,172
Production................................... (50,972) (3,721,249)
-------- -----------
As of September 30, 1995......................... 350,880 56,568,219
======= ==========
-40-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Oil (BBLS) Natural Gas (MCF)
---------- -----------------
Proved developed reserves:
October 1, 1992...................... 199,863 8,418,300
======= ==========
September 30, 1993................... 238,354 41,926,376
======= ==========
September 30, 1994................... 300,813 45,941,369
======= ==========
September 30, 1995................... 248,228 31,534,882
======= ==========
The revisions of previous estimates in fiscal 1993 and fiscal 1994
result from significant additions of proved undeveloped and proved developed
non-producing reserves.
All of the Company's oil and gas reserves are located in United States.
The following is a standardized measure of discounted future net cash
flows and changes therein relating to estimated proved oil and gas reserves, as
prescribed in Statement of Financial Accounting Standards No. 69. The
standardized measure of discounted future net cash flows does not purport to
present the fair market value of the Company's oil and gas properties. An
estimate of fair value would also take into account, among other factors, the
likelihood of future recoveries of oil and gas in excess of proved reserves,
anticipated future changes in prices of oil and gas and related development and
production costs, a discount factor based on market interest rates in effect at
the date of valuation and the risks inherent in reserve estimates.
<TABLE>
<CAPTION>
September 30,
--------------------------------------------
1995 1994 1993
--------- ------- ---------
<S> <C> <C> <C>
Future cash inflows......................................................... $103,811 $97,098 $115,838
Future production costs..................................................... (32,537) (35,994) (47,656)
Future development costs.................................................... (22,976) (12,995) (19,010)
Future income tax expense................................................... (6,829) (5,875) (3,321)
--------- ------- ---------
Future net cash flows....................................................... 41,469 42,234 45,851
Discount factor of 10% for estimated timing of future cash flows............ (20,096) (23,769) (18,895)
--------- ------- ---------
Standardize measure of discounted future cash flows......................... $ 21,373 $18,465 $ 26,956
========= ======= =========
</TABLE>
The future cash flows were computed using the applicable year-end prices
and costs and respective year-end statutory tax rates that related to then
existing proved oil and gas reserves in which the Company has mineral interests.
The estimates of future income tax expense are computed at the blended rate
(Federal and state combined) of 40%.
-41-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
The following were the sources of changes in the standardized measure of
discounted future net cash flows:
<TABLE>
<CAPTION>
September 30,
--------------------------------------------
1995 1994 1993
--------- ------- ---------
<S> <C> <C> <C>
Standardized measure, beginning of year..................................... $18,465 $26,956 $10,618
Sale of oil and gas, net of production costs................................ (6,354) (5,440) (6,613)
Net changes in prices....................................................... 4,474 (9,927) 1,994
Extensions and discoveries.................................................. - - 314
Purchases of reserves in place.............................................. 3,016 - 8,809
Changes in estimated future development costs............................... (6,158) 5,079 (9,525)
Development costs incurred during the period that reduced future
development costs........................................................ 207 706 228
Sale of reserves in place................................................... - - (853)
Revisions in reserve quantity estimates..................................... 1,601 8,887 18,952
Net changes in income taxes................................................. (952) (616) (1,624)
Accretion of discount....................................................... 1,847 2,696 1,062
Other:
Change in timing of production........................................... 3,566 (5,814) 3,043
Other factors............................................................ 1,661 (4,062) 551
------- ------- -------
Standardized measure, end of year........................................... $21,373 $18,465 $26,956
======= ======= =======
</TABLE>
NOTE 12 - OTHER ASSETS
Other assets consist of the following:
<TABLE>
<CAPTION>
September 30,
-----------------------
1995 1994
---- ----
<S> <C> <C>
Indian Offtake Agreement extension - related party......................................... $11,725
Debt issuance costs........................................................................ $ 87 2,957
Debt issuance costs - related party........................................................ 8,757
Long-term catalysts........................................................................ 5,176
Long-term supply agreement support - related party......................................... 855
Forward Sale deferred interest and related costs........................................... 7,273
Officer note receivable.................................................................... 250
Organization costs, net.................................................................... 805 805
Other...................................................................................... 12 600
----- -------
904 38,398
Less: Accumulated amortization............................................................. (441) (17,658)
----- -------
$463 $20,740
===== =======
</TABLE>
In fiscal 1993, the Company recorded $17,355 of deferred assets which
reflected the fair value of the Company's common stock, warrants to purchase
common stock and convertible debt issued to certain shareholders, principally
MG, and their nominees. The securities were issued in consideration for debt
issuances, debt extensions, processing agreements and the extension of the
Indian Offtake Agreement. On October 14, 1994, in conjunction with the MG
Settlement, the Company wrote off all deferred assets related to the agreements
terminated on that date (see Note 3).
-42-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
NOTE 13 - ACCRUED EXPENSES
Accrued expenses consist of the following:
September 30,
-----------------------
1995 1994
---- ----
Interest......................................... $ 391 $ 679
Employee related costs........................... 1,003 7,924
Taxes, including payroll taxes................... 877 9,622
Stock appreciation rights........................ 4,191
Environmental.................................... 1,132
Other............................................ 1,013 3,621
------ -------
$3,284 $27,169
====== =======
NOTE 14 - ENVIRONMENTAL MATTERS
Indian Refining Company
In October 1989, in connection with the Illinois Environmental
Protection Agency's (the "IEPA") concern over contamination from operations
prior to the Company's acquisition of the Indian Refinery, Indian Refining
Company ("IRC"), a wholly-owned subsidiary of the Company which then owned the
Indian Refinery, signed an agreement in principle (the "Agreement in Principle")
with the IEPA which requires IRC to conduct certain environmental tests to
determine the nature and extent of historical contamination at the Indian
Refinery, to develop remediation plans as necessary for the contamination
revealed by the testing, and to provide up to $1,000 of financial security until
the work is completed. IRC recorded the liability related to its obligation to
the IEPA at $5,170. At September 30, 1995, the liability had been reduced to
$3,557. Such environmental liability is included in the determination of the
estimated realizable value of discontinued net refining assets.
On December 12, 1995, the Company sold the stock of IRC to American
Western for one dollar (see Note 3).
Indian Refining Limited Partnership
As part of the purchase of the Indian Refinery from IRLP (see Note 3),
American Western assumed all environmental liabilities of IRLP. At September 30,
1995, such environmental liabilities consisted of an accrued environmental
remediation liability of $8,943 and accrued hazardous waste removal expenses of
$1,458. Such liabilities are included in the determination of the estimated
realizable value of discontinued net refining assets.
Powerine Oil Company
Powerine is the subject of various environmental claims, including being
named as a potentially responsible party ("PRP") in three sites in California.
Powerine, in consultation with outside legal counsel and environmental
specialists, had recorded, prior to its acquisition by Castle, a $28,000 reserve
for various long-term environmental claims. This reserve was to satisfy pending
and anticipated claims such as those related to such discontinued operations
like former gasoline service stations and pipelines, historic off-site waste
disposal sites located within the state of California, refinery groundwater
contamination, and alleged impacts on nearby properties.
At September 30, 1995, the reserve for environmental claims had been
reduced to $23,561 based upon settlements of several environmental claims and
recent environmental appraisals. Such environmental reserve is included in the
determination of the estimated realizable value of discontinued net refining
assets. On January 16, 1996, Powerine merged into a subsidiary of EMC. As a
result of this transaction, Powerine's environmental liabilities were eliminated
from the Company's Consolidated Balance Sheet.
-43-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
As a result of the sales to Kenyen, American Western and EMC, the
Company had divested its refining operations. Nevertheless, should Kenyen,
American Western and/or EMC fail in their efforts with respect to the refineries
they purchased or fail to pay notes due to the Company, it is possible that the
Company and/or its subsidiaries could be included in efforts by vendors to
collect trade payables and/or by environmental authorities in efforts to collect
environmental liabilities. All of the aforementioned entities have minimum
capital.
Although the environmental liabilities related to both of the Company's
Refineries have been assumed by others, there can be no assurance that the
Company or one of its subsidiaries will not be sued for matters related to
environmental liabilities of the Refineries. All three of the companies to which
the refining assets were sold are thinly capitalized and without significant
financial resources. All three are currently seeking to raise financing for
restarting a refinery or for payment of notes related to the purchase of one
refinery. If any of these companies fails in such endeavors and cannot pay such
notes or environmental liabilities, it is possible that the Company or IRLP
(still a subsidiary of the Company) would be party in related legal actions.
Although the Company does not believe it has any liabilities with respect to
such environmental liabilities, a court of competent jurisdiction may find
otherwise and the Company may be required to fund portions of such liabilities.
In recent years, government and other plaintiffs have often sought redress for
environmental damage from the party most capable of payment without regard to
responsibility or fault. Whether or not the Company is ultimately held liable in
such a circumstance, should litigation involving the Company and/or IRLP occur,
the Company would incur substantial legal fees and experience a diversion of
management resources from other operations.
NOTE 15 - DEBT
Long-term debt consists of the following:
September 30,
----------------------
1995 1994
---- ----
Senior Facility................................... $73,041
GECC Loan......................................... $33,196 60,117
Other............................................. 2,500 2,500
------- -------
35,696 135,658
Less: Current portion............................ (12,080) (84,297)
------- -------
$23,616 $51,361
======= =======
The Senior Facility related to IRLP's term debt with a third party
financial institution, Societe Generale. All outstanding obligations under this
facility were assumed by MG on October 14, 1994 in conjunction with the MG
Settlement.
The General Electric Corp. ("GECC") Loan was made to two of the Company's
natural gas subsidiaries, Castle Texas Pipeline L.P. ("Pipeline") and CEC Gas
Marketing L.P. ("Marketing"). The GECC Loan bears interest of 8.33% and is
secured by a first security interest in all of the assets of Pipeline and
Marketing, as well as a pledge of the partnership interests and capital stock of
the general and limited partners of these partnerships. All of the cash flow
generated by Pipeline and Marketing is dedicated to repayment of the GECC Loan.
Although the minimum required 1996 principal payment is $9,580, the Company
expects it will pay approximately $24,000 during 1996.
The cash flow generated by Castle Texas Production L.P. ("Production"),
another wholly-owned subsidiary of the Company, less a specified allowance for
operating expenses, is also dedicated to repayment of the GECC Loan.
The other long-term debt of $2,500 earns interest at the twelve-month
LIBOR rate determined annually on December 11, plus 1/2% (8.06% at September 30,
1995). The debt is due to a financial institution which was previously a
shareholder of the Company. The debt is due in equal quarterly installments of
$625 through June 30, 1996. Subsequent to September 30, 1995, $1,250 of the
other long-term debt was repaid.
-44-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Long-term debt - related parties consists of the following:
September 30,
--------------------
1995 1994
---- ----
MGTFC - Credit agreements............................. $167,880
Loan from Stockholder................................. $250 250
MGTFC Subordinated Loan............................... 9,441
MGTFC Subordinated Note............................... 72,281
MGTFC Revolving Credit Facility....................... 26,861
MG Convertible Debenture.............................. 5,500
Cash Participations................................... (23,748)
------ -------
250 258,465
Less: Current portion, net of cash participations.... (250) (9,974)
---- --------
$ - $248,491
==== ========
As a result of the MG Settlement on October 14, 1994, the loans due to
MG and its subsidiaries (credit agreements, subordinated loan, subordinated
note, revolving credit facility and convertible debentures), net of the
offsetting cash participations in such loans held by the Company, were
discharged (see Note 3). Together with the discharge of the Senior Facility (see
above), such discharged obligations aggregated $321,282 at October 14, 1994.
The Loan from Stockholder of $250 earns interest at the twelve-month
LIBOR rate determined annually on December 11, plus 1/2% (8.06% at September 30,
1995). The debt is due to a stockholder who was also a director of the Company
until January 5, 1996. The debt is due in equal quarterly installments of $63
through June 30, 1996. Subsequent to September 30, 1995, $125 of the Loan from
Stockholder was repaid.
Replacement Credit Facility
On May 25, 1995, IRLP's Revolving Credit Facility with MGTFC (see below)
was refinanced with a $30,000 facility from Bankers Trust, a financial
institution. The credit facility ("Replacement Credit Facility") was granted to
Indian Oil Company ("IOC"), another wholly-owned subsidiary of the Company. The
facility is secured by the inventory, receivables and precious metal catalyst of
Indian, bears interest at prime plus two percent (10.75% at September 30, 1995)
and is guaranteed by the Company and secured by certain non-refining
subsidiaries' exploration and production assets (net book value of approximately
$25,272 at September 30, 1995).
On September 24, 1995, IOC defaulted on the Replacement Credit Facility.
As of September 30, 1995, $13,249 was outstanding under the loan. In
conjunction with the shutdown of the Indian Refinery on September 30, 1995, the
Company began liquidating Indian's assets to satisfy the loan obligations. At
February 29, 1995, the amount outstanding under the loan had been reduced to
$4,540. The Company projects that liquidation value of the collateral supporting
the obligations will be approximately $2,000 less than the loan. Such amount
will be funded by the Company. The Company has agreed to repay the Replacement
Credit Facility and has obtained a conditional commitment letter from a bank for
related financing.
Maturities
The scheduled maturities of long-term debt outstanding as of September
30, 1995 are as follows:
For the Year Ending September 30,
- ---------------------------------
1996.........................................$12,080
1997......................................... 23,616
-------
$35,696
=======
-45-
<PAGE>
NOTE 16 - COMMITMENTS AND CONTINGENCIES
Operating Lease Commitments
The Company has the following noncancelable operating lease commitments
at September 30, 1995:
For the Year Ending September 30,
- ---------------------------------
1996......................................... $195
1997......................................... 182
1998......................................... 159
-----
$536
====
Rent expense for the years ended September 30, 1995, 1994 and 1993,
excluding refining related rent expense, was $255, $255 and $239, respectively.
Compensation Obligations
As of September 30, 1995, the Company has an obligation to fulfill
employment agreements with several of its employees. Subsequent to September 30,
1995, the Company terminated several employment agreements with officers of its
subsidiaries. The Company's compensation obligations, including severance
payments to terminate officers, are as follows:
For the Year Ending September 30,
---------------------------------
1996......................................... $2,129
1997......................................... 143
------
$2,272
======
Under the terms of the employment agreements in effect as of September
30, 1995, certain officers were entitled to bonuses to the extent earnings of
certain subsidiaries, as defined, exceeded certain thresholds. For the years
ended September 30, 1995, 1994 and 1993, no bonuses were accrued.
Letters of Credit
At September 30, 1995, the Company and its subsidiaries had issued or
guaranteed letters of credit as follows:
<TABLE>
<CAPTION>
Description Amount Expiration
----------- ------ ----------
<S> <C> <C>
Oil and gas drilling, operating and plugging bonds............. $ 205 Various
Security for IEPA obligations (see Note 14).................... 1,040 January - September 1996
------
$1,245
======
</TABLE>
The letters of credit applicable to IEPA obligations were issued by IRC,
which was sold to American Western in December 1995 (see Note 3).
-46-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Long Term Supply Commitments
The Company has a gas purchase agreement with MGNG (see Note 21).
Aggregate future commitments under the gas purchase long-term supply commitment
are as follows:
For the Year Ending September 30,
1996.......................................... $ 32,004
1997.......................................... 31,250
1998.......................................... 31,748
1999.......................................... 8,009
---------
$103,011
========
If MGNG fails to perform its obligations under this contract, there is
no assurance that Marketing could fulfill its obligations under the Lone Star
Contract in a manner which would permit Marketing to maintain its current profit
margin on sales of natural gas.
The Company also has a commitment to sell 7,356 mcf (thousand cubic
feet) of natural gas at a fixed price from June 1, 1996 to May 31, 1999. The
Company anticipates supplying the gas from new drilling. The Company's
obligations to sell natural gas to MGNG are as follows:
For the Year Ending September 30,
MCF
(Thousand of cubic feet)
------------------------
1996............................................ 817
1997............................................ 2,452
1998............................................ 2,452
1999............................................ 1,635
-----
7,356
=====
Subsequent to September 30, 1995, Production entered into a swap
agreement to hedge 16% of the gas to be sold to MG at a fixed price. The hedged
price was less than the fixed price resulting in a future profit to the Company
of approximately $200. Production has not yet hedged the other 84% of the gas
that must be delivered to MGNG under the contract. If gas prices increase above
the fixed price to MGNG, Production could incur a loss if it buys or produces
the gas to supply MGNG on the remaining unhedged volumes.
Management Agreements
The Company has two long-term management agreements with Terrapin
Resources, Inc. ("Terrapin") to provide accounting and management with respect
to the Company's exploration and production assets. Terrapin is wholly-owned by
an officer of the Company. Obligations under these agreements are as follows:
For the Year Ending September 30,
1996............................................$ 530
1997............................................ 396
1998............................................ 412
1999............................................ 283
-------
$1,621
======
-47-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
The Company also has two management agreements with subsidiaries of MG
to manage certain pipeline and gas marketing functions. Obligations under these
management agreements are as follows:
For the Year Ending September 30,
1996........................................... $ 420
1997........................................... 437
1998........................................... 454
1999........................................... 317
------
$1,628
======
Additionally, the Company's natural gas marketing and pipeline segment
sells substantially all of its natural gas to only one customer -- Lone Star.
Sales to Lone Star by the Natural Gas Marketing and Transmission segment
aggregated $70,318, $61,228 and $56,641 for the fiscal years ended September 30,
1995, 1994 and 1993, respectively. Approximately 19% of Lone Star' requirements
under the gas sales contract are supplied from wells operated by the Company.
The balance of these requirements are purchased from MGNG pursuant to a gas
purchase contract. If MGNG were to fail to perform its obligations under this
contract, there could be no assurance that the Company could fulfill its
obligations under the Lone Star Contract in a manner which would permit the
Company to maintain its current profit margin on sales of natural gas.
Legal Proceedings
Long-Term Supply Agreement
In 1993, IRLP entered into a Long-Term Supply Agreement (the "LTSA")
with Shell Canada Limited and Salmon Resources Ltd. (collectively "Shell") for
the supply of Caroline Condensate feedstock to the Indian Refinery. MGRM agreed
to be the alternate purchaser under the LTSA in the event IRLP should fail to
perform. On December 23, 1994, Shell filed suit in the United States District
Court for the Northern District of Illinois against IRLP and MGRM (the "Shell
Litigation"). The complaint alleged that MGRM failed to provide Shell with
adequate assurances, pursuant to a request under the Illinois Commercial Code,
concerning its role as "alternate purchaser" under the LTSA, and that as a
result, MGRM repudiated the LTSA pursuant to provisions of the Illinois
Commercial Code. The complaint further alleged that the LTSA should be
terminated because its purpose has been frustrated and the performance has
become impossible.
On October 2, 1995, Shell unilaterally terminated its performance under
the LTSA and ceased delivering Caroline Condensate to the Indian Refinery. On
January 16, 1996, Shell filed an amended complaint, which adds a claim for
$10,000 in damages based upon alleged undercharges and other breaches of the
LTSA. Management believes the claim of Shell is without merit.
On December 12, 1995, IRLP sold the Indian Refinery to American Western
(see Note 3). As part of the sale, American Western assumed all liabilities and
expenses associated with the LTSA litigation. American Western is currently
pursuing this litigation against Shell.
Powerine Arbitration
On April 14, 1995, Powerine repaid all of the indebtedness owed by it to
MGTFC, including $10,828 of disputed amounts (the "Disputed Amount"). On the
same day, the Company and two of its subsidiaries and MG and two of its
subsidiaries entered into the Payoff Loan and Pledge Agreement ("Payoff
Agreement"), which provided the following:
a. MG released Powerine from all liens and claims.
b. MG loaned the Company $10,000.
-48-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
c. Powerine transferred its claim with respect to the Disputed Amount to
the Company.
d. The claim with respect to the disputed Amount was submitted to
binding arbitration (the "Powerine Arbitration").
e. MG can offset the $10,000 loan to the Company against the $10,000
note it issued to the Company as part of the MG Settlement, to the
extent the arbitrator decides the claim with respect to the Disputed
Amount in MG's favor.
The Disputed Amount relates primarily to disputes over the prices paid
by subsidiaries of MG for 388,500 barrels of refined products lifted by MG's
subsidiary, MGRM, and nonpayment for refined products that were processed after
January 31, 1995 and that MGRM was obligated to, but did not, lift and pay for.
To the extent that the arbitrator decides in favor of the Company, the Company's
note to MG will be reduced and the net amount due to the Company from MG will be
increased. If the arbitrator settles the Disputed Amount entirely in the
Company's favor, the Company's note to MG will be cancelled and MG will still
owe the Company its $10,000 note (due October 14, 1997). If the arbitrator
settles the Disputed Amount entirely in MG's favor, the Company's note from MG
will be discharged. In such case the Company's future earnings will also be
adversely impacted since the Company has not recorded any reserve against the
note.
On September 8, 1995, the Company filed its Statement of Claim and
Memorandum. On December 6, 1995, MG filed its Notice of Defense and Response to
Claimant's Statement of Claim and Memorandum. The Company filed a reply on
February 14, 1996 and the parties are proceeding with discovery as to the amount
of damages. The Company expects the arbitration to be settled during the fourth
quarter of fiscal 1996.
In January 1996, MG did not pay interest on the $10,000 note when such
interest was due. As a result, the entire note is due to be paid to the escrow
account for the Powerine Arbitration. The Company has demanded that MG pay the
entire note.
Swap Agreement
In April 1995, IRLP terminated a Natural Gas Swap Agreement (the "Swap
Agreement"), dated October 14, 1994 between MGNG and IRLP, claiming the right to
do so based on breaches of other agreements by MG and its affiliates. MGNG
disregarded IRLP's termination notice and sent IRLP a termination notice
alleging IRLP was the defaulting party and claiming approximately $1,200 of
losses. IRLP has refused to pay MGNG's claim. In June 1995, MGRM, as MGNG's
assignee, filed a complaint in Delaware state court, claiming $1,356 plus
interest under the Swap Agreement. IRLP has answered the complaint. The
Company's management believes that IRLP has good defenses to that claim, expects
to prevail and expects to recover its $707 receivable.
NOTE 17 -- EMPLOYEE BENEFIT PLANS:
Prior to October 1, 1995, the Company did not sponsor any employee
benefit plans; however, employee benefit plans of the Company's consolidated
group were maintained by IRLP and Powerine. Effective October 1, 1995, the
Company adopted a 401(k) plan for its employees.
Defined Benefit Pension Plan:
IRLP established a defined benefit retirement plan (the "IRLP Retirement
Plan") commencing January 1, 1991. All employees of IRLP on January 1, 1991,
including officers, were eligible for benefits under the IRLP Retirement Plan
and all employees joining IRLP after January 1 were eligible after attaining
20.5 years of age and six months of service with IRLP. Beginning in the 1994
fiscal year, employees of Indian Powerine L.P. ("IPLP") were included in the
IRLP Retirement Plan.
The charge against discontinued operations for the years ended September
30, 1995, 1994 and 1993 was $889, $1,280, and $716, respectively.
-49-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Net periodic pension cost included the following components:
September 30,
-----------------------
1995 1994 1993
---- ---- ----
Cost of benefits earned during the period........ $866 $1,165 $694
Interest cost on projected benefit obligation.... 250 206 95
Actual return on assets.......................... (486) (185) (263)
Net amortization and deferral.................... 259 94 190
---- ------ -----
$889 $1,280 $716
==== ====== ====
Significant assumptions used in the actuarial calculations were as follows:
Discount rate............................... 7.25% 8.5% 7.0%
Rate of increase in compensation level..... 5.25% 6.0% 6.0%
Expected long-term rate of return on assets. 9.00% 9.0% 9.0%
A reconciliation of the plan's funded status to amounts included in the
consolidated balance sheet follows:
<TABLE>
<CAPTION>
September 30,
---------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Actuarial present value of benefit obligations:
Vested benefit obligation......................................... ($2,288) ($ 19) ($ 20)
====== ======== ========
Accumulated benefit obligation.................................... ($2,543) ($1,416) ($1,108)
====== ====== ======
Projected benefit obligation...................................... ($4,782) ($3,085) ($2,421)
Plan assets at fair market value..................................... 3,519 1,857 1,401
------- ------- -------
Projected benefit obligation (in excess of) plan assets.............. (1,263) (1,228) (1,020)
Unrecognized net gain (loss)......................................... (118) (451) 229
Unrecognized prior service cost...................................... 40 44 163
------- --------- -------
Pension liability recognized in the consolidated balance sheets...... ($1,341) ($1,635) ($ 628)
====== ====== ======
</TABLE>
Employees are generally entitled to an annual retirement benefit based
on their average earnings. Plan assets were invested in money market funds and
short-term investments.
On December 12, 1995, the Indian Defined Benefit Pension Plan was
transferred to American Western (see Note 3). In addition, American Western
assumed all pension liabilities associated with the Plan. At September 30, 1995
such accrued pension liabilities aggregated $1,341.
-50-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Defined Contribution Plan
Powerine maintained a defined contribution plan (the "Powerine
Retirement Plan") for the majority of its employees. Powerine made contributions
to the retirement plan at the end of each plan year equal to 2.5 percent of each
participant's compensation equal to or less than the social security taxable
wage base ("Wage Base"), plus 5 percent of the participant's compensation in
excess of the Wage Base, subject to certain limitations. Contributions were
invested in various investments as directed by the Powerine Retirement Plan's
administrative committee, primarily combinations of common trust funds.
Powerine's contribution to the Powerine Retirement Plan and amounts charged to
discontinued operations for the years ended September 30, 1995 and 1994
approximated $531 and $484, respectively. On August 31, 1995, the Powerine
Retirement Plan was terminated.
401(k) Plans
IRLP
IRLP sponsored a tax savings 401(k) plan (the "IRLP 401(k) Plan") for
its employees. Employees hired prior to January 1, 1991 became eligible to
participate in the IRLP 401(k) Plan when hired. Employees hired during the
period from January 1, 1991 to January 31, 1991 became eligible to participate
in the IRLP 401(k) Plan on July 1, 1991 (if still employed). All employees hired
after January 31, 1991 became eligible to participate in the IRLP 401(k) Plan on
the January 1 immediately following the date on which the employee has completed
500 hours of eligible service in a six-month period. During fiscal 1994 the plan
was expanded to include employees of IPLP and the Company.
Employees participating in the IRLP 401(k) Plan could authorize IRLP to
contribute up to 15% of their gross compensation to the IRLP 401(k) Plan. IRLP
would match such voluntary employee contributions up to 3% of employee gross
compensation. Employees' contributions to the IRLP 401(k) Plan could not exceed
thresholds set by the Secretary of the Treasury. During the years ended
September 30, 1995, 1994 and 1993, the Company's and its subsidiaries'
contributions to the IRLP 401(k) Plan aggregated $480, $467 and $393,
respectively.
On December 12, 1995, the IRLP 401(k) Plan was transferred to American
Western (see Note 3).
Powerine
Powerine sponsored a 401(k) plan (the "Powerine 401(k) Plan") for the
majority of its employees. Under the terms of the plan, Powerine matched 50% of
the voluntary employee contributions to the plan up to a maximum of 6% of the
participant's compensation. Contributions were invested in various combinations
of common trust funds comprising the investment options available to and
directed by the participant. For the years ended September 30, 1995 and 1994,
Powerine's contributions to the plan were $380 and $282, respectively. Such
contributions were charged to discontinued operations. On August 31, 1995, the
Powerine 401(k) Plan was terminated.
Post Retirement Benefits
Neither the Company nor its subsidiaries provide any other post
retirement benefits to employees.
NOTE 18 -- STOCKHOLDERS' EQUITY
Effective November 18, 1992, the Company issued 300,000 shares of its
common stock to certain nominees of MGRM, including three individuals who were
at that time directors of the Company, in return for MGRM's agreeing to provide
performance assurances of IRLP's obligations in conjunction the LTSA (see Note
16).
-51-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
In connection with the May 1993 extension and restructuring of the
Indian Offtake Agreement, the Revolving Credit Facility, the Subordinated Note,
the MGTFC Credit Agreement and the provision by MG AG (see Note 15) and MG of
support agreements required by the senior lender under the Senior Facility, on
May 11, 1993, the Company issued to MG or its nominees 1 million shares of the
Company's common stock, 7-year warrants to purchase 1,975,000 shares of the
Company's common stock at a purchase price of $11.00 per share and a $5,500
convertible debenture with a maturity of December 31, 1996. The value of the
securities issued was based upon the estimated fair value of such securities,
was recorded as deferred assets and was amortized over the lives of the related
agreements.
On September 16, 1993, the Board of Directors of the Company authorized
a 1-for-2 reverse stock split which became effective November 12, 1993. All
share and per share amounts have been restated to give effect to the 1-for-2
reverse stock split.
On December 2, 1993, the Company consummated a public offering of its
common stock. Pursuant to the terms of the offering, the Company sold 2,800,000
shares of common stock to the public and 700,000 shares of common stock to MG at
a gross offering price of $15.00 per share. The offering resulted in aggregate
net proceeds to the Company of $48,178. Of such amount, $30,800 was used to pay
down various debt obligations of the Company owed to MGTFC. The remainder of
such amount was used for general corporate purposes. As a result of the
offering, MG's percentage ownership of the Company's common stock was reduced
from approximately 49% to approximately 41%. All treasury stock of the Company
was reissued in conjunction with the offering.
On April 21, 1994, the Board of Directors of the Company adopted a
Stockholder Rights plan under which one preferred stock purchase right has been
distributed for each outstanding share of the Company's common stock. Each right
initially entitles holders of common stock to buy one-hundredth of one share of
a new series of preferred stock at an exercise price of $35.00. The rights will
be exercisable only if a person or group, without the prior approval of the
Company's Board of Directors, acquires 15% or more of the outstanding common
stock or announces a tender offer as a result of which such person or group
would own 15% or more of the common stock. If a person to whom these provisions
apply becomes a beneficial owner of 15% or more of the outstanding common stock,
each right (other than rights held by such acquiring person) will also enable
its holder to purchase common stock (or equivalent securities) of the Company
having a value of $70.00 for a purchase price of $35.00. In addition, if the
Company is involved in a merger or other business combination with another
entity, at or after the time that any person acquires 15% or more of the
outstanding common stock, each right will entitle its holder to purchase, at
$35.00 per right, common shares of such other entity having a value of $70.00
On September 9, 1994, the Company acquired and cancelled 3,600,000
shares of its common stock from MG. On October 14, 1994, 969,000 shares of
common stock were surrendered by MG and cancelled by the Company, reducing MG's
ownership of the Company's common stock to zero. In addition, the convertible
debenture was cancelled and all warrants except for 22,500 warrants were
cancelled (see Notes 3 and 19).
The Company is currently precluded from paying dividends as a result of
restrictions under the Replacement Credit Facility (see Note 15). Such
restrictions will be removed once the Replacement Credit Facility lender is
repaid. In addition, both of the Company's natural gas marketing and
transmission subsidiaries are precluded from paying dividends to the Company
pursuant to provisions of the GECC loan.
-52-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
NOTE 19 -- STOCK OPTIONS AND WARRANTS
Option and warrant activities during each of the three years ended
September 30, 1995 are as follows (in whole units):
<TABLE>
<CAPTION>
Non- Incentive
Incentive Qualified Plan Other
Warrants Options Options Options Options Total
-------- ------- ------- ------- ------- -----
<S> <C> <C> <C> <C> <C> <C>
Outstanding-September 30, 1992............. 20,000 101,000 302,500 55,000 478,500
Issued..................................... 1,975,000 7,500 195,000 45,000 2,222,500
Exercised.................................. (20,000) (7,500) (27,500)
Cancelled.................................. (98,500) (172,500) (7,500) (278,500)
Expired.................................... (20,000) (20,000)
---------- -------- --------- ------- ------- ---------
Outstanding-September 30, 1993............. 1,975,000 2,500 110,000 195,000 92,500 2,375,000
Issued..................................... 434,000 100,000 534,000
Exercised.................................. (5,000) (5,000)
Cancelled.................................. (100,000) (100,000)
Expired.................................... (1,055,000) (17,500) (41,666) (7,500) (1,121,666)
--------- -------- -------- -------- ---------- ---------
Outstanding-September 30, 1994............. 920,000 2,500 92,500 487,334 180,000 1,682,334
Issued..................................... 115,000 115,000
Exercised.................................. (35,000) (35,000)
Expired.................................... (897,500) (25,000) (58,500) (10,000) (991,000)
---------- --------- -------- -------- ------- ---------
Outstanding-September 30, 1995............. 22,500 2,500 67,500 543,834 135,000 771,334
========== ========= ======== ======= ======= =========
Reserved at September 30, 1995 22,500 2,500 67,500 562,500 135,000 790,000
========== ========= ======== ======= ======= =========
Reserved at September 30, 1994 920,000 2,500 92,500 562,500 180,000 1,757,500
========== ========= ========= ======= ======= =========
Exercisable at September 30, 1995.......... 0 2,500 67,500 284,627 128,333 482,960
========== ========= ========= ======= ======= =========
Become exercisable during fiscal year ended:
September 30, 1996...................... 139,707 6,667 146,374
September 30, 1997...................... 100,750 100,750
September 30, 1998...................... 18,750 18,750
------- --------- ----------
259,207 6,667 265,874
======= ========= ==========
Exercise prices at:
September 30, 1995...................... $11.00 $6.00 $6.00 $ 8.50- $11.00-
$14.25 $12.25
September 30, 1994...................... $11.00 $6.00 $6.00- $10.25 $ 5.75-
$8.50 $14.25 $12.25
September 30, 1993...................... $11.00 $6.00 $6.00- $12.25 $ 5.36-
$8.50 $11.00
Exercise Termination Dates.............. 2000 1997 1997 2005 2004
</TABLE>
Effective May 18, 1992, the Company's Board terminated the existing
stock plans. Unexercised options to purchase 205,000 shares of common stock
awarded under the prior plans continued to be governed by the terms of the prior
plans.
In fiscal 1993, the Company adopted the 1992 Executive Equity Incentive
Plan (the "Incentive Plan"). The purpose of the Incentive Plan is to increase
the ownership of common stock of the Company by those non-union key employees
(including officers and directors who are officers) and outside directors who
contribute to the continued growth, development and financial success of the
Company and its subsidiaries, and to attract and retain key employees and reward
them for the Company's profitable performance.
-53-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
The Incentive Plan provides that an aggregate of 562,500 shares of
common stock of the Company will be available for awards in the form of stock
options, including incentive stock options and nonqualified stock options
generally at prices at or in excess of market prices at the date of grant.
The Incentive Plan also provides that each outside director of the
Company will annually be granted an option to purchase 5,000 shares of common
stock at fair market value on the date of grant.
In conjunction with the MG Settlement, certain warrants were cancelled
(see Note 3). The remaining 22,500 warrants cannot be exercised without the
Company's consent. The Company intends to withhold its consent.
In addition to stock options and warrants, the Company has issued the
following stock appreciation rights:
<TABLE>
<CAPTION>
Measurement Price
------------------------------------------------------------------------------
$5.00 $6.00 $8.00 $12.50 $13.00 Total
----- ----- ----- ------ ------ -----
<S> <C> <C> <C> <C> <C> <C>
Outstanding-September 30, 1992............... 300,000 67,500 175,000 542,500
Issued....................................... 112,500 60,000 150,000 36,667 359,167
Exercised.................................... (6,667) (6,667)
Cancelled.................................... (87,500) (87,500)
--------- -------- ------- -------- ------ --------
Outstanding-September 30, 1993............... 300,000 180,000 140,833 150,000 36,667 807,500
Exercised.................................... (300,000) (67,500) (20,000) (387,500)
Cancelled.................................... (13,333) (13,333)
--------- -------- ------- -------- ------ -------
Outstanding-September 30, 1994............... -- 112,500 107,500 150,000 36,667 406,667
Exercised.................................... (112,500) (20,000) (132,500)
--------- ------- ------- ------- ------ -------
Outstanding-September 30, 1995............... -- -- 87,500 150,000 36,667 274,167
========= ======= ======= ======= ====== =======
</TABLE>
Subsequent to September 30, 1995, all 274,167 stock appreciation rights
outstanding at September 30, 1995 were cancelled in return for severance
payments to officers of IRLP.
The stock appreciation rights entitled the holder to cash compensation
equal to the difference between the price per share of the Company's common
stock and the measurement price with respect to the number of rights issued,
subject to adjustment. Costs associated with stock appreciation rights were
recorded over the relevant period of employment. During the years ended
September 30, 1995, 1994 and 1993, the Company recorded (income) expense related
to stock appreciation rights of ($1,162),$4,848 and $2,268, respectively.
NOTE 20 -- INCOME TAXES
Provisions for (benefit of) income taxes consist of:
<TABLE>
<CAPTION>
September 30,
----------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Provision for (benefit) income taxes:
Current:
Federal.............................................................. $ 1,852 $ 2,877 $ 3,006
State................................................................ 22 549
Deferred:
Federal.............................................................. 20,157 28,702 4,216
State................................................................ 2,532 (14,827) 903
Adjustment to the valuation reserve for deferred taxes:
Federal.............................................................. 29,415 (34,701) (38,874)
State................................................................ 3,695 17,926 (5,221)
-------- -------- ---------
$57,673 $ 526 ($35,970)
======= ========= =======
Intraperiod tax allocation of tax provision (recovery):
Continuing operations.................................................... $37,823 ($17,077) ($44,081)
Discontinued operations.................................................. 19,850 17,603 8,111
-------- -------- ---------
$57,673 $ 526 ($35,970)
======= ========== =======
</TABLE>
-54-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
The intraperiod tax allocation was made pursuant to FAS 109.
Deferred tax assets (liabilities) are comprised of the following at
September 30, 1995 and 1994:
<TABLE>
<CAPTION>
September 30,
----------------------
1995 1994
---- ----
<S> <C> <C>
Operating loss and other tax carryforwards................................................... $23,786 $65,467
Depletion accounting......................................................................... (1,398) (814)
Depreciation................................................................................. (6,232) (29,327)
Amortization (gas contracts)................................................................. 2,553 3,369
Discontinued net refining assets, including environmental.................................... 18,557 11,586
Installment sale accounting.................................................................. (4,000)
Other........................................................................................ (3,107) 2,621
-------- --------
30,159 52,902
Valuation allowance.......................................................................... (33,110)
------- -------
($ 2,951) $52,902
======== =======
Deferred tax assets - current................................................................ $ 4,623 $68,088
Deferred tax liabilities - non-current....................................................... (7,574) (15,186)
--------- -------
($ 2,951) $52,902
======== =======
</TABLE>
Upon adoption of FAS 109, the Company recorded an asset of $73,909 and
provided a valuation reserve against the asset of $65,395. During fiscal 1993,
the Company reduced the valuation reserve based upon the Company's entering into
certain long-term purchase and sale commitments, refinancing its debt and the
related earnings projections. At September 30, 1994, the Company adjusted its
valuation reserve such that the remaining deferred tax assets approximated the
net tax benefit that the Company expected to realize from its net operating loss
carryforwards as a result of the gain realized from the MG Settlement (See Note
3). As a result of unanticipated delays and larger than expected losses in the
sale of its refineries, the Company did not realize all of its tax
carryforwards. As a result, the Company provided a $31,955 valuation reserve at
December 31, 1994 which was subsequently adjusted to a $33,110 valuation reserve
at September 30, 1995.
The income tax provision (benefit) differs from the amount computed by
applying the statutory federal income tax rate to income (loss) before income
taxes as follows:
<TABLE>
<CAPTION>
Year Ended September 30,
---------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Tax at statutory rate....................................................... $25,400 $13,805 $ 8,174
State taxes, net of federal benefit......................................... 4,063 2,371 1,081
Non-deductible goodwill amortization........................................ 1,855 311
Change in tax rate.......................................................... (1,130)
Changes in prior year's estimates........................................... (6,847)
Changes in valuation allowance.............................................. 33,110 (16,775) (44,095)
Other....................................................................... 92 814
------- -------- ---------
$57,673 $ 526 ($35,970)
======= ======== =======
</TABLE>
The tax provision (benefit) applicable to discontinued operations -
refining differs from the amount computed by applying the statutory federal
income tax rate to income (loss) before income taxes as follows:
-55-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
<TABLE>
<CAPTION>
Year Ended September 30,
---------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Income (loss) before income taxes - discontinued operations - refining...... $60,787 $40,180 $20,446
======= ======= =======
Tax at statutory rate....................................................... $21,275 $14,063 $ 7,163
State taxes, net of federal benefit......................................... 3,403 2,416 948
Non-deductible goodwill amortization........................................ 1,855 311
Change in prior year's estimate............................................. (6,847)
Other....................................................................... 164 813
------- ---------- --------
$19,850 $17,603 $ 8,111
======= ======= ========
</TABLE>
At September 30, 1995, the Company had the following tax carryforwards
available:
Federal Tax
---------------------------
Alternative
Minimum
Regular Tax
------- -------------
Net operating loss................... $39,459 $48,972
Alternative minimum tax credits...... $ 2,650 N/A
Statutory depletion.................. $12,364 $12,364
Investment tax credit................ $ 414 N/A
The net operating loss and investment tax credit carryforwards expire
from 1996 through 2008. Of the Company's net operating losses, approximately
$24,881 (approximately $23,536 for alternative minimum tax purposes) are
applicable to subsidiaries acquired by the Company and may only be used to
offset future taxable income of the acquired companies which generated the loss.
Similar restrictions apply to all of the Company's investment tax credit
carryforwards and approximately $9,000 of the Company's statutory depletion
carryforwards.
On September 9, 1994, the Company experienced a change of ownership for
tax purposes. As a result of such change of ownership, the Company's net
operating loss became subject to an annual limitation of $7,845. Such annual
limitation, however, is increased by the amount of net built in gain at the time
of the change of ownership. Such net built-in gain approximates $191,552. During
fiscal 1995, the Company utilized $116,236 of its net operating loss, including
$108,391 of built-in gain, to offset the gain from the MG Settlement (see Note
3).
The Company also has approximately $35,750 in individual state tax loss
carryforwards available at September 30, 1995. Such carryforwards are primarily
available to offset taxable income apportioned to certain states in which the
Company previously incurred refining losses and currently has only minor
operations and no current plans for future operations.
NOTE 21 -- RELATED PARTIES
During the fiscal year ended September 30, 1994 and 1993, the Company
conducted several transactions with its principal shareholder, MG, and its
subsidiaries. As a result of the MG Settlement on October 14, 1994, MG's
ownership of the Company was reduced to zero and MG was thereafter no longer a
related party. The following summarizes the MG subsidiaries with which the
Company and its affiliates conducted transactions, and the nature and dollar
amount of such related party transactions.
-56-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
The MG affiliates and subsidiaries which the Company engaged in
transactions were as follows:
Metallgesellschaft Corp. A.G. ("MG AG"), German parent
Metallgesellschaft Corp. ("MG"), U.S. subsidiary
MG Refining and Marketing, Inc. ("MGRM"), U.S. subsidiary
MG Trade Finance Corp. ("MGTFC"), U.S. subsidiary
MG Futures, Inc. ("MGF"), U.S. subsidiary
MG Natural Gas Corp. ("MGNG"), U.S. subsidiary
MG Gathering Corp ("MGG"), U.S. subsidiary
MGPC Petcoke, Inc. ("MG Petcoke"), U.S. subsidiary
All of the above U.S. subsidiaries are directly or indirectly
wholly-owned by MG which, in turn, is indirectly owned by MG AG.
The fiscal 1993 and 1994 transactions with MG and its affiliates are as
follows:
<TABLE>
<CAPTION>
Dollar Volume of
Transaction Year Ended
Parties September 30,
------------------------------ ----------------------------
Company MG Description 1994 1993
-------------- ------ ----------- ---- ----
<S> <C> <C> <C> <C>
IRLP MGTFC Interest paid by IRLP to MGTFC on $1,147 $1,537
MGTFC Subordinated Note.
IRLP, IPLP MG Payments by IRLP and IPLP to MG for $50,257 $527,300
crude oil and feedstock supply.
IRLP, IPLP & Powerine MG Payments of fees to MG with respect to $2,614 $1,415
feedstock supply and credit agreements.
IRLP MGRM Payments by MGRM to IRLP under swap $3,082 $18
(hedging) agreement with respect to crude
oil.
Powerine MGRM Payments by Powerine to MGRM for the $47,129
supply of crude and oil.
Powerine MG Petcoke Payment by MG Petcoke to Powerine for $2,516
purchase of coke.
Pipeline & Marketing MGTFC Payment by Pipeline and Marketing of a $3,206
syndication fee for a loan to purchase the
ARCO properties.
Castle Energy Corporation MGTFC Payment by the Company of interest on $7,734
credit agreement loan.
IRLP MGTFC Payment by IRLP to MGTFC for lease $85 $109
catalyst costs.
IRLP MGTFC Payment by IRLP to MGRM for natural $8,462 $7,260
gas supplies.
</TABLE>
-57-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
<TABLE>
<CAPTION>
Dollar Volume of
Transaction Year Ended
Parties September 30,
------------------------------ -------------------------
Company MG Description 1994 1993
-------------- ------ ----------- ---- ----
<S> <C> <C> <C> <C>
IRLP, IPLP & Powerine MGF Payments by IRLP and Powerine to MGF $292 $622
for brokerage services for hedging
activities.
IRLP MGRM Payments received by IRLP for sales of $498,225 $525,690
refined products to MGRM under the
Indian Offtake Agreement.
Powerine MGRM Payments received by Powerine for sales $348,751
of refined products to MGRM under
Powerine Offtake Agreement.
IRLP MGRM Payments by MGRM to IRLP for IRLP's $11,899 $6,320
operating the Indian Refinery at less than
full capacity.
Pipeline MGG Pipeline paid MGG for pipeline manage- $148 $120
ment services.
Marketing MGNG Marketing paid MGNG for gas marketing $240 $195
services.
Marketing MGNG Marketing paid MGNG for gas supplies $31,069 $21,519
under a long-term gas supply agreement
</TABLE>
In addition to the above-related party transactions with MG and its
affiliates, the Company undertook the following related party transactions:
Sale of Subsidiaries
On March 31, 1993, the Company entered into an agreement to sell to
Terrapin its oil and gas partnership management businesses for $1,100 ($800 note
bearing interest at 8% per annum and $300 cash) which approximated book value.
The closing of the stock purchase transaction occurred on June 30, 1993.
Terrapin is wholly-owned by a former officer and director of the Company. In
November 1994, this former officer and director rejoined the Company as an
officer. In December 1994, the note was repaid.
In conjunction with the sale of its partnership management business,
the Company and Production entered into two management agreements with Terrapin
to manage its exploration and production operations. Management fees incurred to
Terrapin for the years ended September 30, 1995, 1994 and 1993 aggregated $579,
$584 and $203, respectively.
Purchase of IRLP Interests
During 1993, the Company acquired the partnership units of IRLP it did
not already own. Certain of these units were acquired from an officer of the
Company for an aggregate of 262,500 stock appreciation rights, entitling the
holder to cash compensation equal to the difference between the price per share
of the Company's common stock and stated prices. In November 1994, 112,500 stock
appreciation rights were exercised for $1,026 and the remaining 150,000 stock
appreciation rights were surrendered as part of the Company's severance
agreement with the officer for $500.
-58-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
Professional Fees
An officer of the Company is also a partner in a law firm which served
as general counsel to the Company. Legal fees incurred by the Company to this
firm during the years ended September 30, 1995, 1994 and 1993 were $2,593,
$5,101 and $1,343, respectively. On June 5, 1995, the officer resigned.
A member of the Board of Directors is also a partner in a law firm
which currently serves as general counsel for the Company. Legal fees paid by
the Company to this firm during fiscal 1995 and 1994 approximated $1,225 and
$806, respectively. On October 6, 1995, the partner in the law firm resigned as
a director of the Company.
Loan to Officer
On February 26, 1993, an officer of a subsidiary of the Company was
loaned $250. The principal amount of the loan was due and payable in full on the
earlier of January 31, 1996 or the termination of the officer's employment. The
loan accrued interest at the prime rate in effect on the date of the loan as
adjusted each January 1. The officer terminated his employment on December 22,
1995. The loan and accrued interest was offset against compensation due to the
officer as part of the officer's severance. In addition, the officer surrendered
all stock appreciation rights which he held.
CORE, Inc.
In the first quarter of fiscal 1995, the Company decided to dispose of
its refining operations. During the period from October 14, 1994 to September
29, 1995, the Company financed three attempts to sell one or both of its
refineries to CORE, Inc. ("CORE") (previously SIPAC, Inc.). CORE is wholly-owned
by a director of the Company. The director was also the President and Chief
Operating Officer of the Company until January 1996. Pursuant to several
agreements with CORE, the Company agreed to reimburse CORE for certain expenses
incurred by CORE in attempting to raise financing for a management buyout of one
or both of the Company's Refineries. Such agreements with CORE also provided
that the Company would be reimbursed for most of such funding should CORE
succeed in raising financing. In September 1995, the third CORE attempt to
obtain financing for the management buyout failed. During the year ended
September 30, 1995, the Company recorded $3,768 of expenses related to CORE. The
Company is not responsible for any CORE expenses incurred after September 29,
1995.
Payment of Legal Fees for Former Director
In conjunction with the MG Settlement, the Company paid legal fees
incurred by a director of the Company. For the years ended September 30, 1995
and 1994, such fees were $327 and $191, respectively. The director resigned in
June 1995.
NOTE 22 - BUSINESS SEGMENTS
Prior to August 14, 1989, when the Indian Refinery was acquired, the Company
was involved in only one business segment, the exploration for and the
production of oil and gas and administration of related oil and gas
partnerships. Upon the acquisition of the Indian Refinery in August 1989, the
Company became engaged in an additional business segment, refining. This segment
had no operations until October 1, 1990. On December 3, 1992, the Company
entered a third segment of the petroleum business - natural gas marketing. The
Company disposed of its partnership administration business in June 1993 but
continued its exploration and production business. As a result of the foregoing,
the Company operated in three segments of the petroleum business during the
fiscal years ended September 30, 1993, 1994 and 1995 - refining, natural gas
marketing and exploration and production. As of September 30, 1995, the Company
disposed of its refining segment (see Note 3).
-59-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
<TABLE>
<CAPTION>
Year Ended September 30, 1995
--------------------------------------------------------------------------------------
Oil & Gas Eliminations
Natural Exploration and
Gas and Refining Corporate
Marketing Production (Discontinued) Items Consolidated
--------- ---------- -------------- ------------ ------------
<S> <C> <C> <C> <C> <C>
Revenues........................... $74,675 $ 9,197 ($ 4,273) $ 79,599
Operating income (loss)............ 16,867 2,991 (4,995) 14,863
Identifiable assets................ 72,724 25,272 18,908 116,904
Capital expenditures............... 47 4,022 $35,355 4 39,428
Depreciation, depletion and
amortization.................... 11,385 2,770 77 14,232
Year Ended September 30, 1994
--------------------------------------------------------------------------------------
Oil & Gas Eliminations
Natural Exploration and
Gas and Refining Corporate
Marketing Production (Discontinued) Items Consolidated
--------- ---------- -------------- ------------ ------------
Revenues........................... $66,424 $ 8,552 ($ 5,165) $ 69,811
Operating income (loss)............ 10,643 2,402 (5,499) 7,546
Identifiable assets................ 80,560 19,714 $469,149 77,068 646,491
Capital expenditures............... 21 956 218,088 346 219,411(1)
Depreciation, depletion and
amortization.................... 11,360 2,092 66 13,518
- ----------------
(1) Includes $152,945 of additions related to the acquisition of Powerine.
Year Ended September 30, 1993
--------------------------------------------------------------------------------------
Oil & Gas Eliminations
Natural Exploration and
Gas and Refining Corporate
Marketing Production (Discontinued) Items Consolidated
--------- ---------- -------------- ------------ ------------
Revenues........................... $62,572 $10,124 ($ 5,896) $ 66,800
Operating income (loss)............ 10,866 3,244 (2,191) 11,919
Identifiable assets................ 89,965 20,161 $230,647 51,965 392,738
Capital expenditures............... 27,909 13,592 35,695 77,196
Depreciation, depletion and
amortization.................... 9,495 2,696 30 12,221
</TABLE>
-60-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
NOTE 23 -- DISCLOSURES ABOUT FAIR VALUE OF FINANCIAL INSTRUMENTS
Cash, Cash Equivalents and Temporary Investments -- For those short-term
instruments, the carrying amount is a reasonable estimate of fair value.
Note receivable - MG - at September 30, 1995, the Company had the
following long-term note receivable:
Note - MG $10,000 8%
The Company believes the interest rate on the note approximates the
market value given the guarantee of the note by MG AG.
Debt -- At September 30, 1995, the Company had the following debt with
interest rates which were fixed:
GECC Loan................................. $33,196 8.33%
The Company has recently conducted negotiations with prospective lenders
and has ascertained that an interest rate of approximately 10% would have been
likely if the Company were to have refinanced the GECC Loan at September 30,
1995. Accordingly, the estimated fair market value of the GECC Loan at September
30, 1995, based upon an interest rate of 10%, and anticipated future cash flows
is $32,688.
All other debt is at rates tied to market indices and is considered to be
stated at fair value.
Other Current Assets and Current Liabilities - the Company believes that
the book values of other current assets and current liabilities approximate the
market values.
NOTE 24 - QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
The following information has been restated to reflect the discontinuance
of refining operations, retroactively.
<TABLE>
<CAPTION>
First Second Third Fourth
Quarter Quarter Quarter Quarter
(December 31) (March 31) (June 30) (September 30)
------------- ---------- --------- --------------
<S> <C> <C> <C> <C>
Fiscal 1995:
Revenues....................................... $22,414 $22,915 $20,766 $13,504
Operating income before interest and income
taxes....................................... 4,784 5,253 4,383 443
Net income (loss).............................. 14,084 36 (1,873) 2,650
Net income (loss) per share.................... $ 1.97 $ 0.01 ($ 0.28) $ .39
</TABLE>
See Note 3 for a discussion of the first quarter gain on the MG
Settlement and the quarterly adjustments to the carrying value of net refining
assets. Changes in the valuation reserve for deferred tax assets are discussed
in Note 20.
The sum of the quarterly per share amounts ($2.09) differs from the
annual per share amount ($2.20) primarily because of the 969,000 shares of the
Company's common stock acquired on October 14, 1994 as part of the MG
Settlement (see Note 3).
-61-
<PAGE>
Castle Energy Corporation
Notes to Consolidated Financial Statements
("000's" Omitted Except Share and Per Share Amounts)
<TABLE>
<CAPTION>
First Second Third Fourth
Quarter Quarter Quarter Quarter
(December 31) (March 31) (June 30) (September 30)
------------- ---------- --------- --------------
<S> <C> <C> <C> <C>
Fiscal 1994:
Revenues....................................... $18,576 $20,668 $12,556 $18,011
Operating income before interest and income
taxes....................................... $ 2,863 $ 3,782 ($ 489) $ 1,390
Net income..................................... $ 8,383 $ 6,699 $ 4,345 $19,490
Net income per share........................... $ 0.82 $ 0.56 $ 0.37 $ 1.73
</TABLE>
Net income for the quarter ended September 30, 1994 increased $16,775
because of a decrease in the Company's valuation reserve against the deferred
tax assets. The decrease resulted from the recognition of additional tax
benefits arising from the anticipated utilization of net operating losses and
other tax carryforwards to offset taxable income derived from the MG Settlement.
NOTE 25 - SUBSEQUENT EVENTS
On December 12, 1995, IRLP sold the Indian Refinery and related
equipment to American Western (see Note 3).
On January 16, 1996, Powerine merged into a subsidiary of EMC (see
Note 3).
In December 1995, the Company received $2,725 from a plaintiff class
escrow fund related to stockholder litigation. The parties reached a settlement
with respect to the stockholder litigation in October 1994. The proceeds to the
Company represent unclaimed funds that were to revert to the Company pursuant
to the Settlement Order for the litigation.
Subsequent to September 30, 1995, the Company entered into a swap
agreement to hedge its natural gas sale commitment to MGNG (see Note 16).
On March 5, 1996, the Company engaged an investment banking firm to
explore strategic alternatives to enhance stockholder value and to act as the
Company's exclusive advisor. The alternatives that may be recommended include
the sale of assets, the sale of the Company, a merger with or joint venture with
another company or other restructuring measures. If such is the case, future
operations of the Company may be different from that contemplated herein.
As discussed in Note 15, all of the cash flow generated by Pipeline and
Marketing is dedicated to the repayment of the GECC loan. As a result, until the
GECC loan is liquidated, cash flow from operations will not be sufficient to
satisfy the Company's obligations. Accordingly, on March 14, 1996 the Company
entered into a $3,800 credit commitment with a financial institution. Funds
borrowed will be secured by the Company's exploration and production assets. The
Company believes that the funds borrowed under the terms of this facility will
allow it to satisfy its obligations during the next twelve months.
-62-
<PAGE>
SCHEDULE III
CASTLE ENERGY CORPORATION
(PARENT)
CONDENSED FINANCIAL INFORMATION - PARENT COMPANY ONLY
YEARS ENDED SEPTEMBER 30, 1995, 1994 AND 1993
The following represents the financial position, statements of
operations and statements of cash flows for Castle Energy Corporation, the
parent company, as of September 30, 1995, 1994 and 1993 and for the three
periods then ended.
CASTLE ENERGY CORPORATION
CONDENSED BALANCE SHEETS
("000's" Omitted, except share amounts)
<TABLE>
<CAPTION>
Years Ended September 30,
---------------------------------------------
1995 1994 1993
--------- ---------- ----------
ASSETS
<S> <C> <C> <C>
Current assets:
Cash.................................................................... $ 6,067 $ 9,729 $ 409
Accounts receivable..................................................... 2,673 858
Deferred taxes.......................................................... 4,623 68,088 14,520
Other assets............................................................ 140 11 144
--------- ---------- ----------
Total current assets............................................. 10,830 80,501 15,931
Deferred income taxes...................................................... 34,595
Intercompany advances...................................................... 8,486 44,449
Other assets............................................................... 300 385 1,452
--------- ---------- ----------
Total assets..................................................... $11,130 $ 89,372 $ 96,427
========= ========== ==========
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
Current liabilities:
Current portion - long-term debt........................................ $ 2,750
Accounts payable and accrued expenses................................... 7,337 $ 4,908 $ 2,783
Income taxes payable.................................................... 507 86 3,006
--------- ---------- ----------
Total current liabilities........................................ 10,594 4,994 5,789
Accumulated losses of subsidiaries in excess of investments:
Exploration and production.......................................... (9,650) (9,402) (9,513)
Refining (discontinued)............................................. (39,996) 2,798 70,301
Natural gas transmission and marketing.............................. (34,462) (8,825) (4,738)
CEC, Inc. .......................................................... 759
Long-term debt, including intercompany debt............................. 34,674 42,875 42,875
Other liabilities....................................................... 1,100
Deferred income taxes................................................... 7,574 19,012
--------- ---------- ----------
Total liabilities................................................ (30,507) 51,452 105,814
--------- ---------- ----------
Stockholders' equity:
Series B participating preferred stock; par value - $1.00;
10,000,000 shares authorized; no shares issued
Common stock, $.50; 25,000,000 shares authorized;
6,693,646, 7,627,646 and 7,722,646 shares issued and
outstanding in 1995, 1994 and 1993, respectively.................... 3,347 3,814 3,891
Additional paid-in capital.............................................. 66,316 73,490 65,387
Accumulated deficit..................................................... (28,026) (39,384) (78,301)
--------- ---------- ----------
41,637 37,920 (9,023)
Treasury stock - at cost (59,860 shares in 1993)........................ (364)
--------- ---------- ----------
41,637 37,920 (9,387)
--------- ---------- ----------
Total liabilities and stockholders' equity (deficit)............. $11,130 $ 89,372 $ 96,427
========= ========== ==========
</TABLE>
-63-
<PAGE>
SCHEDULE III
CASTLE ENERGY CORPORATION
(PARENT)
CONDENSED
CONDENSED STATEMENTS OF OPERATIONS
("000's" Omitted)
<TABLE>
<CAPTION>
Years Ended September 30,
-----------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
Revenues:
Oil and gas sales....................................................... $ 9 $ 15 $ 12
Management fees......................................................... 3,640 4,956 1,414
Interest/dividend income................................................ 5,352 3,354 2,426
-------- -------- --------
9,001 8,325 3,852
-------- -------- --------
Costs and expenses:
General and administrative.............................................. 6,820 10,631 2,265
Oil and gas production.................................................. 6 6 4
Interest expense........................................................ 3,633 2,608 2,124
Depreciation, depletion and amortization................................ 77 66 30
Other................................................................... 1,909 541
-------- ------- -------
12,445 13,852 4,423
-------- ------- -------
Income (loss) before equity in undistributed earnings (losses) of
subsidiaries and income taxes........................................... (3,444) (5,527) (571)
Equity in undistributed earnings (losses) of subsidiaries:
Exploration and production............................................ 248 (111) 1,341
Refining (discontinued)............................................... 44,866 38,537 17,865
Natural gas transmission and marketing................................ 25,636 4,087 4,718
CEC, Inc. ............................................................ 759
-------- -------- -------
68,065 36,986 23,353
Provision for (recovery of) income taxes.............................. 53,168 (1,931) (35,970)
-------- -------- -------
Net income (loss) before cumulative effect of change in accounting
principle........................................................... 14,897 38,917 59,323
Cumulative effect of a change in accounting principle - adoption of
FAS 109............................................................. 8,514
------- ------- -------
Net income ........................................................... $14,897 $38,917 $67,837
======= ======= =======
</TABLE>
-64-
<PAGE>
SCHEDULE III
CASTLE ENERGY CORPORATION
(PARENT)
CONDENSED STATEMENT OF CASH FLOWS
("000's" Omitted)
<TABLE>
<CAPTION>
Years Ended September 30,
----------------------------------------
1995 1994 1993
---- ---- ----
<S> <C> <C> <C>
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss) before equity in undistributed earnings of subsidiaries and
cumulative effect of a change in accounting,
includes (provisions for) recovery of income taxes................... ($56,613) ($ 3,596) $ 35,399
Adjustment to reconcile net income to net cash provided by operating
activities:
Depreciation, depletion and amortization............................. 77 66 30
Deferred income taxes................................................ 52,027 39 (38,976)
Changes in assets and liabilities:
(Increase) in accounts receivable.................................... 2,673 (1,815)
(Increase) decrease in other assets.................................. (129) 1,482 (1,342)
Increase (decrease) in accounts payable and accrued expenses......... 2,850 (795) 5,652
(Decrease) in other liabilities...................................... (1,100) (55)
--------- --------- --------
Total adjustments................................................. 57,498 (2,123) (34,691)
--------- --------- --------
Net cash flows provided by (used in) operating activities......... 885 (5,719) 708
--------- --------- --------
CASH FLOWS FROM INVESTMENT ACTIVITIES:
Proceeds from disposal of fixed assets .................................. 10
Purchase of furniture, fixtures and equipment............................ (3) (348) (40)
Business acquisition, net of cash acquired............................... (8,230)
--------- --------- --------
Net cash provided by (used in) investing activities............... 7 (8,578) (40)
--------- --------- --------
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from issuance of common stock, net.............................. 202 48,207 20
Proceeds of sale of subsidiaries......................................... 265
Loan from shareholder.................................................... 250
Purchase of treasury stock............................................... (175)
Investment in subsidiaries............................................... 3,590 (17,300)
Intercompany (advances) loans............................................ (8,346) (7,290) (654)
--------- --------- --------
Net cash provided by (used in) financing activities............... (4,554) 23,617 (294)
--------- --------- --------
Net increase (decrease) in cash and cash equivalents........................ (3,662) 9,320 374
Cash and cash equivalents - beginning of period............................. 9,729 409 35
--------- --------- --------
Cash and cash equivalents - end of period .................................. 6,067 $ 9,729 $ 409
========= ========= ========
Supplemental schedule of noncash investing and financing activities:
Purchase of Powerine Oil Company:
Basis in assets acquired............................................. $ 186,867
Cash paid for capital stock and transaction costs.................... (8,230)
---------
Basis in liabilities assumed...................................... $ 178,637
=========
Exchange of common stock:
Fair value of debt issuance/extension, processing agreement, issuance
costs, and offtake amendments........................................ $ 11,000
========
Acquisition of common stock in exchange for reduction in cash
participations....................................................... $ 39,817
=========
Debt issued in exchange for debt extensions and offtake amendments.......... $ 5,500
========
Stock issued in exchange for support of supply agreement.................... $ 855
========
Sale of properties for note................................................. $ 600
========
Options exercised for short-term receivable................................. $ 45
========
Transactions with subsidiaries:
Investment in IRLP....................................................... $ 17,355
========
Investment in natural gas marketing and transmission..................... $ 20
========
Investment in exploration and production................................. $ 10
========
Transfer third party debt from Subsidiary to Parent...................... $ 37,125
========
</TABLE>
-65-
<PAGE>
REPORT OF INDEPENDENT ACCOUNTANTS
To the Stockholders and
Board of Directors
CASTLE ENERGY CORPORATION
We have audited the consolidated financial statements of Castle Energy
Corporation ("Company") listed in the accompanying index. These financial
statements are the responsibility of the Company's management; our
responsibility is to express an opinion on these statements based on our audits.
We conducted our audits of these statements in accordance with
generally accepted auditing standards which 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,
assessing the accounting principles used and significant estimates made by
management, and evaluating the overall financial statement presentation. We
believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements audited by us
present fairly, in all material respects, the financial position of Castle
Energy Corporation and its subsidiaries at September 30, 1995 and 1994, and the
results of their operations and their cash flows for each of the three years in
the period ended September 30, 1995, in conformity with generally accepted
accounting principles.
As described in Notes 1, 3, 15, 16, 18 and 21 to the consolidated
financial statements, prior to the Company's settlement with Metallgesellschaft
Corp. ("MG") in October 1994, extensive agreements, transactions and
relationships existed between the two companies and their affiliates. In
addition, MG was a significant shareholder of the Company. As a result of these
relationships, the Company had been heavily reliant upon MG and its affiliates
in the conduct of its refining operations and for its continued viability. The
October 1994 settlement with MG significantly amended or terminated the
relationship between the Company and its affiliates and MG and its affiliates
and resulted in a $391 million gain. In 1995, the Company decided to discontinue
its refining business and recorded a $323 million write down to reflect the
estimated realizable value of its discontinued net refining assets. The
Company's continuing business consists of natural gas marketing and transmission
and oil and gas exploration and production and includes a long-term natural gas
sales agreement with Lone Star Gas Company ("Lone Star Agreement").
Approximately 95% of its 1995 revenues from continuing operations were generated
from the Lone Star Agreement.
On March 14, 1996, the Company obtained a $3.8 million credit
commitment from a financial institution. Funds borrowed will be secured by the
Company's exploration and production assets. As described in Note 25, the
Company believes that funds borrowed under the terms of this commitment will
allow it to satisfy its obligations during the next twelve months. Also, as
discussed in Note 25, on March 5, 1996, the Company engaged an investment
banking firm to explore strategic alternatives to enhance stockholder value and
to act as the Company's exclusive advisor.
As discussed in Note 2, the Company changed its method of accounting
for income taxes effective October 1, 1992.
PRICE WATERHOUSE LLP
Philadelphia, PA
March 14, 1996
-66-
<PAGE>
PART III
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
There have been no disagreements on any matter of accounting principles
or financial statement disclosure with the Company's independent accountants
during the fiscal years ended September 30, 1995, 1994 or 1993.
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND KEY EMPLOYEES
The Directors and executive officers of the Company and its significant
subsidiaries are as follows:
<TABLE>
<CAPTION>
Name Age Position(s)
---- --- -----------
<S> <C> <C>
Directors of the Company
- ------------------------
Joseph L. Castle II .................... 63 Chairman of the Board and Chief Executive Officer of the
Company
William S. Sudhaus...................... 47 Director
Sidney F. Wentz......................... 63 Director
Martin R. Hoffmann...................... 63 Director
Executive Officers of the Company
- ---------------------------------
Richard E. Staedtler.................... 51 Senior Vice President, Chief Financial Officer and Chief
Accounting Officer of the Company
Steven J. Grenfell...................... 31 Treasurer and Controller of the Company
Executive Officers of Significant
- ---------------------------------
Subsidiaries of the Company
- ---------------------------
Ryk J. Holden........................... 37 President of CEC Gas Marketing L.P. ("Marketing"), a wholly-
owned subsidiary of the Company
Harold W. Hawkins....................... 45 President of Castle Texas Pipeline L.P. ("Pipeline"), a wholly-
owned subsidiary of the Company
Timothy M. Murin........................ 40 President of Castle Texas Production L.P. ("Production") and
Castle Exploration Company, Inc ("CECI"), wholly-owned
subsidiaries of the Company
</TABLE>
A description of the business experience of each of the directors,
executive officers of the Company and executive officers of significant
subsidiaries of the Company is as follows:
Directors of the Company
Joseph L. Castle II has been a Director of the Company since 1985. Mr.
Castle is the Chairman of the Board of Directors and Chief Executive Officer of
the Company, having served as Chairman from December 1985 through May 1992 and
since December 20, 1993. Mr. Castle also served as President of the Company from
December 1985 through December 20, 1993 when he reassumed his position as
Chairman of the Board. Mr. Castle has worked in the energy industry in various
capacities since 1971. Mr. Castle is a director of The Reading Company, Comcast
Corporation, Charming Shoppes, Inc. and Mark Centers Trust, a real estate
investment trust.
William S. Sudhaus has been a director of the Company since February
1993. Mr. Sudhaus served as Executive Vice President of the Company since
February 1993 and as President and Chief Operating Officer of the Company since
December 1993. In addition, Mr. Sudhaus served as the Chairman and Chief
Executive Officer of Indian Refining Limited Partnership ("IRLP"). Mr. Sudhaus
-67-
<PAGE>
also served as Chairman and Chief Executive Officer of Powerine Oil Company
("Powerine") from October 1993 to February 1995. Effective January 1, 1996, Mr.
Sudhaus resigned from all positions with the Company and its subsidiaries except
that of director of the Company. Mr. Sudhaus was also the Chairman and Chief
Executive Officer of CORE Refining Corporation ("CORE") from March 1995. See
"Certain Relationships and Related Transactions."
Sidney F. Wentz has been Chairman of the Board of The Robert Wood
Johnson Foundation, the nation's largest health care philanthropy, since June
1989. Commencing in 1967, he held several positions with Crum and Forster, an
insurance holding company, retiring as Chairman and Chief Executive Officer in
1988. Previously, he was an attorney with the law firm of White & Case and then
Corporate Attorney for Western Electric Company/AT&T. Mr. Wentz is a director of
Ace Limited, a Bermuda-based insurance company, and a trustee for Morristown
Memorial Hospital and Drew University.
Martin R. Hoffmann is of counsel to the law firm of Skadden, Arps,
Slate, Meagher & Flom. He has been a Senior Visiting Fellow at the Center for
Technology, Policy and Industrial Development of the Massachusetts Institute of
Technology since 1993 and a private business consultant since 1993. From 1989 to
1993, Mr. Hoffmann served as Vice President and General Counsel of Digital
Equipment Corporation. Prior to assuming this position, Mr. Hoffmann practiced
law as Managing Partner of the Washington, D.C. office of Gardner, Carton and
Douglas from 1977 to 1989. Mr. Hoffmann also served in various capacities at the
United States Department of Defense, including General Counsel from 1974 to 1975
and Secretary of the Army from 1975 to 1977. He is a director of Sea Change
Technology, Inc. and a past director of E-Systems Corporation.
Executive Officers of the Company
Richard E. Staedtler has been Senior Vice President and Chief Financial
Officer of the Company since November 1994. Mr. Staedtler served as a Director
of the Company from 1986 through September 1992, and as Chief Financial Officer
of the Company from 1984 through June 1993, when he formed Terrapin Resources
Corp. ("Terrapin") to purchase Minden Energy Corporation, then a wholly-owned
subsidiary of the Company. Mr. Staedtler also serves as President of Terrapin,
which provides certain administrative services to the Company. See "Certain
Relationships and Related Transactions -- Transactions with Management and
Others."
Steven J. Grenfell has been Controller and Treasurer of the Company
since January 1996. From August 1993 to December 1995, Mr. Grenfell served as
Assistant Controller of the Company. From July 1992 to August 1993, Mr. Grenfell
served as Controller of Technology Service Group, Inc. From September 1986 to
July 1992, Mr. Grenfell was employed by Price Waterhouse LLP as a staff
accountant, senior accountant and manager.
Executive Officers of Significant Subsidiaries of the Company
Ryk J. Holden is President of Marketing, a wholly-owned subsidiary of
the Company engaged in gas marketing and gas merchant activities. Mr. Holden
became President of Marketing in January 1995. From February 1993 until January
1995, Mr. Holden was a Vice President of Business Development and Supply of MG
Natural Gas Corp. ("MGNG"), a subsidiary of Metallgesellschaft Corp. ("MG") and
President of MG Gathering Corp. ("MGG"), an indirect subsidiary of MG. (See
"Certain Relationships and Related Transactions.") From December 1987 through
January 1993, Mr. Holden held various positions with ENRON Corp.
Harold W. Hawkins became President of Pipeline in July 1995. From
December 1992 until July 1995, Mr. Hawkins was the Manager of Operations for
MGG. (See "Certain Relationships and Related Transactions.") From 1972 until
1993, Mr. Hawkins was employed in various supervisory roles by Atlantic
Richfield Company ("ARCO").
Timothy M. Murin has been the President of Production since December
1995 and has been the President of CECI since June 1993. From August 1986 to
June 1993, Mr. Murin served as the Vice President - Exploration and Production
of CECI.
SECTION 16 COMPLIANCE
Section 16(a) of the Securities Exchange Act of 1934, as amended (the
"Exchange Act"), requires the Company's officers, directors and owners of more
than 10% of any class of the Company's securities registered pursuant to Section
12 of the Exchange Act to file reports of ownership and changes in ownership
with the Commission. The Commission's rules also require such persons to furnish
the Company with a copy of all Section 16(a) reports that they file.
-68-
<PAGE>
Based solely on a review of the copies of the reports which the Company
received and written representations from certain persons, the Company believes
that, except as set forth below, all such reporting persons complied with such
requirements:
W. Arthur Benson, a director of the Company until June 5, 1995, did not
file a Form 4 report with respect to four transactions in June and July 1995,
which transactions have since been reported on a Form 5.
Richard E. Staedtler, the Company's Chief Financial Officer, was
approximately three months late in filing a Form 5 for fiscal 1995 reporting one
exempt grant of options.
ITEM 11. EXECUTIVE COMPENSATION
Summary Compensation
The following table summarizes all compensation earned by the Named
Executives for the Company's fiscal years ending September 30, 1993, 1994 and
1995. It should be noted that Messrs. Sudhaus, Wright, Gualtieri, and Hermes
were all executive officers of one or more of the Company's refining
subsidiaries during the three year period ending September 30, 1995. In
addition, Mr. Sudhaus was the Chief Operating Officer of the Company from
February 1993 until January 3, 1996. As of September 30, 1995, the Company had
discontinued all refining operations. Mr. Wright resigned from all his positions
with the Company's subsidiaries as of December 22, 1995. Messrs. Gualtieri and
Hermes resigned from all their positions with the Company's subsidiaries
effective December 31, 1995, as did Mr. Sudhaus, effective January 1, 1996. Mr.
Sudhaus did, however, continue as a director of the Company.
<TABLE>
<CAPTION>
SUMMARY COMPENSATION TABLE
Long-Term
Compensation
Awards
------------
Securities
Annual Compensation Underlying All Other
Fiscal -------------------- Options/ Severance Compensation
Name and Principal Position Year Salary($) Bonus($) SARs(#) (3) ($)
- ----------------------------- ------ --------- -------- ---------- ----------- --------------
<S> <C> <C> <C> <C> <C> <C>
Joseph L. Castle II.............. 1995 $415,625 $ 59,375
Chairman of the Board, 1994 416,667 285,000 $ 6,000(1)
Chief Executive Officer and 1993 300,000 $ 32,500 9,000(1)
Director of the Company
William S. Sudhaus............... 1995 450,000 157,500 $240,000(4)
Former President, Chief 1994 443,695 292,311 75,000 6,000(1)
Operating Officer of the 1993 409,690 122,907 37,500 7,500(1)
Company, former Chief
Executive Officer of
Powerine and IRLP and
current Director of the
Company
John D.R. Wright, III............ 1995 279,083 65,000 308,000(2)(7)
Former President and Chief 1994 273,114 50,000
Operating Officer of IRLP 1993 260,250 50,000 87,500(2)
A. L. Gualtieri.................. 1995 289,361 74,900 140,000(4) 21,748(5)
Former President and Chief 1994 333,754 53,202 50,000 207,103(4)
Operating Officer of 1993
Powerine
David M. Hermes.................. 1995 201,983 118,500 304,000(4) 140,219(8)
Former Senior Vice 1994 181,042 262,875 50,000
President, Raw Material 1993 196,875 37,500 16,666
Supply of Indian Powerine
L.P., a wholly-owned
subsidiary of the Company
</TABLE>
-69-
<PAGE>
- ---------------------
(1) Directors' fees.
(2) Mr. Wright was granted 175,000 stock appreciation rights ("SARs") pursuant
to a Bonus Payment Rights Agreement dated October 1, 1991 among Mr. Wright,
IRLP and Indian Refining & Marketing, Inc. ("IR&M"), the general partner of
IRLP. Pursuant to an Amendment to Agreement dated as of February 25, 1993,
IR&M, IRLP and Mr. Wright agreed to reduce the number of SARs then held by
Mr. Wright from 175,000 to 87,500. In addition, the terms of the SARs held
by Mr. Wright were amended to provide that (a) until the aggregate amount
received by Mr. Wright upon exercise of SARs equals $2 million, each SAR
would be exercisable for the sum of (i) the amount (the "Basic Value") by
which the average closing price of shares of Common Stock of the Company
for the 20 trading days prior to the date of exercise exceeds the base
price of $8.00, plus (ii) the Basic Value up to $11.42 (the "Incremental
Value"); (b) thereafter and until the aggregate Basic Value of the SARs to
be exercised equals the aggregate Incremental Value received by Mr. Wright
described in (a) above, Mr. Wright would not receive any amount upon the
exercise of SARs; and (c) thereafter, each SAR would be exercisable for the
Basic Value. In January 1996, Mr. Wright surrendered his SARs as part of
his severance agreement with IRLP in consideration for a payment of
$308,000 see "Employment Agreements."
(3) Represents severance expense which, although accrued in fiscal 1995, was
not paid until fiscal 1996.
(4) Amounts paid as consideration for termination of prior employment contract.
(5) Consists of car allowance and vacation payout.
(6) Amounts paid as consideration for termination of prior employment contract.
(7) Proceeds received for surrender of SARs; recorded as expense in fiscal 1995
but paid in fiscal 1996.
(8) Proceeds received for exercise of SARs.
Option Grants in Last Fiscal Year (Year Ended September 30, 1995)
No options were granted to Named Executives during the fiscal year
ended September 30, 1995.
Option/SAR Exercises And Option/SAR Values
The following table shows the number of SAR's exercised during the year
ended September 30, 1995 by Named Executives, the value realized upon such
exercise and the total number of unexercised options and SARs held at September
30, 1995 by such officers. The table also shows the values for unexercised
"in-the-money" options and SARs which represent the positive spread between the
exercise price of such stock options or SARs and the fair market value of the
shares of Common Stock as of September 30, 1995 which was $9.50 per share.
-70-
<PAGE>
AGGREGATED OPTION/SAR EXERCISES IN LAST FISCAL YEAR AND
FISCAL YEAR END OPTION/SAR VALUES
<TABLE>
<CAPTION>
Number of
Securities
Underlying Value of
Unexercised Unexercised
Options/SARs in-the-Money
at Fiscal Year-End Options/SARs
(September 30, 1995) at Fiscal Year-End
Shares Value (#) ($)
Acquired on Realized Exercisable/ Exercisable/
Name Exercise (#) ($) Unexercisable Unexercisable
---- -------------- ----- --------------- --------------
<S> <C> <C> <C> <C>
Joseph L. Castle II 0 - 91,875/8,125 $236,250/-
William S. Sudhaus 0 - 85,625/26,875 -/-
John D.R. Wright, III 0 - 87,500/- -/-
A. L. Gualtieri 0 - 37,500/12,500 -/-
David M. Hermes 20,000(1) 140,219 50,000/16,667 -/-
</TABLE>
- ----------------
(1) Represents the number of shares with respect to which SARs were exercised.
Subsequent to September 30, 1995, Mr. Sudhaus surrendered all 150,000
of his SARs upon his resignation from the Company and Mr. Wright surrendered
all 87,500 of his SARs as part of his severance agreement with IRLP. See
"Employment Agreements":
Pension Plans
The Company has no defined benefit pension plans.
IRLP Retirement Plan. IRLP established a defined benefit retirement
plan (the "IRLP Retirement Plan") commencing January 1, 1991. All employees of
IRLP and IPLP, including officers, were eligible for benefits under the IRLP
Retirement Plan commencing on the first January 1 after attaining 20.5 years of
age and five years of service with IRLP or IPLP. The IRLP Retirement Plan is
administered by a trustee and is funded at amounts required by the Employee
Retirement Income Security Act of 1974, as amended.
The table below shows the estimated annual retirement benefits at age
65 to participants in the IRLP Retirement Plan.
PENSION PLAN TABLE
------------------
Average Earnings Years of Service(1)
- ---------------- -------------------
15 20 25 30 35
-- -- -- -- --
$125,000 $14,880 $19,840 $24,800 $29,760 $34,720
$150,000 and 16,755 22,340 27,925 33,510 39,095
greater
- ---------------
(1) Employees are generally entitled to annual retirement benefits equal to
1.1% of average earnings up to compensation covered by social security and
0.5% of average earnings that exceed compensation covered by social
security, up to a maximum of $150,000. Such annual benefit is multiplied by
the years of service up to a maximum of 35 years.
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Average earnings are generally computed based upon all salary and
bonuses received by each eligible employee during the five highest paid
compensation years during the last ten years before retirement.
Employees may retire at age 65 or at age 62 if they have 20 years of
vested service.
As of September 30, 1995, the Named Executives were credited under the
IRLP Retirement Plan with the years of service indicated: William S. Sudhaus,
five years; John D.R. Wright III, four years; and David M. Hermes, four years.
On December 12, 1995, IRLP sold the Indian Refinery to American Western
Refining L.P. ("American Western"), a subsidiary of Gadgil Western Corp
("Gadgil"). As part of the sale, the IRLP Retirement Plan was transferred to
American Western.
Compensation of Directors
All of the Outside Directors are paid director's fees of $25,000 per
year. In addition, all Directors received fees for attending meetings of the
Board of Directors. Until March 23, 1995, the fee per meeting was $1,500.
Thereafter, it was reduced twenty-five percent (25%) to $1,125. Committee
members also receive a fee for attending a committee meeting. Such fee was $500
per meeting until March 23, 1995 and $375 per meeting thereafter.
In addition each Outside Director is granted an option to purchase
5,000 shares of Common Stock each calendar year on the earlier to occur of (a)
the first trading day coinciding with or immediately following the fifteenth day
after the Company's regular Annual Stockholders' Meeting or (b) the first
trading day in May, for serving as a director. The Company issued to each of
Messrs. Bonovitz and Sullivan options to purchase 5,000 shares of Common Stock
at $11.75 per share for 1994 and options to purchase another 5,000 shares of
Common Stock at $9.00 per share for 1995.
In addition to the foregoing, Mr. Sullivan was paid a special fee of
$40,000 related to meetings concerning the disposition of the Company's refining
operations.
Employment Agreements
Employment Agreements among the Company and certain of its subsidiaries
and the Named Executives are described below:
Effective January 1, 1994, Joseph L. Castle II entered into an
Employment Agreement with the Company pursuant to which Mr. Castle agreed to
serve as Chairman and Chief Executive Officer of the Company through December
31, 1995. This agreement provided for Mr. Castle to receive annual compensation
at the rate of $475,000 plus cost of living increases and discretionary bonuses
to be determined by the Compensation Committee of the Board of Directors (the
"Compensation Committee"). Mr. Castle's agreement also provided that he would be
entitled to receive certain separation pay and benefits in the event that the
Company fails to renew the agreement or following a change in control of the
Company, as such event is described in the agreement. Under the agreement, a
change in control included any person becoming the beneficial owner of more than
50% of the Company's voting stock or the sale of all or substantially all of the
assets of the Company. Mr. Castle has agreed to waive any such payments which
might have resulted from the Company's disposition of its refining operations.
In addition, Mr. Castle's agreement provides certain benefits upon Mr. Castle's
retirement from the Company. Upon retirement, subject to certain conditions set
forth in the agreement, Mr. Castle will be entitled to receive, for life, 20% of
his annual base salary, as defined in the agreement, or one of three actuarially
equivalent benefits.
Effective April 1, 1995, Mr. Castle's annual salary was reduced
twenty-five percent (25%) to $356,250 with his consent. At September 30, 1995,
Mr. Castle' accrued retirement benefits aggregated $984,577. The Company has not
renewed Mr. Castle's employment agreement which expired December 31, 1995.
Effective January 1, 1994, William S. Sudhaus entered into an Amended
and Restated Employment Agreement with the Company pursuant to which Mr. Sudhaus
agreed to serve as President and Chief Operating Officer of the Company and
Chairman and Chief Executive Officer of IRLP and Powerine. This agreement
provided for Mr. Sudhaus to receive annual compensation at the rate of $450,000
plus cost of living increases and bonuses based on the profitability of the
refining subsidiaries, and discretionary bonuses to be determined by the
Compensation Committee. The agreement also provided that Mr. Sudhaus would be
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entitled to receive certain separation pay and benefits following a change in
control of the Company, as such event is defined in the agreement. Under the
agreement, a change in control included any person becoming the beneficial owner
of more than 50% of the Company's voting stock, any such person having nominated
or designated more than 50% of the Company's directors, or the sale of all or
substantially all of the assets of the Company.
Effective April 1, 1995, Mr. Sudhaus agreed to a fifteen percent (15%)
reduction in his annual salary to $382,500 but the agreement included a
provision that such salary reduction would be restored retroactively under
certain conditions, including the failure to consummate a management buyout of
the Indian Refinery.
Effective, January 3, 1996, Mr. Sudhaus resigned from all executive
officer positions he held in the Company and its refining subsidiaries and the
Company and Mr. Sudhaus entered into a severance agreement which was effective
January 1, 1996. Under the terms of the severance agreement, Mr. Sudhaus
received $240,000 from the Company and surrendered his 150,000 SARs to the
Company for additional consideration of $500,000 to be paid over nine months.
The Company has paid Mr. Sudhaus $351,112 through February 29, 1996. The
remaining $388,888 is payable in equal monthly installments through September
30, 1996 but prepayment of the remaining balance is required upon the sale of
substantially all of the Company's remaining assets or if certain financing is
received by the Company.
Mr. Sudhaus remains a director of the Company.
On October 1, 1991, John D.R. Wright, III entered into an Employment
Agreement with IR&M and IRLP, as amended on February 25, 1993, pursuant to which
Mr. Wright agreed to serve as President and Chief Operating Officer of IR&M
through January 31, 1996. This agreement provided for Mr. Wright to receive
annual compensation at the rate of $250,000 plus cost of living increases and
bonuses based on achievement of certain targeted levels of performance by the
Indian Refinery and based on the profitability of IRLP. Mr. Wright's agreement
also provided that he would be entitled to receive certain separation pay and
benefits following a change in control of IRLP, as such event is described in
the agreement. Under the agreement, a change in control occurs if neither the
Company nor MG owns at least 50% of the equity interests in IRLP or if IRLP no
longer owns at least 50.01% of the Indian Refinery. In connection with Mr.
Wright's agreement, Mr. Wright was also a party to a Bonus Payment Rights
Agreement, dated October 1, 1991, as amended on February 25, 1993, with IR&M and
IRLP pursuant to which Mr. Wright received 87,500 SARs from IR&M.
Effective April 1, 1995, Mr. Wright agreed to a fifteen percent (15%)
salary reduction but the related agreement included a provision that such
reduction would be restored under certain conditions, including the failure to
consummate a management buyout of the Indian Refinery. Subsequent to September
30, 1995, Mr. Wright's salary reduction was restored retroactive to April 1,
1995.
On December 22, 1995, Mr. Wright resigned from all positions he held in
IR&M and IRLP. In January 1996, the Company and Mr. Wright entered into a
severance agreement whereby Mr. Wright was paid $308,000 and Mr. Wright agreed
to surrender the 87,500 SARs he owned. The $308,000 consisted of $58,000 cash
and the discharge of a $250,000 note owed to IR&M by Mr. Wright.
On April 1, 1994, A. L. Gualtieri entered into an Employment Agreement
with Powerine, a wholly-owned refining subsidiary, pursuant to which Mr.
Gualtieri agreed to serve as President and Chief Operating Officer of Powerine
through December 31, 1995. This agreement provided for Mr. Gualtieri to receive
annual compensation at the rate of $280,000 plus cost of living increases and
discretionary bonuses based on achievement of certain targeted levels of
performance of Powerine as determined by the Compensation Committee. Mr.
Gualtieri's agreement also provided that he would be entitled to receive certain
separation pay and benefits following a change in control of Powerine, as such
event is described in the agreement. Under the agreement, a change in control
includes any person becoming the beneficial owner of more than 50% of the
Company's or Powerine's voting stock or the sale of all or substantially all of
the assets of Powerine. Mr. Gualtieri was elected Chairman and Chief Executive
Officer of Powerine, in addition to President, in February 1995.
In November 1995, Mr. Gualtieri informed Powerine that he would resign
as of December 31, 1995. Powerine and Mr. Gualtieri were unable to agree upon
the amount of compensation to which Mr. Gualtieri was entitled under his
employment agreement as a result of his resignation. In December 1995, Powerine
paid Mr. Gualtieri $140,000 as severance compensation. Effective January 16,
1996 Powerine sold its remaining assets pursuant to a merger with a subsidiary
of Energy Merchant Corp. ("EMC") and EMC became responsible for Mr. Gualtieri's
unsatisfied severance compensation claims.
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On February 14, 1992, David M. Hermes entered into an Employment
Agreement with IR&M, Powerine and IP Oil Company ("IPCO"), another wholly-owned
refining subsidiary of the Company, as amended on March 1, 1993, March 2, 1994
and May 9, 1994, pursuant to which Mr. Hermes agreed to serve as Senior Vice
President, Raw Material Supply of IR&M, Powerine and IPCO through February 28,
1997. The agreement, which was guaranteed by the Company, provided for Mr.
Hermes to receive annual compensation at the rate of $200,000 plus cost of
living increases and discretionary bonuses based on achievement of certain
targeted levels of performance by IR&M. In addition, Mr. Hermes was advanced
$75,000 in 1992, which amount was either to be applied against Mr. Hermes'
future compensation or to be repaid if Mr. Hermes' employment was terminated
under certain circumstances prior to February 29, 1996. In connection with Mr.
Hermes's agreement, Mr. Hermes also entered into a Bonus Payment Rights
Agreement, dated February 12, 1992, pursuant to which Mr. Hermes received 20,000
SARs which were exercised on November 4, 1994, for which Mr. Hermes received
$140,219.
In January 1996, the Company and Mr. Hermes entered into a severance
agreement, which was effective December 31, 1995. Under the terms of the
severance agreement, Mr. Hermes resigned from all of his positions with IR&M,
Powerine and IPCO. In return, the Company agreed to pay Mr. Hermes $304,000 and
discharged a $75,000 advance from the Company to Mr. Hermes. Of this amount.
$152,500 had been paid by February 28, 1996. The remaining $151,500 is payable
in equal monthly installments through August 31, 1996.
As of February 28, 1996, neither the Chief Executive Officer nor any of
the Named Executive officers had an employment contract with the Company,
although Mr. Castle is entitled to benefits from his employment contract which
terminated December 31, 1995. All of the Named Executive officers, other than
Mr. Castle, have terminated their positions with the Company and its
subsidiaries except Mr. Sudhaus who continues as a director of the Company.
Retention Bonus Program
On March 17, 1994, the Compensation Committee approved a retention
bonus program (the "Retention Bonus Program") pursuant to which the Compensation
Committee could, in its sole discretion, award a retention bonus to any covered
executive in any calendar quarter during which the Retention Bonus Program is in
effect. The covered executives included each of the Named Executives. Each
retention bonus award could include one or both of: (a) an acceleration of the
payment of a designated percentage of the covered executive's then current
annual performance bonus, not to exceed 100% of such performance bonus prorated
on a quarterly basis; and (b) the payment of an additional bonus which for any
quarter may not aggregate more than 7.5% of such executive's base salary. The
Retention Bonus Program also contemplated that a retention bonus pool be
established for employees other than the covered executives. The Compensation
Committee could have made retention bonus awards from this bonus pool in its
sole discretion. The Board of Directors terminated the Retention Bonus Program
effective December 31, 1994.
During the fiscal year ended September 30, 1995, Mr. Castle earned and
received $59,375, Mr. Sudhaus earned and received $157,500 and Mr. Gualtieri
earned and received $74,900 under the Retention Bonus Program. Mr. Hermes earned
and received a discretionary bonus of $118,500.
Compensation Committee Interlocks and Insider Participation
During fiscal 1995, the Compensation Committee consisted of Sheldon M.
Bonovitz, Chairman, John W. Sullivan and, until his cessation of service as a
director on June 5, 1995, Warren V. Musser.
During fiscal 1995, the Company engaged the law firm of Duane, Morris &
Heckscher, of which Mr. Bonovitz is Vice Chairman and a partner, to provide
legal services for the Company. In May 1995, Duane, Morris & Heckscher became
general counsel of the Company.
On December 11, 1991, John W. Sullivan and a financial institution
entered into a Loan Agreement with the Company pursuant to which Mr. Sullivan
loaned the Company $250,000 (the "Sullivan Loan"). The Sullivan Loan matures on
June 30, 1996 and earns interest at the annual rate of LIBOR plus one-half of
one percent established in advance on November 21 of each year while the
Sullivan Loan is outstanding. Interest is payable annually on December 31 of
each year and at maturity of the Sullivan Loan. The Company may elect to pay
interest in either cash or Common Stock. Should the Company elect to pay
interest in Common Stock, Mr. Sullivan may elect to capitalize the interest in
lieu of accepting the Common Stock. The Company paid $8,139 to Mr. Sullivan as
interest during the year ended September 30, 1995. The Company repaid $125,000
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for the Sullivan Loan subsequent to September 30, 1995. The remaining principal
balance is payable in two installments of $62,500 each on March 31, 1996 and
June 30, 1996.
Mr. Bonovitz resigned as a Director on October 6, 1995. Mr. Sullivan
resigned as a director on January 5, 1996.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
PRINCIPAL HOLDERS OF VOTING SECURITIES
The following table sets forth, as of March 15, 1996, the names of all
persons who were known by the Company to be the beneficial owners (as defined in
the rules of the Securities and Exchange Commission (the "Commission") of more
than five percent of the shares of Common Stock of the Company:
<TABLE>
<CAPTION>
Amount and Nature of Percent of
Name and Address of Beneficial Owner Beneficial Ownership(1) Class(1)
- ------------------------------------ ----------------------- --------
<S> <C> <C>
FMR Corp. 988,750(2) 14.77%
82 Devonshire Street
Boston, Massachusetts 02109
Joseph L. Castle II and Sally W. Castle 539,883(3) 7.96%
One Radnor Corporate Center, Suite 250
100 Matsonford Road
Radnor, Pennsylvania 19087
First Pacific Advisors Inc. 525,000(5) 7.84%
11400 West Olympic Boulevard, Suite 1200
Los Angeles, California 90064
Brandywine Asset Management, Inc. 466,500(6) 6.97%
3 Christina Center, 201 N. Walnut Street
Wilmington, Delaware 19801
Corbyn Investment Management, Inc. 409,525(4) 6.12%
Suite 108
2330 W. Joppa Road
Lutherville, Maryland 21093
</TABLE>
- ----------
(1) Based on a total of 6,693,646 shares of Common Stock issued and outstanding
as of March 15, 1996. In calculating each respective holder's percentage
ownership and beneficial ownership in the table above, shares of Common
Stock which the holder has the right to acquire within 60 days are
included.
(2) These shares are beneficially owned by Fidelity Management & Research
Company as a result of its serving as investment adviser to various
investment companies registered under Section 8 of the Investment Company
Act of 1940 and as investment adviser to certain other funds which are
generally offered to limited groups of investors. Based on information
furnished by stockholder as of February 14, 1996, the most recent date as
of which such information was so furnished.
(3) Joseph L. Castle II and Sally W. Castle are husband and wife. As such, each
is deemed to beneficially own 539,883 shares of Common Stock. Includes (a)
410,733 shares of Common Stock owned by Mr. Castle and 37,275 shares of
Common Stock owned by Mrs. Castle; (b) 67,500 shares of Common Stock
issuable upon exercise of options which are exercisable within 60 days by
Mr. Castle at $6.00 per share; (c) 24,375 shares of Common Stock issuable
upon exercise of options which are exercisable within 60 days by Mr. Castle
at $12.25 per share.
(4) These shares are beneficially owned by a group consisting of Corbyn
Investment Management, Inc., an investment adviser registered under the
Investment Advisers Act of 1940 and Greenspring Fund, Inc., an investment
company registered under the Investment Company Act of 1940 and for which
Corbyn Investment Management, Inc. serves as investment adviser. Based upon
information furnished by stockholder as of January 25, 1996.
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(5) Based on information furnished by stockholder as of February 13, 1996, the
most recent date as of which such information was so furnished.
(6) Based on information furnished by stockholder as of February 22, 1996, the
most recent date as of which such information was so furnished.
SECURITY OWNERSHIP OF MANAGEMENT
The following table sets forth, as of March 15, 1996, the shares of
Common Stock beneficially owned by each of the Company's Chief Executive Officer
and the Company's four other most highly compensated executive officers during
fiscal 1995 (the "Named Executives"), by each Director and nominee for Director
of the Company and by the Directors, nominee and executive officers of the
Company as a group, with sole voting and investment power unless otherwise
indicated:
<TABLE>
<CAPTION>
Amount and Nature of Percent of
Name of Beneficial Owner Beneficial Ownership (1) Class (1)(2)
- ------------------------ ------------------------ -------------
<S> <C> <C>
Joseph L. Castle II............................................ 539,883(3) 7.96%
William S. Sudhaus (9)......................................... 85,625(4) 1.26%
David M. Hermes (9)............................................ 50,000(5)
John D.R. Wright, III (9)...................................... 0
A.L. Gualtieri (9)............................................. 37,500(6)
Martin R. Hoffmann............................................. 2,000(7)
Sidney F. Wentz................................................ 0
All Directors, Nominees and Executive Officers
as a group (12 persons)........................................ 757,783(8) 10.82%
</TABLE>
- -------------
(1) Based on a total of 6,693,646 shares of Common Stock issued and outstanding
as of March 15, 1996. In calculating each respective holder's percentage
ownership and beneficial ownership in the table above, shares of Common
Stock which the holder has the right to acquire within 60 days are
included.
(2) Percentages of less than one percent are omitted.
(3) Joseph L. Castle II and Sally W. Castle are husband and wife. As such, each
is deemed to beneficially own 539,883 shares of Common Stock. Includes (a)
410,733 shares of Common Stock owned by Mr. Castle and 37,275 shares of
Common Stock owned by Mrs. Castle; (b) 67,500 shares of Common Stock
issuable upon exercise of options which are exercisable within 60 days by
Mr. Castle at $6.00 per share; and (c) 24,375 shares of Common Stock
issuable upon exercise of options which are exercisable within 60 days by
Mr. Castle at $12.25 per share.
(4) Represents (a) 61,250 shares of Common Stock issuable upon exercise of
options which are exercisable within 60 days by Mr. Sudhaus at $11.00 per
share and (b) 24,375 shares of Common Stock issuable upon exercise of
options which are exercisable within 60 days by Mr. Sudhaus at $12.25 per
share.
(5) Represents (a) 12,500 shares of Common Stock issuable upon exercise of
options which are exercisable within 60 days by Mr. Hermes at $12.25 per
share and (b) 37,500 shares of Common Stock issuable upon exercise of
options which are exercisable within 60 days by Mr. Hermes at $11.00 per
share.
(6) Represents shares of Common Stock issuable upon exercise of options which
are exercisable within 60 days by Mr. Gualtieri at $11.00 per share.
(7) These shares are held by an Individual Retirement Account for the benefit
of Mr. Hoffmann.
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(8) Includes 307,500 shares of Common Stock issuable upon exercise of options
which are exercisable within 60 days, including 173,125 options exercisable
by Messrs. Sudhaus, Hermes and Gualtieri (see below).
(9) At March 15, 1996, Messrs. Sudhaus, Hermes, Wright and Gualtieri were no
longer executive officers of the Company or any of its significant
subsidiaries.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS:
TRANSACTIONS WITH MANAGEMENT AND OTHERS
Stockholder Loan
See "Compensation Committee Interlocks and Insider Participations."
Legal Fees
Mr. Craig Culbertson, a former officer of the Company and several of
its subsidiaries, is also a partner in a law firm. The law firm served as
general counsel to the Company until June 1995 and has remained as special
counsel thereafter. Subsequent to September 30, 1995, Mr. Culbertson resigned
from all positions he held in the Company and its subsidiaries. During the year
ended September 30, 1995, the Company and its subsidiaries incurred legal fees
of $2,593,000 to the law firm.
Loan to Officer
On February 26, 1993, John D.R. Wright, III, an officer of a
subsidiary, was loaned $250,000. The principal amount of the loan was due and
payable in full on the earlier of January 31, 1996 or the termination of the
officer's employment. The loan accrued interest at the prime rate in effect on
the date of the loan as adjusted each January 1. Mr. Wright terminated his
employment on December 22, 1995. The loan and accrued interest was offset
against amounts due to Mr. Wright for his surrender of his stock appreciation
rights (see "Executive Compensation").
Management Fees
On March 31, 1993, the Company entered into an agreement to sell to
Terrapin its oil and gas partnership management businesses for $1,100,000
($800,000 note bearing interest at 8% per annum and $300,000 cash) which
approximated the book value of its partnership interests. The closing of the
stock purchase transaction occurred on June 30, 1993. Terrapin is wholly-owned
by Richard Staedtler. Mr. Staedtler was an executive officer of the Company from
September 1983 until June 1993. In November 1994, he rejoined the Company as
its Chief Financial Officer.
In conjunction with the sale of its partnership management business,
the Company and one of its subsidiaries entered into two management agreements
with Terrapin to manage its exploration and production operations. Management
fees incurred to Terrapin for the year ended September 30, 1995 aggregated
$584,000.
Payment of Legal Fees for Former Director
In conjunction with its settlement with MG in October 1994, the Company
paid certain legal fees incurred by Mr. W. Arthur Benson, who was a director of
the Company until June 6, 1995. During the year ended September 30, 1995, the
Company paid $327,000 of legal fees on behalf of Mr. Benson.
CORE
In October 1994, the Company decided to dispose of its refining
operations. During the period from October 14, 1994 until September 29, 1995,
the Company financed three efforts to sell both or one of its two refineries to
CORE (previously SIPAC, Inc.). CORE is wholly-owned by Mr. William Sudhaus.
Until his resignation in January 1996, Mr. Sudhaus was an executive officer of
the Company and the Chairman of the Board and Chief Executive Officer of several
refining subsidiaries of the Company. He remains a director of the Company.
Under the terms of agreements with CORE, the Company was obligated to reimburse
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CORE for certain expenses paid by CORE in its attempts to obtain financing for a
management buyout of one or both of the Company's refineries. Such agreements
also provided that the Company would be repaid for most of such funding should
CORE be successful. In September 1995, the final CORE attempt to obtain
financing failed. During the year ended September 30, 1995, the Company and its
subsidiaries incurred $3,768,000 of reimbursement obligations related to CORE.
EXERCISE/DISCHARGE OF SARs
In November 1992, the Company granted William Sudhaus, an executive
officer, 112,500 SARs in exchange for his partnership interests in IRLP. The
exercise price was $6.00. In June 1993, the Company granted Mr. Sudhaus an
additional 150,000 SARs in exchange for the remaining partnership interests in
IRLP owned by Mr. Sudhaus. The exercise price was $12.50. In November 1994, Mr.
Sudhaus received $1,026,035 upon exercising the first 112,500 SARs. In January
1996, Mr. Sudhaus exchanged the remaining 150,000 SARs for $500,000.
CERTAIN BUSINESS RELATIONSHIPS
MG AND ITS AFFILIATES
Immediately prior to the MG Settlement described in greater detail
below, in excess of 40% of the Company's outstanding common stock was owned by
Metallgesellschaft Corp. ("MG"), a wholly-owned subsidiary of Metallgesellschaft
AG ("MG AG"), a German conglomerate. From August 1989 until the MG Settlement,
the Company and its subsidiaries entered into many agreements with MG and its
affiliates, including agreements pursuant to which MG and its affiliates
financed the Company's refining and natural gas marketing operations, purchased
all of the Company's refined product output, and supplied natural gas to the
Company for resale under a long-term contract to a third party. In December
1993, the Company was informed that MG and MG AG had incurred substantial cash
expenditures and losses related in part to margin payments required by the New
York Mercantile Exchange and various over-the-counter derivatives trading
counterparties as a result of a decline in oil prices. Thereafter, in its annual
report issued in February 1994, MG AG announced that its consolidated net loss
for fiscal 1993 was DM 2.025 billion ($1.241 billion).
As a result of the financial difficulties surrounding MG and its
affiliates, the Company became concerned that MG and its affiliates would be
unable to perform their obligations under their agreements with the Company or
might seek to avoid performance through litigation challenging the validity of
some or all of such agreements. Although the Company believed it would be
successful in any litigation seeking to enforce the agreements, the Company also
believed that the risks and substantial costs of such litigation, including the
risk of being unable to collect any damages which might be awarded, as well as
the disruption to the Company's business, made litigation undesirable. In
addition, the Company believed that MG might enter bankruptcy and seek to reject
some or all of such agreements, in which case the Company would be likely to
recover little if any damages. In addition, relationships between the Company
and MG, as a major stockholder of the Company, had become adversarial, which the
Company believed was not in the best interests of the Company or its other
stockholders. Accordingly, in July 1994 the Company and MG commenced
negotiations to attempt to restructure the contractual and other relationships
between MG and its affiliates and the Company and its affiliates.
On August 31, 1994, the Company entered into two agreements with MG and
certain of its affiliates pursuant to which the parties thereto agreed to amend
or terminate a number of contractual relationships among them (the "MG
Settlement"). In the first step of the MG Settlement, which closed on September
9, 1994, MG transferred 3.6 million shares of Common Stock to the Company in
exchange for approximately $39.8 million of participations the Company held in
debt obligations of the Company and its affiliates to MG Trade Finance Corp.
("MGTFC"), a wholly-owned subsidiary of MG.
In the second step of the MG Settlement, which closed on October 14,
1994, MG (a) cancelled certain debt obligations owed to MGTFC by the Company and
its affiliates, and assumed IRLP's obligations under its $120 million senior
facility with Societe Generale (the "Senior Facility"), together totaling
approximately $322 million, (b) transferred back to the Company the remaining
969,000 shares of Common Stock held by MG and a $5.5 million debenture
convertible into 500,000 shares of Common Stock, (c) issued to the Company a $10
million note payable in three years (the "MG Note"), (d) terminated all of its
interests in the Company's natural gas operations and (e) agreed to supply all
crude oil necessary for the Company to meet its delivery obligations under a
forward sale contract with a third party entered into in September 1993. In
exchange for the foregoing, IRLP and Powerine (i) amended their offtake
agreements (the "Indian Offtake Agreement" and the "Powerine Offtake Agreement,"
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respectively and collectively the "Offtake Agreements") to terminate effective
February 1, 1995 although sales under the Powerine Offtake Agreement were to
continue subsequently, (ii) amended their working capital facilities to
terminate on March 31, 1995, and (iii) transferred to MG certain of the
Company's participations in debt obligations of the Company and its affiliates
to MGTFC. In connection with the MG Settlement, IRLP and MGNG also entered into
a four-year natural gas swap agreement.
As a result of the MG Settlement, MG's ownership of the Company's
common stock was reduced to zero and most of the related party transactions
between MG and its affiliates and the Company and its affiliates were terminated
or restructured except as outlined below. Furthermore, as of October 14, 1994,
the consummation of the MG Settlement, MG and its affiliates ceased to be a
related party.
On April 14, 1995, Powerine repaid all of the indebtedness owed by it
to MGTFC, including $10,828,000 of disputed amounts (the "Disputed Amount"). On
the same day, the Company and two of its subsidiaries and MG and two of its
subsidiaries entered into the Payoff Loan and Pledge Agreement ("Payoff
Agreement), which provided the following:
a. MG released Powerine from all liens and claims.
b. MG loaned the Company $10,000,000.
c. Powerine transferred its claim with respect to the Disputed Amount to
the Company.
d. The claim with respect to the Disputed Amount was submitted to
binding arbitration (the "Powerine Arbitration").
e. MG can offset the $10,000,000 loan to the Company against the
$10,000,000 MG note it issued to the Company as part of the MG
Settlement, to the extent the arbitrator decides the claim with
respect to the Disputed Amount in MG's favor.
The Disputed Amount relates primarily to disputes over the prices paid
by subsidiaries of MG for 388,500 barrels of refined products lifted by MG's
subsidiary, MGRM, and nonpayment for refined products that were processed after
January 31, 1995 and that MGRM was obligated to, but did not, lift and pay for.
To the extent that the arbitrator decides in favor of the Company, the Company's
note to MG will be reduced and the net amount due to the Company from MG will be
increased. If the arbitrator settles the Disputed Amount entirely in the
Company's favor, the Company's note to MG will be cancelled, MG will still owe
the Company its $10 million note (due October 14, 1997) and MG will also owe the
Company $828,000. If the arbitrator settles the Disputed Amount entirely in MG's
favor, the Company's note from MG will be discharged. In such case the Company's
future earnings will also be adversely impacted since the Company has not
recorded any reserve against the note.
On September 8, 1995, the Company filed its Statement of Claim and
Memorandum. On December 6, 1995, MG filed its Notice of Defense and Response to
Claimant's Statement of Claim and Memorandum. The Company filed a reply on
February 14, 1996, and the parties are proceeding with discovery as to the
amount of damages.
In January 1996, MG did not pay interest on the $10,000,000 note when
such interest was due. As a result, the entire note is due to be paid to the
escrow account for the Powerine Arbitration. The Company has demanded that MG
pay the entire note.
DUANE, MORRIS & HECKSCHER
During the period from October 1, 1994 to October 4, 1995, Mr. Sheldon
Bonovitz served as a director of the Company. Mr. Bonovitz is also a member of
the law firm of Duane, Morris & Heckscher. During the fiscal year ended
September 30, 1995, the Company engaged Duane, Morris & Heckscher to perform
legal services. In May 1995, Duane, Morris & Heckscher became the Company's
general counsel.
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<PAGE>
ITEM 14. EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
(a) 1. and 2. Financial Statements and Financial Statement Schedules
Financial statements and schedules filed as part of this Report on Form 10-K
are listed in Item 8 to this Form 10-K.
3. Exhibits
The Exhibits required by Item 601 of Regulation S-K and filed herewith or
incorporated by reference herein are listed in the Exhibit Index below.
<TABLE>
<CAPTION>
Exhibit Number Description of Document
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<S> <C>
3.1 Restated Certificate of Incorporation(15)
3.2 Bylaws(10)
4.1 Specimen Stock Certificate representing Common Stock(8)
4.2 Rights Agreement between Castle Energy Corporation and American Stock Transfer and Trust
Company as Rights Agent, dated as of April 21, 1994(10)
10.1 Credit Agreement between Castle Energy Corporation and MG Trade Finance Corp., dated
October 24, 1990(1)
10.2 Sixth Amendment to Credit Agreement, effective as of May 27, 1993, between MG Trade Finance
Corp. and Castle Energy Corporation(2)
10.3 Seventh Amendment to Credit Agreement, dated August 25, 1993, between MG Trade Finance Corp.
and Castle Energy Corporation(8)
10.4 Amended and Restated Revolving Loan and Security Agreement, dated May 27, 1993, among Indian
Refining Limited Partnership, Indian Refining & Marketing Inc. and MG Trade Finance Corp.(8)
10.5 Purchase and Sale Agreement, dated September 3, 1992, by and among Castle Energy Corporation,
Atlantic Richfield Company, Tabasco Gas Pipe Line Company and B&A Marketing Company(6)
10.6 Loan Agreement, dated December 11, 1991, among Castle Energy Corporation, Union d'Etudes et
d'Investissements and John W. Sullivan with MG Trade Finance Corp. joining for the limited purpose
stated therein(3)
10.7 Intercreditor Agreement, dated December 11, 1991, among MG Trade Finance Corp., Union d'Etudes
et d'Investissements and John W. Sullivan(3)
10.8 Amended and Restated Offtake Agreement, dated May 12, 1993, between Indian Refining Limited
Partnership and MG Refining and Marketing, Inc.(8)
10.9 Agreement for the Purchase and Sale of Feedstocks, dated February 1, 1992, between
Metallgesellschaft Corp. and Indian Refining Limited Partnership(4)
10.10 Amendment 1 to Agreement for the Purchase and Sale of Feedstocks, dated February 1, 1992,
between Metallgesellschaft Corp. and Indian Refining Limited Partnership(5)
10.11 Amendment No. 2 to Agreement for the Purchase and Sale of Feedstocks, dated June 29, 1993,
between Metallgesellschaft Corp. and Indian Refining Limited Partnership(8)
10.12** Long Term Supply Agreement, dated November 1, 1992, among Shell Canada Limited, Salmon
Resources Ltd. and Indian Refining Limited Partnership, Indian Refining & Marketing Inc. and MG
Refining and Marketing, Inc.(7)
10.13 First Amendment to Long Term Supply Agreement, dated as of January 12, 1993, among Indian
Refining Limited Partnership, Indian Refining & Marketing Inc., MG Refining and Marketing, Inc.,
Salmon Resources Ltd. and Shell Canada Limited(8)
</TABLE>
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<PAGE>
<TABLE>
<CAPTION>
Exhibit Number Description of Document
-------------- -----------------------
<S> <C>
10.14 Second Amendment to Long Term Supply Agreement, dated June 28, 1993, among Shell Canada
Limited, Salmon Resources Ltd. and Indian Refining Limited Partnership, Indian Refining &
Marketing Inc. and MG Refining and Marketing, Inc.(8)
10.15 Replacement Gas Purchase Contract, effective February 1, 1992, between ARCO Oil and Gas
Company and Lone Star Gas Company(8)
10.16 Loan Agreement, dated September 30, 1993, among Castle Texas Production Limited Partnership,
Castle Production Company, Castle Energy Corporation and MG Trade Finance Corp., and
Appendix A thereto(9)
10.17 Swap Agreement, dated May 27, 1993, between Indian Refining Limited Partnership and MG
Refining and Marketing, Inc.(8)
10.18 Amendment to Swap Agreement, dated July 29, 1993, between Indian Refining Limited Partnership
and MG Refining and Marketing, Inc.(8)
10.19 Amended and Restated Pipeline Management Agreement, effective as of December 1, 1992, between
Castle Texas Pipeline Limited Partnership and MG Gathering Corp.(8)
10.20 Amended and Restated Service Agreement, effective as of December 1, 1992, between CEC Gas
Marketing Limited Partnership and MG Natural Gas Corp.(8)
10.21 Consent and Agreement, dated May 27, 1993, between Shell Canada Limited and Salmon Resources
Ltd. and Societe Generale, Southwest Agency(8)
10.22 Consent, dated May 27, 1993, between Texaco Pipeline, Inc. and Societe Generale, Southwest
Agency(8)
10.23 Registration Rights Agreement, dated as of December 11,
1991, among Castle Energy Corporation, MG Trade Finance
Corp., Union d'Etudes et d'Investissements and John W.
Sullivan(3)
10.24 Bonus Payment Rights Agreement, dated November 20, 1992, among Indian Refining Limited
Partnership, Indian Refining & Marketing Inc. and William S. Sudhaus(8)
10.25 Bonus Payment Rights Agreement, dated June 21, 1993, among Indian Refining Limited Partnership,
Indian Refining & Marketing Inc. and William S. Sudhaus(8)
10.26 Amended and Restated Employment Agreement, dated December 21, 1992, among Indian Refining
Limited Partnership, Indian Refining & Marketing Inc., Castle Energy Corporation, William S.
Sudhaus and Danik Corporation(8)
10.27 Employment Agreement, dated October 1, 1991, among John D.R. Wright, III, Indian Refining
Management Company and Indian Refining Limited Partnership(3)
10.28 Amendment to Agreement, dated February 25, 1993, between Indian Refining & Marketing Inc.,
Indian Refining Limited Partnership and John D.R. Wright, III(8)
10.29 Bonus Payment Rights Agreement, dated October 1, 1991, among Indian Refining Management
Company, Indian Refining Limited Partnership and John D.R. Wright, III(3)
10.30 Letter Agreement, dated February 25, 1993, between John D.R. Wright, III and Indian Refining &
Marketing Inc.(8)
10.31 Management Agreement, dated July 1, 1993, between Castle Energy Corporation and Terrapin
Resources, Inc.(8)
10.32 Consent Order, dated May 14, 1992, between Indian Refining Company and the Illinois
Environmental Protection Agency(5)
10.33 Castle Energy Corporation 1992 Executive Equity Incentive Plan(8)
10.34 First Amendment to Castle Energy Corporation 1992 Executive Equity Incentive Plan, effective
May 11, 1993(8)
</TABLE>
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<PAGE>
<TABLE>
<CAPTION>
Exhibit Number Description of Document
-------------- -----------------------
<S> <C>
10.35 Loan Agreement, dated August 6, 1993, among Castle Texas Pipeline Limited Partnership, CEC Gas
Marketing Limited Partnership, Castle Pipeline Company, CEC Marketing Company, Castle Energy
Corporation and General Electric Capital Corporation, and exhibits thereto(8)
10.36 Letter Guarantee, dated August 31, 1993, between Metallgesellschaft AG, CEC Gas Marketing
Limited Partnership and General Electric Capital Corporation(8)
10.37 Amended and Restated Gas Purchase Contract, dated as of August 1, 1993, between MG Natural Gas
Corp. and CEC Gas Marketing Limited Partnership(8)
10.38 Offtake Agreement, dated as of October 1, 1993, by and between MG Refining and Marketing, Inc.
and Powerine Oil Company(8)
10.39 Amended and Restated Agreement for the Purchase and Sale of Feedstocks, dated as of October 1,
1993, by and between Metallgesellschaft Corp., Indian Refining Limited Partnership, Powerine Oil
Company and Indian Powerine L.P.(8)
10.40 Agreement for the Purchase and Sale of Feedstocks, dated as of September 15, 1993, among Indian
Powerine L.P., Indian Refining Limited Partnership and Powerine Oil Company(8)
10.41 First Amendment to Loan Agreement, dated as of September 17, 1993, among Indian Refining
Limited Partnership, Indian Refining & Marketing Inc. and MG Trade Finance Corp.(8)
10.42 Second Amended and Restated Offtake Agreement, dated as of October 1, 1993, between MG
Refining and Marketing, Inc. and Indian Refining Limited Partnership(8)
10.43 First Allonge to Subordinated Note, dated as of October 1, 1993, by Indian Refining Limited
Partnership in favor of MG Refining and Marketing, Inc.(8)
10.44 First Allonge to Subordinated Note, dated as of October 1, 1993, by Indian Refining Limited
Partnership in favor of MG Trade Finance Corp.(8)
10.45 Guaranty, dated as of October 1, 1993, by Castle Energy Corporation for the benefit of MG Trade
Finance Corp.(8)
10.46 Purchase Money Security Agreement, dated as of October 1, 1993, between Indian Powerine L.P. and
MG Trade Finance Corp.(8)
10.47 Global Consent, dated as of October 1, 1993, among Societe Generale, Southwest Agency, MG Trade
Finance Corp., Metallgesellschaft Corp., MG Refining and Marketing, Inc. and Indian Refining
Limited Partnership(8)
10.48 Amended and Restated Loan Agreement, dated as of October 1, 1993, between Powerine Oil
Company and MG Trade Finance Corp.(8)
10.49 Second Amendment to Deed of Trust with Assignment of Rents, Leases and Profits, Security
Agreement and Fixture Filing, dated October 1, 1993, by Powerine Oil Company in favor of MG
Trade Finance Corp.(8)
10.50 Amended and Restated Assignment of Agreements, Permits,
Licenses, Warranties and Authorizations, dated as of
October 1, 1993, between Powerine Oil Company and MG
Trade Finance Corp.(8)
10.51 Amended and Restated Secured Promissory Note (Revolving Note), dated as of October 1, 1993, by
Powerine Oil Company in favor of MG Trade Finance Corp.(8)
10.52 Second Amended and Restated Secured Promissory Note (Term Note), dated as of October 1, 1993,
by Powerine Oil Company in favor of MG Trade Finance Corp.(8)
10.53 Amended and Restated Pledge and Security Agreement, dated as of October 1, 1993, by Powerine
Oil Company in favor of MG Trade Finance Corp.(8)
10.54 Amended and Restated Three Party Security Agreement and Collateral Assignment of Hedging
Account, dated as of October 1, 1993, among Powerine Oil Company, MG Futures, Inc. and MG
Trade Finance Corp.(8)
</TABLE>
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<PAGE>
<TABLE>
<CAPTION>
Exhibit Number Description of Document
-------------- -----------------------
<S> <C>
10.55 Guaranty, dated as of October 1, 1993, by Castle Energy Corporation for the benefit of MG Trade
Finance Corp.(8)
10.56 Three Party Security Agreement and Collateral Assignment of Hedging Account, dated October 1,
1993, among Indian Powerine L.P., MG Futures, Inc. and Powerine Oil Company(8)
10.57 Subordinated Offtake Note, dated as of October 1, 1993, by Powerine Oil Company in favor of MG
Refining and Marketing, Inc.(8)
10.58 Security Agreement, dated as of October 1, 1993, by Powerine Oil Company in favor of MG Refining
and Marketing, Inc.(8)
10.59 Deed of Trust with Assignment of Rents, Leases and Profits, Security Agreement and Fixture Filing,
dated as of October 1, 1993, by Powerine Oil Company for the benefit of MG Refining and
Marketing, Inc.(8)
10.60 Letter agreement (re Natural Gas Swap), dated September 30, 1993, between Metallgesellschaft Corp.
and Castle Texas Production Limited Partnership(8)
10.61 Letter agreement (re Gas Purchase Contract), dated September 30, 1993, between Castle Texas
Production Limited Partnership and MG Natural Gas Corp.(8)
10.62 Crude Oil Forward Sale Contract, dated September 28, 1993, between Indian Powerine L.P. and
Percolin Limited(8)
10.63 Confirmation of Crude Oil Forward Sale, dated September 29, 1993, between Indian Powerine L.P.
and Percolin Limited(8)
10.64 Side Letter Agreement, dated September 28, 1993, between Indian Powerine L.P. and Percolin
Limited(8)
10.65 Crude Oil Forward Sale Contract, dated September 28, 1993, between Indian Powerine L.P. and MG
Refining and Marketing, Inc.(8)
10.66 Confirmation of Crude Oil Forward Sale, dated September 29, 1993, between Indian Powerine L.P.
and MG Refining and Marketing, Inc.(8)
10.67 Pledge and Security Agreement, dated October 1, 1993, by Indian Powerine L.P. in favor of
Powerine Oil Company(8)
10.68 Employment Agreement, dated as of January 1, 1994, by and between Castle Energy Corporation and
Joseph L. Castle II(11)
10.69 Employment Agreement, dated as of January 1, 1994, by and among Castle Energy Corporation,
Indian Refining & Marketing Inc., Powerine Oil Company, Indian Refining Limited Partnership and
William S. Sudhaus(11)
10.70 Letter Agreement, dated February 12, 1992, by and between Indian Refining and Marketing Inc. and
David Hermes(15)
10.71 Bonus Payments Rights Agreement, dated February 12, 1992, by and among Indian Refining and
Marketing Inc., Indian Refining Limited Partnership and David Hermes(15)
10.72 Letter Agreement, dated March 1, 1993, between Indian Refining and Marketing Inc. and David
Hermes(15)
10.73 Letter Agreement, dated March 2, 1994, between Indian Refining and Marketing Inc. and David
Hermes(15)
10.74 Letter Agreement, dated May 9, 1994, among Powerine Oil Company, Indian Refining & Marketing
Inc., IP Oil Co., Inc., Castle Energy Corporation and David Hermes(15)
10.75 Employment Agreement, dated April 1, 1994, by and between Powerine Oil Company and Albert L.
Gualtieri, Jr.(15)
</TABLE>
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<PAGE>
<TABLE>
<CAPTION>
Exhibit Number Description of Document
-------------- -----------------------
<S> <C>
10.76 Stock Purchase Agreement, dated August 31, 1994, among MG Trade Finance Corp.,
Metallgesellschaft Corp., Indian Powerine L.P. and Castle Energy Corporation (12)
10.77 Settlement Agreement, dated August 31, 1994, among Metallgesellschaft AG, Metallgesellschaft
Capital Corp., Metallgesellschaft Corp., MG Refining and Marketing, Inc., MG Trade Finance Corp.,
MG Natural Gas Corp., MG Gathering Corp., and MG Futures Inc. and Castle Energy Corporation,
Indian Refining Limited Partnership, IP Oil Co., Inc., Powerine Oil Company, Indian Powerine L.P.,
Indian Refining & Marketing Inc., Castle Texas Production Limited Partnership, Castle Texas
Pipeline Limited Partnership, CEC Gas Marketing Limited Partnership, Castle Production Co., Castle
Pipeline Company, CEC Marketing Company and CEC, Inc.(12)
10.78 Amendment to the Amended and Restated Offtake Agreement, dated October 14, 1994, between MG
Refining and Marketing, Inc. and Indian Refining Limited Partnership(15)
10.79 Amendment to the Offtake Agreement, dated October 14, 1994, between MG Trade Finance Corp.
and Powerine Oil Company(15)
10.80 First Amendment to the Amended and Restated Loan Agreement, dated October 14, 1994, between
Powerine Oil Company and MG Trade Finance Corp.(15)
10.81 Third Amendment to the Amended and Restated Revolving Loan and Security Agreement, dated
October 14, 1994, among Indian Refining Limited Partnership, Indian Refining & Marketing Inc. and
MG Trade Finance Corp.(15)
10.82 Crude Oil Forward Sale Contract, dated October 14, 1994, between Percolin Limited and MG
Refining and Marketing, Inc.(13)
10.83 Crude Oil Sale Contract, dated October 14, 1994, between Indian Powerine L.P. and MG Refining
and Marketing, Inc.(13)
10.84 Natural Gas Swap Agreement, dated October 14, 1994, between MG Natural Gas Corp. and Indian
Refining Limited Partnership(13)
10.85 Participation Cancellation Agreement, dated October 14, 1994, among Indian Powerine L.P., MG
Refining and Marketing, Inc., MG Trade Finance Corp. and Metallgesellschaft Corp.(13)
10.86 Pledge Agreement (Partnership Interests), dated October 14, 1994, between Castle Energy
Corporation and MG Trade Finance Corp.(13)
10.87 Pledge Agreement (Capital Stock), dated October 14, 1994, among Castle Energy Corporation,
Powerine Holding Company and MG Trade Finance Corp.(13)
10.88 Stock Option Agreement, dated October 14, 1994, among Castle Energy Corporation, Powerine
Holding Company and Powerine Oil Company(13)
10.89 Assignment Agreement, dated October 14, 1994, among Powerine Holding Company, Powerine Oil
Company, Castle Energy Corporation and Wilmington Trust Company(13)
10.90 Stock Option Agreement, dated October 14, 1994, between Castle Energy Corporation and Indian
Refining & Marketing Inc.(13)
10.91 Assignment Agreement, dated October 14, 1994, among Castle Energy Corporation, Indian Refining
& Marketing Inc. and Wilmington Trust Company(13)
10.92 Stock and Asset Purchase Agreement among SIPAC Inc. and Castle Energy Corporation, Indian
Refining & Marketing Inc., Indian Refining Limited Partnership, IP Oil Co., and Indian Powerine
L.P., dated December 6, 1994(14)
10.93 Petroleum Coke Purchase and Sales Agreement between Powerine Oil Company and MGPC Petcoke,
Inc., dated as of January 1, 1994(15)
10.94 August 30, 1994 Letter Agreement between Castle Energy Corporation and ARCO regarding the
Purchase of the Oak Hill Production Payment(16)
</TABLE>
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<PAGE>
<TABLE>
<CAPTION>
Exhibit Number Description of Document
-------------- -----------------------
<S> <C>
10.95 Letter Agreement, dated February 21, 1995, between William S. Sudhaus and Castle Energy
Corporation(17)
10.96 Letter Agreement, dated February 24, 1995, between William S. Sudhaus and Castle Energy
Corporation(17)
10.97 Powerine Petroleum Sale and Storage Agreement, dated April 8, 1995, between Wickland Oil
Company and Powerine Oil Company(17)
10.98 The Castle Agreement, dated April 8, 1995, among Wickland Oil Company, Castle Energy
Corporation, and Indian Powerine L.P.(17)
10.99 Security Agreement, dated April 8, 1995, between Powerine Oil Company and Wickland Oil
Company(17)
10.100 Supplemental Letter Agreement, dated April 13, 1995, between Powerine Oil Company and Wickland
Oil Company amending the Powerine Petroleum Sale and Storage Agreement(17)
10.101 Payoff Loan and Pledge Agreement, dated April 13, 1995, among Powerine Oil Company, CEC, Inc.,
Castle Energy Corporation, Metallgesellschaft Corp., MG Refining & Marketing, Inc., and MG Trade
Finance Corp.(17)
10.102 Promissory Note, dated April 13, 1995, by CEC, Inc. in favor of Metallgesellschaft Corp., in the
principal amount of $10,000,000(17)
10.103 Letter Agreement, dated May 10, 1995, between John D. R. Wright and Castle Energy
Corporation(17)
10.104 Letter Agreement, dated May 10, 1995, between William S. Sudhaus and Castle Energy Corporation
(17)
10.105 Payoff Agreement, dated May 25, 1995, between Indian Refining Limited Partnership, Indian
Refining & Marketing, Inc., Castle Energy Corporation, Indian Powerine L.P., Metallgesellschaft
Corp., MG Refining and Marketing, Inc., and MG Trade Finance Corp.(17)
10.106 Supplemental Letter Agreement, dated June 1, 1995, between Powerine Oil Company, Castle Energy
Corporation, Indian Powerine L.P., CEC, Inc. and Wickland Oil Company to the Powerine Petroleum
Sale and Storage Agreement(17)
10.107 Supplemental Letter Agreement, dated June 30, 1995, between Powerine Oil Company, Castle Energy
Corporation, Indian Powerine L.P., CEC, Inc. and Wickland Oil Company to the Powerine Petroleum
Sale and Storage Agreement(17)
10.108 Line of Credit Agreement, dated May 25, 1995, between
Indian Oil Company, BT Commercial Corporation,
MeesPierson N.V., and Bankers Trust Company(17)
10.109 Borrower Security Agreement, dated May 25, 1995, by Indian Oil Company in favor of BT
Commercial Corporation(17)
10.110 Guaranty Agreement, dated May 25, 1995, made by Castle Energy Corporation, Castle Production
Resource Company, and Castle Production Company in favor of BT Commercial Corporation(17)
10.111 Stock and Asset Purchase Agreement, dated November 21, 1995, among Castle Energy Corporation,
Indian Refining I, Limited Partnership, Indian Refining and Marketing I, Inc. and AM West G.P., Inc.(18)
10.112 Agreement and Plan of Merger by and among Energy Merchant Corp., POC Acquisition Corporation,
Powerine Holding Corp., Castle Energy Corporation and Powerine Oil Company, dated January 10,
1996.(18)
10.113 Letter Agreement, dated January 3, 1996, among Castle Energy Corporation, Indian Refining and
Marketing I, Inc., Powerine Oil Company, Indian Refining I., L.P. and William S. Sudhaus regarding
Mr. Sudhaus' resignation.(18)
</TABLE>
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<PAGE>
<TABLE>
<CAPTION>
Exhibit Number Description of Document
-------------- -----------------------
<S> <C>
10.114 Letter Agreement, dated January 22, 1996, among Castle Energy Corporation, Powerine Oil
Company, Indian Refining and Marketing I, Inc., IP Oil Company and David M. Hermes regarding
Mr. Hermes' resignation.(18)
10.115 Letter Agreement, dated January 29, 1996, between Indian Refining and Marketing Company, Indian
Refining & Marketing Inc., Indian Refining Limited Partnership and John D. R. Wright III regarding
Mr. Wright's termination.(18)
10.116 Amendment No. 1 to Stock and Asset Purchase Agreement Dated as of November 21, 1995.(18)
11.1 Statement re: Computation of Earnings Per Share(18)
21 List of subsidiaries of Registrant(18)
23.1 Consent of Price Waterhouse LLP(18)
23.2 Consent of Ryder Scott Company(18)
23.3 Consent of Huntley & Huntley(18)
27 Financial Data Schedule(18)
</TABLE>
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<PAGE>
(b) Reports on Form 8-K
The Company filed the following reports on Form 8-K during the last
quarter of the Company's fiscal year ended September 30, 1995
<TABLE>
<CAPTION>
Date Item
---- ----
<S> <C> <C>
(i) September 30, 1995 Item 2. Acquisition or Disposition of Assets
Item 7 Financial Statements, Pro Forma Financial Information and Exhibits
- ----------
** The confidential portion of this document has been omitted and filed with the Securities and Exchange Commission
(1) Incorporated by reference to the Registrant's Form 10-K for the fiscal year ended September 30, 1990
(2) Incorporated by reference to the Registrant's Form 10-Q for the fiscal third quarter ended June 30, 1991
(3) Incorporated by reference to the Registrant's Form 10-K for the fiscal year ended September 30, 1991
(4) Incorporated by reference to the Registrant's Form 10-Q for the second quarter ended December 31, 1991
(5) Incorporated by reference to the Registrant's Form 10-K for the fiscal year ended September 30, 1992
(6) Incorporated by reference to the Registrant's Form 8-K, dated December 3, 1992
(7) Incorporated by reference to the Registrant's Form 10-Q for the second quarter ended March 31, 1993
(8) Incorporated by reference to the Registrant's Form S-1 (Registration Statement), dated September 29, 1993
(9) Incorporated by reference to the Registrant's Form 10-K for the fiscal year ended September 30, 1993
(10) Incorporated by reference to the Registrant's Form 10-Q for the second quarter ended March 31, 1994
(11) Incorporated by reference to the Registrant's Form 10-Q/A for the third quarter ended June 30, 1994
(12) Incorporated by reference to the Registrant's Form 8-K, dated August 31, 1994.
(13) Incorporated by reference to the Registrant's Form 8-K, dated November 3, 1994.
(14) Incorporated by reference to the Registrant's Form 8-K, dated December 9, 1994.
(15) Incorporated by reference to the Registrant's Form 10-K for the fiscal year ended September 30, 1994.
(16) Incorporated by reference to the Registrant's Form 10-Q for the first quarter ended December 31, 1994.
(17) Incorporated by reference to the Registrant's Form 10-Q for the third quarter ended June 30, 1995.
(18) Incorporated by reference to the Registrant's Form 10-K for the fiscal year ended September 30, 1995.
</TABLE>
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<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.
CASTLE ENERGY CORPORATION
Date: March 19, 1996 By: /s/ Joseph L. Castle
- ----------------------------- -------------------------------
Joseph L. Castle II
Chairman of the Board
and Chief Executive Officer
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<PAGE>
DIRECTORS AND OFFICERS
BOARD OF DIRECTORS
(February 29, 1996)
JOSEPH L. CASTLE II WILLIAM S. SUDHAUS
Director Director
Chairman & Chief Executive Officer President of TALON Resources
MARTIN R. HOFFMANN SIDNEY F. WENTZ
Director Director
Of Counsel to Washington, D.C. Chairman of The Robert Wood Johnson
office of Skadden, Arps, Slate, Foundation
Meagher & Flom
OPERATING OFFICERS
JOSEPH L. CASTLE II RICHARD E. STAEDTLER
Chairman & Chief Executive Officer Chief Financial Officer
STEVEN J. GRENFELL
Treasurer and Controller
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<PAGE>
PRINCIPAL OFFICES
Headquarters Drilling And Operating
Castle Energy Corporation Castle Exploration Company, Inc.
One Radnor Corporate Center 1815 Washington Road
Suite 250 Pittsburgh, PA 15241-1423
100 Matsonford Road
Radnor, PA 19087
Exploration And Production Natural Gas Transmission and Marketing
Castle Texas Production Limited
Partnership Castle Texas Pipeline Limited Partnership
2410 State Highway, 322 North 2410 State Highway, 322 North
Henderson, Texas 75652 Henderson, Texas 75652
CEC Gas Marketing Limited Partnership
2410 State Highway, 322 North
Henderson, Texas 75652
AGENTS
Counsel Independent Reservoir Engineers
Duane, Morris & Heckscher Huntley & Huntley, Inc.
1 Liberty Place, 42 Floor 340 Mansfield Avenue
Philadelphia, PA 19103-7396 Pittsburgh, PA 15220
Independent Accountants Ryder Scott and Company
600 Seventeenth Street, Suite 900N
Price Waterhouse LLP Denver, Colorado 80202
Thirty South Seventeenth Street
Philadelphia, PA 19103
Registrant and Transfer Agent
American Stock Transfer
40 Wall Street, 46th Floor
New York, New York 10005
-90-
